ER26-3552-000 · 2026-08-18 · Midcontinent Independent System Operator, Inc.

Tab A - Marked Tariff Sheets.pdf

Tab A – Marked Tariff Sheets

MISO
1.F
FERC Electric Tariff
Definitions - F
MODULES
65.0.0, 66.0.0
Effective On: October 18, 2026
Facility:  An electric generating unit or an electric generating station composed of one or more 
contiguous electric generating units aggregated at a single geographical site. 
Facilities Study:  An engineering study conducted by the Transmission Provider or ITC in 
collaboration with the affected Transmission Owner(s) and ITC Participant(s) to 
determine the required modifications to the Transmission System, including the cost and 
scheduled completion date for such modifications, that will be required to provide the 
requested Transmission Service.  The Transmission Provider shall have the final 
determination and ultimate responsibility for any such studies.  Facilities Studies for any 
transmission facilities not under the operational control of the Transmission Provider 
shall be performed by the Transmission Owner, or ITC, or any entity it designates to 
perform the studies.  
Fast Ramping Resource:  A Generation Resource that:  (1) meets the qualification criteria of 
having a: (i) ramp rate greater than eighty (80) MW per minute; (ii) Fast Ramping 
Resource Performance Score that meets or exceeds the Fast Ramping Resource 
Performance Threshold when responding to regulation signals in Fast Ramping Resource 
Performance Tests; and (iii) duration greater than 20 minutes or more for Use Limited 
Resources; and (2) as such, will receive a fast changing regulation signal for a market 
interval for which it has been offered.
Fast Ramping Resource Historical Performance Score:  A performance score calculated on a 
Regulation Qualified Resource as the ratio of its Fast Ramping Resource Passed Intervals 
to its Fast Ramping Resource Valid Intervals in the Dispatch Intervals in all previous 
Hours when it was offered as a Fast Ramping Resource.

MISO
1.F
FERC Electric Tariff
Definitions - F
MODULES
65.0.0, 66.0.0
Effective On: October 18, 2026
Fast Ramping Resource Passed Interval:  An AGC signal interval, within a Fast Ramping 
Resource Performance Test, that is considered passed by a Resource offered as a Fast 
Ramping Resource for a particular Hour, during Regulating Reserve Deployment for the 
AGC signal interval if the MW response of the Resource for the Setpoint Instruction, 
adjusted for the communication delay, is within the tolerance range (i.e., +/- 0.25 MW if 
the delta change is 0.8 MW or less, and +/- 30 percent if the delta change is greater than 
0.8 MW).
Fast Ramping Resource Performance Score:  A score calculated during a Fast Ramping 
Resource Performance Test.
Fast Ramping Resource Performance Test:  A test performed in real time to evaluate the 
capability of a Regulation Qualified Resource that is offered as a Fast Ramping Resource 
to perform reliably as a Fast Ramping Resource while deploying Regulating Reserve.  
The test will be performed on such a Regulation Qualified Resource that is receiving 
either fast or regular regulation signals.  At the start of each hourly interval, the Resource 
will be assigned an initial score that is the higher of the Fast Ramping Resource 
Historical Performance Score or the Fast Ramping Resource Performance Threshold.  
Within each hourly interval, at the end of each Dispatch Interval, a new adjustment to the 
initial score will be calculated as the ratio of Fast Ramping Resource Passed Intervals to 
Fast Ramping Resource Valid Intervals in the current and all previous Dispatch Intervals 
in the particular hourly interval. 
Fast Ramping Resource Performance Threshold:  A minimum Fast Ramping Resource 
Performance Score of seventy percent (70%) that a Resource is required to meet to be

MISO
1.F
FERC Electric Tariff
Definitions - F
MODULES
65.0.0, 66.0.0
Effective On: October 18, 2026
qualified as a Fast Ramping Resource.
Fast Ramping Resource Valid Interval:  An AGC signal interval is considered valid for a 
Resource undergoing a Fast Ramping Resource Performance Test, during its Regulating 
Reserve Deployment for an AGC signal interval, during which a new Setpoint Instruction 
is calculated that changes by a threshold MW of at least 0.1 MW from the previous 
Setpoint Instruction.
Fast Start Resource: An online Generation Resource that is started, synchronized and injects 
Energy, or a Demand Response Resource that reduces its Energy consumption, within 
sixty (60) minutes of being notified and that has a minimum run time of one hour or less 
and that will participate in setting price as described in the process in Schedule 29A of 
this Tariff.  A Fast Start Resource does not include fuel-limited resources such as pumped 
storage, Electric Storage Resources, run-of-river hydro, and wind resources.  Offline 
Generation Resources will not participate in setting price as described in the process in 
Schedule 29A of this Tariff. 
Fast Start Resource All-In Energy Offer:  The sum of an online Fast Start Resource’s Energy 
Offer, its amortized No Load Offer and, during its Minimum Run Time, its amortized 
Start up Offer; provided, that, in the case of a Demand Response Resource – Type I, it 
shall be the sum of the Energy Offer, its amortized Hourly Curtailment Offer and its 
amortized Shut-Down Offer over its minimum interruption duration.
Fast Start Resource All-In Reference Level:  The sum of an online Fast Start Resource’s 
Energy Reference Level, its amortized No Load Reference Level and, during its 
Minimum Run Time, its amortized Start up Reference Level; provided, that, in the case

MISO
1.F
FERC Electric Tariff
Definitions - F
MODULES
65.0.0, 66.0.0
Effective On: October 18, 2026
of a Demand Response Resource – Type I, it shall be the sum of the Energy Reference 
Level, its amortized Hourly Curtailment Offer Reference Level and its amortized Shut-
Down Offer Reference Level over its minimum interruption duration.
Feasibility Upgrade Process:  The procedure that enables additional ARRs to be allocated based 
upon Network Upgrades as part of the MTEP process.
Federal Energy Regulatory Commission (FERC) Uniform System of Accounts:  The 
Commission’s Uniform System of Accounts in the Code of Federal Regulations, Title 18, 
Conservation of Power and Water Resources, Parts 1-399, pursuant to which electric 
public utilities, licensees and other companies within FERC jurisdiction are required to 
maintain their books and records.
Federal Power Marketing Agency:  Any agency or instrumentality of the United States (other 
than the Tennessee Valley Authority), which sells electric Energy.
FERC Market Rules:  The market behavior rules and the prohibition against electricity Energy 
market manipulation codified by the Commission in its Rules and Regulations at 18 CFR 
§ 1c.2 and 35.37, respectively; and any related proscriptions or any successor rules that 
the Commission from time to time may issue, approve or otherwise establish.
File Transfer Protocol (FTP):  The standardized File Transfer Protocol for data transfer.
Final Planning Reserve Margin Requirement (Final PRMR):  For LSEs not selecting the 
Reliability Based Demand Curve Opt Out, the PRMR established as a result of the PRA 
clearing using RBDCs.  For LSEs selecting the RBDC Opt Out, Final PRMR is based on 
the sum of the applicable PRM plus the applicable RBDC Opt Out Adder.  LSEs under 
state jurisdiction where the state has overridden the PRM established by the Transmission

MISO
1.F
FERC Electric Tariff
Definitions - F
MODULES
65.0.0, 66.0.0
Effective On: October 18, 2026
Provider will have a Final PRMR based on the planning reserve margin established by 
the state.
Financial Schedule:  A financial arrangement between two Market Participants designating a 
Source Point, Sink Point and Delivery Point establishing the obligations of the buyer and 
seller for the payment of Cost of Congestion and Cost of Losses.  The Transmission 
Provider is not the Energy Market Counterparty to the sale of Energy under a Financial 
Schedule transaction and collects and disburses the Transmission Usage Charge as agent 
for the parties to the Financial Schedule.
Financial Security:  A Cash Deposit or Irrevocable Letter of Credit in an amount and form 
determined by and acceptable to Transmission Provider, provided by an Applicant and/or 
Tariff Customer to Transmission Provider as security.  
Financial Transmission Right (FTR):  A financial instrument that entitles the holder to receive 
compensation for or requires the holder to pay certain congestion related transmission 
charges that arise when the Transmission System is congested and differences in 
Marginal Congestion Components of Day-Ahead Ex Post LMPs result.
Firm Flow:  The estimated impacts of firm transactions under network and point-to-point 
Transmission Service on a particular Coordinated Flowgate.
Firm Point-To-Point Transmission Service:  Transmission Service under this Tariff that is 
reserved and/or scheduled between specified Points of Receipt and Points of Delivery 
pursuant to Module B of this Tariff. 
Firm Service Level:  The MW portion of the total demand of a Demand Resource that is not 
subject to curtailment as a Demand Resource.

MISO
1.F
FERC Electric Tariff
Definitions - F
MODULES
65.0.0, 66.0.0
Effective On: October 18, 2026
First Planning Area:  The Transmission System of the Transmission Provider Region as it 
existed immediately before the effective date of the Second Planning Area.  The First 
Planning Area may be modified from time to time by:  (1) the addition of any 
transmission facilities in the Midwest portion of the United States (i.e., Illinois, Indiana, 
Iowa, Kentucky, Michigan, Minnesota, Missouri, Montana, North Dakota, Ohio, South 
Dakota, and Wisconsin) where transmission facilities not under the functional control of 
the Transmission Provider are subsequently conveyed to the functional control of the 
Transmission Provider to be used to provide Transmission Service under Module B of the 
Tariff; or (2) the withdrawal from the Transmission Provider Region of a Member 
located in the First Planning Area.
Fixed Carrying Charge:  An annual charge calculated by taking the cost of service carrying 
charge elements expressed as a percent multiplied by the Transmission Owner or ITC’s 
rate base.  The carrying charge elements include: operations and maintenance, 
depreciation expense, other taxes, return, and income taxes. 
Fixed Demand Bid:  A request to purchase a specified MWh quantity of Energy, at specified 
locations in the Transmission Provider Region, during specific Hours of the next 
Operating Day submitted to the Day-Ahead Energy and Operating Reserve Market.  
Demand Bids may only be submitted by a Market Participant that is itself a Load Serving 
Entity (LSE) or is purchasing Energy to serve an LSE.
Fixed Interchange Schedule:  An Interchange Schedule consisting of a fixed, non-Dispatchable 
amount, used in the Energy and Operating Reserve Markets.
Fixed Resource Adequacy Plan (FRAP):  A plan submitted by an LSE through the MECT to

MISO
1.F
FERC Electric Tariff
Definitions - F
MODULES
65.0.0, 66.0.0
Effective On: October 18, 2026
the Transmission Provider that is approved by the Transmission Provider which 
demonstrates that the LSE has sufficient ZRCs to meet all or part of its Initial PRMR for 
one or more LRZs in a Season.
Flowgate:  A representative modeling of a facility or group of facilities that may act as a 
constraint to power transfer on the Bulk Electric System.
Flowgate Rating:  The Total Transfer Capability of a Flowgate.
Forced Outage or Generator Forced Outage:  An immediate reduction in output, Capacity or 
removal from service, in whole or in part, of a Generation Resource by reason of an 
Emergency or threatened Emergency, unanticipated failure, inability to return on 
schedule from a Planned Transmission Outage, or other cause beyond the control of the 
owner or operator of the facility, as specified in the relevant portions of the BPM for 
Outage Operations.  A reduction in output or removal from service of a Generation 
Resource in response to changes in Energy Market conditions does not constitute a 
Generator Forced Outage.
Forecast LSE Requirement:  The forecasted Demand including the effect of all losses for an 
LSE at a CPNode for a Month less the Full Responsibility Purchases plus the Full 
Responsibility Sales and minus the Demand Resources that were registered to net for a 
given Month all at the same CPNode.
Forecast Maximum Limit:  For a Dispatchable Intermittent Resource, The the maximum MW 
level at which a Dispatchable Intermittentthe Resource is forecasted to operate.  In 
addition, for a ZG Resource participating as a DIR, the maximum MW level at which a 
Resource may operate shall be less than the Demand of the Resource’s ZG Associated

MISO
1.F
FERC Electric Tariff
Definitions - F
MODULES
65.0.0, 66.0.0
Effective On: October 18, 2026
Loads.  
Foreign Guarantor:  A Guarantor that is organized under the laws of a jurisdiction outside of 
the United States or Canada.
Foreign Guaranty:  A Corporate Guaranty accepted from a Guarantor that is organized under 
the laws of a jurisdiction outside of the United States or Canada.
Forward Reliability Assessment Commitment (FRAC):  A RAC process conducted up to seven 
(7) days prior to, and before the closing of, the Day-Ahead Energy and Operating 
Reserve Market.
FTR and ARR Transactions Cleared But Not Yet Settled:  This service category is a component 
of the FTR Potential Exposure.  The FTR and ARR Transactions Cleared But Not Yet 
Settled are calculated on a monthly basis.  If the net monthly value is positive, it is 
included in the FTR Potential Exposure calculation.  If the net monthly value is negative, 
the value is not included in the FTR Potential Exposure calculation. 
FTR Auction:  An auction conducted periodically through which the Transmission Provider, 
subject to the Simultaneous Feasibility Test:  (i) awards FTRs of various durations and 
(ii) facilitates the selling of existing FTRs between Market Participants.
FTR Auction Credit Allocation:  
The amount of the Applicant’s and/or Tariff Customer’s 
Total Credit Limit allocated to FTR Auctions.
FTR Auction Credit Exposure:  Exposure to non-payment associated with the amount of the 
Applicant’s and/or Tariff Customer’s FTR Bids and Offers submitted in the auction. 
FTR Auction Participant:  A Market Participant that participates in an FTR Auction 
administered by the Transmission Provider.

MISO
1.F
FERC Electric Tariff
Definitions - F
MODULES
65.0.0, 66.0.0
Effective On: October 18, 2026
FTR Auction Settled Transactions Exposure:  The potential exposure to non-payment 
associated with FTR Auction transactions that have been cleared and settled.
FTR Bid:  A bid to purchase an FTR through an FTR Auction.
FTR Bidder:  A Market Participant submitting an FTR Bid.
FTR Delivery Point:  The transaction Delivery Point specified in a receipt point to delivery point 
FTR.
FTR Holder:  A Market Participant that owns one (1) or more FTRs.
FTR MCP:  The price at which a set of Comparable FTRs are sold through an FTR Auction.
FTR Obligation:  A receipt point to delivery point FTR that imposes a financial obligation on 
the FTR Holder if congestion exists in the direction from the FTR Delivery Point to the 
FTR Receipt Point. 
FTR Offer:  An offer to sell an FTR through an FTR Auction.
FTR Offeror:  A Market Participant submitting an FTR Offer.
FTR Option:  A receipt point to delivery point FTR that imposes no financial obligations on the 
FTR Holder under any conditions.
FTR Period:  The period(s) of time on a given Day during which an FTR is in effect (On Peak, 
Off Peak, or full Day time period(s)).
FTR Potential Exposure:  The sum of exposure values as defined in Section V.B of Attachment 
L to this Tariff.  Included are all FTR related charge types.
FTR Potential Exposure Violation:  A condition that exists whenever a Tariff Customer’s FTR 
Potential Exposure plus the larger of the FTR Auction Credit Allocation or FTR Auction 
Credit Exposure exceeds its Financial Security less its alternative capitalization

MISO
1.F
FERC Electric Tariff
Definitions - F
MODULES
65.0.0, 66.0.0
Effective On: October 18, 2026
requirement as further defined in Section V.C of Attachment L to this Tariff.
FTR Quantity:  The quantity in MW specified in an FTR.
FTR Receipt Point:  The transaction receipt point specified in an FTR.
FTR Transactions Cleared But Not Yet Settled:  The value of the FTRs based on the clearing 
price(s) established as a result of an FTR Auction which has been cleared, but has not yet 
been settled.
Fuel Cost Uncertainty Adder:  An amount determined by the Independent Market Monitor, not 
to exceed $100 per MWh, that is included in the Reference Level determination to 
account for fuel cost uncertainty when the resulting Reference Level exceeds $1,000 per 
MWh.
Full Responsibility Purchases:  The total of all purchases coincident with the expected Demand 
of the LSE under which the seller is contractually obligated to deliver Energy plus 
reserves to the purchaser, expressed in MWs for the hour. Reserve provision by the seller 
as a percent must meet or exceed the PRM obligation for the purchasing LSE.  Up Ramp 
Capability and Down Ramp Capability by the seller as a percent must meet or exceed the 
PRM obligation for the purchasing LSE.  Short-Term Reserve provision by the seller as a 
percent must meet or exceed the PRM obligation for the purchasing LSE.  Each 
purchaser and seller must agree on which of their transactions are to be reported under 
this heading.
Full Responsibility Sales:  The total of all sales coincident with the expected Demand of the 
LSE under which the seller is contractually obligated to deliver Energy plus reserves to 
the purchaser, expressed in MWs for the hour. Reserve provision by the seller as a

MISO
1.F
FERC Electric Tariff
Definitions - F
MODULES
65.0.0, 66.0.0
Effective On: October 18, 2026
percent must meet or exceed the PRM obligation for the purchasing LSE.  Up Ramp 
Capability and Down Ramp Capability by the seller as a percent must meet or exceed the 
PRM obligation for the purchasing LSE.  Short-Term Reserve provision by the seller as a 
percent must meet or exceed the PRM obligation for the purchasing LSE.  Each 
purchaser and seller must agree on which of their transactions are to be reported.

MISO 
1.H
FERC Electric Tariff 
Definitions - H
MODULES 
62.0.0, 63.0.0
Effective On: October 18, 2026
Headroom:  For all Resources committed by the Transmission Provider in any real-time RAC 
processes or the LAC process conducted for the Operating Day, the difference between 
(i) the real-time Economic Maximum Dispatch and (ii) the sum of the Real-Time (a) 
Dispatch Target for Energy, (b) Dispatch Target for Regulating Reserve, (c) Dispatch 
Target for Spinning Reserve, (d) Dispatch Target for Supplemental Reserve, and (e) 
Dispatch Target for Short-Term Reserve. 
High Utilization Factor Unit (HUFU) Reserved Source Point (RSP):  An RSP that does not 
qualify for inclusion in the BRSS per section 43.2.4.a.i.(b) but has a RSP Utilization 
Factor of seventy percent (70%) or greater. 
Historic Unit Consideration: A right to receive excess Planning Resource Auction revenue 
based on qualification described in Section 69A.7.7(a). 
Hour:  A sixty (60) minute clock hour interval commencing the first second of each clock hour. 
Hot-to-Cold Time:  The number of hours that must elapse between the time a Generation 
Resource, Demand Response Resource – Type II, or Electric Storage Resource is 
desynchronized and the time at which a cold Start-Up Offer would apply.   
Hot-to-Intermediate Time:  The number of hours that must elapse between the time a 
Generation Resource, Demand Response Resource – Type II, or Electric Storage 
Resource is desynchronized and the time at which an intermediate Start-Up Offer would 
apply.  
Hourly Bi-Directional Ramp Rate:  The MW/minute rate at which a Generation Resource, an 
External Asynchronous Resource, or Demand Response Resource - Type II can respond 
to either increasing or decreasing Setpoint Instructions that may be submitted to override

MISO 
1.H
FERC Electric Tariff 
Definitions - H
MODULES 
62.0.0, 63.0.0
Effective On: October 18, 2026
the default value submitted during the asset registration process. 
Hourly Charge Ramp Rate:  The MW/minute response rate for an Electric Storage Resource 
moving from zero output to its Hourly Economic Minimum Charge Limit and/or from the 
Hourly Economic Minimum Charge Limit to zero output that is utilized in the clearing of 
the Day-Ahead Energy and Operating Reserve Market and all Reliability Assessment 
Commitment processes, and in responding to either increasing or decreasing Setpoint 
Instructions between zero and the Hourly Economic Minimum Charge Limit that may be 
submitted to override the default value submitted during the asset registration process. 
Hourly Curtailment Offer:  The compensation request, in dollars per Hour, in a Demand 
Response Resource-Type I Offer by a Market Participant representing the fees required 
for operating a Demand Response Resource Type I in an interrupted state. 
Hourly Discharge Ramp Rate:  The MW/minute response rate for an Electric Storage Resource 
moving from zero output to its Hourly Economic Maximum Discharge Limit and/or from 
the Hourly Economic Maximum Discharge Limit to zero output that is utilized in the 
clearing of the Day-Ahead Energy and Operating Reserve Market and all Reliability 
Assessment Commitment processes, and in responding to either increasing or decreasing 
Setpoint Instructions between zero and the Hourly Economic Maximum Discharge Limit 
that may be submitted to override the default value submitted during the asset registration 
process. 
Hourly Economic Maximum Limit:  The maximum MW level at which a Generation Resource, 
Demand Response Resource Type II, or External Asynchronous Resource may operate 
under normal system conditions that may be submitted to override the default value

MISO 
1.H
FERC Electric Tariff 
Definitions - H
MODULES 
62.0.0, 63.0.0
Effective On: October 18, 2026
submitted during the asset registration process.  In addition, for a ZG Resource 
participating as a Generation Resource, the maximum MW level at which the Resource 
may operate under normal system conditions shall be less than the Demand of the 
Resource’s ZG Associated Loads. 
Hourly Economic Maximum Charge Limit: The maximum withdrawal MW level at which an 
Electric Storage Resource may operate under normal system conditions that may be 
submitted to override the default value submitted during the asset registration process. 
Hourly Economic Maximum Discharge Limit: The maximum injection MW level at which an 
Electric Storage Resource may operate under normal system conditions that may be 
submitted to override the default value submitted during the asset registration process.  In 
addition, for a ZG Resource participating as an Electric Storage Resource, the maximum 
MW level at which the Resource may operate under normal system conditions shall be 
less than the Demand of the Resource’s ZG Associated Loads. 
Hourly Economic Minimum Limit:  The minimum MW level at which a Generation Resource, 
Demand Response Resource Type II, or External Asynchronous Resource may operate 
under normal system conditions that may be submitted to override the default value 
submitted during the asset registration process.   
Hourly Economic Minimum Charge Limit: The minimum withdrawal MW level at which an 
Electric Storage Resource may operate under normal system conditions that may be 
submitted to override the default value submitted during the asset registration process. 
Hourly Economic Minimum Discharge Limit: The minimum injection MW level at which an 
Electric Storage Resource may operate under normal system conditions that may be

MISO 
1.H
FERC Electric Tariff 
Definitions - H
MODULES 
62.0.0, 63.0.0
Effective On: October 18, 2026
submitted to override the default value submitted during the asset registration process. 
Hourly Electric Storage Resource Efficiency Factor: An operating characteristic of an Electric 
Storage Resource that is the amount of increase in Energy Storage Level for each 1 MWh 
of Charge Energy withdrawn by that Resource and may be submitted to override the 
default value submitted during the asset registration process. 
Hourly Emergency Maximum Limit:  The maximum MW level at which a Generation 
Resource, an External Asynchronous Resource, or Demand Response Resource Type II 
may operate under Emergency conditions that may be submitted to override the default 
value submitted during the asset registration process.  In addition, for a ZG Resource 
participating as a Generation Resource, the maximum MW level at which a Resource 
may operate under Emergency conditions shall be less than the Demand of the 
Resource’s ZG Associated Loads. 
Hourly Emergency Maximum Charge Limit: The maximum withdrawal MW level at which an 
Electric Storage Resource may operate under Emergency system conditions that may be 
submitted to override the default value submitted during the asset registration process. 
Hourly Emergency Maximum Discharge Limit: The maximum injection MW level at which an 
Electric Storage Resource may operate under Emergency system conditions that may be 
submitted to override the default value submitted during the asset registration process.  In 
addition, for a ZG Resource participating as an Electric Storage Resource, the maximum 
MW level at which the Resource may operate under Emergency system conditions shall 
be less than the Demand of the Resource’s ZG Associated Loads. 
Hourly Emergency Minimum Limit:  The minimum MW level at which a Generation Resource,

MISO 
1.H
FERC Electric Tariff 
Definitions - H
MODULES 
62.0.0, 63.0.0
Effective On: October 18, 2026
an External Asynchronous Resource, or Demand Response Resource Type II may operate 
under Emergency conditions that may be submitted to override the default value 
submitted during the asset registration process. 
Hourly Emergency Minimum Charge Limit: The minimum withdrawal MW level at which an 
Electric Storage Resource may operate under Emergency system conditions that may be 
submitted to override the default value submitted during the asset registration process. 
Hourly Emergency Minimum Discharge Limit: The minimum injection MW level at which an 
Electric Storage Resource may operate under Emergency system conditions that may be 
submitted to override the default value submitted during the asset registration process. 
Hourly Ex Post MCP:  The average Regulating Reserve MCP, Regulating Mileage MCP, 
Spinning Reserve MCP, Supplemental Reserve MCP, Up Ramp Capability MCP, Down 
Ramp Capability MCP, and Short-Term Reserve MCP applicable to a specific Resource 
derived through time and quantity weighting of the applicable Ex Post MCPs over the 
Hour, and used for purposes of Settlement of Operating Reserves, Regulating Mileage, 
Up Ramp Capability, Down Ramp Capability, and Short-Term Reserve in the Real-Time 
Energy and Operating Reserve Market. 
Hourly Fast Ramping Resource:  An hourly Offer parameter flag (“Yes/No”) representing 
whether a Resource is offered into the Real-Time Energy and Operating Reserve Market 
as a Fast Ramping Resource. 
Hourly Integrated Forecast Maximum Limit:  The hourly integration of the Forecast Maximum 
Limits of a Dispatchable Intermittent Resource as used by the SCED algorithm in the 
Real-Time Energy and Operating Reserve Market for a given Hour.

MISO 
1.H
FERC Electric Tariff 
Definitions - H
MODULES 
62.0.0, 63.0.0
Effective On: October 18, 2026
Hourly Maximum Energy Storage Level:  The maximum amount of Energy that may be stored 
by an Electric Storage Resource on a sustained basis, expressed in MWh, that may be 
submitted to override the default value submitted during the asset registration process.  
This is equivalent to the hourly maximum State of Charge. 
Hourly Minimum Energy Storage Level: The minimum amount of Energy that may be stored 
by an Electric Storage Resource on a sustained basis, expressed in MWh, that may be 
submitted to override the default value submitted during the asset registration process.  
This is equivalent to the hourly minimum State of Charge. 
Hourly Neutral Zone Lower Limit:  A MWh lower limit representing a percentage of the 
Capacity of a Fast Ramping Resource up to which it is being offered, which will be used 
in the Automatic Generation Control fast ramping regulation signal logic. 
Hourly Neutral Zone Upper Limit:  A MWh upper limit representing a percentage of the 
Capacity of a Fast Ramping Resource up to which it is being offered, which will be used 
in the Automatic Generation Control fast ramping regulation signal logic. 
Hourly Ramp Rate:  The MW/minute response rate for a Generation Resource, External 
Asynchronous Resource, or Demand Response Resource Type-II that is utilized in the 
clearing of the Day-Ahead Energy and Operating Reserve Market and all Reliability 
Assessment Commitment processes that may be submitted to override the default value 
submitted during the asset registration process. 
Hourly Real-Time Ex Post LMP:  The LMP derived through mathematical integration of the 
Dispatch Interval Real-Time Ex Post LMPs over the Hour, and used for purposes of 
Settlement of Energy transactions in the Real-Time Energy and Operating Reserve

MISO 
1.H
FERC Electric Tariff 
Definitions - H
MODULES 
62.0.0, 63.0.0
Effective On: October 18, 2026
Market. 
Hourly Real-Time Ex Post MCP:  The average MCPs for Regulating Reserve, Spinning 
Reserve, Supplemental Reserve, Up Ramp Capability, Down Ramp Capability, and 
Short-Term Reserve applicable to a specific Resource derived through time and quantity 
weighting of the applicable Real-Time Ex Post MCPs over the Hour, and used for 
purposes of Settlement of Operating Reserves, Up Ramp Capability, Down Ramp 
Capability, and Short-Term Reserve in the Real-Time Energy and Operating Reserve 
Market. 
Hourly Regulation Maximum Charge Limit: The maximum withdrawal MW level at which an 
Electric Storage Resource can respond to automatic control signals, that may be 
submitted to override the default value submitted during the asset registration process. 
Hourly Regulation Maximum Discharge Limit: The maximum injection MW level at which an 
Electric Storage Resource can respond to automatic control signals, that may be 
submitted to override the default value submitted during the asset registration process.  In 
addition, for a ZG Resource participating as an Electric Storage Resource, the maximum 
MW level at which the Resource can respond to automatic control signals shall be less 
than the Demand of the Resource’s ZG Associated Loads. 
Hourly Regulation Maximum Limit:  The maximum MW output at which a Generation 
Resource, Demand Response Resource – Type II, or External Asynchronous Resource 
can respond to automatic control signals that may be submitted to override the default 
value submitted during the asset registration process.  In addition, for a ZG Resource 
participating as a Generation Resource, the maximum MW level at which a Resource can

MISO 
1.H
FERC Electric Tariff 
Definitions - H
MODULES 
62.0.0, 63.0.0
Effective On: October 18, 2026
respond to automatic control signals shall be less than the Demand of the Resource’s ZG 
Associated Loads. 
Hourly Regulation Minimum Charge Limit: The minimum withdrawal MW level at which an 
Electric Storage Resource can respond to automatic control signals, that may be 
submitted to override the default value submitted during the asset registration process. 
Hourly Regulation Minimum Discharge Limit: The minimum injection MW level at which an 
Electric Storage Resource can respond to automatic control signals, that may be 
submitted to override the default value submitted during the asset registration process. 
Hourly Regulation Minimum Limit:  The minimum MW output at which a Generation 
Resource, Demand Response Resource–Type II, or External Asynchronous Resource can 
respond to automatic control signals that may be submitted to override the default value 
submitted during the asset registration process. 
Hourly Single-Directional-Down Ramp Rate:  The MW/minute rate at which a Generation 
Resource, an External Asynchronous Resource, or Demand Response Resource-Type II 
can respond to the Setpoint Instructions in the downward direction only that may be 
submitted to override the default value submitted during the asset registration process. 
Hourly Single-Directional-Up Ramp Rate:  The MW/minute rate at which a Generation 
Resource, an External Asynchronous Resource, or Demand Response Resource-Type II 
can respond to the Setpoint Instructions in the upward direction only that may be 
submitted to override the default value submitted during the asset registration process. 
Hourly Transmission Congestion Charges Collection:  The aggregate amount of Transmission 
Usage Charge collected in a given Hour.

MISO 
1.H
FERC Electric Tariff 
Definitions - H
MODULES 
62.0.0, 63.0.0
Effective On: October 18, 2026
Hub:  A Commercial Pricing Node developed for financial and trading purposes.  
HUFU ARR:  An ARR allocated during the LTTR Restoration and Termination Stage of an 
Annual ARR Allocation from a HUFU ARR Entitlement. 
HUFU ARR Entitlement:  An ARR Entitlement defined from a HUFU RSP to the applicable 
ARR Zone.  The MW amount of a HUFU ARR Entitlement is calculated, and 
corresponds to, the RSP MW at a fifty percent (50%) implied capacity factor.  A HUFU 
ARR Entitlement is calculated as follows: 
HUFU MW Level = (total net generation MWh in the test period) / (50% x Total Hours 
in the test period). 
Hub LMP:  The weighted-averaged LMP for an invariant set of Elemental Pricing Nodes that 
comprise the Hub.  The weights are static over time, except for those of Elemental 
Pricing Nodes constituting ARR Zones administered as Hub Commercial Pricing Nodes.  
The weights, or weighting factors, for determining ARR Zone LMPs are updated daily 
based on State Estimator information. 
High-Voltage Direct Current Facilities:  The high voltage direct current transmission facilities, 
including associated alternating current facilities, if any, that are subject to Section 27A 
of this Tariff and that are specifically identified in:  (i) any Agency Agreement pertaining 
to such facilities between the Transmission Provider and the Transmission Owner that 
owns or operates such facilities, or (ii) in any other contractual arrangement that permits 
the Transmission Provider to provide HVDC Service over such facilities, as set forth in 
Section 27A of this Tariff. 
High-Voltage Direct Current Facility Upgrades:  All or portion of the modifications or

MISO 
1.H
FERC Electric Tariff 
Definitions - H
MODULES 
62.0.0, 63.0.0
Effective On: October 18, 2026
additions to any HVDC Facilities for the general benefit of all Users of such HVDC 
Facilities. 
High-Voltage Direct Current Service:  Firm and Non-Firm Point-to-Point Transmission Service 
provided by the Transmission Provider on HVDC Facilities pursuant to Section 27A of 
this Tariff.  
High-Voltage Direct Current Service Agreement:  Any executed or unexecuted agreement for 
HVDC Service, as reflected in Attachment A-3, A-4, and B-1 of this Tariff. 
High-Voltage Direct Current Service Charge(s):  The charge(s) for HVDC Service, as stated in 
the relevant HVDC Service Agreement. 
Hybrid Resource:  A Generator that combines more than one type of Electric Facility for the 
production and/or storage for later injection of electricity that participates as a single 
Generation Resource in the Energy and Operating Reserve Market.

MISO
1.P
FERC Electric Tariff
Definitions - P
MODULES
69.0.0, 70.0.0
Effective On: October 18, 2026
Partial-Year FTR Allocation:  The procedure used by the Transmission Provider to allocate 
FTRs to Market Participants in the new ARR Zones added as a result of Transmission 
Provider Region expansion that becomes effective after the start of the Annual ARR 
Allocation period.  The Partial-Year FTR Allocation will cover the partial year period 
when the new ARR Zone(s) become effective to the start of the next Annual ARR 
Allocation.  For the partial year period, the Market Participants in the new ARR Zone(s) 
may request an allocation of FTRs, which will be in lieu of an allocation of ARRs. 
Party(ies):  The Transmission Provider, ITC where appropriate, Market Participants, 
Transmission Customers, or any combination of the above. 
Past Due Amount:  Any amount invoiced by the Transmission Provider that is not paid when 
due.
Peak Reserved Source Set:  Set of Resources including those constituting the Baseload Reserved 
Source Point that have met the Resource Qualification Requirements for inclusion as a 
Reserved Source Point for a given ARR Zone. 
Peak Usage:  A Market Participant’s Total Forecasted Peak Load in a given ARR Zone for the 
upcoming Annual ARR Allocation period calculated using the immediate prior three year 
actual peak Loads.  The Total Forecast Peak Load is the sum of the forecast Network 
Integration Transmission Service peak Load for the upcoming allocation period plus peak 
Load served by Option A – Grandfathered Agreements plus peak Load served by Option 
B – Grandfathered Agreements.
Penalty Level:  A component of a mitigation measure described in Module D that represents the 
amount of Energy purchased by a Market Participant that is an LSE or represents an LSE

MISO
1.P
FERC Electric Tariff
Definitions - P
MODULES
69.0.0, 70.0.0
Effective On: October 18, 2026
in the Real Time Energy Market in excess of the Allowance Level the entity is subject to. 
Physical Withholding Threshold Quantity:  Threshold employed by the IMM to identify 
physical withholding by a supplier of Planning Resources for the Planning Resource 
Auction, expressed in MW.
Plan:  The Transmission Provider’s Market Monitoring Plan set forth in Module D of this Tariff.
Planned Transmission Outage:  Any transmission outage scheduled for the performance of 
maintenance or repairs or the implementation of a system enhancement which is planned 
in advance for pre-determined duration and which meets the notification requirements for 
such outages as specified by the Transmission Provider.  
Planning Advisory Committee:  A committee of stakeholders established under the ISO 
Agreement for the purpose of providing input to the planning staff on the development of 
the MTEP.  
Planning Area(s):  A collective or alternative reference to the First Planning Area and/or the 
Second Planning Area.
Planning Coordinator:  The entity responsible for the longer term reliability of its planning 
coordinator area.
Planning Reserve Margin (PRM):  The percentage above forecasted Coincident Peak Demand 
of Planning Resources for the Transmission Provider Region in order to meet the LOLE.  
This percentage will include a quantity sufficient to cover transmission losses.
Planning Reserve Margin Requirement (PRMR):  The amount of ZRCs required of each LSE 
with Coincident Peak Demand in an LRZ to meet the LSE’s Resource Adequacy 
Requirements in each Season.

MISO
1.P
FERC Electric Tariff
Definitions - P
MODULES
69.0.0, 70.0.0
Effective On: October 18, 2026
Planning Resource:  A Capacity Resource or Load Modifying Resource that can be used to 
satisfy PRMR.
Planning Resource Auction (PRA):  Auctions conducted by the Transmission Provider to 
determine the ACP and the cleared ZRC Offers for each LRZ and ERZ for each Season 
in the applicable Planning Year.
Planning Year:  The period of time from June 1st of one year to May 31st of the following year 
that is used for developing Resource Plans.  The first Planning Year shall commence on 
June 1, 2009.
PMAX:  The maximum Generator real power output reported in MWs on a seasonal basis.
PMIN:  The minimum Generator real power output reported in MWs on a seasonal basis.
Point(s) of Delivery:  Point(s) on the Transmission System where Capacity and Energy 
transmitted by the Transmission Provider will be made available to the Receiving Party 
under Module B and Module C of this Tariff.  The Point(s) of Delivery shall be specified 
in the Service Agreement for Long Term Firm Point To Point Transmission Service or 
the HVDC Service Agreement.
Point(s) of Receipt:  Point(s) of interconnection on the Transmission System where Capacity and 
Energy will be made available to the Transmission Provider by the Delivering Party 
under Module B and Module C of this Tariff.  The Point(s) of Receipt shall be specified 
in the Service Agreement for Long Term Firm Point To Point Transmission Service or 
the HVDC Service Agreement.
Point(s) of Withdrawal:  The point(s) where a non-transmission facility that is used to withdraw 
Energy from the Transmission System to serve Load connects to the Transmission

MISO
1.P
FERC Electric Tariff
Definitions - P
MODULES
69.0.0, 70.0.0
Effective On: October 18, 2026
System.
Point-To-Point Transmission Service:  The reservation of Capacity and of Energy on either a 
firm or non firm basis from the Point(s) of Receipt to the Point(s) of Delivery under 
Module B of this Tariff. 
Portfolio:  For Multi-Value Project purposes, means two or more Multi-Value Projects proposed 
to be located in one or more Transmission Pricing Zones that, when evaluated together, 
are expected to result in system-wide benefits across the MISO footprint or benefits 
across the subregion. For purposes of the Portfolio, subregion refers to either the MISO 
Midwest MVP Cost Allocation Subregion or MISO South MVP Cost Allocation 
Subregion.
Post Reserve Deployment Constraints:  The post zonal Operating Reserve and Short-Term 
Reserve deployment flows on the transmission constraints and Sub-Regional Power 
Balance Constraints, used to determine the Co-optimized Zonal Regulating Reserve 
Requirement, Co-optimized Zonal Contingency Reserve Requirement, Co-optimized 
Zonal Spinning Reserve Requirement, and Co-optimized Zonal Short-Term Reserve 
Requirement, for each Reserve Zone.
Post Reserve Deployment Constraints Demand Curve:  Demand curves used to price Post 
Reserve Deployment Constraints.
Power Purchaser:  The entity that is purchasing the Capacity and reserved Energy to be 
transmitted under this Tariff. 
PPA Schedule: Schedule associated with a PPA that is executed after April 3, 2014.
Pre-Confirmed Application:  An Application that commits the Eligible Customer to execute a 
Service Agreement upon receipt of notification that the Transmission Provider can

MISO
1.P
FERC Electric Tariff
Definitions - P
MODULES
69.0.0, 70.0.0
Effective On: October 18, 2026
provide the requested Transmission Service.
Price Sensitive Demand Bids:  Demand Bids in which the Market Participant specifies a 
maximum price (dollars per MWh) at which the Market Participant desires to purchase 
the designated MWh of Energy.
Price Taker:  A Market Participant with an Energy and/or Operating Reserve Offer not capable 
of setting LMPs or MCPs. 
Production Costs:  The Energy output cost of a Generation Resource or a Demand Response 
Resource-Type II based upon Start Up, No Load and Energy Offer cost components set 
forth in an Offer or the Energy reduction cost of a Demand Response Resource-Type I 
based upon Shut Down Offer, Hourly Curtailment Offer and Energy Offer cost 
components set forth in an Offer.
Project Cost:  All costs for Network Upgrades, as determined by the Transmission Provider to be 
a single transmission expansion project, including those costs associated with seeking and 
obtaining all necessary approvals for the design, engineering, construction, and testing of 
the Network Upgrades.  These Network Upgrades will include costs classified by the 
Transmission Owners and Independent Transmission Companies as transmission plant 
using the Uniform System of Accounts 350 through 359 or equivalent set of accounts for 
any Coordinating Owner. 
Project Financial Security:  The Cash Deposit or Irrevocable Letter of Credit described in 
Appendix 1 to Attachment FF of the Tariff that a Selected Developer is required to 
provide.
Proposal: A proposal to construct, implement, own, operate, maintain, repair, and restore all

MISO
1.P
FERC Electric Tariff
Definitions - P
MODULES
69.0.0, 70.0.0
Effective On: October 18, 2026
Competitive Transmission Facilities associated with a Competitive Transmission Project, 
in response to a Request for Proposal. Proposals may be submitted in one of two different 
forms: (i) a Single-Developer Proposal; or (ii) a Joint-Developer Proposal. The term 
“Proposal” shall include “Single-Developer Proposal” and “Joint-Developer Proposal”. 
Proposal Cure Period: A period of time, as set forth within Attachment FF, Section VIII.D.10, 
allowed for an RFP Respondent to correct deficiencies identified by the Transmission 
Provider in its previously submitted Proposal. The Proposal Cure Period commences 
upon notification by the Transmission Provider to an RFP Respondent of deficiencies in 
its Proposal. 
Proposal Participant(s): Any entity or entities involved in a Proposal, excluding the RFP 
Respondent(s), that will co-own the Competitive Transmission Project and rely on the 
RFP Respondent(s) to be the Selected Developer(s) responsible for constructing and 
implementing the Competitive Transmission Facilities associated with the Competitive 
Transmission Project. Proposal Participants may be identified in a Proposal as 
responsible for one or more aspects of operations, maintenance, repair, or restoration, on 
terms comparable to those that would apply if the RFP Respondent(s) intended to rely on 
a third-party contractor. 
Proposal Submission Deadline: The date and time Proposals must be submitted to the 
Transmission Provider by in order to be considered and evaluated by the Transmission 
Provider. The Submission Deadline shall be no later than 5:00 PM EPT on the date specified 
in the RFP, which shall not exceed one hundred and sixty-five (165) Calendar Days from the 
date the RFP was issued by the Transmission Provider, unless such date falls on a Saturday, 
Sunday, or MISO observed holiday in which case the Proposal Submission Deadline shall be

MISO
1.P
FERC Electric Tariff
Definitions - P
MODULES
69.0.0, 70.0.0
Effective On: October 18, 2026
the next Business Day that is not a MISO observed holiday.
Proposed Generator Planned Outage:  The planned removal from service, in whole or in part, 
of a Generation Resource for inspection, maintenance or repair for which the Generation 
Owner has sought or will seek approval from the Transmission Provider for such planned 
removal in accordance with the Business Practices Manuals.
Protected Information:  Privileged and non public information to be maintained by the 
Transmission Provider.
Proxy Offers: The Offers created for resources that are deployed during Emergency operating 
procedures by the Transmission Provider as specified in Schedule 29A.
Pseudo-tie:  A telemetered reading or value that is updated in real time and used as a tie line 
flow in the Area Control Error equation but for which no physical tie or energy metering 
actually exists.  The integrated value is used as a metered MWh value for interchange 
accounting purposes.  Pseudo tied status of Resources and Loads may only be changed 
during Network Model updates and the timing of such updates shall be as defined in the 
Business Practices Manuals. 
Pseudo-tie Agreement:  The Agreement between MISO and a Market Participant included as 
Attachment FFF-1 or Attachment FFF-2 to this Tariff, as applicable, outlining the terms 
and conditions of the real-time transfer of control of a generating unit or load to (or from) 
the MISO Balancing Authority Area from (or to) a specified external Balancing 
Authority Area.
Public Power:  For credit scoring purposes, an Applicant or Market Participant that is a not for 
profit municipality, cooperative, Joint Action Agency, or agent representing one or more 
Public Power entities and whose credit quality is directly derived from the credit quality

MISO
1.P
FERC Electric Tariff
Definitions - P
MODULES
69.0.0, 70.0.0
Effective On: October 18, 2026
of the Public Power entities represented through the agency relationship.
Public Power Composite Score:  For credit scoring purposes, the weighted average value of the 
Public Power Qualitative Score and the Public Power Quantitative Score.  The relative 
weights are sixty percent (60%) and forty percent (40%). 
Public Power Qualitative Score:  A component of a Public Power Composite Score which has, 
for credit scoring purposes, a value ranging from 1 to 6.99, with 1 being the best and 6.99 
being the worst.  The value is based on a review by the Transmission Provider of 
qualitative factors relative to an Applicant’s business, including but not limited to: i) 
regulatory; ii) legal; iii) demographic; and iv) energy supply/price factors as provided in 
Attachment L to this Tariff.
Public Power Quantitative Score:  A component of a Public Power Composite Score which has, 
for credit scoring purposes, a value ranging from 1 to 6.99, with 1 being the best and 6.99 
being the worst.  The value is based on a review by the Transmission Provider of various 
financial metrics as detailed in the Transmission Provider’s credit scoring model in 
Attachment L.

MISO
1.Z
FERC Electric Tariff
Definitions - Z
MODULES
42.0.0, 43.0.0
Effective On: October 18, 2026
Zero Injection Generation (ZG) Associated Load:  A source of electrical load that has a Point of 
Withdrawal that is at the same substation as the Point of Interconnection to the 
Transmission System (i.e. same voltage level at the interconnecting substation) as the 
Generating Facility with ZG Interconnection Service that will serve it.
Zero Injection Generation (ZG) Interconnection Service:  A limited form of Interconnection 
Service that allows an Interconnection Customer to connect its Generating Facility to the 
Transmission System or Distribution System, as applicable, for the limited purpose of 
delivering energy to ZG Associated Load.  ZG Interconnection Service does not grant 
any right to inject energy onto the Transmission System except as may be authorized by 
Section 3.11 of the Generator Interconnection Procedures.  ZG Interconnection Service 
does not convey Transmission Service.  ZG Interconnection Service also does not 
provide a right to serve, or a right to Transmission Service to serve, a ZG Associated 
Load or retail customer except as allowed by applicable state law.
Zero Injection Generation (ZG) Resource:  A generating resource with an Attachment X 
defined ZG Interconnection Agreement.  A ZG Resource may participate as a Generation 
Resource, Dispatchable Intermittent Resource, Electric Storage Resource, or Behind the 
Meter Generation resource.
Zonal Deliverability Charge (ZDC):  A positive charge per ZRC associated with ZRCs in a 
FRAP that may be assessed to an LSE based upon the congestion contribution to the 
constraints between LRZs or ERZs of any ZRCs that are located outside of the LRZ 
where the LSE has Load.
ZDC Hedge:  The mechanism that permits an LSE to avoid Zonal Deliverability Charge

MISO
1.Z
FERC Electric Tariff
Definitions - Z
MODULES
42.0.0, 43.0.0
Effective On: October 18, 2026
assessments through the investment in new or upgraded Transmission System facilities 
which are a result of approved firm transmission service requests where the LSE’s 
Planning Resource and the LSE’s Demand are in separate LRZs or the Planning Resource 
is located in an ERZ.
Zonal Export Ability:  The ability of an LRZ to export capacity to areas outside of that LRZ.  
Equal to an LRZ’s base interchange plus the LRZ’s incremental ability to export 
generation.
Zonal Import Ability:  The ability of an LRZ to import capacity from areas outside of that LRZ. 
Equal to an LRZ’s base interchange plus the LRZ’s incremental ability to import 
generation.
Zonal Operating Reserve:  Operating Reserve that is available on a Reserve Zone basis.
Zonal Regulating Reserve:  Regulating Reserve that is available on a Reserve Zone basis.
Zonal Resource Credit (ZRC):  A MW unit of a Planning Resource that has been converted 
from a MW of Seasonal Accredited Capacity to a credit in the MECT, which is eligible to 
be offered by a Market Participant into the PRA, to be sold bilaterally, eligible to be used 
for replacement capacity, and/or to be submitted through a Fixed Resource Adequacy 
Plan.
Zonal Uplift Report:  A monthly report of Day-Ahead Revenue Sufficiency Guarantee Credits, 
Real-Time Revenue Sufficiency Guarantee Credits, Day-Ahead Margin Assurance 
Payments, and Real-Time Offer Revenue Sufficiency Guarantee Payments, paid in 
dollars, and categorized by Local Resource Zone, Interface, day, and uplift category.

MISO
1.Z
FERC Electric Tariff
Definitions - Z
MODULES
42.0.0, 43.0.0
Effective On: October 18, 2026
ZRC Near-Shortage Conditions:  Any Season in a Planning Resource Auction in which there is 
sufficient volume of ZRC Offers in the LRZ to meet LCR, but the Season’s ACP is 
greater than the daily CONE value (i.e. 1/365 times CONE).
ZRC Offer:  An offer into the PRA of ZRCs by a Market Participant.
ZRC Offer Revenue Sufficiency Charge:  A charge that is assessed to an LSE that has cleared 
under ZRC Shortage Conditions and/or ZRC Near-Shortage Conditions for one or more 
Season’s in the Planning Resource Auction.
ZRC Offer Revenue Sufficiency Credit:  A Resource credit guaranteed by the Transmission 
Provider ensuring the minimum recovery of a Planning Resource’s Allowable ZRC Costs 
that have been cleared for one or more Seasons in the Planning Resource Auction.
ZRC Shortage Conditions:  Any Season in a Planning Resource Auction in which there is an 
insufficient volume of ZRC Offers in the LRZ to cover LCR.
Zone:  A set of Buses in a geographic area as determined by the Transmission Provider.

MISO
38.2.2
FERC Electric Tariff
Market Participant Application and Qualifications
MODULES
42.0.0, 43.0.0
Effective On: October 18, 2026
To qualify as a Market Participant, a Market Participant Applicant shall fulfill the following 
requirements.
a.
Submit a duly executed Market Participant Application to the Transmission Provider, in
such form as shall be established by the Transmission Provider.
i.
A Market Participant Applicant shall not qualify as a Market Participant until the
Transmission Provider has duly executed a Market Participant Agreement that has
previously been duly executed by the Market Participant Applicant.
ii.
Notwithstanding any information provided to the Transmission Provider prior to
the submission of the Market Participant Application, the Market Participant
Applicant must provide all information required in the Market Participant
Application.
b.
Demonstrate to the Transmission Provider that it or its Designated Agent complies with
all applicable metering, telemetry, data storage and transmission, and other reliability,
operation, planning and accounting standards and requirements for operating in the
Transmission Provider Region as set forth in this Tariff.
i.
A Market Participant Applicant that intends to assign to a Scheduling Agent, an
MDMA, or other Market Participant certain Markets Activities shall demonstrate
to the Transmission Provider’s satisfaction that it has assigned these
responsibilities to a qualified Designated Agent by forwarding to the
Transmission Provider a certificate that represents the underlying relationship
between the Market Participant and the Designated Agent.  In the event an entity
other than the Local Balancing Authority is designated as an MDMA, the Local

MISO
38.2.2
FERC Electric Tariff
Market Participant Application and Qualifications
MODULES
42.0.0, 43.0.0
Effective On: October 18, 2026
Balancing Authority must still receive the metered data.  If a Market Participant 
designates another entity as a Scheduling Agent or MDMA, the Market 
Participant remains financially responsible for all Market Activities represented 
by the Scheduling Agent or MDMA.
ii.
A Market Participant Applicant that, as a Market Participant, intends to make
purchases and sales of Energy, Operating Reserves, Up Ramp Capability, Down
Ramp Capability, and/or Short-Term Reserve or Other Ancillary Services, or
FTRs on behalf of other entities shall so inform the Transmission Provider.  The
Market Participant shall remain financially responsible and liable for all Market
Activities in the Energy and Operating Reserve Markets in which it engages
regardless of on whose behalf it has arranged to make purchases and sales.  The
Market Participant’s purchases and sales for other entities may, however, impact
its own creditworthiness assessment.
c.
Inform the Transmission Provider of its intent to submit Self-Schedules, Bilateral
Transactions, Bids, Offers, including Virtual Bids and Offers, or hold FTRs.
i.
Market Participant Applicants that are party to Grandfathered Agreement(s) and
intend to terminate such agreements and provide or receive Transmission Service
under this Tariff shall so inform the Transmission Provider pursuant to procedures
established by the Transmission Provider.  Such Market Participants that intend to
maintain service under such agreements should inform the Transmission Provider
in accordance with the process set forth by the Transmission Provider of its
selection of the optional treatment of transactions pursuant to such agreements

MISO
38.2.2
FERC Electric Tariff
Market Participant Application and Qualifications
MODULES
42.0.0, 43.0.0
Effective On: October 18, 2026
under the Energy and Operating Reserve Markets as described in Section 38.8.3.  
In addition, the Market Participant Applicant shall provide the information listed 
in Section 38.2.3.a.  
d.
A Market Participant Applicant seeking to submit Demand Bids into the Day-Ahead
Energy and Operating Reserve Market shall demonstrate to the Transmission Provider
that the end-users to be served by Energy purchased in the Energy and Operating Reserve
Markets are located within the Transmission Provider Region or will be brought within
the Transmission Provider Region prior to any purchases from the Energy and Operating
Reserve Markets.
e.
A Market Participant Applicant seeking to submit Generation Offers or Electric Storage
Resource Offers, including Self-Schedules, to sell in the Energy and Operating Reserve
Markets shall demonstrate to the Transmission Provider that such Market Participant
Applicant:  (i) has exclusive rights through ownership, operational control, or other
contractual arrangements to the output of Resources capable of responding to the
Dispatch Target and, if applicable, Setpoint Instructions; (ii) meets any applicable
requirements pursuant to RAR; and (iii) complies with all metering, telemetry, data
storage and communication protocols, and other reliability, operation, planning and
accounting standards and requirements for operating in the Transmission Provider Region
necessary to allow the Transmission Provider to validate the ability of the Generation
Resource or Electric Storage Resource to respond to the Dispatch Targets, and, if
applicable, Setpoint Instructions.
Criteria for generating facility, including a storage facility, with ZG Interconnection

MISO
38.2.2
FERC Electric Tariff
Market Participant Application and Qualifications
MODULES
42.0.0, 43.0.0
Effective On: October 18, 2026
Service. A ZG Resource that is greater than 5 MW in size must register, prior to its 
Commercial Operation Date, as a Generation Resource, Energy Storage Resource, or 
Dispatchable Intermittent Resource based on its applicable operating characteristics.
A Market Participant Applicant seeking to submit ZRC Offers, including Self Schedules 
or FRAPs, for LMRs to sell capacity in the PRA shall demonstrate to the Transmission 
Provider that such Market Participant Applicant:  (i) has exclusive rights through 
ownership, operational control, or other contractual arrangements to the output of LMRs 
capable of responding to Scheduling Instructions; (ii) meets any applicable requirements 
pursuant to RAR; and (iii) complies with all metering, data storage, accounting and 
communication protocol requirements applicable to LMRs under the Tariff, Business 
Practices Manuals, or necessary to allow the Transmission Provider to validate the ability 
of the LMR to respond to the Scheduling Instructions.
f.
A Market Participant Applicant seeking to engage in Market Activities shall demonstrate
to the Transmission Provider that it meets all of the requirements established by the
Transmission Provider and included in this Tariff for each activity as to which Market
Participant seeks to participate, including, without limitation, executing a credit
agreement in a form acceptable to the Transmission Provider, providing any Financial
Security required by the Transmission Provider and otherwise complying with the Credit
Policy.
g.
A Market Participant Applicant seeking to submit Demand Response Resource–Type I
Offers or Demand Response Resource–Type II Offers in the Energy and Operating
Reserve Markets shall:  (i) demonstrate to the Transmission Provider that it has exclusive

MISO
38.2.2
FERC Electric Tariff
Market Participant Application and Qualifications
MODULES
42.0.0, 43.0.0
Effective On: October 18, 2026
rights through ownership, operational control, or other contractual rights to the output of 
such Resources, (ii) that such Resources are capable of responding to the Dispatch Target 
for Energy and Operating Reserve and Setpoint Instructions if a Demand Response 
Resource–Type II or that such Resources are capable of responding to commitment 
instructions to supply Energy or responding to deployment instructions associated with 
Dispatch Targets for Contingency Reserve in the case of a Demand Response Resource–
Type I; (iii) designate those Resources as either a Demand Response Resource–Type I or 
Demand Response Resource–Type II with the Transmission Provider; (iv) demonstrate to 
the Transmission Provider that it complies with all metering, telemetry, data storage, and 
communication protocols, and other reliability, operation, planning, and accounting 
standards and requirements for operating in the Transmission Provider Region necessary 
to allow the Transmission Provider to validate the ability of the Resource to respond as 
described under (ii) above; and (v) verify to the Transmission Provider during the asset 
registration process that it has received any required approvals from all applicable state 
regulatory agencies to enable such Resources to participate in the Energy and Operating 
Reserve Markets.
h.
Transmission Provider Evaluation of Application.  Upon submission of a complete 
Market Participant Application, and such other information as shall be requested by the 
Transmission Provider, and a signed written representation that the Market Participant 
Applicant will be able to execute the Market Participant Agreement as provided in 
Attachment W of this Tariff upon approval of the Application, the Transmission Provider 
shall investigate and evaluate whether the Market Participant Applicant meets the criteria

MISO
38.2.2
FERC Electric Tariff
Market Participant Application and Qualifications
MODULES
42.0.0, 43.0.0
Effective On: October 18, 2026
specified in Section 38.2.2.  As soon as practicable, but in any event not later than sixty 
(60) Days after submission of the requested information, the Transmission Provider shall 
notify the Market Participant Applicant of its determination, along with a written 
summary of the basis for the determination.  The Transmission Provider shall grant the 
sought for status upon a reasonable showing by the Market Participant Applicant that it 
meets the criteria specified in Section 38.2.2, subject to its execution of the applicable 
Market Participant Agreement and upon approval of the Application.

MISO
68A.8
FERC Electric Tariff
Calculation of Transmission Losses
MODULES
37.0.0, 38.0.0
Effective On: October 18, 2026
Calculation of Transmission Losses
a.
The Transmission Provider shall calculate the LBA transmission loss percentages for 
each Season using the process described as follows:
1.
The Transmission Provider's State Estimator calculates transmission losses (MW) 
as part of the solution output process every five (5) minutes.
2.
The transmission losses (MW) are computed on all transmission lines and 
transformers by summing up real power at both ends for each transmission 
element (retaining the convention for flow direction) or as the difference in real 
power (without the sign convention for flow direction) for each State Estimator 
solution.
3.
The individual transmission losses (MW) for each element are summed to a total 
transmission values for each Local Balancing Authorities (LBA) level.
4.
These LBA transmission loss values are then integrated across each hour to 
calculate an hourly transmission loss value (MW) for each LBA.
5.
The total transmission loss value (MW) for each LBA will be the hourly 
integrated transmission losses value (MW) for the hour of the Coincident Peak 
Demand from the calendar year two years prior to the upcoming Planning Year.
6.
For the purposes of the Transmission Provider Region, the LBA transmission loss 
percentages are calculated as the total LBA transmission losses divided by the 
total LBA peak data at that MISO peak hour for each Season.  For purposes of a 
Local Resource Zone, the LBA transmission loss percentages are calculated as the 
total LBA transmission losses divided by the total LBA peak data at the LRZ peak

MISO
68A.8
FERC Electric Tariff
Calculation of Transmission Losses
MODULES
37.0.0, 38.0.0
Effective On: October 18, 2026
hour for each Season.
b.
The Local Balancing Authority (LBA) transmission loss percentage shall apply to the 
LSE's applicable LBA Coincident Peak Demand and Local Resource Zone Peak Demand 
forecast to determine the LSE transmission losses.  Behind-the-Meter-Generation Resources that 
are interconnected to the Transmission System and are not a ZG Resource shall be treated like 
other Resources with respect to transmission losses.  Behind-the-Meter-Generation Resources 
that are not interconnected to the Transmission System, ZG Resources and Demand Resources 
shall be adjusted to account for serving load without incurring transmission losses by grossing up 
the MW quantity of such resources by (1.0 + the appropriate LBA transmission loss percentage).

MISO
69A.1.1
FERC Electric Tariff
Forecasted Demand Identification
MODULES
39.0.0, 40.0.0
Effective On: October 18, 2026
Forecasted Demand Identification
a.
The Demand forecasts required in Section 69A.1 shall include: (1) the Coincident Peak 
Demand within each LBA Area in the Transmission Provider Region for the upcoming Planning 
Year; (2) the monthly non-coincident peak Demand and net Energy for Load within each LBA 
Area, for the upcoming Planning Year and the following Planning Year; (3) the non-coincident 
peak Demand and net Energy for Load within each LBA Area, for each Season, for the eight 
Planning Years subsequent to the two for which monthly values are provided in (2); and (4) the 
available Local Resource Zone Peak Demand within each LBA Area in the Local Resource Zone 
for the upcoming Planning Year.  All of these forecasts shall be submitted by November 1st prior 
to each Planning Year and shall be consistent with Good Utility Practice.  Forecast providers 
shall use the MECT or other means described in the BPM for Resource Adequacy to submit the 
requisite information.  Details regarding the items required in the Demand forecasts submittal are 
in the BPM for Resource Adequacy.  
b.
The supplied Coincident Peak Demand and Local Resource Zone Peak Demand forecasts 
shall include the Demand expected for the forecast time period (e.g. the Coincident Peak 
Demand hour) augmented to include the normal Demand from forecasted demand resources, 
whether registered or not registered with the Transmission Provider, including Demand from any 
retail demand side management programs.  The Coincident Peak Demand forecast shall identify, 
in MW, the expected contribution of each ZG Associated Load and identify its associated ZG 
Resource.  A ZG Resource is ineligible for Seasonal Accredited Capacity unless its ZG 
Associated Load is explicitly identified in the Coincident Peak Demand forecast.  Such forecasts 
may include Demand reductions achieved by energy efficiency programs that will be fully

MISO
69A.1.1
FERC Electric Tariff
Forecasted Demand Identification
MODULES
39.0.0, 40.0.0
Effective On: October 18, 2026
implemented prior to the start of the Planning Year.  Energy efficiency programs are installed 
measures on retail customer facilities that achieve a permanent reduction in electric Energy 
usage while maintaining a comparable quality of service and must comply with the guidelines set 
forth in the BPM for Resource Adequacy.  Energy efficiency program effects included in the 
load forecast must follow state and RERRA regulations and measurement and verification 
requirements, as applicable.  All submissions for such forecast values shall include distribution 
losses, but not transmission losses.  The Transmission Provider will be responsible for the 
calculation of the applicable transmission losses for the forecasts provided and for annually 
publishing such values for each LBA on its website by October 1, as specified in Section 68A.8 
and the BPM for Resource Adequacy. 
c.
In order to assist with the development of the Coincident Peak Demand and Local 
Resource Zone Peak Demand forecasts, the Transmission Provider will make available the 
historical monthly peak hours for each of the four months June through September, since 2005, 
or as available, for the Transmission Provider Region and for each Local Resource Zone.  On or 
before March 1st of each year, the Transmission Provider will review a sampling of submitted 
Demand forecast methodologies and inputs to ensure accuracy and consistency, in accordance 
with the BPM for Resource Adequacy.  If the Transmission Provider determines that the 
Demand forecast methodologies are inaccurate or inconsistent, the Transmission Provider shall 
work with the applicable LSEs to reconcile such issues.  If reconciliation is not achieved, or if 
Local Resource Zone Peak Demand forecasts are not available, then the Transmission Provider 
will provide the required forecast values.
d.
All Coincident Peak Demand and Local Resource Zone Peak Demand forecasts shall

MISO
69A.1.1
FERC Electric Tariff
Forecasted Demand Identification
MODULES
39.0.0, 40.0.0
Effective On: October 18, 2026
reflect a 50% probability that the Demand will not exceed the forecasted Demand for the 
relevant period.
e.
Consistent with Section 69A.1.2.1, the EDC must provide both the Transmission 
Provider and the respective LSEs with each retail customer’s peak load contribution (“PLC”) in 
each Season, including transmission losses and PRM as determined by the Transmission 
Provider, in the EDC’s service territory by December 15th.  At least five (5) Business Days 
before January 15, LSEs must notify the EDC and the Transmission Provider if they disagree 
with the EDC calculated PLC value.
f.
If an LSE knows it will gain a wholesale customer by the beginning of any Season in the 
next Planning Year, then that LSE may provide the Transmission Provider with the Coincident 
Peak Demand and the Local Resource Zone Peak Demand forecast for such acquired load by 
November 1.  In all other cases, the existing Market Participant serving such wholesale customer 
shall provide the Transmission Provider by November 1st with the Market Participant’s forecast 
of the wholesale customer’s Coincident Peak Demand and Local Resource Zone Peak Demand.

MISO
69A.3.1.g
FERC Electric Tariff
Determination of Deliverability
MODULES
42.0.0, 44.0.0
Effective On: October 18, 2026
A.
Determination of Deliverability of Generation Resources, Electric Storage 
Resources, and External Resources:
The Transmission Provider shall be responsible for determining whether Generation Resources, 
Electric Storage Resources, and External Resources eligible to be Capacity Resources are 
deliverable to Load.  The deliverable amount of such Generation Resources, Electric Storage 
Resources, and External Resources will be any combination of the following: 
i. 
The amount of Network Resource Interconnection Service under Attachment X;
ii. 
The amount of Energy Resource Interconnection Service under Attachment X that 
is coupled with firm Transmission Service;
iii. 
The amount of firm Transmission Service associated with a Grandfathered 
Agreement that can only be used to satisfy PRMR within the LRZ of the Load 
under the Grandfathered Agreement; 
iv. 
The amount of aggregate deliverability that a Generation Resource or External 
Resource was granted through the market transition deliverability test by the 
Transmission Provider and could qualify for Network Resource Interconnection 
Service; or 
v. 
The amount of non-aggregate deliverability that a Generation Resource or 
External Resource was granted by the transmission provider and confirmed by a 
Network Customer as a designated Network Resource under the OASIS 
reservation process in place prior to either the initial effective date of the Energy 
Market in 2005 or that corresponding Transmission Owner’s integration date, will 
be accepted by the Transmission Provider as deliverable to the Network Loads of

MISO
69A.3.1.g
FERC Electric Tariff
Determination of Deliverability
MODULES
42.0.0, 44.0.0
Effective On: October 18, 2026
the Network Customer for that term of the confirmed designation, as such term 
may be extended.; or,
vi.
The amount of ZG Interconnection Service under Attachment X only for a ZG 
Resource. 
B.
Determination of Deliverability of Intermittent Generation, Dispatchable 
Intermittent Resources, and Electric Storage Resources:
The Transmission Provider shall be responsible for determining whether Intermittent Generation, 
Dispatchable Intermittent Resources, and Electric Storage Resources eligible to be Capacity 
Resources are deliverable to Load.  The deliverable amount of such Intermittent Generation, 
Dispatchable Intermittent Resources, and Electric Storage Resources will be any combination of 
the following: 
i.
The amount of Network Resource Interconnection Service under Attachment X;
ii.
The amount of Energy Resource Interconnection Service under Attachment X that 
is coupled with firm Transmission Service;
iii.
The amount of firm Transmission Service associated with a Grandfathered 
Agreement that can only be used to satisfy PRMR within the LRZ of the Load 
under the Grandfathered Agreement; 
iv.
The amount of aggregate deliverability that the Intermittent Generation or 
Dispatchable Intermittent Resource was granted through the market transition 
deliverability test by the Transmission Provider and could qualify for Network 
Resource Interconnection Service; or, 
v.
The amount of non-aggregate deliverability that a Intermittent Generation or

MISO
69A.3.1.g
FERC Electric Tariff
Determination of Deliverability
MODULES
42.0.0, 44.0.0
Effective On: October 18, 2026
Dispatchable Intermittent Resource was granted by the transmission provider and 
confirmed by a Network Customer as a designated Network Resource under the 
OASIS reservation process in place prior to either the initial effective date of the 
Energy Market in 2005 or that corresponding Transmission Owner’s integration 
date, will be accepted by the Transmission Provider as deliverable to the Network 
Loads of the Network Customer for that term of the confirmed designation, as 
such term may be extended.; or,
vi.
The amount of ZG Interconnection Service under Attachment X only for a ZG 
Resource.
C.
Determination of Deliverability of Resources with Provisional Generator 
Interconnection Agreements:
The Transmission Provider shall be responsible for determining whether Resources with 
Provisional Generator Interconnection Agreements are deliverable to Load.  The deliverable 
amount of such Resources will be the amount of interconnection service established through the 
annual ERIS evaluation in accordance with the BPM for Generator Interconnection that is 
coupled with firm Transmission Service.

MISO
69A.3.1.h
FERC Electric Tariff
Replacement of Planning Resources
MODULES
43.0.0, 44.0.0
Effective On: October 18, 2026
Replacement of Planning Resources 
A.
Replacement of Planning Resources
A Planning Resource may replace Cleared ZRCs with Uncleared ZRCs pursuant to the 
following circumstances:
i.
Retirement and Suspension
1.
A Planning Resource for which a Market Participant requests a change in 
status in accordance with the System Support Resource (SSR) provisions 
described in Section 38.2.7 will no longer qualify as a Planning Resource 
effective as of the actual date that the status of the Planning Resource changes 
to Retire pursuant to Section 38.2.7.  
2.
A Generation Resource that has the status of Suspend pursuant to Section 
38.2.7 will continue to qualify as a Planning Resource in accordance with the 
BPM for Resource Adequacy.  
3.
If a Planning Resource for which a Market Participant converts Seasonal 
Accredited Capacity into ZRCs is Retired or Suspended prior to the end of the 
Season during the Planning Year in which the ZRCs cleared, such Market 
Participant must replace the Cleared ZRCs with Uncleared ZRCs.  If a Market 
Participant does not replace such ZRCs associated with a Retired or 
Suspended Planning Resource, a Capacity Replacement Non-Compliance 
Charge will be assessed as determined below in this Section.
ii.
ICAP Deferral
1.
A Planning Resource for which a Market Participant submits an ICAP

MISO
69A.3.1.h
FERC Electric Tariff
Replacement of Planning Resources
MODULES
43.0.0, 44.0.0
Effective On: October 18, 2026
Deferral Notice will be subject to ICAP Deferral Requirements and Charges 
pursuant to Section 69A.7.9.    
2.
If a Market Participant’s Planning Resource fails to satisfy the ICAP deferral 
requirements set forth in Section 69A.7.9 and the Market Participant does not 
replace Cleared ZRCs with Uncleared ZRCs, an ICAP Deferral Non-
Compliance Charge will be assessed pursuant to Section 69A.7.9.  
iii.
Outage
1.
If a Planning Resource, including a ZG Resource of any type, for which a 
Market Participant converts Seasonal Accredited Capacity into ZRCs is 
unable to meet the applicable performance requirements for the Cleared ZRCs 
as described in Section 69A.5 for greater than thirty-one (31) Days in total due 
to full or partial Generator Planned Outage during the Season of the Planning 
Year in which the ZRCs cleared, or for Planning Resources that are subject to 
Diversity Contracts for greater than one (1) Month during any Season of the 
Planning Year in which the ZRCs cleared, such Market Participant must 
replace the Cleared ZRCs with Uncleared ZRCs to transfer the performance 
requirements applicable to the Planning Resource.  If a Market Participant 
does not replace such ZRCs associated with a Planning Resource, a Capacity 
Replacement Non-Compliance Charge will be assessed as determined below 
in this Section.  
2.
Any combination of Cleared ZRCs that are on full or partial Generator 
Planned Outage for greater than thirty-one (31) Days in total during a Season,

MISO
69A.3.1.h
FERC Electric Tariff
Replacement of Planning Resources
MODULES
43.0.0, 44.0.0
Effective On: October 18, 2026
or for any other reason including full or partial Generation Outages that were 
not planned but were known or could have been reasonably anticipated at the 
time of the PRA, as set forth in the Market Monitoring and Mitigation 
Business Practices Manual, or unavailable because subject to a Diversity 
Contract that is not available for greater than one (1) Month during a Season, 
will be assessed a Capacity Replacement Non-Compliance Charge.  
3.
If a Planning Resource for which a Market Participant converts Seasonal 
Accredited Capacity into ZRCs is unable to meet the applicable performance 
requirements for the Cleared ZRCs as described in Sections 69A.3.3.1 and 
69A.5 due to a Catastrophic Generator Outage any time during the Season(s) 
of the Planning Year in which the ZRCs cleared such Market Participant may 
replace the Cleared ZRCs with Uncleared ZRCs to transfer the performance 
requirements applicable to the Planning Resource. 
iv.
Load Modifying Resources
1.
A Behind the Meter Generator for which a Market Participant converts 
Seasonal Accredited Capacity into ZRCs that is unable to meet the applicable 
performance requirements for the Cleared ZRCs as described in Section 
69A.3.3.1 due to either an outage submitted in accordance with the BPM for 
Resource Adequacy or due to regulatory restrictions resulting in the 
unavailability of the BTMG may replace the Cleared ZRCs with Uncleared 
ZRCs. 
2.
A Demand Resource for which a Market Participant converts Seasonal

MISO
69A.3.1.h
FERC Electric Tariff
Replacement of Planning Resources
MODULES
43.0.0, 44.0.0
Effective On: October 18, 2026
Accredited Capacity into ZRCs is unable to meet applicable performance 
requirements for the Cleared ZRCs as described in Section 69A.3.3.1 due to a 
change in ownership of the end use facility or through state or RERRA action 
which results in the termination of contracts with the Demand Resource may 
replace the Cleared ZRCs with Uncleared ZRCs. 
3.
A Market Participant representing an LMR may through consultation with the 
IMM as set forth in Section 64.3.e of Module D replace the Cleared ZRCs 
with Uncleared ZRCs. The performance obligation of the Uncleared ZRCs 
take the place of the applicable performance obligation of the Cleared ZRCs 
that were replaced.
v.
General Provisions
1.
A Planning Resource may not transfer its performance requirements by 
replacing the Cleared ZRCs with Uncleared ZRCs for any reason other than 
those reasons discussed immediately above.  
2.
A Planning Resource for which a Market Participant converts Seasonal 
Accredited Capacity into ZRCs that are used to replace Cleared ZRCs must 
meet the applicable performance requirements as described in sections 
69A.3.3.1 and 69A.5 for the balance of the Season of the Planning Year, 
subject to the same replacement requirements set forth above.  
3.
Cleared ZRCs can be replaced with Uncleared ZRCs that are not from the 
same LRZ or ERZ by examining post-replacement clearing as if it were the 
PRA clearing results, so that such replacement: (1) does not violate any CIL

MISO
69A.3.1.h
FERC Electric Tariff
Replacement of Planning Resources
MODULES
43.0.0, 44.0.0
Effective On: October 18, 2026
used in the PRA; (2) does not violate any CEL used in the PRA; (3) does not 
reduce the remaining total ZRCs for any LRZ of Cleared ZRCs below the 
LCR for that LRZ; and (4) does not exceed any flow ranges established under 
applicable seams agreements, coordination agreements, or transmission 
service agreements.  
4.
ZRC replacements from LRZs or ERZs other than that of the Cleared ZRCs 
will be processed in accordance with the following parameters:
i.
ZRC replacement shall be processed on a first come, first served basis.
ii.
The amount of Cleared ZRCs in each LRZ or ERZs at the time of a ZRC 
replacement shall be based upon the current amounts of Cleared ZRCs, 
including any previous replacement transactions.   
5.
ZRC replacement shall have no impact on settlements from the PRA, FRAPs, 
and RBDC Opt Out, including any assessed Capacity Replacement Non-
Compliance Charges.
B.
Capacity Replacement Non-Compliance Charge and Distribution
i.
Capacity Replacement Non-Compliance Charges will be calculated as follows:  
the number of days for which the Market Participant had a replacement 
requirement but failed to replace per section 69A.3.1.h.a above multiplied by the 
amount of ZRCs that failed to be replaced multiplied by the sum of the ACP for 
the applicable Season and the daily CONE value (1/365 times CONE). The ACP 
and the CONE values will be based on the LRZ where the Planning Resource 
cleared those ZRCs. If the Planning Resource is represented in an ERZ connected

MISO
69A.3.1.h
FERC Electric Tariff
Replacement of Planning Resources
MODULES
43.0.0, 44.0.0
Effective On: October 18, 2026
to a single SRRZ, the applicable CONE value will be the greatest CONE value of 
all LRZs in the respective SRRZ. For External Resources represented in ERZs 
that are connected to multiple SRRZs or that are not connected to any SRRZs, the 
applicable CONE value will be the greatest CONE value of all LRZs in those 
connected SRRZs.
ii.
Distribution of Capacity Replacement Non-Compliance Charges:  Capacity 
Replacement Non-Compliance Charge revenues received by the Transmission 
Provider will be distributed to Market Participants representing LSEs that have 
met their Final PRMR during the applicable Season of the Planning Year on a pro 
rata basis, based upon their respective LSEs’ share of Final PRMR for the 
Transmission Provider Region.

MISO
69A.3.3
FERC Electric Tariff
Load Modifying Resources
MODULES
35.0.0, 37.0.0
Effective On: October 18, 2026
Load Modifying Resources 
Load Modifying Resources can be offered as ZRCs in the PRA or can be used in FRAPs 
pursuant to Section 69A.9 or used in an RBDC Opt Out pursuant to Section 69A.9.1.  As 
described below, a Demand Resource or a BTMG is eligible to qualify as a Load Modifying 
Resource if it meets the following requirements.  A ZG Resource may qualify as a BTMG if not 
registered as a Generation Resource or DIR.  All LMRs that are cleared in the PRA or were 
submitted in a FRAP for a Season or submitted in an RBDC Opt Out must be available for use in 
the event of an Emergency as declared by the Transmission Provider, pursuant to the Emergency 
operating procedures of the Transmission Provider, unless replaced with other ZRCs pursuant to 
Section 69A.3.1.h.  ZRCs from Demand Resources will be grossed-up by the amount of avoided 
transmission losses in accordance with Section 68A.8.b and also by the applicable PRM in 
accordance with Section 68A.2.  ZRCs from BTMGs will be grossed-up by the amount of 
avoided transmission losses in accordance with Section 68A.8.b.  In accordance with the BPM 
for Resource Adequacy, the Transmission Provider will qualify an LMR for the applicable 
Season in the upcoming Planning Year.  The amount of ZRCs from Demand Resources and 
BTMG has to be consistent with the expected reduction in demand at the time of the 
Transmission Provider’s expected Coincident Peak Demand.

MISO
69A.3.6
FERC Electric Tariff
Behind the Meter Generation Eligibility
MODULES
45.0.0, 49.0.0
Effective On: October 18, 2026
Behind the Meter Generation Eligibility 
1.
In accordance with the BPM for Resource Adequacy, the Transmission Provider will 
qualify a BTMG for the applicable Season in the upcoming Planning Year.  A Market 
Participant that possesses ownership or equivalent contractual rights in a BTMG can 
request accreditation for such BTMG.  The Market Participant registering the BTMG 
must include the contracts with each end-use customer indicating rights behind the 
BTMG to generate behind-the-meter generation.  Notwithstanding, a copy of a contract 
with an end-use customer will not be required if the Market Participant is, or has non-
contractual legal rights to control, the end use customer.  In addition, the a Market 
Participant registering a BTMG or ZG Resource participating as a BTMG must meet the 
following requirements: 
a.
registering such resource(s) with the Transmission Provider as documented in the 
BPM for Resource Adequacy.
b.
demonstrating GVTC capability for applicable Season in each Planning Year on 
an annual basis as established in the BPM for Resource Adequacy, and by 
submitting the GVTC results to the Transmission Provider no later than 
September 30 prior to such Planning Year for existing accredited BTMG unless 
the Transmission Provider has granted an extension pursuant to Section 
69A.3.6.1.k.  All new BTMGs or an existing accredited BTMG that has an 
increased installed capacity shall submit their GVTC to the Transmission Provider 
prior to qualification, but no later than March 1 prior to the PRA as established in 
the BPM for Resource Adequacy.

MISO
69A.3.6
FERC Electric Tariff
Behind the Meter Generation Eligibility
MODULES
45.0.0, 49.0.0
Effective On: October 18, 2026
c.
submitting generator availability data (including, but not limited to, NERC GADS 
information) into a database provided by the Transmission Provider and as 
established in the BPM for Resource Adequacy.  A Market Participant is not 
required to report generator availability data based on GVTC for a BTMG less 
than 10 MW if the Market Participant has never provided such data for such 
BTMG.  A Market Participant that begins reporting generator availability data 
based upon GVTC for a BTMG that is less than 10 MW must continue to report 
such data.  
d.
having a notification time requirement less than or equal to 6 hours to receive 
credit as a Planning Resource. 
e.
demonstrating that the BTMG is able to sustain energy production at the 
accredited MW level for at least four (4) continuous Hours;  
f.
demonstrating that the BTMG is capable of being deployed at the accredited MW 
level for: (i) at least the first five (5) times requested in the Summer Season; and 
(ii) at least the first five (5) times requested in the Winter Season; (iii) at least the 
first three (3) times requested in the Spring Season; and (iv) at least the first three 
(3) times requested in the Fall Season, based on their physical capability when 
called upon by the Transmission Provider during an Emergency during any 
applicable Season in a Planning Year for which the BTMG receives credit as a 
Planning Resource.  Limitations due to applicable regulatory restrictions that are 
more restrictive than the physical limitations of the BTMG will supersede the 
physical availability of the BTMG.

MISO
69A.3.6
FERC Electric Tariff
Behind the Meter Generation Eligibility
MODULES
45.0.0, 49.0.0
Effective On: October 18, 2026
g.
There shall be no penalties assessed to a Market Participant representing the entity 
that has offered ZRCs from the LMR if the BTMG Resource is unavailable for 
interruption as a result of maintenance requirements in accordance with Good 
Utility Practice, or for reasons of Force Majeure, or in the event the specified 
BTMG reduction had already been accomplished for other reasons (e.g., 
economic considerations, operating the BTMG Resource at or above the credited 
level of BTMG Resource, or local reliability concerns in accordance with 
instructions from the Local Balancing Authority). 
h.
A BTMG Resource for which operation is not an obligation during Emergency 
events declared by the Transmission Provider pursuant to the Transmission 
Provider emergency operating procedures, will not qualify as an LMR.  
i.
A Market Participant shall be prohibited from registering a BTMG Resource for 
which credit is already being taken by a Market Participant.
j.
Market Participants providing physical, regulatory, or contractual limitations of 
the notice time and availability of BTMG must provide appropriate 
documentation to the Transmission Provider in accordance with the BPM for 
Resource Adequacy. 
k.
A Market Participant for a BTMG required to submit GVTC results must use 
Reasonable Efforts to submit GVTC by September 30 prior to the upcoming 
Planning Year.  If circumstances prevent the Market Participant from submitting 
the GVTC results for the BTMG by September 30, the Market Participant must 
notify the Transmission Provider no later than five (5) Business Days after

MISO
69A.3.6
FERC Electric Tariff
Behind the Meter Generation Eligibility
MODULES
45.0.0, 49.0.0
Effective On: October 18, 2026
September 30 and request an extension.  The extension request must include a 
reasonable explanation and justification for missing the deadline and an expected 
completion date prior to the upcoming Planning Year.  The Transmission Provider 
will review each extension request on a case by case basis to determine whether 
or not to approve or deny the request to extent the GVTC deadline.  Denial of an 
extension will not preclude the Market Participant for the BTMG from utilizing 
the ICAP Deferral process as described in Section 69A.7.9.
2.
Installed Capacity (ICAP) Deferral
If a Market Participant for a BTMG has not completed GVTC testing by the deadlines 
provided in 69A.3.6.1.b, is not expected to demonstrate deliverability, or is otherwise not 
expected to demonstrate commercial operation prior to March 1, ZRCs from such 
capacity may be used the PRA, in a FRAP (including through bilateral ZRC transactions) 
or in an RBDC Opt Out, subject to the notification, credit, and non-compliance 
provisions of Section 69A.7.9.

MISO
69A.3.9
FERC Electric Tariff
Penalty Provisions for LMRs
MODULES
39.0.0, 42.0.0
Effective On: October 18, 2026
Penalty Provisions for LMRs 
Unless an LMR is unavailable as a result of maintenance requirements, for reasons of Force 
Majeure, or because the number of required deployments based on the registered number has 
been reached, the Market Participant representing the entity that had ZRCs from LMRs, 
including ZG Resources participating as BTMG, that cleared in the PRA, were used in a FRAP, 
or were used in an RBDC Opt Out will be subject to the following penalties in the event the 
LMR is called upon during an Emergency as declared by the Transmission Provider and the 
LMR fails to perform in accordance with its Market Participant’s response to such Market 
Participant’s Scheduling Instructions.  The penalties defined below will only apply to the portion 
of the Market Participant’s response to such Market Participant’s Scheduling Instruction that is 
not followed during the Emergency declaration and will only be assessed by the Transmission 
Provider after giving the operator of the LMR an opportunity to provide documentation of the 
specific circumstances that would justify exemption from such penalties.  There will not be an 
LMR penalty assessed for any portion of the Scheduling Instruction which had already been 
accomplished by an LMR for other reasons (e.g., for economic considerations, self-scheduling at 
or above the credited amount of BTMG or local reliability concerns in accordance with 
instructions from the Local Balancing Authority) at the time the request for interruption is made 
by the Transmission Provider.  Likewise, for certain Demand Resources that are temperature 
dependent (e.g., a Demand Resource program involving air conditioning load), the specified 
Demand reduction may be adjusted in a manner defined in the measurement and verification 
procedures developed by the Transmission Provider to reflect the circumstances at the time a 
Demand Resource is called upon to reduce Demand.

MISO
69A.3.9
FERC Electric Tariff
Penalty Provisions for LMRs
MODULES
39.0.0, 42.0.0
Effective On: October 18, 2026
a.
The Transmission Provider shall assess the responsible Market Participant the 
costs that were otherwise incurred to replace the deficient Planning Resource at 
the time the Market Participant’s LMR is called upon by the Transmission 
Provider and does not respond in full or in part consistent with the Market 
Participant’s response to MISO’s Scheduling Instructions.  These costs will be the 
product of the amount of specified Demand reduction not achieved and the 
Hourly Real-Time Ex Post LMP at the Load CPNode, plus any applicable 
Revenue Sufficiency Guarantee charges.  The Transmission Provider shall 
allocate any such penalty revenues only to the Market Participants representing 
the LSEs in the Local Balancing Authority Area(s) that experienced the 
Emergency that required the use of an LMR.  Such revenues shall be distributed 
on a Load Ratio Share basis.  For any situation where either an LMR does not 
respond to an interruption request, including those circumstances where the LMR 
is claimed to be unavailable as a result of maintenance requirements or for 
reasons of Force Majeure, the Transmission Provider shall initiate an 
investigation with the Market Participant which has registered the Demand 
Resource or BTMG and was qualified as an LMR into the cause of the LMR not 
being available when called upon to reduce Demand.   If deemed appropriate by 
the Transmission Provider, the Transmission Provider will disqualify the Demand 
Resource or BTMG from further use as an LMR for the remainder of the current 
Planning Year, and will discontinue payment of the applicable ACP for the 
remainder of the current Planning Year when the LMR was unavailable. If such

MISO
69A.3.9
FERC Electric Tariff
Penalty Provisions for LMRs
MODULES
39.0.0, 42.0.0
Effective On: October 18, 2026
LMR was used in a FRAP or cleared in the PRA or used in an RBDC Opt Out, 
then the Market Participant will be charged the applicable ACP for the remainder 
of the current Planning Year for the Unforced Capacity of the LMR.  The 
revenues collected will be distributed on a pro rata basis in such LRZ based upon 
an LSE’s Final PRMR.
b.
In the event the same LMR is unavailable on a second occasion (with at least a 
separation period of 24 hours) when called upon to respond to Scheduling 
Instructions, except for a validated circumstance of maintenance requirements or 
for reasons of Force Majeure, the Market Participant taking credit for that LMR 
shall make the same penalty payment as indicated in Section 69A.3.9.a above, and 
the Demand Resource or BTMG will no longer qualify as an LMR and will not 
receive the applicable ACP for the remainder of the current Planning Year and 
will not be eligible for LMR status for the next Planning Year. If such LMR was 
used in a FRAP or cleared in the PRA or used in an RBDC Opt Out, then the 
Market Participant will be charged the applicable ACP for the remainder of the 
current planning year for the Unforced Capacity of the LMR.  The revenues 
collected will be distributed on a pro rata basis in such LRZ based upon an LSE’s 
Final PRMR.

MISO
69A.4.1
FERC Electric Tariff
Seasonal Accredited Capacity of Capacity Resources
MODULES
39.0.0, 43.0.0
Effective On: October 18, 2026
Seasonal Accredited Capacity of Capacity Resources 
The Transmission Provider will determine the Seasonal Accredited Capacity for each Capacity 
Resource.
a. 
The Seasonal Accredited Capacity for a Capacity Resource that is a Generation 
Resource, but not a Dispatchable Intermittent Resource, Intermittent Generation, 
Electric Storage Resource, External Resource, or Use Limited Resource, or a ZG 
Resource, is based on an evaluation of the type and volume of interconnection 
service, GVTC value, and Real-Time offered availability of such Generation 
Resource or Electric Storage Resource for each Season as set forth in Schedule 
53.  
b. 
The Seasonal Accredited Capacity for a Capacity Resource that is an External 
Resource, but not a Dispatchable Intermittent Resource, Intermittent Generation 
or Use Limited Resource, is based on the GVTC value and XEFORd values of 
such External Resource for each Season. External Resources that are not required 
to report generator availability data will have a forced outage rate based on the 
class average forced outage rate of the resource type.
c. 
The Transmission Provider will determine the Seasonal Accredited Capacity for a 
DRR that qualifies as a Capacity Resource and that interrupts or controls Load, 
based upon historical performance and availability, for each Season, as set forth in 
Schedule 53.
d. 
The Transmission Provider will determine the Seasonal Accredited Capacity for 
each DRR that qualifies as a Capacity Resource and that is a behind the meter

MISO
69A.4.1
FERC Electric Tariff
Seasonal Accredited Capacity of Capacity Resources
MODULES
39.0.0, 43.0.0
Effective On: October 18, 2026
generation facility based on an evaluation of the GVTC value and Real-Time 
offered availability for such behind the meter generation facility for each Season 
as set forth in Schedule 53. If such behind the meter generation facility is 
interconnected to the Transmission System, the Transmission Provider will 
consider the type and volume of interconnection service when determining the 
Seasonal Accredited Capacity. 
e. 
The Seasonal Accredited Capacity for a Capacity Resource that is a Dispatchable 
Intermittent Resource or Intermittent Generation will be determined by the 
Transmission Provider based on historical performance, availability, and type and 
volume of interconnection service, for each Season in accordance with the BPM 
for Resource Adequacy.
f.
The Seasonal Accredited Capacity value for a Capacity Resource that is a Hybrid 
Resource will be established by the Transmission Provider based on the sum of 
the Seasonal Accredited Capacity values of its respective Electric Facilities for 
the production and/or storage for later injection of electricity, up to the level of 
firm interconnection service, prior to a minimum amount of operating data 
becoming available. Once sufficient operation data is available, as defined in the 
BPM, the Seasonal Accredited Capacity value for a Hybrid Resource will be 
determined by the Transmission Provider based on historical performance, 
availability, and type and volume of interconnection service, for each Season in 
accordance with the BPM.
g.
The Seasonal Accredited Capacity of a Capacity Resource that is an Electric

MISO
69A.4.1
FERC Electric Tariff
Seasonal Accredited Capacity of Capacity Resources
MODULES
39.0.0, 43.0.0
Effective On: October 18, 2026
Storage Resource will be established by the Transmission Provider based on an 
evaluation of the type and volume of interconnection service, a GVTC value 
based upon a power and energy test, and an XEFORd. Electric Storage Resources 
that are not required to report generator availability data will have an XEFORd 
rate based on their class average forced outage rate.
h.
The Seasonal Accredited Capacity for a Capacity Resource that is a Use Limited 
Resource will be determined by the Transmission Provider based on the type and 
volume of interconnection service, the GVTC and XEFORd values of such Use 
Limited Resource in accordance with the BPM for Resource Adequacy.
i.
The Seasonal Accredited Capacity for a ZG Resource shall be determined based 
on its participation type as set forth above, subject to the following additional 
requirements:
1.
The Seasonal Accredited Capacity of a ZG Resource is capped at the 
specified portion of the Coincident Peak Demand forecast attributable to 
the ZG Associated Load less any SAC assigned to the ZG Associated 
Load.
2.
The Seasonal Accredited Capacity of a ZG Resource shall be grossed-up 
by the amount of avoided Transmission Losses, as set forth in Section 
68A.8.b.

MISO
69A.4.5
FERC Electric Tariff
Attributes of ZRCs
MODULES
38.0.0, 42.0.0
Effective On: October 18, 2026
Attributes of ZRCs 
A Market Participant that owns or possesses equivalent contractual rights to a qualified Planning 
Resource can convert the convertible Seasonal Accredited Capacity of the Resource (Seasonal 
Accredited Capacity MW) as determined in section 69.A.3.1.g into ZRCs through the MECT in 
order to offer such ZRCs into a PRA.  Market Participants also can unconvert and/or transfer 
ZRCs through the MECT to another Market Participant, as described in the BPM for Resource 
Adequacy.  All ZRCs associated with a ZG Resource must be used as part of an LSE’s Fixed 
Resource Adequacy Plan (FRAP) or RBDC Opt Out.
A.
Eligibility for Zonal Resource Credits for a Capacity Resource that is a Planning 
Resource that is not Intermittent Generation or Dispatchable Intermittent Resource.
For a Capacity Resource that is not Intermittent Generation or Dispatchable Intermittent 
Resource the amount of Capacity that is eligible to be converted to Zonal Resource Credits shall 
be the convertible Seasonal Accredited Capacity value of the Capacity Resource.  The 
convertible Seasonal Accredited Capacity shall be determined by:
i.
Determining the Installed Capacity; 
ii.
Determining the Seasonal Accredited Capacity of the Capacity Resource; 
iii.
Allocating the Capacity Resource’s Seasonal Accredited Capacity value where:
a.
If the Capacity Resource has only Energy Resource Interconnection Service, 
the Seasonal Accredited Capacity will be allocated to the Capacity Resource’s 
Energy Resource Interconnection Service Seasonal Accredited Capacity 
value, which will be calculated by multiplying the lesser of the Capacity

MISO
69A.4.5
FERC Electric Tariff
Attributes of ZRCs
MODULES
38.0.0, 42.0.0
Effective On: October 18, 2026
Resource’s ICAP or Energy Resource Interconnection Service by SAC 
divided by ICAP;
b. If the Capacity Resource has both Network Resource Interconnection Service 
and Energy Resource Interconnection Service, the Seasonal Accredited 
Capacity will be allocated first to the Capacity Resource’s Network Resource 
Interconnection Service Seasonal Accredited Capacity value, which will be 
calculated by multiplying the lesser of the Capacity Resource’s ICAP or 
Network Resource Interconnection Service by SAC divided by ICAP, as 
provided below:
NRIS SAC = MIN (NRIS, ICAP) × (SAC/ICAP)
c.
Any remaining total Seasonal Accredited Capacity value will then be 
allocated to Energy Resource Interconnection Service Seasonal Accredited 
Capacity as provided below:
ERIS SAC = MAX (0, (ICAP-NRIS)) × (SAC/ICAP)
d. The resulting Network Resource Interconnection Service Seasonal Accredited 
Capacity value shall be eligible to be converted into Zonal Resource Credits; 
and
e.
The resulting Energy Resource Interconnection Service Seasonal Accredited 
Capacity value that is coupled with firm Transmission Service shall be 
eligible to be converted into Zonal Resource Credits up to the Energy 
Resource Interconnection Service Unforced Capacity value of the Capacity

MISO
69A.4.5
FERC Electric Tariff
Attributes of ZRCs
MODULES
38.0.0, 42.0.0
Effective On: October 18, 2026
Resource, by multiplying the firm Transmission Service amount by SAC 
divided by ICAP.
f.
If the Capacity Resource has ZG Interconnection Service, the Seasonal 
Accredited Capacity will be allocated as one-hundred percent (100%) of SAC.
B.
Eligibility for Zonal Resource Credits for a Capacity Resource that is an 
Intermittent Generation or Dispatchable Intermittent Resource
For Intermittent Generation and Dispatchable Intermittent Resources that are Capacity 
Resources, the amount of Capacity eligible to be converted to Zonal Resource Credits shall be 
the convertible Seasonal Accredited Capacity value of the Intermittent Generation or 
Dispatchable Intermittent Resource, which is equal to the total Seasonal Accredited Capacity 
value multiplied by the quotient of the deliverability adjusted Capacity factor divided by the peak 
performance Capacity factor of the Capacity Resource where:
a.
the deliverability-adjusted capacity factor is the average of the actual Energy 
output capped at the demonstrated deliverability of the Intermittent Generation or 
Dispatchable Intermittent Resource determined in Section 69A.3.1.g during the 
highest system peak load observances for each Season that the Capacity Resource 
was in service divided by the Installed Capacity of the Capacity Resource; and,
b.
the existing peak performance Capacity factor is the average of the actual Energy 
output during the highest system peak load observances for each Season that the 
Capacity Resource was in service divided by the Installed Capacity of the 
Capacity Resource.

MISO
69A.7.3
FERC Electric Tariff
Uncleared ZRCs
MODULES
33.0.0, 34.0.0
Effective On: October 18, 2026
Uncleared ZRCs
Once the PRA has concluded, a Market Participant may convert back to Seasonal Accredited 
Capacity any ZRCs that do not clear in the PRA.  ZRCs associated with a ZG Resource that are 
not used in a FRAP may not be used as Uncleared ZRCs.

MISO
69A.7.8
FERC Electric Tariff
Self-Scheduling Option:
MODULES
34.0.0, 35.0.0
Effective On: October 18, 2026
Self-Scheduling Option:  
LSEs with sufficient ZRCs within an LRZ where the LSE has forecasted Demand will be able to 
avoid the financial impact of that LRZ’s ACP for the Final PRMR by Self-Scheduling such 
ZRCs into the PRA (i.e., by Offering ZRCs into the PRA at a zero price so that the ZRCs will 
clear).  For Planning Resources associated with ZRCs represented outside the LRZ where the 
LSE has PRMR, an LSE would also need to use the financial hedges described in Section 
69A.7.7 to avoid the financial effects of potential price differences between LRZs or between an 
LRZ and an ERZ.  ZRCs obtained from a ZG Resource may not be used in a Self-Schedule.

MISO
69A.9
FERC Electric Tariff
Use of FRAP in the Planning Resource Auction
MODULES
38.0.0, 39.0.0
Effective On: October 18, 2026
Use of FRAP in the Planning Resource Auction
An LSE electing to use a Fixed Resource Adequacy Plan (FRAP) in the PRA for any Season can 
continue to use its existing resource planning processes to meet all or any portion of its Initial 
PRMR by providing the Transmission Provider with a FRAP, as described below: 
a.
An LSE electing to use a FRAP for any Season must submit a FRAP for each LRZ to the 
Transmission Provider by the 7th Business Day of March prior to a Planning Year in 
order for the LSE to demonstrate that the LSE has designated ZRCs in order to meet all 
or any portion of the LSE’s Initial PRMR for such LRZ.  Market Participants submitting 
registrations for new and existing Load Modifying Resources can be included in the 
Module E Capacity Tracking Tool beginning as early as December prior to the Planning 
Year.  Load Modifying Resources registrations submitted to the Transmission Provider 
will be evaluated to determine if Load Modifying Resources meet the qualification 
requirements. Market Participants that submit registrations by February 1 prior to the 
Planning Year will be evaluated by the Transmission Provider and will be notified of the 
outcome on or before February 21 that precedes the Planning Year.
Market Participants that submit registrations between February 2 and February 15 prior to 
the Planning Year will be evaluated by the Transmission Provider and will be notified of 
the outcome at least two Business Days prior to the FRAP deadline.  The Transmission 
Provider will make a good faith effort to notify Market Participants that submit 
registrations after February 15 but not later than March 1 of the outcomes of such 
registrations no later than the FRAP deadline.  All ZRCs associated with a ZG Resource 
must be used as part of an LSE’s Fixed Resource Adequacy Plan (FRAP) or RBDC Opt

MISO
69A.9
FERC Electric Tariff
Use of FRAP in the Planning Resource Auction
MODULES
38.0.0, 39.0.0
Effective On: October 18, 2026
Out.  All ZRCs associated with a ZG Resource that are not used in a FRAP shall have no 
capacity value as set forth in Section 69A.7.3.  The FRAP must include the LSE’s 
forecasted Coincident Peak Demand for each LRZ for each Season and also identify the 
ZRCs that the LSE owns, or has contractual rights to, in order to provide Planning 
Resources to meet the FRAP designated portion of its Initial PRMR and also its load ratio 
share of the LCR for each LRZ for each Season.  The Transmission Provider will 
evaluate each LSE’s FRAP to determine if it meets the designated portion of the LSE’s 
Initial PRMR and the LSE’s share of LCR and the Transmission Provider will notify the 
LSE via the MECT prior to March 15th before a Planning Year of the extent that the 
portion of an LSE’s Initial PRMR or share of LCR for each LRZ is not covered by a 
submitted FRAP.  The LSE will have until the PRA offer window opens to remedy any 
deficiencies in their FRAP for each Season.
b.
To the extent that the LSE’s ZRCs satisfy the portion of the LSE’s Initial PRMR for the 
applicable Season(s) submitted through a FRAP, (1) the LSE will not have an obligation 
to make ZRC Offers for the ZRCs included in the FRAP into the PRA, or otherwise 
participate in the PRA for such Season; and (2) the LSE will not have an obligation to 
pay the applicable ACP for the LSE’s Initial PRMR within such LRZ that is covered by 
the FRAP.  The Transmission Provider will consider all PRMR and ZRCs, including 
PRMR and ZRCs in FRAPs, as part of the Transmission Provider’s reliability assessment 
when conducting the PRA.

MISO
69A.9
FERC Electric Tariff
Use of FRAP in the Planning Resource Auction
MODULES
38.0.0, 39.0.0
Effective On: October 18, 2026
c.
Any portion of an LSE’s Initial PRMR not covered by the FRAP may be purchased 
through the PRA.  An LSE will be charged the applicable ACP for any PRMR that is 
procured through the PRA.
d.
If an LSE owns or controls ZRCs that are not included in the LSE’s FRAP, then such 
LSE may submit ZRC Offers into the PRA for all such excess ZRCs, subject to Module 
D.  
e.
To the extent that an LSE designates ZRCs in a FRAP that are represented in the same 
LRZ as the LSE’s Demand to meet the LSE’s Initial PRMR for such LRZ, then the LSE 
will not be subject to a Zonal Deliverability Charge for such ZRCs.
f.
An LSE that contains ZRCs from Planning Resources that are not represented in the same 
LRZ where the LSE has Demand may be subject to a Zonal Deliverability Charge, which 
will be calculated as described in Section 69A.7.6(b).

MISO
69A.9.1
FERC Electric Tariff
Use of RBDC Opt Out in the Planning Resource Auction
MODULES
34.0.0, 35.0.0
Effective On: October 18, 2026
Use of RBDC Opt Out in the Planning Resource Auction
An LSE electing to use the RBDC Opt Out can continue to use its existing resource planning 
processes to meet its Final PRMR by providing the Transmission Provider with an RBDC Opt 
Out, as described below:
a.
The RBDC Opt Out Lock-In Period will be three consecutive Planning Years for 
all Seasons.  If an LSE fails to submit an RBDC Opt Out then the LSE will be 
required to participate in the PRA through any combination of the other Tariff-
defined options, or pay the Capacity Deficiency Charge, for each Planning Year 
in which the LSE does not submit an RBDC Opt Out. 
b.
An LSE under state jurisdiction where the State Regulatory Authority has 
overridden the PRM established by the Transmission Provider is not eligible to 
select the RBDC Opt Out.
c.
An LSE selecting the RBDC Opt Out will be required to meet its Final PRMR for 
the entirety of its load and losses, and its entire share of LCR for each LRZ, for 
each Season.  All ZRCs associated with a ZG Resource must be used as part of an 
LSE’s Fixed Resource Adequacy Plan (FRAP) or RBDC Opt Out.
d.
An LSE must provide an initial notification of its intent to elect the RBDC Opt 
Out no later than January 15th prior to the upcoming Planning Year.  An LSE 
electing the RBDC Opt Out must submit its final plan for each LRZ to the 
Transmission Provider by the 7th Business Day of March prior to each Planning 
Year during the RBDC Opt Out Lock-In Period in order for the LSE to 
demonstrate that the LSE has designated ZRCs in order to meet the LSE’s Final

MISO
69A.9.1
FERC Electric Tariff
Use of RBDC Opt Out in the Planning Resource Auction
MODULES
34.0.0, 35.0.0
Effective On: October 18, 2026
PRMR, and share of LCR for each LRZ, for each Season.  Market Participants 
using the RBDC Opt Out must submit all registrations for new and existing 
resources to be used in the RBDC Opt Out through the MECT consistent with the 
timelines established in the Business Practices Manual for Resource Adequacy.  
The RBDC Opt Out must include the LSE’s seasonal forecasted Coincident Peak 
Demand for each LRZ and also identify the ZRCs that the LSE owns, or has 
contractual rights to, in order to provide Planning Resources to meet its Final 
PRMR, and also its share of the LCR for each LRZ for each Season.  The 
Transmission Provider will evaluate each LSE’s RBDC Opt Out on an annual 
basis to determine if it meets the LSE’s Final PRMR and the LSE’s share of LCR 
requirements for all Seasons.  The Transmission Provider will notify the LSE 
prior to March 15th before the applicable Planning Year whether the submitted 
RBDC Opt Out meets the LSE’s Final PRMR, and share of LCR for each LRZ, 
requirement for each Season during the applicable Planning Year.  The LSE must 
remedy any deficiencies in its RBDC Opt Out for each Season before the PRA 
offer window opens.
e.
The Transmission Provider will notify the RERRA(s) following the submission of 
an initial intent to elect the RBDC Opt Out by an LSE.  RERRA(s) may elect to 
notify the Transmission Provider within twenty (20) Business Days whether the 
LSE’s load subject to the RERRA’s respective jurisdiction is authorized to select 
the RBDC Opt Out.  Upon receipt of such a notification from the RERRA(s) that 
the LSE is not authorized to elect the RBDC Opt Out for the LSE’s load subject to

MISO
69A.9.1
FERC Electric Tariff
Use of RBDC Opt Out in the Planning Resource Auction
MODULES
34.0.0, 35.0.0
Effective On: October 18, 2026
the RERRA’s respective jurisdiction, the Transmission Provider will reject the 
LSE’s RBDC Opt Out for such load.  If the Transmission Provider receives no 
notification from the RERRA(s) within the twenty (20) Business Day period, and 
an LSE has demonstrated that it has designated ZRCs in order to meet its Final 
PRMR, and share of LCR for each LRZ, for each Season, then the proposed 
RBDC Opt Out by the LSE will be deemed accepted by the Transmission 
Provider.
f.
To the extent that the LSE’s ZRCs satisfy the LSE’s Final PRMR for the 
applicable Season(s) submitted through an RBDC Opt Out, (1) the LSE will not 
have an obligation to make ZRC Offers for the ZRCs included in the RBDC Opt 
Out into the PRA, or otherwise participate in the PRA for such Season; and (2) 
the LSE will not have an obligation to pay the applicable ACP for the LSE’s Final 
PRMR within such LRZ.  The Transmission Provider will consider all PRMR and 
ZRCs, including PRMR and ZRCs in RBDC Opt Outs, as part of the 
Transmission Provider’s reliability assessment when conducting the PRA.
g.
If an LSE owns or controls ZRCs that are not included in the LSE’s RBDC Opt 
Out, then such LSE may submit ZRC Offers into the PRA for all such excess 
ZRCs, subject to Module D.  Such ZRC Offers may not include ZRCs associated 
with a ZG Resource.
h.
To the extent that an LSE designates ZRCs in an RBDC Opt Out that are 
represented in the same LRZ as the LSE’s Demand to meet the LSE’s Final 
PRMR for such LRZ, then the LSE will not be subject to a Zonal Deliverability

MISO
69A.9.1
FERC Electric Tariff
Use of RBDC Opt Out in the Planning Resource Auction
MODULES
34.0.0, 35.0.0
Effective On: October 18, 2026
Charge for such ZRCs.
i.
An LSE that designates ZRCs from Planning Resources that are not represented in 
the same LRZ where the LSE has Demand may be subject to a Zonal 
Deliverability Charge, which will be calculated as described in Section 
69A.7.6(b).
j.
LSEs that submit an RBDC Opt Out may not use any of the other options to 
satisfy their Final PRMR including: (i) submitting a Fixed Resource Adequacy 
Plan; (ii) Self-Scheduling ZRCs; (iii) purchasing ZRCs through the Planning 
Resource Auction process, and/or (iv) paying the Capacity Deficiency Charge to 
meet all or a portion of their Initial PRMR.
k.
LSEs that elect the RBDC Opt Out that do not meet their Final PRMR shall pay 
the RBDC Opt Out Deficiency Charge, which is 2.748 times applicable LRZ’s 
CONE multiplied by the difference in ZRCs between the LSEs Final PRMR and 
the amount of ZRCs submitted as the LSEs RBDC Opt Out for each Season in 
which the LSE fails to meet its Final PRMR.
l.
RBDC Opt Out Deficiency Charge revenues will be distributed to Market 
Participants representing LSEs on a pro rata basis, based upon their respective 
LSE's share of Final PRMR for the Transmission Provider Region minus the Final 
PRMR associated with the RBDC Opt Out Deficiency Charge.  If the LRZ where 
LSEs incurred RBDC Opt Out Deficiency Charges failed to meet its Local 
Clearing Requirement ("LCR"), then RBDC Opt Out Deficiency Charge revenues 
will be distributed to Market Participants representing LSEs on a pro rata basis,

MISO
69A.9.1
FERC Electric Tariff
Use of RBDC Opt Out in the Planning Resource Auction
MODULES
34.0.0, 35.0.0
Effective On: October 18, 2026
based upon their respective LSE's share of Final PRMR minus the Final PRMR 
associated with the RBDC Opt Out Deficiency Charge in such LRZ.
m.
The Transmission Provider will determine the RBDC Opt Out Adder that will be 
applicable for the upcoming Planning Year every year on or before December 15. 
The RBDC Adder applicable during the first Planning Year in which an LSE 
elects to use the RBDC Opt Out will apply for such LSE’s entire RBDC Opt Out 
Lock-In Period.
n.
The Transmission Provider will determine the RBDC Opt Out Adder based on a 
Seasonal average of the RBDC based PRA clearing for the prior three Planning 
Years.  If the prior year RBDC based PRA clearing is not available, simulated 
RBDC based PRA clearing will be used to determine the RBDC Opt Out Adder.

MISO
SCHEDULE 53
FERC Electric Tariff
Seasonal Accredited Capacity Calculation
SCHEDULES
41.0.0, 42.0.0
Effective On: October 18, 2026
Schedule 53
Seasonal Accredited Capacity Calculation
I.
General
Seasonal Accredited Capacity (SAC) for a Capacity Resource that is a DRR or 
Generation Resource but not a Dispatchable Intermittent Resource, Intermittent Generation, 
Electric Storage Resource, External Resource, or Use Limited Resource will be determined 
pursuant to this Schedule 53.  The resources accredited pursuant to this Schedule 53, as 
described above, are here and after referred to as “Schedule 53 Resources”.  A two-tiered 
weighting structure is used to calculate Seasonal Accredited Capacity for Schedule 53 
Resources.  Outage exemptions for planned outages and exemptions for any operating 
limitations, such as thermal, voltage, or stability limits referenced in the BPM for Outage 
Operations, provided by the Transmission Provider or Transmission Operator to preserve the 
reliability of the Transmission System, that modify the must offer obligation set forth in Section 
69A.5.a will be factored into calculating the tiers of a Schedule 53 Resource’s Seasonal 
Accredited Capacity.
II.
Tier 1 and Tier 2 Planned Outage Exemption Requirements
Generator Planned Outages scheduled to begin before September 1, 2022, will be granted 
a Tier 1 and Tier 2 exemption based on Section 38.2.5.g.ix., and as set forth in the Business 
Practices Manual for Resource Adequacy.  Generator Planned Outages scheduled to begin on or 
after September 1, 2022, will be evaluated for Tier 1 and Tier 2 exemptions based on the 
following requirements. Only full Generator Planned Outages or full Proposed Generator 
Planned Outages shall be eligible for the Tier 1 and Tier 2 planned outage exemptions set forth 
below.

MISO
SCHEDULE 53
FERC Electric Tariff
Seasonal Accredited Capacity Calculation
SCHEDULES
41.0.0, 42.0.0
Effective On: October 18, 2026
Generator Outage 
Submission Criteria
Maintenance Margin >=0 
for duration of outage
Maintenance Margin <0 for 
any day in the duration of 
outage
>120 days prior to outage start 
date, and >120 days from end 
of previous outage for unit
Exempt Tier 1 & 2
Exempt Tier 1 Only
>120 days Prior to Outage 
Start date and <120 days from 
end of Previous outage for 
unit or Outage submitted 
between 31-119 days Prior to 
outage start date
Exempt Tier 1 Only
No Exemption
14-30 days prior to outage 
start date and passes No Harm 
Test
Exempt Tier 1 Only
No Exemption
Outage moved per MISO 
request
Exempt Tier 1 & 2
(Weather, forced outages, other 
conditions in BPM-008)
Exempt Tier 1 & 2 
(Weather, forced outages, other 
conditions in BPM-008)
at Transmission Provider’s 
discretion or Tier 1 only at 
Transmission Provider’s 
discretion
A.
Tier 2 Planned Outage exemptions  
i.
The Generator Owner or Generator Operator: (a) schedules its first 
Generator Planned Outage 120 days or more in advance of the outage start 
date and 120 days or more beyond the end date of any previously 
scheduled outages for the generator unit; and (b) the Proposed Generator 
Planned Outage is to occur entirely during a period in which there is 
adequate Maintenance Margin at the time advance notice of the outage is 
provided to the Transmission Provider. There is adequate margin when the 
Maintenance Margin is greater than or equal to zero megawatts after 
subtracting the megawatts of the requested Proposed Generator Planned 
Outage. The request shall be determined based on highest queued request.

MISO
SCHEDULE 53
FERC Electric Tariff
Seasonal Accredited Capacity Calculation
SCHEDULES
41.0.0, 42.0.0
Effective On: October 18, 2026
ii.
The Generator Owner or Generator Operator reschedules its Generator 
Planned Outage at the Transmission Provider’s request: (a) the Proposed 
Generator Planned Outage is to occur 120 days or more in advance of the 
outage start date and 120 days or more beyond the end date of any 
previously scheduled outages for the generator unit; and (b) Generator 
Planned Outage has inadequate Maintenance Margin at time of submittal 
and moves to a time of adequate Maintenance Margin.  
iii.
The Transmission Provider may, at its discretion, grant a Tier 2 Planned 
Outage exemption if the Generator Owner or Generator Operator 
reschedules its Generator Planned Outage at the Transmission Provider’s 
request due to weather, forced outages, or other conditions listed in the 
Business Practices Manual for Outage Operations without regard to how 
many days in advance the outage was submitted or whether there was 
projected to be adequate Maintenance Margin for the duration of the 
outages.
B.
Tier 1 Planned Outage exemptions
i.
The Generator Owner or Generator Operator receives a Tier 2 Planned Outage 
exemption under section A.i above. 
ii. The Generator Owner or Generator Operator: (a) schedules its first Generator 
Planned Outage 120 days or more in advance of the outage start date and 120 
days or more beyond the end date of any previously scheduled outages for the 
generator unit; and (b) the Proposed Generator Planned Outage is to occur

MISO
SCHEDULE 53
FERC Electric Tariff
Seasonal Accredited Capacity Calculation
SCHEDULES
41.0.0, 42.0.0
Effective On: October 18, 2026
during a period when there is inadequate Maintenance Margin at the time the 
outage is provided to the Transmission Provider. There is inadequate margin 
when the Maintenance Margin is less than or equal to zero megawatts, for any 
day of outage, after subtracting the megawatts of the requested Proposed 
Generator Planned Outage. The request shall be determined based on highest 
queued request. 
iii. Subsequent generator unit outage requests 120 days or more in advance and/or 
Generator Owners or Generator Operators Generator Planned Outage less than 
120 days in advance and at least 31 days in advance of outage start date. 
Proposed Generator Planned Outage to occur entirely during a period in which 
the generator unit has an adequate projected margin, at the time the outage is 
provided to the Transmission Provider. There is adequate margin when the 
Maintenance Margin is greater than or equal to zero megawatts after 
subtracting the megawatts of the requested Proposed Generator Planned 
Outage. The request shall be determined based on highest queued request. 
iv. Generator Owners or Generator Operators Generator Planned Outage less than 
31 days in advance and at least 14 days in advance of outage start date. A 
Proposed Generator Planned Outage to occur entirely during a period the 
generator unit has an adequate Maintenance Margin at the time the outage is 
provided to the Transmission Provider and the outage passes the No Harm 
Test. There is adequate margin when the Maintenance Margin is greater than 
or equal to zero megawatts after subtracting the megawatts of the requested

MISO
SCHEDULE 53
FERC Electric Tariff
Seasonal Accredited Capacity Calculation
SCHEDULES
41.0.0, 42.0.0
Effective On: October 18, 2026
Proposed Generator Planned Outage. The request shall be determined based 
on highest queued request.
v. Generator Owner or Generator Operator reschedules its Generator Planned 
Outage at the Transmission Provider’s request due to inadequate Maintenance 
Margin for the duration of outage, at the time the outage is provided to the 
Transmission Provider.  Maintenance Margin is less than zero megawatts after 
subtracting the megawatts of the requested Proposed Generator Planned 
Outage.  This requirement does not include outages submitted less than 14 
days in advance of the start date. 
vi. The Transmission Provider may, at its discretion, grant a Tier 1 Planned 
Outage exemption if the Generator Owner or Generator Operator reschedules 
its Generator Planned Outage at the Transmission Provider’s request due to 
weather, forced outages, or other conditions listed in Business Practices 
Manual for Outage Operations without regard to how many days in advance 
the outage was submitted or whether there was projected to be adequate 
Maintenance Margin for the duration of the outages.
C.
No Harm Tests
Outages submitted between 14 to 30 days of start date will be evaluated for final 
approval and exemption status together.  The No Harm Tests include, but are not 
limited to, outage approval, compliance with all applicable operation guides, 
review of possible conflicting outages or system conditions, and system capacity 
(Maintenance Margin, Multiday Operational Margin, 30-day margin). It also

MISO
SCHEDULE 53
FERC Electric Tariff
Seasonal Accredited Capacity Calculation
SCHEDULES
41.0.0, 42.0.0
Effective On: October 18, 2026
includes the criteria outlined in the Business Practices Manual for Generator 
Outage.
D.
Limitation Provided by Transmission Provider or Transmission Operator
The Transmission Provider will grant the equivalent of a Tier 2 Planned Outage 
exemption if a Schedule 53 Resource is provided an operating limitation, such as 
thermal, voltage, or stability limits referenced in the BPM for Outage Operations, 
provided by the Transmission Provider or the Transmission Operator to preserve 
the reliability of the Transmission System, that is lower than the must offer 
obligation described in Section 69A.5.a.
III.
Resource Adequacy Hours
Resource Adequacy (RA) Hours represent the periods of highest risk and greatest need 
during a Season and throughout the year. They include hours during Maximum Generation 
Emergency declarations and the hours when the operating margin, a measure of available supply 
capacity above demand and reserve requirements, is at its lowest. 
Resource Adequacy Hours will be identified based on an evaluation of the three (3) most 
recent completed years using the period beginning September 1st and ending August 31st, which 
will be used to determine Resource Adequacy Hours for each Season (Seasonal RA Hours) and 
for each annual period (Annual RA Hours). Both Seasonal RA Hours and Annual RA Hours will 
be determined for the First Planning Area and Second Planning Area separately. The RA Hours 
determined in subpart III.A & III.B below are the only RA Hours that will be used to calculate 
Tier 2 ISAC in subpart V.C below. Where certain Seasonal RA Hours do not apply for a 
Resource due to a Tier 2 Planned Outage exemption or for periods where the Resource was not

MISO
SCHEDULE 53
FERC Electric Tariff
Seasonal Accredited Capacity Calculation
SCHEDULES
41.0.0, 42.0.0
Effective On: October 18, 2026
designated for RAR under Module E-1 of the Tariff and the Resource does not otherwise have 65 
RA Hours identified for the Season then a Seasonal RA Hour Deficiency exists per subpart 
III.A.iii and the Resource’s Annual Average Offered Capacity is multiplied by the Seasonal RA 
Hour Deficiency per subpart V.C of this Schedule 53.
A.
Seasonal RA Hours.  Seasonal RA Hours will include a target of 65 hours for 
each Season consisting of:
i.
All operating hours during any declared Maximum Generation Emergency 
in a Season, excluding any operating hour where a Resource has a Tier 2 
Planned Outage exemption or has periods where the Resource was not 
designated for RAR under Module E-1 of the Tariff.  If more than 65 of 
such hours exists for any Season, all will be considered Seasonal RA 
Hours, and;
ii.
If there are fewer than 65 hours identified for the Season in Section III.A.i 
above, additional hours will be identified up to a total of 65 starting with 
those hours with the lowest Operating Margin that is below a threshold of 
25 percent excluding any operating hour where a Resource has a Tier 2 
Planned Outage exemption or has periods where the Resource was not 
designated for RAR under Module E-1 of the Tariff, and;
iii.
If 65 hours have still not been identified, then a Seasonal RA Hours 
Deficiency exists which is the number of hours less than 65 for any 
Season.  
B.
Annual RA Hours will include of a target of 260 hours for each of the three (3)

MISO
SCHEDULE 53
FERC Electric Tariff
Seasonal Accredited Capacity Calculation
SCHEDULES
41.0.0, 42.0.0
Effective On: October 18, 2026
most recent periods beginning September 1st and ending August 31st consisting of:
i.
All hours during Maximum Generation Emergency declarations excluding 
any operating hour where a Resource has a Tier 2 Planned Outage 
exemption or has periods where the Resource was not designated for RAR 
under Module E-1 of the Tariff.  If more than 260 of such hours exists for 
any period, all will be considered Annual RA Hours, and;
ii.
If there are fewer than 260 hours identified for the period in Section III.B.i 
above, additional hours will be identified up to a total of 260 starting with 
those hours with the lowest Operating Margin that is below a threshold of 
25 percent excluding any operating hour where a Resource has a Tier 2 
Planned Outage exemption or has periods where the Resource was not 
designated for RAR under Module E-1 of the Tariff.
C.
Seasonal Non-RA Hours.  Seasonal Non-RA Hours will consist of all hours not 
included in Section III.A.i-iii. If a Resource has a Tier 1 and/or Tier 2 Planned 
Outage exemption for any of the operating hours identified as Seasonal Non-RA 
Hours or has periods where the Resource was not designated for RAR under 
Module E-1 of the Tariff, such hours will not be included in the applicable 
Seasonal Accredited Capacity calculation.
D.
Tier 1 Planned Outage exemptions apply only to Non-RA Hours.  Tier 2 Planned 
Outage exemptions apply for both RA Hours and Non-RA Hours referenced in 
this Schedule 53.
IV.
Operating Margin Calculation

MISO
SCHEDULE 53
FERC Electric Tariff
Seasonal Accredited Capacity Calculation
SCHEDULES
41.0.0, 42.0.0
Effective On: October 18, 2026
The Operating Margin is determined using historical information to identify Seasonal RA 
Hours and Annual RA Hours within the three (3) most recent periods beginning September 1st 
and ending August 31st.
Operating Margin Equation
Where:
For all Resources online and under normal dispatch control.
For Resources where all of the following is true: (i) Resource is Offline; (ii) it’s cold-start 
lead-time is less than or equal to 12 hours; and (iii) is not on outage.
V.
Seasonal Accredited Capacity Calculation
A.
Annual Average Offered Capacity (AAOC) will be determined for each Resource 
subject to this Schedule 53 and utilized in the Seasonal Accredited Capacity 
calculation as applicable. The AAOC for a Resource is calculated by averaging 
Hourly Emergency Maximum Limit, or Targeted Demand Reduction Level for 
DRR-1, during the Annual RA Hours identified in Section III.B above for each 
12-month period within the three (3) most recent periods beginning September 1st

MISO
SCHEDULE 53
FERC Electric Tariff
Seasonal Accredited Capacity Calculation
SCHEDULES
41.0.0, 42.0.0
Effective On: October 18, 2026
and ending August 31st.  For any Annual RA Hour where a Resource is offline 
and the sum of the Resource’s Start-Up Time and Start-Up Notification Time 
Offers exceeds 24 hours, the Resource’s Hourly Emergency Maximum Limit, or 
Targeted Demand Reduction Level for DRR-1, will be set to zero (0).
B.
Tier 1 Intermediate SAC (ISAC) is calculated as the sum of Hourly Emergency 
Maximum Limit, or Targeted Demand Reduction Level for DRR-1, during each 
of the Resource’s Seasonal Non-RA Hours, divided by the total number of 
Seasonal Non-RA Hours for each Season within the three (3) most recent periods 
beginning September 1st and ending August 31st.
C.
Tier 2 ISAC is calculated as the sum of Hourly Emergency Maximum Limit, or 
Targeted Demand Reduction Level for DDR-1, for the Resource’s Seasonal RA 
Hours, plus the product of: Annual Average Offered Capacity multiplied by the 
Seasonal RA Hour Deficiency; divided by the total number of Seasonal RA Hours 
plus the Seasonal RA Hour Deficiency for each Season within the three (3) most 
recent periods beginning September 1st and ending August 31st.  For any 
Seasonal RA Hour where a Resource is offline and the sum of the Resource’s 
Start-Up Time and Start-Up Notification Time Offers exceeds 24 hours, the 
Resource’s Hourly Emergency Maximum Limit, or Targeted Demand Reduction 
Level for DRR-1, will be set to zero (0).
D.
For purposes of paragraphs A through C above, the Hourly Emergency Maximum 
Limit, or Targeted Demand Reduction Level for DRR-1, will be capped at the 
currently effective GVTC value of the Resource.  If a Resource is committed for a

MISO
SCHEDULE 53
FERC Electric Tariff
Seasonal Accredited Capacity Calculation
SCHEDULES
41.0.0, 42.0.0
Effective On: October 18, 2026
portion of its ICAP due to partial clearing, the partial clearing will not reduce the 
values in the Offers considered in the accreditation calculations, which will be 
capped at the currently effective GVTC value of the Resource.
E.
In the case of an increase in generating Capacity of a Generation Resource, for 
purposes of paragraphs A through C above, the historical values for Hourly 
Emergency Maximum Limit will be adjusted up for those hours prior to such 
increase going into effect as set forth in the Business Practices Manual for 
Resource Adequacy.
F.
RA Hours will receive a greater weight than non-RA hours. 
G.
ISAC will be calculated using the following equation:
ISAC = ISACTier1_value × ISACTier1_weighting + ISACTier2_value × ISACTier2_weighting
Where:
Weighting by Planning Year
Tier
2023- 2024 
Planning Year
2024-2025 
Planning Year
2025-2026 Planning 
Year and beyond
ISAC𝑇𝑖𝑒𝑟1_𝑤𝑒𝑖𝑔ℎ𝑡𝑖𝑛𝑔
40%
30%
20%
ISAC𝑇𝑖𝑒𝑟2_𝑤𝑒𝑖𝑔ℎ𝑡𝑖𝑛𝑔
60%
70%
80%
H.
A system-wide conversion ratio will be determined using the following equation:
The system-wide conversion ratio will be determined on an annual basis 
consistent with the schedule established in the BPM.

MISO
SCHEDULE 53
FERC Electric Tariff
Seasonal Accredited Capacity Calculation
SCHEDULES
41.0.0, 42.0.0
Effective On: October 18, 2026
I.
Seasonal Accredited Capacity will be calculated for each Resource by multiplying 
its ISAC by the system-wide conversion ratio determined above using the 
following equation:
VI.
New Resources or Resources with Insufficient Performance Data
New Resources or existing Resources that do not have at least 60 days of Real-Time 
offered availability when designated for RAR over the last three (3) years for each Season 
(Summer, Fall, Winter, Spring) will have a SAC based on the Class Average SAC to ICAP Ratio 
for its Resource type, not to exceed the identified Coincident Peak Demand forecast of the ZG 
Associated Load, if any.  For Planning Year 2022/23 Schedule 53 Resources that were not 
committed under the annual construct during the period considered in the SAC calculations can 
direct MISO to accredit them in accord with their offers as described in Section IV above instead 
of using a class average.  Resources on a Catastrophic Generator Outage during a Season they 
are designated for RAR may elect to use a SAC based on the Class Average SAC to ICAP Ratio 
for its Resource type, not to exceed the identified Coincident Peak Demand forecast of the ZG 
Associated Load, if any, the next time it is accredited for that Season provided all of its 
committed ZRCs were replaced with Uncleared ZRCs and that it has successfully returned from 
the Catastrophic Generator Outage.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
ATTACHMENT X 
 
GENERATOR INTERCONNECTION PROCEDURES (GIP) 
 
 
SECTION 1. DEFINITIONS. 
 
10 kW Inverter Process shall mean the procedure for evaluating an Interconnection 
Request for a certified inverter-based Small Generating Facility no larger than 10 kW that uses 
the screen set forth in Section 14. 
 
Adverse System Impact shall mean the negative effects due to technical or operational 
limits on conductors or equipment being exceeded that may compromise the safety and 
reliability of the electric system. 
 
Affected System(s) shall mean an electric transmission system or the electric system 
associated with an Existing Generating Facility or of a higher queued Generating Facility, which 
is an electric system other than the Transmission Provider’s Transmission System that is affected 
by the Interconnection Request.  An Affected System may or may not be subject to FERC 
jurisdiction. 
 
Affected System Interconnection Customer shall mean any entity that submits an 
interconnection request for a Generating Facility to a transmission system other than 
Transmission Provider’s Transmission System that may cause the need for Affected System 
Network Upgrades on the Transmission Provider’s Transmission System. 
 
Affected System Network Upgrades shall mean the additions, modifications, and 
upgrades to Transmission Provider’s Transmission System required to accommodate Affected 
System Interconnection Customer’s proposed interconnection to a transmission system other 
than Transmission Provider’s Transmission System.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Affected System Operator shall mean the entity that operates an Affected System. 
 
Affected System Queue Position shall mean the queue position of an Affected System 
Interconnection Customer in Transmission Provider’s interconnection queue relative to 
Transmission Provider’s Interconnection Customers’ Queue Position. 
 
Affected System Study shall mean the evaluation of Affected System Interconnection 
Customers’ proposed interconnection(s) to a transmission system other than the Transmission 
Provider’s Transmission System that have an impact on Transmission Provider’s Transmission 
System, as described in Section 8 of this GIP. 
 
Affected System Study Agreement shall mean the agreement contained in Appendix 16 
to this GIP that is made between Transmission Provider and host transmission provider, in 
absence of JOA, JPA, or other agreement filed with the Commission, as noted in Section 8 of 
this GIP. 
 
Affected System Study Report shall mean the report issued following completion of an 
Affected System Study. 
 
Affiliate shall mean, with respect to a corporation, partnership or other entity, each such 
other corporation, partnership or other entity that directly or indirectly, through one or more 
intermediaries, controls, is controlled by, or is under common control with, such corporation, 
partnership or other entity. 
 
Ancillary Services shall mean those services that are necessary to support the 
transmission of capacity and energy from resources to loads while maintaining reliable operation 
of the Transmission System in accordance with Good Utility Practice. 
 
Applicable Laws and Regulations shall mean all duly promulgated applicable federal, 
state and local laws, regulations, rules, ordinances, codes, decrees, judgments, directives, or

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
judicial or administrative orders, permits and other duly authorized actions of any Governmental 
Authority having jurisdiction over the Parties, their respective facilities and/or the respective 
services they provide.  
 
Applicable Reliability Standards shall mean the requirements and guidelines of the 
Electric Reliability Organization and the Balancing Authority Area of the Transmission System 
to which the Generating Facility is directly interconnected. 
 
Automatic Withdrawal Penalty shall mean the penalty assessed by Transmission 
Provider to an Interconnection Customer that chooses to withdraw or is deemed to have 
withdrawn its Interconnection Request from Transmission Provider’s interconnection queue in 
certain specified circumstances.  The calculation of the Withdrawal Penalty is set forth in Section 
7.6.2.1.1 of this GIP. 
 
Balancing Authority shall mean an entity that integrates resource plans ahead of time, 
maintains demand and resource balance within a Balancing Authority Area, and supports 
interconnection frequency in real time. 
 
Balancing Authority Area shall mean the collection of generation, transmission, and 
loads within the metered boundaries of the Balancing Authority.  The Balancing Authority 
maintains load-resource balance within this area. 
 
Base Case shall mean the base case power flow, short circuit, and stability databases 
used for the Interconnection Studies by Transmission Provider or Interconnection Customer. 
 
Base Case Data shall mean base case power flow, short circuit and stability databases, 
including all underlying assumptions, and contingency lists.  Such databases and lists, hereinafter 
referred to as Base Cases, shall include all (1) generation projects and (2) transmission projects, 
including merchant transmission projects that are proposed for the Transmission System for 
which a transmission expansion plan has been submitted and approved by the MISO Board.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
 
Breach shall mean the failure of a Party to perform or observe any material term or 
condition of the Generator Interconnection Agreement. 
 
Breaching Party shall mean a Party that is in Breach of the Generator Interconnection 
Agreement. 
 
Business Day shall mean Monday through Friday, excluding Federal Holidays. 
 
Calendar Day shall mean any day including Saturday, Sunday or a Federal Holiday. In 
the event that a period specified in this GIP is calculated in Calendar Days ends on a non-
business day, such period shall be deemed to conclude on the following business day. 
 
Cluster shall mean a group of one or more Interconnection Requests that are studied 
together for the purpose of conducting a Group Study. 
 
Commercial Operation shall mean the status of a Generating Facility that has 
commenced generating electricity for sale, excluding electricity generated during Trial 
Operation. 
 
Commercial Operation Date (COD) of a unit shall mean the date on which the 
Generating Facility commences Commercial Operation as agreed by the Parties pursuant to 
Appendix E to the Generator Interconnection Agreement. 
 
Commitment Projection shall mean a projection of the number of MW expected to 
commit to the JTIQ Portfolio from ERAS and all DPP study clusters that already have passed 
DP1 as described in Section 9.4.2.e.ii of Rate Schedule 6 (MISO SPP-JOA).  
 
Common Use Upgrade shall mean an Interconnection Facility, Network Upgrade, 
System Protection Facility, or any other classified addition, alteration, or improvement on the

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Transmission System or the transmission system of an Affected System, not classified under 
Attachment FF as a Baseline Reliability Project, Market Efficiency Project, or Multi-Value 
Project, that is needed for the interconnection of multiple Interconnection Customers’ Generating 
Facilities and which is the shared responsibility of such Interconnection Customers.   
 
Confidential Information shall mean any proprietary or commercially or competitively 
sensitive information, trade secret or information regarding a plan, specification, pattern, 
procedure, design, device, list, concept, policy or compilation relating to the present or planned 
business of a Party, or any other information as specified in Article 22 of the GIA, which is 
designated as confidential by the Party supplying the information, whether conveyed orally, 
electronically, in writing, through inspection, or otherwise, that is received by another Party. 
 
Connection Facilities shall mean the Transmission Owner’s Connection Facilities and 
the MHVDC Connection Customer’s Connection Facilities, as defined in the MHCP. 
 
Contingent Facilities shall mean those unbuilt Interconnection Facilities and Network 
Upgrades upon which the Interconnection Request’s costs, timing and study findings are 
dependent, and if delayed or not built, could cause a need for restudies of the Interconnection 
Request or a reassessment of the Interconnection Facilities and/or Network Upgrades and/or 
costs and timing.  Contingent Facilities may include facilities identified in MTEP that if delayed 
or not built could impact the timing of the Interconnection Request. 
 
Customer Engagement Window shall mean the time period prior to the start of 
Definitive Planning Phase I set forth in Section 3.3.4 of this GIP. 
 
Default shall mean the failure of a Breaching Party to cure its Breach in accordance with 
Article 17 of the Generator Interconnection Agreement. 
 
Definitive Planning Phase shall mean the Generator Interconnection Procedures process 
which leads to a Generator Interconnection Agreement.  An Interconnection Customer enters the

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Definitive Planning Phase pursuant to GIP Section 7.2.  The Definitive Planning Phase includes 
three distinct phases (Definitive Planning Phases I, II, and III) pursuant to Section 7 of the 
Generator Interconnection Procedures. 
 
Definitive Planning Phase Queue Position shall mean the order of a valid 
Interconnection Request, relative to all other pending valid Interconnection Requests, in the 
Definitive Planning Phase.  The Definitive Planning Phase Queue Position is established based 
upon the date of initial submission of the Interconnection Request provided that the 
Interconnection Request subsequently satisfies all of the requirements of GIP Section 7.2 of the 
Generator Interconnection Procedures to enter the Definitive Planning Phase and is accepted as 
valid by the Transmission Provider.  All Interconnection Requests within the same Definitive 
Planning Phase cycle shall have equal priority (i.e. similarly queued). 
 
Demonstrated Capability shall mean the continuous net real power output that the 
Generating Facility is required to demonstrate in compliance with Applicable Reliability 
Standards.   
 
Dispute Resolution shall mean the procedure for resolution of a dispute between or 
among the Parties in which they will first attempt to resolve the dispute on an informal basis.  
 
Distribution System shall mean the Transmission Owner’s facilities and equipment, or 
the Distribution System of another party that is interconnected with Transmission Owner’s 
Transmission System, if any, connected to the Transmission System, over which facilities 
Transmission Service or Wholesale Distribution Service under the Tariff is available at the time 
Interconnection Customer has requested interconnection of a Generating Facility for the purpose 
of either transmitting electric energy in interstate commerce or selling electric energy at 
wholesale in interstate commerce and which are used to transmit electricity to ultimate usage 
points such as homes and industries directly from nearby generators or from interchanges with 
higher voltage transmission networks which transport bulk power over longer distances.  The 
voltage levels at which distribution systems operate differ among Local Balancing Authorities

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
and other entities owning distribution facilities interconnected to the Transmission System.   
 
Distribution Upgrades shall mean the additions, modifications, and upgrades to the 
Distribution System at or beyond the Point of Interconnection to facilitate interconnection of the 
Generating Facility and render the delivery service necessary to affect Interconnection 
Customer’s wholesale sale of electricity in interstate commerce.  Distribution Upgrades do not 
include Interconnection Facilities. 
 
Effective Date shall mean the date on which the Generator Interconnection Agreement 
becomes effective upon execution by the Parties subject to acceptance by the Commission, or if 
filed unexecuted, upon the date specified by the Commission. 
 
Electric Reliability Organization shall mean the North American Electric Reliability 
Corporation or its successor organization. 
 
Emergency Condition shall mean a condition or situation:  (1) that in the reasonable 
judgment of the Party making the claim is imminently likely to endanger, or is contributing to 
the endangerment of, life, property, or public health and safety; or (2) that, in the case of either 
Transmission Provider or Transmission Owner, is imminently likely (as determined in a non-
discriminatory manner) to cause a material adverse effect on the security of, or damage to the 
Transmission System, Transmission Owner’s Interconnection Facilities or the electric systems of 
others to which the Transmission System is directly connected; or (3) that, in the case of 
Interconnection Customer, is imminently likely (as determined in a non-discriminatory manner) 
to cause a material adverse effect on the security of, or damage to, the Generating Facility or 
Interconnection Customer’s Interconnection Facilities.  System restoration and blackstart shall be 
considered Emergency Conditions; provided that Interconnection Customer is not obligated by 
the Generator Interconnection Agreement to possess blackstart capability.  Any condition or 
situation that results from lack of sufficient generating capacity to meet load requirements or that 
results solely from economic conditions shall not constitute an Emergency Condition, unless one 
of the enumerated conditions or situations identified in this definition also exists.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
 
Energy Displacement Agreement shall mean an agreement between an Interconnection 
Customer with an Existing Generating Facility on the Transmission Provider’s Transmission 
System and an Interconnection Customer with a proposed Generating Facility seeking to 
interconnect with Surplus Interconnection Service.  The Energy Displacement Agreement 
specifies the term of operation, the Generating Facility Interconnection Service limit, and the 
mode of operation for energy production (common or singular operation). 
 
Energy Resource Interconnection Service (ER Interconnection Service) shall mean 
an Interconnection Service that allows Interconnection Customer to connect its Generating 
Facility to the Transmission System or Distribution System, as applicable, to be eligible to 
deliver the Generating Facility’s electric output using the existing firm or non-firm capacity of 
the Transmission System on an as available basis.  Energy Resource Interconnection Service 
does not convey transmission service. 
 
Engineering & Procurement (E&P) Agreement shall mean an agreement that 
authorizes Transmission Owner to begin engineering and procurement of long lead-time items 
necessary for the establishment of the interconnection in order to advance the implementation of 
the Interconnection Request. 
 
Environmental Law shall mean Applicable Laws or Regulations relating to pollution or 
protection of the environment or natural resources.  
 
Existing Generating Facility shall mean a Generating Facility that is either under 
construction or is in service, and has an unsuspended interconnection agreement with its host 
transmission provider. 
 
Expanded Scope Analysis shall mean the analysis described in Section 9.4.2.d.iv.a of 
Rate Schedule 6 (MISO-SPP JOA).

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Expedited Resource Addition Study (ERAS) shall mean the temporary procedure for 
expediting interconnection projects identified for claimed resource adequacy and/or reliability 
needs. 
 
Expedited Resource Addition Study (ERAS) Quarterly Study Period shall mean the 
period of time in which ERAS Interconnection Requests are submitted to the Transmission 
Provider and compiled for study.  There are four study periods in a year with the following start 
and end dates: 
Quarter 1: The first Business Day of March through the last Business Day of May; 
Quarter 2: The first Business Day of June through the last Business Day of August; 
Quarter 3: The first Business Day of September through the last Business Day of 
November; 
Quarter 4: The first Business Day of December through the last Business Day of 
February. 
 
Expedited Generator Interconnection Agreement (EGIA) shall mean the 
interconnection agreement for the Expedited Resource Addition Study established between the 
Transmission Provider and/or the Transmission Owner and the Interconnection Customer as set 
forth in Section 3.9 of this Attachment X.  This agreement shall take the form of the 
Transmission Provider’s pro forma Generator Interconnection Agreement modified for the 
Expedited Resource Addition Study.  Unless otherwise provided in the GIP, all requirements 
applicable to the pro forma Generator Interconnection Agreement shall apply to the Expedited 
Generator Interconnection Agreement. 
 
Facilities Construction Agreement (FCA) shall mean the form of facilities construction 
agreement, set forth in Appendix 8 to these Generator Interconnection Procedures.  The FCA 
shall be used when an Interconnection Customer or an Affected System Interconnection 
Customer causes the need for the construction of Network Upgrades, Affected System Network 
Upgrades, or System Protection Facilities on the transmission system of the Transmission 
Provider.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
 
Fast Track Process shall mean the procedure for evaluating an Interconnection Request 
for a certified Small Generating Facility no larger than five MW that includes the screen set forth 
in Section 14, customer options meeting, and optional supplemental review. 
 
Federal Holiday shall mean a Federal Reserve Bank holiday for a Party that has its 
principal place of business in the United States and a Canadian Federal or Provincial banking 
holiday for a Party that has its principal place of business located in Canada. 
 
Federal Power Act shall mean the Federal Power Act, as amended, 16 U.S.C. §§ 791a 
et seq. 
 
FERC shall mean the Federal Energy Regulatory Commission, also known as 
Commission, or its successor. 
 
Final System Impact Study shall mean the Interconnection System Impact Study 
performed during Definitive Planning Phase III. 
 
Force Majeure shall mean any act of God, labor disturbance, act of the public enemy, 
war, insurrection, riot, fire, storm or flood, explosion, breakage or accident to machinery or 
equipment, any order, regulation or restriction imposed by governmental, military or lawfully 
established civilian authorities, or any other cause beyond a Party’s control.  A Force Majeure 
event does not include an act of negligence or intentional wrongdoing by the Party claiming 
Force Majeure. 
 
Generating Facility shall mean Interconnection Customer’s device(s) for the production 
and/or storage for later injection of electricity identified in the Interconnection Request, but shall 
not include the Interconnection Customer’s Interconnection Facilities and shall not include a 
SATOA as defined in Module A. A Generating Facility consists of one or more generating 
unit(s) and/or storage device(s) which usually can operate independently and be brought online

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
or taken offline individually. 
 
Generating Facility Capacity shall mean the net capacity of the Generating Facility and 
the aggregate net capacity of the Generating Facility where it includes more than one device for 
the production and/or storage for later injection of electricity. 
 
Generating Facility Modification shall mean modification to an Existing Generating 
Facility, including comparable replacement of only a portion of the equipment at the Existing 
Generating Facility. 
 
Generating Facility Replacement shall mean replacement of one or more generating 
units and/or storage devices at an Existing Generating Facility with one or more generating units 
or storage devices at the same electrical Point of Interconnection as those being decommissioned 
and electrically disconnected.  
 
Generator Interconnection Agreement (GIA) shall mean the form of interconnection 
agreement, set forth in Appendix 6 to these Generator Interconnection Procedures. 
 
Generator Interconnection Procedures (GIP) shall mean the interconnection 
procedures set forth herein. 
 
Generator Upgrades shall mean the additions, modifications, and upgrades to the 
electric system of an Existing Generating Facility or of a higher queued Generating Facility at or 
beyond the Point of Interconnection to facilitate interconnection of the Generating Facility and 
render the Transmission Service necessary to affect Interconnection Customer’s wholesale sale 
of electricity in interstate commerce. 
 
Good Utility Practice shall mean any of the practices, methods and acts engaged in or 
approved by a significant portion of the electric industry during the relevant time period, or any 
of the practices, methods and acts which, in the exercise of reasonable judgment in light of the

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
facts known at the time the decision was made, could have been expected to accomplish the 
desired result at a reasonable cost consistent with good business practices, reliability, safety and 
expedition.  Good Utility Practice is not intended to be limited to the optimum practice, method, 
or act to the exclusion of all others, but rather to be acceptable practices, methods, or acts 
generally accepted in the region. 
 
Governmental Authority shall mean any federal, state, local or other governmental 
regulatory or administrative agency, court, commission, department, board, or other 
governmental subdivision, legislature, rulemaking board, tribunal, or other governmental 
authority having jurisdiction over the Parties, their respective facilities, or the respective services 
they provide, and exercising or entitled to exercise any administrative, executive, police, or 
taxing authority or power; provided, however, that such term does not include Interconnection 
Customer, Transmission Provider, Transmission Owner, or any Affiliate thereof. 
 
Group Restudy shall mean a restudy of a Group Study conducted pursuant to Section 
7.5 of this GIP. 
 
Group Study(ies) shall mean the evaluation of one or more Interconnection Requests 
within a Cluster as described in Section 7 of this GIP.  Group Studies are divided into phases as 
described in section 7.3 of this GIP. 
 
Hazardous Substances shall mean any chemicals, materials or substances defined as or 
included in the definition of “hazardous substances,” “hazardous wastes,” “hazardous materials,” 
“hazardous constituents,” “restricted hazardous materials,” “extremely hazardous substances,” 
“toxic substances,” “radioactive substances,” “contaminants,” “pollutants,” “toxic pollutants” or 
words of similar meaning and regulatory effect under any applicable Environmental Law, or any 
other chemical, material or substance, exposure to which is prohibited, limited or regulated by 
any applicable Environmental Law.  
 
HVDC Facilities shall mean the high voltage direct current transmission facilities,

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
including associated alternating current facilities, if any, that are subject to Section 27A of the 
Tariff and that are specifically identified in (i) any Agency Agreement pertaining to such 
facilities between Transmission Provider and Transmission Owner that owns or operates such 
facilities, or (ii) in any other arrangement that permits or will permit Transmission Provider to 
provide HVDC Service over such facilities as set forth in Section 27A of the Tariff. 
 
HVDC Service shall mean Firm and Non-Firm Point-To-Point Transmission Service 
provided by Transmission Provider on HVDC Facilities pursuant to Section 27A of the Tariff. 
 
Initial Synchronization Date shall mean the date upon which the Generating Facility is 
initially synchronized and upon which Trial Operation begins. 
 
Injection Rights shall mean the Transmission Provider’s pre-certification of the 
Transmission System’s capability to receive capacity and energy from the MHVDC 
Transmission Line at the requested Point of Connection, and in the specified MW quantity, 
without degrading the reliability of the Transmission System, as described in Section 16 of the 
GIP and Section 3.2.3 of the MHCP. 
 
In-Service Date (ISD) shall mean the date upon which Interconnection Customer 
reasonably expects it will be ready to begin use of the Transmission Owner’s Interconnection 
Facilities to obtain back feed power. 
 
Interconnection Customer shall mean any entity, including Transmission Provider, 
Transmission Owner or any of the Affiliates or subsidiaries of either, that proposes to 
interconnect its Generating Facility with the Transmission System. 
 
Interconnection Customer Decision Point I shall mean the time period beginning when 
the Interconnection Customer is provided the Preliminary System Impact Study results including 
cost estimates for upgrades and concludes after fifteen (15) Business Days.

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Interconnection Customer Decision Point II shall mean the time period beginning 
when the Interconnection Customer is provided the Revised System Impact Study results 
including cost estimates for upgrades and concludes after fifteen (15) Business Days. 
 
Interconnection Customer’s Interconnection Facilities (ICIF) shall mean all facilities 
and equipment, as identified in Appendix A of the Generator Interconnection Agreement, that 
are located between the Generating Facility and the Point of Change of Ownership, including 
any modification, addition, or upgrades to such facilities and equipment necessary to physically 
and electrically interconnect the Generating Facility to the Transmission System or Distribution 
System, as applicable.  Interconnection Customer’s Interconnection Facilities are sole use 
facilities. 
 
Interconnection Facilities shall mean the Transmission Owner’s Interconnection 
Facilities and the Interconnection Customer’s Interconnection Facilities.  Collectively, 
Interconnection Facilities include all facilities and equipment between the Generating Facility 
and the Point of Interconnection, including any modification, additions or upgrades that are 
necessary to physically and electrically interconnect the Generating Facility to the Transmission 
System.  Interconnection Facilities shall not include Distribution Upgrades, Generator Upgrades, 
Stand Alone Network Upgrades or Network Upgrades. 
 
Interconnection Facilities Study(ies) shall mean a study conducted by Transmission 
Owner, or its agent, for Interconnection Customer(s)  to determine a list of facilities (including 
Interconnection Customer’s Interconnection Facilities or Affected System Interconnection 
Customer’s interconnection facilities, Transmission Owner’s Interconnection Facilities, System 
Protection Facilities, and if such upgrades have been determined, Network Upgrades, 
Distribution Upgrades, Generator Upgrades, Common Use Upgrades, and Affected System 
Network Upgrades, as identified in the Interconnection System Impact Study, Affected System 
Study, or Affected System Operator’s applicable study), the cost of those facilities, and the time 
required to interconnect with the Transmission System or the Affected System Operator’s 
transmission system.

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ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
 
Interconnection Request shall mean (1) an Interconnection Customer’s request, in the 
form of Appendix 1 to the Generator Interconnection Procedures, to interconnect a new 
Generating Facility or a request for the Expedited Resource Addition Study for a new generation 
capacity, or to increase the capacity of, or make a Material Modification to the operating 
characteristics of, an Existing Generating Facility that is interconnected with the Transmission 
System, or to interconnect an Existing Generating Facility that is external to the Transmission 
System, or to change Energy Resource Interconnection Service to Network Resource 
Interconnection Service for an Existing Generating Facility; or (2) an MHVDC Connection 
Customer’s request, in the form of Appendix 1 to the Generator Interconnection Procedures, to 
obtain Injection Rights. 
 
Interconnection Service shall mean the service provided by Transmission Provider 
associated with interconnecting the Generating Facility to the Transmission System, or external 
host transmission provider if applicable, and enabling it to receive electric energy and capacity 
from the Generating Facility at the Point of Interconnection pursuant to the terms of the 
Generator Interconnection Agreement or Point of Delivery as set forth in Service Agreement for 
Network Resource Interconnection Service for an External Generating Facility and, if applicable, 
the Tariff. 
 
Interconnection Study (or Study) shall mean any of the following studies: the 
Replacement Impact Study, the Reliability Assessment Study, the Optional Interconnection 
Study, the Interconnection System Impact Study including evaluations for Surplus 
Interconnection Service, and the Interconnection Facilities Study, or the Restudy of any of the 
above, described in the Generator Interconnection Procedures. 
 
Interconnection System Impact Study shall mean an engineering study that evaluates 
the impact of the proposed interconnection on the safety and reliability of Transmission System 
and, if applicable, an Affected System.  The study shall identify and detail the system impacts 
that would result if the Generating Facility were interconnected without project modifications or

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
system modifications, or to study potential impacts, including but not limited to those identified 
in the Scoping Meeting as described in the Generator Interconnection Procedures. 
 
Interconnection Study Agreement shall mean the forms of agreement contained in 
Attachment B to Appendix 1 of the Generator Interconnection Procedures for conducting all 
studies required by the Generator Interconnection Procedures. 
 
IRS shall mean the Internal Revenue Service. 
 
Joint Operating Agreement (“JOA”) shall mean an agreement between adjacent 
balancing authorities or transmission providers for the coordination of operations. 
 
Joint Planning Agreement (“JPA”) shall mean an agreement between adjacent 
balancing authorities or transmission providers for the coordination of planning. 
 
Joint Operating Agreement between the Midcontinent Independent System 
Operator, Inc. and Southwest Power Pool, Inc. (MISO-SPP JOA) shall mean Rate Schedule 
6 to the MISO Tariff. 
 
Joint Targeted Interconnection Queue (JTIQ) shall refer to the study and processes 
described in Section 9.4.2 of Rate Schedule 6 (MISO-SPP JOA). 
 
Joint Targeted Interconnection Queue Study (“JTIQ Study”) shall mean a 
transmission planning study conducted jointly by SPP and MISO to facilitate the interconnection 
of new generator capacity in both Parties’ regions. 
 
JTIQ Commitment Group Member shall mean any JTIQ Commitment Group Member 
included in a Commitment Group consistent with Section 9.4 of Rate Schedule 6 (MISO-SPP 
JOA).

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
JTIQ Commitment Group or Commitment Group shall mean a group of JTIQ 
Commitment Group Members that have executed a JTIQ Generator Interconnection Agreement 
within the twelve (12) month period ending April 30th of each year.  The Commitment Group 
shall also include JTIQ Commitment Group Members for which a JTIQ Generator 
Interconnection Agreement has been filed unexecuted by SPP or the Transmission Provider and 
the Commission has accepted the agreement within the twelve (12) month period ending April 
30th of each year. 
 
JTIQ Generator Charge shall mean the charge to JTIQ Commitment Group Members 
to recover the JTIQ Commitment Group Member’s share of the JTIQ Monthly Revenue 
Requirement for each of the JTIQ Upgrades in the JTIQ Portfolio in the Transmission Provider’s 
Region. 
 
JTIQ Participation Group shall mean the group of Interconnection Requests that shall 
consist of all interconnection customers included in the JTIQ Screening Groups whose 
interconnection request meets the distribution factor and impact criteria specified in Section 
9.4.2(d)((ii) of Rate Schedule 6 (MISO-SPP JOA). 
 
JTIQ Portfolio shall mean a group of JTIQ Upgrades identified pursuant to Section 9.4 
of Rate Schedule 6 (MISO-SPP JOA). 
 
JTIQ Screening Group shall mean a group of MISO Interconnection Customers and 
SPP interconnection customers whose Interconnection Requests will be screened for inclusion in 
a JTIQ Participation Group. The JTIQ Screening Group shall consist of all interconnection 
customers who have submitted interconnection requests into a MISO ERAS, SPP ERAS, DPP 
study cluster, or SPP DISIS study cluster that: (1) has a study commencement or kick off date 
that is after the date that the Parties’ respective Boards of Directors have approved a JTIQ 
Portfolio; and (2) has not commenced DPP Phase I, a MISO ERAS, the SPP ERAS, or DISIS 
Phase One studies pursuant to each party’s OATT as of the date that the Parties have declared 
the JTIQ Portfolio fully subscribed.

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ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
 
JTIQ Service Agreements shall mean the JTIQ Commitment Agreement attached to the 
MISO GIA as Appendix 17 and the SPP’s pro forma agreement(s)  that obligate interconnection 
customers to provide security for and  pay the JTIQ Generator Charge for JTIQ Network 
Upgrades included in the applicable JTIQ Portfolio. 
 
JTIQ Upgrade shall mean a Network Upgrade included in a JTIQ portfolio pursuant to 
Section 9.4 of Rate Schedule 6 (MISO-SPP JOA).  
 
Local Balancing Authority shall mean an operational entity or a Joint Registration 
Organization which is (i) responsible for compliance with the subset of the Electric Reliability 
Organization Balancing Authority Reliability Standards defined in the Balancing Authority 
Agreement for their local area within the MISO Balancing Authority Area, (ii) a Party to 
Balancing Authority Agreement, excluding MISO, and (iii) provided in the Balancing Authority 
Agreement. 
 
Local Resource Zone (LRZ) shall mean a geographic area within the Transmission 
Provider Region that is prescribed by the Transmission Provider, based upon the criteria in 
Section 68A.3, to address congestion that limits Planning Resource deliverability. 
 
Loss shall mean any and all damages, losses, claims, including claims and actions 
relating to injury to or death of any person or damage to property, demand, suits, recoveries, 
costs and expenses, court costs, attorney fees, and all other obligations by or to third parties, 
arising out of or resulting from the other Party’s performance, or non-performance of its 
obligations under the Generator Interconnection Agreement on behalf of the indemnifying Party, 
except in cases of gross negligence or intentional wrongdoing, by the indemnified party. 
 
Material Modification shall mean: (1) modification to an Interconnection Request in the 
queue that has a material adverse impact on the cost or timing of any other Interconnection 
Request with an equal or later queue priority date; or a Qualified Change.

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
 
Merchant HVDC Connection Customer (MHVDC Connection Customer) shall mean 
any entity that proposes to interconnect an MHVDC Transmission Line with the Transmission 
System, as set forth in the MHCP. 
 
Merchant HVDC Connection Procedures (MHCP) shall mean the connection 
procedures set forth in Attachment GGG to the Tariff. 
 
Merchant HVDC Transmission Connection Request (MHVDC Transmission 
Connection Request) shall mean an MHVDC Connection Customer’s request, in the form of 
Appendix 1 to the MHCP to interconnect a new MHVDC Transmission Line, increase the 
capacity of an existing MHVDC Transmission Line, or make a substantial modification to the 
operating characteristics of an existing MHVDC Transmission Line. 
 
Merchant HVDC Transmission Connection Agreement (Transmission Connection 
Agreement or TCA) shall mean the form of the transmission connection agreement for 
merchant HVDC transmission facilities set forth in Appendix 2 to the MHCP. 
 
Merchant HVDC Transmission Line (MHVDC Transmission Line) shall mean the 
merchant high voltage direct current transmission line external to the Transmission System that 
is proposed for connection to the Transmission System, as defined in the MHCP. 
 
Metering Equipment shall mean all metering equipment installed or to be installed at 
the Generating Facility, Interconnection Customer’s Interconnection Facilities, and/or 
Transmission Owner's Interconnection Facilities pursuant to the Generator Interconnection 
Agreement at the metering points, including but not limited to instrument transformers, MWh-
meters, data acquisition equipment, transducers, remote terminal unit, communications 
equipment, phone lines, and fiber optics. 
 
Monitoring and Consent Agreement shall mean an agreement that defines the terms

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
and conditions applicable to a Generating Facility acquiring Surplus Interconnection Service.  
The Monitoring and Consent Agreement will list the roles and responsibilities of an 
Interconnection Customer seeking to interconnect with Surplus Interconnection Service and 
Transmission Owner to maintain the total output of the Generating Facility inside the parameters 
delineated in the GIA. 
 
Multi-Party Facilities Construction Agreement (MPFCA) shall mean the form of 
facilities construction agreement, set forth in Appendix 9 to these Generator Interconnection 
Procedures.  The MPFCA shall be used when multiple Interconnection Requests or 
interconnection requests from Affected System Interconnection Customers cause the need for the 
construction of Common Use Upgrades on the Transmission System and share cost 
responsibility for such Common Use Upgrades.   
 
Network Customer shall have that meaning as provided in the Tariff. 
 
Network Resource shall mean any designated generating resource owned, purchased, or 
leased by a Network Customer under the Tariff.  Network Resources do not include any 
resource, or any portion thereof, that is committed for sale to third parties or otherwise cannot be 
called upon to meet the Network Customer’s Network Load on a non-interruptible basis. 
 
Network Resource Interconnection Service (NR Interconnection Service) shall mean 
an Interconnection Service that allows Interconnection Customer to integrate its Generating 
Facility with the Transmission System in the same manner as for any Generating Facility being 
designated as a Network Resource.  Network Resource Interconnection Service does not convey 
transmission service.  Network Resource Interconnection Service shall include any network 
resource interconnection service established under an agreement with, or the tariff of, a 
Transmission Owner prior to integration into MISO, that is determined to be deliverable through 
the integration deliverability study process. 
 
Network Upgrades shall mean the additions, modifications, and upgrades to the

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ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Transmission System required at or beyond the point at which the Interconnection Facilities 
connect to the Transmission System or Distribution System, as applicable, to accommodate the 
interconnection of the Generating Facility(ies) to the Transmission System.  Network Upgrades 
shall not include any HVDC Facility Upgrades. 
 
Notice of Dispute shall mean a written notice of a dispute or claim that arises out of or in 
connection with the Generator Interconnection Agreement or its performance. 
 
Optional Interconnection Study shall mean a sensitivity analysis based on assumptions 
specified by Interconnection Customer in the Optional Interconnection Study Agreement. 
 
Optional Interconnection Study Agreement shall mean the form of agreement 
contained in Appendix 5 of the Generator Interconnection Procedures for conducting the 
Optional Interconnection Study. 
 
Outage Transfer Distribution Factor (OTDF) Outage Transfer Distribution Factor, as 
defined by the Electric Reliability Organization. 
 
Party or Parties shall mean Transmission Provider, Transmission Owner, 
Interconnection Customer, or any combination of the above. 
 
Permissible Technological Advancement shall mean advancements to turbines, 
inverters, plant supervisory controls, excitation systems, or other technological advancements 
submitted to the Transmission Provider prior to the issuance of a draft Generator Interconnection 
Agreement for such project provided that such advancements does not: (1) degrade the electrical 
characteristics of the generating equipment; (2) does not cause any material adverse impact on the 
Transmission System with regard to short circuit capability limits, steady-state thermal and 
voltage limits, or dynamic system stability and response; (3) does not increase the installed 
capacity of the Generating Facility; or (4) change the fuel source of the proposed Generating

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Facility.   
 
Point of Change of Ownership (PCO) shall mean the point, as set forth in Appendix A 
to the Generator Interconnection Agreement, where the Interconnection Customer’s 
Interconnection Facilities connect to the Transmission Owner’s Interconnection Facilities. 
 
Point of Connection shall mean the point, as set forth in an MHVDC Transmission 
Connection Request, where the MHVDC Transmission Line connects to the Transmission 
System. 
 
Point of Interconnection (POI) shall mean the point, as set forth in Appendix A of the 
GIA, where the Interconnection Facilities connect to the Transmission System. 
 
Point(s) of Withdrawal (POW) shall mean the point(s) where a non-transmission 
facility that is used to withdraw Energy from the Transmission System to serve Load connects to 
the Transmission System. 
 
Potential MW Total shall mean a projection of the number of MW that may commit to 
the JTIQ Portfolio from all ERAS and study clusters to date, including the current study 
cluster(s).   
 
Power Transfer Distribution Factor (PTDF) Power Transfer Distribution Factor, as 
defined by the Electric Reliability Organization. 
 
Preliminary System Impact Study shall mean the Interconnection System Impact Study 
performed during Definitive Planning Phase I 
 
Pre-Queue Phase shall mean Interconnection Customer outreach and education effort 
undertaken prior to the submission of the Interconnection Request.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Proportional Impact Method shall mean a technical analysis conducted by 
Transmission Provider to determine the degree to which each Generating Facility in the Group 
Study contributes to the need for a specific Network Upgrade. 
 
Provisional Generator Interconnection Agreement shall mean the interconnection 
agreement for Provisional Interconnection Service established between the Transmission 
Provider and/or the Transmission Owner and the Interconnection Customer as set forth in 
Section 7.9 of this Attachment X.  This agreement shall take the form of the Generator 
Interconnection Agreement modified for provisional purposes.  Unless otherwise provided in the 
GIP, all requirements applicable to the Generator Interconnection Agreement shall apply to the 
Provisional Generator Interconnection Agreement. 
 
Provisional Interconnection Service shall mean Interconnection Service provided by 
the Transmission Provider associated with interconnecting the Interconnection Customer’s 
Generating Facility to the Transmission Provider’s Transmission System and enabling that 
Transmission System to receive electric energy and capacity from the Generating Facility at the 
Point of Interconnection, pursuant to the terms of the Provisional Generator Interconnection 
Agreement and the Tariff. 
 
Provisional Interconnection Study shall mean an engineering study, performed at 
Interconnection Customer’s request, as a condition to entering into a Provisional Generator 
Interconnection Agreement, that evaluates the impact of the proposed interconnection on the 
safety and reliability of the Transmission System and, if applicable, any Affected System.  The 
study shall identify and detail the impacts on the Transmission System and, if applicable, an 
Affected System, from stability, short circuit, and voltage issues that would result if the 
Generating Facility were interconnected without project modifications or system modifications. 
 
Qualified Change shall mean a planned modification to an Existing Generating Facility 
that is undergoing evaluation for a Generating Facility Modification or Generating Facility 
Replacement, and has a material adverse impact on the Transmission System with respect to: i)

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
steady-state thermal or voltage limits, ii) dynamic system stability and response, or iii) short-
circuit capability limit; compared to the impacts of the Existing Generating Facility prior to the 
modification or replacement. 
 
Queue Position shall mean the order of a valid Interconnection Request, relative to all 
other pending valid Interconnection Requests.  The Queue Position is established based upon the 
date and time of initial receipt of the Interconnection Request by Transmission Provider pursuant 
to section 4.1 of this GIP. 
 
Reasonable Efforts shall mean, with respect to an action required to be attempted or 
taken by a Party under the Generator Interconnection Agreement, efforts that are timely and 
consistent with Good Utility Practice and are otherwise substantially equivalent to those a Party 
would use to protect its own interests. 
 
Relevant Electric Retail Regulatory Authority (RERRA) shall mean an entity that has 
jurisdiction over and establishes prices and/or policies for providers of retail electric service to 
end-customers, such as the city council for a municipal utility, the governing board of a 
cooperative utility, the state public utility commission or any such entity. 
 
Reliability Assessment Study shall mean an engineering study that evaluates the impact 
of a proposed Generating Facility Replacement on the reliability of Transmission System during 
the time period between the date that the Existing Generating Facility ceases commercial 
operations and the Commercial Operation Date of the Replacement Generating Facility. 
 
Replacement Generating Facility shall mean a Generating Facility that replaces an 
Existing Generating Facility, or a portion thereof, at the same electrical Point of Interconnection 
pursuant to Section 3.7 of this Attachment X. 
 
Replacement Impact Study shall mean an engineering study that evaluates the impact of 
a proposed Generating Facility Replacement on the reliability of the Transmission System.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
 
Revised System Impact Study shall mean the Interconnection System Impact Study 
performed during Definitive Planning Phase II 
 
Scoping Meeting shall mean the meeting between representatives of Interconnection 
Customer or MHVDC Connection Customer, Transmission Owner, Affected System and 
Transmission Provider conducted for the purpose of discussing the proposed Interconnection 
Request and any alternative interconnection options, exchanging information including any 
transmission data and earlier study evaluations that would be reasonably expected to impact such 
interconnection options, refining information and models provided by Interconnection 
Customer(s), discussing the Group Study materials posted to OASIS pursuant to Section 3.4 of 
this GIP, and analyzing such information. 
 
Shared Interconnection Request shall mean (1) multiple Interconnection Customer’s 
request, in the form of Appendix 1 to the Generator Interconnection Procedures, to interconnect 
new Generating Facilities, or to increase the capacity of, or make a Material Modification to the 
operating characteristics of, Existing Generating Facilities that are interconnected with the 
Transmission System, or to interconnect Existing Generating Facilities that are external to the 
Transmission System, or to change Energy Resource Interconnection Service to Network 
Resource Interconnection Service for Existing Generating Facilities; or (2) multiple MHVDC 
Connection Customer’s request, in the form of Appendix 1 to the Generator Interconnection 
Procedures, to obtain Injection Rights. 
 
Shared Network Upgrade shall mean a Network Upgrade or Common Use Upgrade that 
is funded by an Interconnection Customer(s), including when the Transmission Owner elects to 
fund the capital cost of such a Network Upgrade or Common Use Upgrade under Section 11.3 of 
the GIA, and also benefits other Interconnection Customer(s) or MHVDC Connection 
Customer(s) that are later identified as beneficiaries.  
 
Site Control shall mean a documented right for one or more parcels of land for the

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
purpose of constructing a Generating Facility, Interconnection Customer’s Interconnection 
Facilities, and, if applicable (i.e., when the Interconnection Customer is providing the site 
for such facilities), the Transmission Owner’s Interconnection Facilities and Network 
Upgrades at the POI that the Interconnection Customer will develop.  Such documented 
right shall be one of the following: (1) ownership of a site; (2) a leasehold interest in a site; 
(3) an option to purchase or acquire a leasehold interest in a site; or (4) any other 
contractual or legal right to possess or occupy a site.  Transmission Provider will maintain 
acreage requirements for each Generating Facility type on its OASIS or public website. 
 
Small Generating Facility shall mean a Generating Facility that has an aggregate net 
Generating Facility Capacity of no more than five MW and meets the requirements of Section 14 
and Appendix 3. 
 
Southwest Power Pool (SPP) shall refer to the Southwest Power Pool, Inc. the Regional 
Transmission Organization that is the counterparty to Rate Schedule 6 (MISO-SPP JOA). 
 
Special Protection System (SPS) shall mean an automatic protection system or remedial 
action scheme designed to detect abnormal or predetermined system conditions, and take 
corrective actions other than and/or in addition to the isolation of faulted components, to 
maintain system reliability.  Such action may include changes in demand (MW and MVar), 
energy (MWh and Mvarh), or system configuration to maintain system stability, acceptable 
voltage, or power flows.  An SPS does not include: (a) underfrequency or undervoltage load 
shedding; (b) fault conditions that must be isolated; (c) out-of-step relaying not designed as an 
integral part of an SPS; or (d) Transmission Control Devices. 
 
Stand-Alone Network Upgrades shall mean Network Upgrades, that are not part of an 
Affected System or a JTIQ Upgrade, that Interconnection Customer or MHVDC Connection 
Customer may construct without affecting day-to-day operations of the Transmission System 
during their construction.  Transmission Provider, Transmission Owner and Interconnection 
Customer or MHVDC Connection Customer must agree as to what constitutes Stand Alone

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Network Upgrades and identify them in Appendix A to the Generator Interconnection 
Agreement or Appendix B of the Transmission Connection Agreement.  If the Transmission 
Provider or Transmission Owner and Interconnection Customer disagree about whether a 
particular Network Upgrade is a Stand Alone Network Upgrade, the Transmission Provider or 
Transmission Owner that disagrees with the Interconnection Customer must provide the 
Interconnection Customer a written technical explanation outlining why the Transmission 
Provider or Transmission Owner does not consider the Network Upgrade to be a Stand Alone 
Network Upgrade within fifteen (15) Business Days of its determination. 
 
Substation Network Upgrades shall mean Network Upgrades that are required at or 
near the Point of Interconnection and are identified in the first portion of the Interconnection 
Facilities Study as described in GIP Section 7.3.2.5. 
 
Supplemental Affected System Analysis shall mean the affected systems analysis 
described in Section 7.3.2.3.1 of this GIP and Section 9.4.2.e.iii.a.i of the Rate Schedule 6 
(MISO-SPP JOA) to determine if Supplemental Affected System Upgrades are required for one 
or more JTIQ Participation Group member(s). 
 
Supplemental Affected System Upgrade shall mean a Network Upgrade in addition to 
those required to address the impact of interconnection requests in the current study cluster as 
described in Section 9.4.2.e.iii.a.i of Rate Schedule 6 (MISO-SPP-JOA). 
 
Surplus Host Unit shall mean the Generating Facility from which Surplus 
Interconnection Service will be obtained. 
 
Surplus Interconnection Service shall mean any Interconnection Service that is derived 
from the unneeded portion of Interconnection Service established in a GIA or in agreement with, 
or under the tariff of, a Transmission Owner prior to integration into MISO, such that if Surplus 
Interconnection Service is utilized the total amount of Interconnection Service at the Point of 
Interconnection would remain the same.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
 
System Planning and Analysis Phase shall mean the phase of the Generator 
Interconnection Procedure process, prior to January 4, 2017, which consisted of an 
Interconnection System Impact Study for those Interconnection Requests that were studied in 
this phase.   
 
System Protection Facilities shall mean the equipment, including necessary protection 
signal communications equipment, required to protect (1) the Transmission System or other 
delivery systems or other generating systems from faults or other electrical disturbances 
occurring at the Generating Facility and (2) the Generating Facility from faults or other electrical 
system disturbances occurring on the Transmission System or on other delivery systems or other 
generating systems to which the Transmission System is directly connected. 
 
Target MW Value shall mean the projected new generation interconnection MW 
enabled by the JTIQ Portfolio.  The Target MW Value for each JTIQ Portfolio shall be identified 
in Section 9.4 and related subsections of Rate Schedule 6. 
 
Tariff shall mean the Transmission Provider’s Tariff through which open access 
transmission service and Interconnection Service are offered, as filed with the Commission, and 
as amended or supplemented from time to time, or any successor tariff.   
 
Threshold Charge shall mean the charge calculated using an estimate of plant in service 
value for the JTIQ Portfolio, excluding amounts funded under the GRIP Program, as described in 
Section 9.4.2 of Rate Schedule 6 (MISO-SPP JOA). 
 
Transient Tolerance Window shall mean the period of time after a reduction or loss of 
load by the ZG Associated Load by the end of which window the Generating Facility with ZG 
Interconnection Service must have reduced its injections to an amount not greater than the Load 
of the ZG Associated Load.  The Transient Tolerance Window shall be no greater than 20 
seconds, and is further described by the Business Practices Manual for Large Load.  The

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Transient Tolerance Window will be subject to Transmission Owner local planning criteria. 
 
Transmission Control Devices shall mean a generally accepted transmission device that 
is planned and designed to provide dynamic control of electric system quantities, and are usually 
employed as solutions to specific system performance issues.  Examples of such devices include 
fast valving, high response exciters, high voltage DC links, active or real power flow control and 
reactive compensation devices using power electronics (e.g., unified power flow controllers), 
static var compensators, thyristor controlled series capacitors, braking resistors, and in some 
cases mechanically switched capacitors and reactors.  In general, such systems are not 
considered to be Special Protection Systems. 
 
Transmission Owner shall mean that Transmission Owner as defined in the Tariff, 
which includes an entity that owns, leases or otherwise possesses an interest in the portion of the 
Transmission System at which Interconnection Customer proposes to interconnect or otherwise 
integrate the operation of the Generating Facility.  Transmission Owner should be read to include 
any Independent Transmission Company that manages the transmission facilities of 
Transmission Owner and shall include, as applicable, the owner and/or operator of distribution 
facilities interconnected to the Transmission System, over which facilities transmission service 
or Wholesale Distribution Service under the Tariff is available at the time Interconnection 
Customer requests Interconnection Service and to which Interconnection Customer has requested 
interconnection of a Generating Facility for the purpose of either transmitting electric energy in 
interstate commerce or selling electric energy at wholesale in interstate commerce. 
 
Transmission Provider shall mean the Midcontinent Independent System Operator, Inc. 
(“MISO”), the Regional Transmission Organization that controls or operates the transmission 
facilities of its transmission-owning members used for the transmission of electricity in interstate 
commerce and provides transmission service under the Tariff. 
 
Transmission Owner’s Interconnection Facilities (TOIF) shall mean all facilities and 
equipment owned by Transmission Owner from the Point of Change of Ownership to the Point

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
of Interconnection as identified in Appendix A to the Generator Interconnection Agreement, 
including any modifications, additions or upgrades to such facilities and equipment.  
Transmission Owner’s Interconnection Facilities are sole use facilities and shall not include 
Distribution Upgrades, Generator Upgrades, Stand Alone Network Upgrades or Network 
Upgrades.  
 
Transmission System shall mean the facilities owned by Transmission Owner and 
controlled or operated by Transmission Provider or Transmission Owner that are used to provide 
transmission service (including HVDC Service) or Wholesale Distribution Service under the 
Tariff. 
 
Trial Operation shall mean the period during which Interconnection Customer is 
engaged in on-site test operations and commissioning of the Generating Facility prior to 
Commercial Operation. 
 
User-Defined Model shall mean any set of programming code created by equipment 
manufacturers or developers that captures the latest features of controllers that are mainly 
software-based and represent the entities’ control strategy but does not necessarily correspond to 
any particular generic library model, as contained in Attachment A to Appendix 1 of the GIP.    
 
Variable Energy Resource shall mean a device for the production of electricity that is 
characterized by an energy source that: (1) is renewable; (2) cannot be stored by the facility 
owner or operator; and (3) has variability that is beyond the control of the facility owner or 
operator. 
 
Wholesale Distribution Service shall have that meaning as provided in the Tariff.  
Wherever the term “transmission delivery service” is used, Wholesale Distribution Service shall 
also be implied. 
 
Zero Injection Generation (ZG) Associated Load shall mean a source of electrical load

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
that has a Point of Withdrawal that is at the same substation as the Point of Interconnection to the 
Transmission System (i.e. same voltage level at the interconnecting substation) as the Generating 
Facility with ZG Interconnection Service that will serve it. 
 
Zero Injection Generation (ZG) Interconnection Service shall mean a limited form of 
Interconnection Service that allows an Interconnection Customer to connect its Generating 
Facility to the Transmission System or Distribution System, as applicable, for the limited 
purpose of delivering energy to ZG Associated Load.  ZG Interconnection Service does not grant 
any right to inject energy onto the Transmission System except as may be authorized by Section 
3.11 of the Generator Interconnection Procedures.  ZG Interconnection Service does not convey 
Transmission Service.  ZG Interconnection Service also does not provide a right to serve, or a 
right to Transmission Service to serve, a ZG Associated Load or retail customer except as 
allowed by applicable state law. 
 
Zero Injection Generation (ZG) Resource shall mean a generating resource with an 
Attachment X defined ZG Interconnection Agreement.  A ZG Resource may participate as a 
Generation Resource, Dispatchable Intermittent Resource, Electric Storage Resource, or Behind 
the Meter Generation resource. 
 
ZG Facilities Study shall mean the study described in Section 3.2.5.2.2 of these GIP that 
is used to identify any Network Upgrades or Interconnection Facilities that may be needed to for  
an Interconnection Request seeking ZG Interconnection Service. 
 
ZG Impact Assessment shall mean the study described in Section 3.2.5.2.1 of these GIP 
that is used to evaluate the impact of an Interconnection Request seeking ZG Interconnection 
Services. 
 
ZG Interconnection Agreement (ZGIA) shall mean the form of interconnection 
agreement governing the terms and conditions of ZG Interconnection Service, set forth in 
Appendix 19 to the GIP.  This agreement shall follow the form of the Transmission Provider’s

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
pro forma Generator Interconnection Agreement with modifications to reflect ZG 
Interconnection Service and the ZG Interconnection Service study process.  Unless otherwise 
provided in the GIP, all requirements applicable to the pro forma Generator Interconnection 
Agreement shall apply to the ZGIA.  A ZGIA is a form of GIA and, where used in the Tariff, 
references to Generator Interconnection Agreements or GIAs encompasses ZGIAs. 
 
ZG Interconnection Process Quarterly Study Period shall mean the period of time in 
which Interconnection Requests seeking ZG Interconnection Service are submitted to the 
Transmission Provider and compiled for study.  There are four study periods in a year with the 
following start and end dates: 
Quarter 1: The first Business Day of March through the last Business Day of May; 
Quarter 2: The first Business Day of June through the last Business Day of August; 
Quarter 3: The first Business Day of September through the last Business Day of 
November; 
Quarter 4: The first Business Day of December through the last Business Day of 
February.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
SECTION 2. SCOPE AND APPLICATION. 
 
2.1 
Application of Generator Interconnection Procedures. 
a. 
Sections 2 through 13 of the GIP apply to processing an Interconnection Request 
pertaining to a Generating Facility.  The GIP specifically applies when one of the 
following is proposed by an Interconnection Customer:  (i) a new Generating 
Facility at a new Point of Interconnection that does not meet the criteria set forth 
in Sections 2.1 (b) or (c), (ii) additional generation at an existing Point of 
Interconnection, (iii) an increase in the capacity of an Existing Generating 
Facility, (iv) a Generating Facility Modification that may constitute a Material 
Modification to the operating characteristics of an Existing Generating Facility, or 
(v) a Replacement Generating Facility.  The evaluation in subpart (iv) will be 
performed expeditiously depending on the specific information regarding any 
proposed Generating Facility Modification and the existence of an Emergency 
Condition. 
 
b. 
Section 14 of the GIP applies to a request to interconnect a certified Small 
Generating Facility meeting the certification criteria set forth in Appendix 3.   
 
c. 
A request to interconnect a certified inverter-based Small Generating Facility no 
larger than 10 kW shall be evaluated under the Appendix 4 – 10 kW Inverter 
Process. 
 
d. 
A request to interconnect to HVDC Facilities subject to Section 27A of the Tariff 
will be incorporated into the queue as described in Sections 2 through 13 of the 
GIP.  Modifications to the process necessitated by the physics of a connection to 
HVDC Facilities are found in Section 15 of the GIP, and will apply to those 
requests to interconnect to HVDC Facilities. 
 
e. 
Network Resource Interconnection Service is available to Existing Generating

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Facilities connected to facilities external to the Transmission System, including 
any Existing Generating Facilities connected to any MHVDC Transmission Line.  
Such a request for Network Resource Interconnection Service shall be 
memorialized with a Service Agreement as found in Appendix 13 of the GIP. 
 
f. 
Sections 1 through 7, Section 10, Section 13 and Section 16 of the GIP apply to 
processing an Interconnection Request pertaining to Injection Rights for an 
MHVDC Transmission Line.  Any such request for Injection Rights will be 
incorporated into the queue as described in Sections 2 through 7 of the GIP.  
Procedures for obtaining Injection Rights and the conversion of those rights to 
external Network Resource Interconnection Service are set forth in Section 16 of 
the GIP. All references to MHVDC Connection Customer(s) in these GIP shall be 
understood to refer to MHVDC Connection Customer(s) seeking Injection Rights. 
 
g. 
A request for Replacement Generating Facility shall be evaluated pursuant to 
Section 3.7 of the GIP. 
 
h. 
A request for Generating Facility Modification for an Existing Generating Facility 
must be submitted to and coordinated with the Transmission Provider pursuant to 
the provisions set forth in the Generator Interconnection Business Practices 
Manual to allow the Transmission Provider to determine whether the proposed 
modification would result in a substantive modification to the operating 
characteristics of such Existing Generating Facility. 
 
i.  
An Interconnection Request for a new Generating Facility to be studied through 
the Expedited Resource Addition Study process shall be evaluated pursuant to 
Section 3.9.2. 
 
j. 
A request for ZG Interconnection Service shall be evaluated pursuant to Section 
3.11 of the GIP.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
2.2 
Comparability. 
Transmission Provider shall receive, process and analyze all Interconnection Requests in 
a timely manner as set forth in the GIP.  Transmission Provider shall process and analyze 
Interconnection Requests from all Interconnection Customers comparably, regardless of 
Generating Facility ownership, and from all MHVDC Connection Customers 
comparably, regardless of MHVDC Transmission Line ownership. 
 
2.3 
Base Case Data. 
Transmission Provider shall maintain base power flow, short circuit and stability 
databases, including all underlying assumptions, and contingency list on a password-
protected website, subject to confidentiality provisions in GIP Section 13.1.  In addition, 
Transmission Provider shall maintain network models and underlying assumptions on 
such password-protected website.  Such network models and underlying assumptions 
should reasonably represent those used during the most recent Interconnection Study and 
be representative of current system conditions.  A link to the information is provided on 
Transmission Provider’s OASIS site.  Interconnection Customers and password-protected 
website users must sign a confidentiality agreement before the release of commercially 
sensitive information or Critical Energy Infrastructure Information in the Base Case data.  
Such databases and lists shall include all (i) generation projects and (ii) transmission 
projects, including merchant transmission projects that are proposed for the Transmission 
System for which a transmission expansion plan has been submitted and approved by the 
MISO Board. 
 
2.4 
No Applicability to Transmission Service. 
Nothing in the GIP shall constitute a request for transmission service or confer upon an 
Interconnection Customer or MHVDC Connection Customer any right to receive 
transmission service or Wholesale Distribution Service under the Tariff.   
 
SECTION 3. INTERCONNECTION REQUESTS.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
3.1 
General. 
An Interconnection Customer or MHVDC Connection Customer shall submit to 
Transmission Provider an Interconnection Request in the form of Appendix 1 to the GIP 
and the deposit along with the other items listed in Section 3.3.1 of these GIP in the 
manner specified by the Generator Interconnection Business Practices Manual (BPM-
015).  Transmission Provider shall apply the deposit towards the cost of any 
Interconnection Study.  Interconnection Customer or MHVDC Connection Customer 
shall submit a separate Interconnection Request for each site.  Where multiple Generating 
Facilities share a site, Interconnection Customer(s) may submit separate Interconnection 
Requests or a single Interconnection Request in accordance with Section 3.3.1 of these 
GIP.  An Interconnection Request to evaluate one site at two different voltage levels shall 
be treated as two Points of Interconnection; provided, however, that an Interconnection 
Request for Injection Rights shall only evaluate one voltage level at each Point of 
Connection. 
 
Transmission Provider shall have a process in place to consider requests for 
Interconnection Service below the Generating Facility Capacity.  These requests for 
Interconnection Service shall be studied at the level of Interconnection Service requested 
for purposes of Interconnection Facilities and Network Upgrades, and associated costs, 
but may be subject to other studies at the full Generating Facility Capacity to ensure 
safety and reliability of the system, with the study costs borne by the Interconnection 
Customer.  If after the additional studies are complete, Transmission Provider determines 
that additional Network Upgrades are necessary, then Transmission Provider must: (1) 
specify which additional Network Upgrade costs are based on which studies; and (2) 
provide a detailed explanation of why the additional Network Upgrades are necessary.  
Any Interconnection Facility and/or Network Upgrade costs required for safety and 
reliability also will be borne by the Interconnection Customer.  Interconnection 
Customers may be subject to additional control technologies as well as testing and 
validation of those technologies consistent with Article 6 of the GIA.  The necessary 
control technologies and protection systems shall be established in Appendix C of the

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
executed, or requested to be filed unexecuted, GIA. 
 
Interconnection Requests that include at least one electric storage resource shall 
document their operating assumptions (i.e., whether the interconnecting Generating 
Facility will or will not charge from the Transmission System and at what level) pursuant 
to Attachment X, Appendix 1.  Notwithstanding the foregoing, Transmission Provider 
shall apply the charging operating assumptions contained in the fuel dispatch 
methodology as specified by the Generator Interconnection Business Practices Manual 
(BPM-015).  The operating assumptions for charging as modified by the fuel dispatch 
methodology cannot be higher than those documented in the Interconnection Request.   
 
Transmission Provider may determine that Good Utility Practice, including Applicable 
Reliability Standards, otherwise requires the use of different operating assumptions.  If 
Transmission Provider finds Interconnection Customer’s requested operating 
assumptions conflict with Good Utility Practice, Transmission Provider must provide 
Interconnection Customer an explanation in writing of why the submitted operating 
assumptions are insufficient or inappropriate by no later than thirty (30) Calendar Days 
before the end of the Customer Engagement Window and allow Interconnection 
Customer to revise and resubmit requested operating assumptions one time at least ten 
(10) Calendar Days prior to the end of the Customer Engagement Window.   
 
Transmission Provider shall study these requests for Interconnection Service, with the 
study costs borne by Interconnection Customer, using the submitted operating 
assumptions for purposes of Interconnection Facilities, Network Upgrades, and 
associated costs.  These requests for Interconnection Service also may be subject to other 
studies at the full Generating Facility Capacity to ensure safety and reliability of the 
system, with the study costs borne by Interconnection Customer.  Interconnection 
Customer’s Generating Facility may be subject to additional control technologies as well 
as testing and validation of such additional control technologies consistent with Article 6 
of the GIA.  The necessary control technologies and protection systems shall be set forth

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
in Appendix C of the executed, or requested to be filed unexecuted, GIA. 
 
3.2 
Identification of Types of Services. 
At the time the Interconnection Request is submitted, Interconnection Customer must 
request NR Interconnection Service, ER Interconnection Service, ZG Interconnection 
Service, or Surplus Interconnection Service, as described; provided, however, any 
Interconnection Customer requesting NR Interconnection Service may also request that it 
be concurrently studied as an ER Interconnection Service, up to the expiration of 
Interconnection Customer Decision Point II.  Interconnection Customer may then elect to 
proceed with NR Interconnection Service or to proceed under a lower level of NR 
Interconnection Service to the extent that only certain upgrades will be completed. A 
description of the modeling details used when studying a project as ER Interconnection 
Service or NR Interconnection Service can be found in Section 6 of the Generator 
Interconnection Business Practices Manual (BPM-015). MHVDC Connection Customer 
may only request Injection Rights pursuant to Section 16 of the GIP and shall not be 
eligible to receive any Interconnection Services specified in the GIP.   
 
3.2.1 Energy Resource Interconnection Service (ER Interconnection Service). 
 
3.2.1.1 The Product.  ER Interconnection Service allows Interconnection 
Customer to connect the Generating Facility to the Transmission System 
or Distribution System, as applicable, and be eligible to deliver the 
Generating Facility’s output using the existing firm or non-firm capacity 
of the Transmission System on an “as available” basis and may be granted 
on a conditional basis.  ER Interconnection Service does not in and of 
itself convey any right to deliver electricity to any specific customer or 
Point of Delivery. 
 
 
3.2.1.2 The Study.  The study consists of short circuit/fault duty, steady state 
(thermal and voltage) and stability analyses.  The short circuit/fault duty

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
analysis would identify the Interconnection Facilities required and the 
Network Upgrades necessary to address short circuit issues associated 
with the Interconnection Facilities.  The stability and steady state studies 
would identify necessary upgrades to allow full output of the proposed 
Generating Facility and would also identify the maximum allowed output, 
at the time the study is performed, of the interconnecting Generating 
Facility without requiring additional Network Upgrades.  Notwithstanding 
the foregoing, the output of the Generating Facility and the charging of 
electric storage resources will be modified by Transmission Provider’s 
fuel dispatch methodology in the manner specified by the Generator 
Interconnection Business Practices Manual (BPM-015). 
 
3.2.2 Network Resource Interconnection Service (NR Interconnection Service). 
 
3.2.2.1 The Product.  Transmission Provider must conduct the necessary studies 
and Transmission Owner shall cause the construction of the Network 
Upgrades, System Protection Facilities, Distribution Upgrades or 
Generator Upgrades, subject to the approval of Governmental Authorities, 
needed to integrate the Generating Facility in the same manner as for any 
Generating Facility being designated as a Network Resource.  NR 
Interconnection Service allows the Generating Facility to be designated as 
a Network Resource, up to the Generating Facility’s full output on the 
same basis as existing Network Resources that are interconnected to the 
Transmission or Distribution System as applicable, and to be studied as a 
Network Resource on the assumption that such a designation will occur.  
NR Interconnection Service may be granted on a conditional basis 
pursuant to the terms of Article 4.1.2.3 of the GIA.  A Generating Facility 
requesting NR Interconnection Service shall be deemed to request ER 
Interconnection Service of an equivalent amount to the extent that the 
Generating Facility does not already have ER Interconnection Service in

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
order to allow Interconnection Customer to connect the Generating 
Facility to the Transmission System or Distribution System, as applicable, 
and be eligible to deliver the Generating Facility’s output. The total NR 
Interconnection Service shall not exceed the total ER Interconnection for a 
Generating Facility.  Interconnection Customer with an in-service 
Generating Facility or with an executed GIA, having ER Interconnection 
Service or equivalent interconnection service can request NR 
Interconnection Service by making an Interconnection Request for 
obtaining only NR Interconnection Service. 
 
3.2.2.2 The Study.  The Interconnection Study for NR Interconnection Service 
shall assure that the Generating Facility meets the requirements for NR 
Interconnection Service and will qualify the Generating Facility as a 
Network Resource under Module B and the RAR of the Transmission 
Provider’s Tariff.  As a general matter, the Generating Facility’s 
interconnection is studied with the Transmission System at both off-peak 
and peak loads, under a variety of severely stressed conditions, to 
determine whether, with the Generating Facility at full output, the 
aggregate of generation in the local area can be delivered to the aggregate 
of load on the Transmission System or Distribution System, as applicable, 
consistent with Applicable Reliability Standards.  This approach assumes 
that some portion of existing Network Resources is displaced by the 
output of the Generating Facility.  NR Interconnection Service does not 
convey any right to deliver electricity to any specific customer or Point of 
Delivery. 
 
3.2.3 Surplus Interconnection Service. 
 
3.2.3.1 The Product.  Surplus Interconnection Service is restricted 
Interconnection Service that allows an Interconnection Customer to

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
increase the gross generating capability at the same Point of 
Interconnection of an Existing Generating Facility without increasing the 
total amount of Interconnection Service at the Point of Interconnection. 
The total combined generating output at the Point of Interconnection for 
Both the original and surplus Interconnection Customer is limited to and 
shall not exceed the total amount of Interconnection Service of an Existing 
Generating Facility.  Surplus Interconnection Service does not convey any 
right to deliver electricity to any specific customer or Point of Delivery.  If 
the Existing Generating Facility has only ERIS, any Surplus 
Interconnection Service associated with that Existing Generating Facility 
at the same Point of Interconnection shall be ERIS.  If the Existing 
Generating Facility has NRIS, any Surplus Interconnection Service 
associated with that Existing Generating Facility at the same Point of 
Interconnection could be either ERIS or NRIS. 
 
3.2.3.2 The Study.  The Interconnection Study for Surplus Interconnection 
Service consists of reactive power, short circuit/fault duty, stability 
analyses, and steady-state (thermal/voltage) analyses may be performed as 
necessary to ensure that all required reliability conditions are studied.  If 
the Existing Generating Facility’s Interconnection Service was not studied 
under off-peak conditions, and if warranted, in the Transmission 
Provider's sole discretion, by the fuel-based dispatch assumptions 
specified in the Generator Interconnection Business Practices Manual, off-
peak steady state analyses shall be performed to the required level 
necessary to demonstrate reliable operation of the Surplus Interconnection 
Service.  If the Transmission Provider is unable to verify that the Existing 
Generating Facility was previously studied for the granted level of 
Interconnection Service as provided in Section 3.3.1.1(3) of this GIP, the 
Transmission Provider may perform steady state analyses to demonstrate 
reliable operation of the Surplus Interconnection Service in accordance

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
with the GIP and Generator Interconnection Business Practice Manual.  
The Transmission Provider will perform the applicable studies for the 
surplus Interconnection Request, pursuant to the provisions set forth in the 
Generator Interconnection Business Practices Manual, to determine 
whether the Surplus Interconnection Service proposed in the surplus 
Interconnection Request would result in material adverse impact on the 
Transmission System and/or Affected Systems, as compared to the 
impacts that are created by the Existing Generating Facility, respecting its 
dispatch levels from the original steady state interconnection study, 
without the inclusion of the proposed Surplus Interconnection Service.  If 
no original study is available, the Transmission Provider shall apply the 
current fuel dispatch assumptions used for new Generating Facilities to the 
Existing Generating Facility in the steady state study.  If Transmission 
Provider determines that the proposed Surplus Interconnection Service 
would result in a material adverse impact on the Transmission System 
and/or Affected Systems, then the proposed surplus Interconnection 
Request is deemed to be a Qualified Change and the Interconnection 
Customer shall proceed through Definitive Planning Phase cycle similar to 
a request for interconnection of a new Generating Facility or withdraw the 
surplus Interconnection Request.  The Interconnection Study for the 
surplus Interconnection Request will identify the Interconnection Facilities 
required and the Network Upgrades necessary to address reliability issues 
associated with the Interconnection Facilities. 
 
Transmission Provider shall study Surplus Interconnection Service 
requests for a Generating Facility that includes at least one electric storage 
resource and for which Transmission Provider approves operating 
assumptions pursuant to Section 3.1 according to the Transmission 
Provider’s fuel dispatch methodology in the manner specified by the 
Generator Interconnection Business Practices Manual (BPM-015).

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
 
3.2.4  Injection Rights 
 
 
3.2.4.1 The Product.  Injection Rights serve as a pre-certification of the 
Transmission System’s capability to receive capacity and energy from the 
MHVDC Transmission Line at the requested Point of Connection, and in the 
specified MW quantity, without degrading the reliability of the Transmission 
System.  Injection Rights do not grant Interconnection Service or Transmission 
Service to the MHVDC Connection Customer.  Injection Rights must be 
converted to external Network Resource Interconnection Service as set forth in 
Section 16.2 of the GIP before those rights may be used to offer energy or 
capacity into the MISO markets. 
 
 
3.2.4.2 The Study.  Requests for Injection Rights shall include both ERIS-level 
and NRIS-level evaluations.  For ERIS-level evaluation, the study will include 
short circuit/fault duty, steady state (thermal and voltage) and stability analyses.  
The stability and steady state studies would identify necessary upgrades to allow 
full output of the proposed MHVDC Transmission Line and would also identify 
the maximum allowed output, at the time the study is performed, of the 
interconnecting MHVDC Transmission Line without requiring any additional 
upgrades. 
 
 
For NRIS-level evaluation, the study will assure that the output of the MHVDC 
Transmission Line meets the requirements for NR Interconnection Service and 
will qualify any Existing Generating Facility connected to the MHVDC 
Transmission Line as a Network Resource under Module B and the RAR of the 
Transmission Provider Tariff.  As a general matter, such Generating Facility’s 
interconnection with the Transmission System is studied at both off-peak and 
peak loads, under a variety of severely stressed conditions, to determine whether, 
with such Generating Facility at full output, the aggregate of generation in the

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
local area can be delivered to the aggregate of load on the Transmission System or 
Distribution System, as applicable, consistent with Applicable Reliability 
Standards.  This approach assumes that some portion of an existing Network 
Resource is displaced by the output of such Generating Facility. 
3.2.5 ZG Interconnection Service 
3.2.5.1 The Product.  ZG Interconnection Service is restricted Interconnection 
Service that allows an Interconnection Customer to connect its Generating 
Facility to the Transmission System or Distribution System, as applicable, 
for the limited purpose of delivering energy to a source of electrical load 
that is at the same substation as the Point of Interconnection to the 
Transmission System (i.e. same voltage level at the interconnecting 
substation) as the Generating Facility with ZG Interconnection Service 
that will serve it. 
 
This service is available only if the study required by Section 3.2.3.2 of 
these GIP determines that the proposed interconnection:   
(1) will not result in any injections of Energy onto the Transmission 
System beyond the substation identified in the Interconnection Request 
as the Point of Interconnection.  The restriction on Energy injection in 
this paragraph shall not apply to transient, limited injections associated 
with a reduction or loss of Load by the ZG Associated Load provided 
these remain within any Transient Tolerance Window established in 
the Business Practices Manual for Large Load.   
 
(2) Will not require the construction or modification of any Network 
Upgrades to address impacts to the Transmission System with the 
exception of Network Upgrades located at the same substation as the 
POI, except for System Protection Facilities at adjacent substations.  
 
ZG Interconnection Service is specific to the ZG Associated Load(s) that the

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Generating Facility identifies in its Interconnection Request, and which shall be 
memorialized in the ZGIA.  ZG Interconnection Service does not grant any right 
to inject energy onto the Transmission System beyond the Point of 
Interconnection except as may be authorized by Section 3.11 of these Generator 
Interconnection Procedures.  ZG Interconnection Service does not provide 
interconnection service for the purpose of serving Load other than the ZG 
Associated Load(s) identified in the Interconnection Request and memorialized in 
the ZGIA.  ZG Interconnection Service does not convey transmission service, 
which is obtained through a separate process, and does not provide a right to 
serve, or a right to transmission service to serve, a retail customer except as 
specifically allowed by state laws and regulations.   
 
The ZG Interconnection Service product does not supersede any state or local 
laws or regulations nor does it authorize operations that would violate state or 
local laws and regulations, including those establishing which entities have the 
right or obligation to serve load.  Interconnection Customers are separately 
responsible for adhering to all Applicable Laws and Regulations.  
 
3.2.5.2 The Study.  The Study shall include a ZG System Impact Assessment 
and, if needed, a ZG Facilities Study as described below.   
 
The Generating Facility’s requesting ZG Interconnection Service will be 
studied at a level not to exceed the Demand of the ZG Associated Load 
other than as necessary to study outages of the ZG Associated Load.  The 
Generating Facility’s requesting ZG Interconnection Service will be 
dispatched, and granted service at a level not to exceed the total Demand 
of the ZG Associated Load. 
 
3.2.5.2.1  ZG Impact Assessment.  The ZG Impact Assessment shall 
consist of a review of the proposed configuration of the

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Generating Facility, its electrical connection both to the 
designated ZG Associated Load(s) and to the Transmission 
System, and the proposed control equipment and/or operating 
procedures to determine whether these are sufficient to prevent 
injections onto the Transmission System beyond the substation 
where the Point of Interconnection is located.  The 
Transmission Provider shall perform short circuit/fault duty, 
stability analyses, and steady state (thermal and voltage) if 
necessary based on the proposed configuration.  The stability 
and steady state studies shall study the ability of the Generating 
Facility to interconnect to the Transmission System without 
requiring additional Network Upgrades to maintain reliability, 
including analysis for the ZG Associated Load tripping offline 
consistent with the Transient Tolerance Window established in 
the Business Practices Manual for Large Load.  For ZG 
Interconnection Service to be granted, these analyses must 
determine that no Network Upgrades are needed to maintain 
system reliability other than Network Upgrades at the same 
substation as the Point of Interconnection or System Protection 
Facilities.   
 
3.2.5.2.2  ZG Facilities Study.  The ZG Facilities Study shall identify 
any Network Upgrades at the same substation as the POI, 
and/or operating procedures that are required to prevent 
injections of Energy, other than transient injections during 
Load reduction or loss events, and to maintain reliability during 
these permitted transient injections.  The ZG Facilities Study 
shall identify any required system protection facilities and 
equipment.  Further, the study shall identify any 
Interconnection Facilities required to interconnect the proposed

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Generating Facility to the Transmission System.  
 
The portion of the ZG Facilities Study for Interconnection 
Facilities will start at the same time as the ZG Impact 
Assessment.  The ZG Facilities Study will identify estimates 
for cost and the time required to construct the Interconnection 
Facilities.  The portion of the ZG Facilities Study for Network 
Upgrades shall begin upon the identification of a need for such 
Network Upgrades in the ZG Impact Assessment but not later 
than one Business Day after the ZG Impact Study results are 
provided to the Interconnection Customer.   
 
3.3 
Valid Interconnection Request.  
 
3.3.1 Initiating an Interconnection Request. 
The Transmission Provider shall post on the MISO public website a notice of an 
application deadline for a cluster entering DPP studies at least 45 calendar days prior to 
the application deadline.  An Interconnection Customer or an MHVDC Connection 
Customer wishing to join the next Definitive Planning Phase shall submit their 
Interconnection Request to the Transmission Provider in the manner required by the 
Generator Interconnection Business Practices Manual (BPM-015) no later than the 
application deadline, which will be at least ninety (90) Calendar Days prior to the 
scheduled kick-off of the Definitive Planning Phase I of that cycle, published on the 
MISO public website.  Beginning with the third Group Study after the Commission-
approved effective date of Transmission Provider’s filing made in compliance with the 
Final Rule in Docket No. RM22-14-000, the Transmission Provider shall set an 
application deadline for the next Definitive Planning Phase Group Study, which deadline 
shall be 45 Calendar Days (or next Business Day if the 45th Calendar Day falls on a 
weekend or holiday) after the close of Decision Point 2 of the previous Definitive 
Planning Phase Group Study.  Any Interconnection Request received after the application

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
deadline published on the MISO public website shall, subject to section 4.1.1, be applied 
towards a subsequent Definitive Planning Phase cycle.  A Provisional Generator 
Interconnection Agreement may be requested as set forth in Section 7.9 of the GIP.  The 
Generating Facility described in a valid Interconnection Request may not connect to, or 
propose to connect to, the transmission facilities of any transmission provider other than 
the Transmission Provider except that: 1) an Interconnection Customer may propose to 
include a Generating Facility already connected to a different transmission system in an 
Interconnection Request to the Transmission Provider if the Interconnection Request 
contains a commitment by the Interconnection Customer to disconnect the Generating 
Facility from such other transmission system prior to achieving Commercial Operation 
under a Generator Interconnection Agreement with the Transmission Provider and, 2) an 
Interconnection Customer may proposed to connect an Existing Generating Facility to the 
transmission facilities of another transmission provider provided such Interconnection 
Customer retires the Existing Generating Facility in accordance with Attachment Y to the 
Tariff prior to the date such generating facilities achieve commercial operation with such 
other transmission provider.  Submission of Generating Facilities included in an 
Interconnection Request to another transmission provider for connection to their systems 
shall result in such Interconnection Request being deemed withdrawn pursuant to Section 
3.6 of these Generator Interconnection Procedures. 
 
An Interconnection Customer requesting to join the next Expedited Resource Addition 
Study (ERAS) shall submit their Interconnection Request to the Transmission Provider 
no later than the ERAS application deadline as published on the MISO public website, at 
least fifteen (15) Business Days prior to the scheduled kick-off of the ERAS cycle 
published on the MISO public website.  The valid ERAS request shall be included in an 
ERAS Quarterly Study Period that commences after it was submitted. 
 
Study deposits for the Definitive Planning Phase (DPP) and the Expedited Resource 
Addition Study are required based on the Megawatt amount of the new Interconnection 
Service requested per the following schedule:

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
 
Amount of new 
Interconnection Service 
and/or Injection Rights 
requested (MW) 
Non-Refundable 
Deposit 1 (D1) 
Study Deposit 2 (D2) 
< 6 MW 
Calculated according to 
the procedure in 3.3.1 
and posted by 
Transmission Provider 
prior to the application 
deadline. 
$50,000 
20 ≥ MW ≥ 6 
$120,000 
50 ≥ MW > 20  
$180,000 
100 ≥ MW > 50 
$270,000 
200 ≥ MW > 100 
$320,000 
500 ≥ MW > 200 
$420,000 
1000 > MW > 500 
$530,000 
MW ≥ 1000 
$640,000 
 
The Transmission Provider shall calculate the amount of the Non-Refundable Deposit 1 
(D1) by determining the inflation adjustment in accordance with the inflation calculator 
located at the U.S. Bureau of Labor Statistics website.  The inflation adjustment shall be 
calculated from the effective date of the original D1 amount of $5,000, August 2008, to 
the most up-to-date data available at the time the notification takes place, where such 
amount will be rounded to the nearest $100 and posted on the Transmission Provider’s 
website.  The Transmission Provider shall post a Non-Refundable Deposit 1 (D1) once 
every three years.  The Non-Refundable Deposit 1 (D1) amount calculated pursuant to 
this paragraph shall be applicable to all study groups with an application deadline that is 
sixty (60) or more Calendar Days after the date that the Transmission Provider posts such 
amount and to all Interconnection Requests seeking ZG Interconnection Service that are 
received by the Transmission Provider after the date of such posting.  The posting and 
will remain effective until Transmission Provider posts a revised calculation pursuant to 
this paragraph. 
 
An Interconnection Request for the Expedited Resource Addition Study shall be 
accompanied by a Non-Refundable Deposit 1 (D1) of $100,000.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
 
An Interconnection Request for a Replacement Generating Facility and/or an 
Interconnection Request seeking ZG Interconnection Service or Surplus Interconnection 
Service shall be accompanied by a Non-Refundable Deposit 1 (D1) and a study deposit in 
the amount of $150,000. 
 
Thirty (30) Calendar Days after the execution of a non-Provisional Generator 
Interconnection Agreement or a Transmission Connection Agreement in which the 
Injection Rights option has been selected, Interconnection Customer or MHVDC 
Connection Customer may replace any non-encumbered balance of the study deposits 
with an irrevocable letter of credit or surety reasonably acceptable to Transmission 
Provider.  The surety bond must be issued by an insurer reasonably acceptable to 
Transmission Provider and must specify a reasonable expiration date.  The Transmission 
Provider may establish additional requirements for what constitutes a surety bond, 
including but not limited to, duration satisfaction, demand timeframe and issuer 
requirements through the Generator Interconnection Business Practices manual (BPM-
015). 
 
Interconnection Customer or MHVDC Connection Customer shall be required to provide 
to Transmission Provider the following data as further described in the Generator 
Interconnection Business Practices Manual (BPM-015) along with its Interconnection 
Request: 
 
(i) 
a detailed stability model for the proposed Generating Facility or MHVDC 
Transmission Line;  
(ii) 
a detailed power flow model for the proposed Generating Facility or 
MHVDC Transmission Line;  
(iii) 
Technical data as outlined in Attachment A of Appendix 1 of this GIP; 
(iv) 
an Interconnection Study Agreement executed by Interconnection 
Customer or MHVDC Connection Customer in the form of Appendix 1,

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Attachment B;   
(v) 
a definitive Point of Interconnection or Point of Connection; 
(vi) 
for Interconnection Requests proposing to share Interconnection Customer 
Interconnection Facilities with another pending Interconnection Request 
or existing project, a consent agreement in accordance with Section 3.3.1.4 
of these Generator Interconnection Procedures;   
(vii) 
a one line diagram showing the Generating Facility or MHVDC 
Transmission Line and associated electrical equipment with appropriate 
rating and impedance information;  
(viii) Megawatt amount of new Interconnection Service or Injection Rights 
requested; and 
(ix)  
If applicable, (1) the requested operating assumptions to be used by 
Transmission Provider that reflect the proposed charging behavior of the 
Generating Facility that includes at least one electric storage resource, and 
(2) a description of any control technologies (software and/or hardware) 
that will limit the operation of the Generating Facility to the operating 
assumptions submitted by Interconnection Customer. 
 
In addition, Interconnection Customer or MHVDC Connection Customer proposing to 
enter the Definitive Planning Phase shall provide the Definitive Planning Phase entry 
milestone in the form of either cash, irrevocable letter of credit or surety bond reasonably 
acceptable to Transmission Provider.  The surety bond must be issued by an insurer 
reasonably acceptable to Transmission Provider and must specify a reasonable expiration 
date.  The Transmission Provider may establish additional requirements for what 
constitutes a surety bond, including but not limited to, duration satisfaction, demand 
timeframe and issuer requirements through the Generator Interconnection Business 
Practices manual (BPM-015).   
 
The Definitive Planning Phase entry milestone (M2) will be calculated as $8,000 per 
Megawatt amount of new Interconnection Service or Injection Rights requested.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
 
The Expedited Resource Addition Study entry milestone (M2) will be calculated as 
$24,000 per Megawatt for the amount of new Interconnection Service requested. 
 
Except as otherwise provided for Site Control in Section 7.2 of this GIP, all applicable 
deposits, milestone payments, and data required to enter the Definitive Planning Phase, 
including the exemptions noted in Section 4.1.2, must be received at the time  of the 
submission of the interconnection request on the Transmission Provider website. 
 
All applicable deposits, milestone payments and data required to enter the Expedited 
Resource Addition Study must be received at the time the application is submitted. 
 
Interconnection Customer shall provide proof of Site Control or a cash deposit in lieu of 
Site Control in accordance with the requirements and timing established in Section 7.2 of 
this GIP.  In the event that an Interconnection Customer or MHVDC Connection 
Customer has a state regulatory requirement to process two Points of Interconnection or 
Points of Connection through the entire process, that Interconnection Customer or 
MHVDC Connection Customer is not required to comply with the Site Control 
requirements in Section 7.2 for the second Interconnection Request, provided it is 
properly identified as the required alternative. 
 
The Non-Refundable Deposit 1 (D1) and Study Deposit 2 (D2) shall be applied toward 
the costs related to processing the Interconnection Request, including costs of 
Interconnection Studies and GIA negotiation. 
 
The expected In-Service Date of the Generating Facility or MHVDC Transmission Line 
shall be no later than the process window for the Transmission Provider’s regional 
expansion planning period not to exceed seven years from the date the Interconnection 
Request is received by Transmission Provider, unless Interconnection Customer or 
MHVDC Connection Customer demonstrates that engineering, permitting and

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
construction of the Generating Facility or MHVDC Transmission Line will take longer 
than the regional expansion planning period, nor shall it be any sooner than the process 
time described in the Generator Interconnection Procedures and confirmed in the Pre-
Queue Phase.  The In-Service Date may succeed the date the Interconnection Request is 
received by Transmission Provider by a period up to ten years, or longer where 
Interconnection Customer or MHVDC Connection Customer and Transmission Provider 
agree, such agreement not to be unreasonably withheld. 
 
The expected Commercial Operation Date of a Replacement Generating Facility shall be 
no more than three (3) years from the date of cessation of operation of the Existing 
Generating Facility.  For Existing Generating Facilities that have not yet reached 
Commercial Operation, the specified Commercial Operation Date in the GIA of a 
Replacement Generating Facility shall be no later than the specified Commercial 
Operation Date in the GIA of the Existing Generating Facility.  For Existing Generating 
Facility that is in suspension pursuant to Section 38.2.7 of the Tariff or in Forced Outage, 
the start date of suspension or outage shall be considered the date of cessation of 
operation of the Existing Generating Facility for purposes of calculating the three (3) year 
limit. If the requested period of time between the cessation of operation of the Existing 
Generating Facility and expected Commercial Operation Date of the Replacement 
Generating Facility is more than three (3) years, the request shall be treated as an 
Interconnection Request for a new Generating Facility.  An Existing Generating Facility 
that was in suspension pursuant to Section 38.2.7 of the Tariff is subject to the time 
limitations in Section 38.2.7(n) of the Tariff. 
 
Where multiple Generating Facilities owned by a single Interconnection Customer share 
a site, such Interconnection Customer may submit separate Interconnection Requests or 
single Interconnection Request.  Where multiple Generating Facilities are owned by 
different Interconnection Customers and share a site, Interconnection Customers may 
submit a single Interconnection Request (Shared Interconnection Request), but the 
Interconnection Request must include an agreement between the Interconnection

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Customers which designates a primary point of contact for communications and 
designates a single authorized contact for payments and refunds, and the agreement must 
clearly identify ownership of each proposed Generating Facility.  An existing 
Interconnection Request may not be combined with another to form a Shared 
Interconnection Request. 
 
An Interconnection Request for a Generating Facility requesting processing through the 
Expedited Resource Addition Study shall identify the claimed resource adequacy and/or 
reliability need(s) for which it is being submitted.  This should include the location (i.e. 
the county and state, the electrical bus location(s), and the Local Resource Zone) of any 
load to be served via the off take agreement as well as the peak demand for electricity 
expected over any one hour period in MWs—the amount of Interconnection Service 
requested must not exceed 150 percent of the identified MW need. The Generating 
Facility and the associated resource adequacy and/or reliability need(s) must be within 
the same Local Resource Zone, unless the resource adequacy and/or reliability need is 
included in a resource filing made to the RERRA that is providing the verification 
required in Section 3.9.1.  
 
The expected Commercial Operation Date included in the Interconnection Request for a 
Generating Facility requesting processing through the Expedited Resource Addition 
Study shall be no later than three calendar years from the submission date of the 
Interconnection Request. 
 
3.3.1.1 Additional Requirements for a Surplus Interconnection Request 
application 
 
A request for Surplus Interconnection Service made by an Interconnection 
Customer must meet the requirements listed in section 3.3.1 above, plus the 
following requirements:

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
1. 
The Interconnection Customer of the Existing Generating Facility, or one 
of its affiliates, shall have priority to utilize Surplus Interconnection 
Service.  If the Interconnection Customer of the Existing Generating 
Facility or one of its affiliates does not exercise its priority, then the 
Interconnection Customer may make Surplus Interconnection Service 
available to other potential Interconnection Customers.  
 
2. 
The surplus Interconnection Request shall be accompanied by written 
confirmation from an officer of the Interconnection Customer of the 
Surplus Host Unit , indicating: (i) the amount of Surplus Interconnection 
Service made available by the Interconnection Customer of the Surplus 
Host Unit; (ii) the type of Interconnection Service (i.e., ERIS or NRIS) 
made available by the Interconnection Customer of the Surplus Host Unit 
in accordance with the provisions of Section 3.2.3.1 of this GIP; (iii) the 
circumstances under which the proposed Surplus Interconnection Service 
would be available, including an indication of whether the proposed 
Interconnection Service would be available on a continuous basis (i.e., a 
certain number of MW of Surplus Interconnection Service would always 
be available for use by a co-located generating facility) or on a scheduled, 
periodic basis (i.e., a specified number of MW of Surplus Interconnection 
Service that would be available intermittently. 
 
3. 
Except as provided in Section 3.3.1.1(3)(a) of this Attachment X, the 
Interconnection Customer must include the MISO Interconnection System 
Impact Study performed for the Existing Generating Facility when the 
Generating Facility was originally proposed for interconnection to the 
MISO Transmission System or, for Generating Facilities studied under a 
predecessor transmission provider’s interconnection process, the original 
system impact study performed at the time such Generating Facility was 
originally studied for interconnection to the transmission system.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Transmission Provider will use that study to appropriately scope the study 
for evaluation of the surplus Interconnection Request.  If the 
Interconnection Customer cannot provide such system impact study with 
its application, it shall indicate that such study is not available. 
 
a. 
A Request for Surplus Interconnection Service may be submitted 
by an Interconnection Customer prior to the date that the Surplus 
Host Unit has obtained an effective Generator Interconnection 
Agreement provided the following requirements are met: 
 
1. 
The Surplus Host Unit has a valid Interconnection Request 
and has completed Interconnection Customer Decision 
Point II of the GIP prior to the date that the surplus 
Interconnection Request is submitted; 
2. 
The surplus Interconnection Request satisfies each of the 
requirements of Section 3.3.1.1 of this GIP except that 
instead of providing the MISO Interconnection System 
Impact Study for an Existing Generating Facility specified 
by Section 3.3.1.1(3), the Surplus Interconnection 
Customer shall provide the most recently completed 
Interconnection System Impact Study in the form of the 
Revised System Impact Study for Definitive Planning 
Phase II or the Final System Impact Study for Definitive 
Planning Phase III for the Surplus Host Unit with the 
surplus Interconnection Request;  
3. 
The Surplus Interconnection Customer identifies the study 
cycle and project number of the Surplus Host Unit in the 
surplus Interconnection Request; and 
4. 
If sharing Interconnection Customer Interconnection 
Facilities with the Existing Generating Facility, evidence

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
that the Interconnection Customer has entered into a 
consent agreement that meets the requirements of Section 
3.3.1.4. 
5. 
If the Surplus Interconnection Customer Generating 
Facility partially or completely consists of energy storage 
devices, the Surplus Interconnection Customer 
Interconnection Request shall contain a description of any 
control technologies (software and/or hardware) that will 
limit the concurrent operation of the Existing Generating 
Facilities and Surplus Facilities to the original 
Interconnection Service limit. 
 
4. 
The surplus Interconnection Request must be submitted to the 
Transmission Provider by the Interconnection Customer at least one (1) 
year prior to the Commercial Operation Date of the Generating Facility 
requesting Surplus Interconnection Service. 
 
5. 
If a Material Modification study for the Surplus Host Unit is pending at 
the time the surplus Interconnection Request is submitted, then the surplus 
Interconnection Study for Surplus Interconnection Service shall not 
kickoff until the Material Modification study has completed and any 
approved modifications have been added to Generation Interconnection 
Agreement. 
 
The Transmission Provider shall commence processing and studying a surplus 
Interconnection Request that conforms to the requirements of this Section 
3.3.1.1(3)(a) of the GIP in accordance with the provision of Section 3.3.1.2 of this 
GIP provided that no GIA may be tendered for such surplus Interconnection 
Request prior to the date that the Surplus Host Unit has become subject to an 
effective Generator Interconnection Agreement.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
 
3.3.1.2 Evaluation Process for Surplus Interconnection Request and the 
Requirements for the Request to Remain Valid 
 
The following conditions will apply for evaluation of surplus Interconnection 
Request: 
 
1. 
Within thirty (30) Calendar Days of the Transmission Provider’s receipt of 
the completed surplus Interconnection Request, Transmission Provider 
will commence a study of the proposed Surplus Interconnection Service 
pursuant to Section 3.2.3.2 of this GIP to determine whether such service 
would result in any material adverse impact to the Transmission System 
and/or Affected Systems and amounts to a Material Modification.  After 
the commencement of the surplus Interconnection Study for Surplus 
Interconnection Service, if a Material Modification request on the Surplus 
Host Unit is submitted, the surplus Interconnection Request will be 
paused.  Once the Material Modification request has been approved, the 
surplus Interconnection Request will be reevaluated and may require the 
Interconnection Customer to update the surplus Interconnection Request.  
The updated surplus Interconnection Request is subject to the surplus 
Interconnection Request timing requirements.  Transmission Provider 
shall use Reasonable Efforts to complete the study of the surplus 
Interconnection Request within ninety (90) Calendar Days.  If 
Transmission Provider determines that the surplus Interconnection 
Request would result in a material adverse impact to the Transmission 
System and/or Affected Systems, then the surplus Interconnection Request 
shall proceed through the Definitive Planning Phase as a new 
Interconnection Request. 
 
2. 
Within thirty (30) Calendar Days after having received results of the

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Transmission Provider’s evaluation, Interconnection Customer requesting 
Surplus Interconnection Service shall inform Transmission Provider of its 
election to proceed with its surplus Interconnection Request.  After 
receiving the Interconnection Customer’s election notice, Transmission 
Provider will initiate an Interconnection Facilities Study or tender a draft 
GIA, as appropriate.  If the Interconnection Customer fails to provide a 
notice of its election to proceed within thirty (30) Calendar Days after 
having received results of the Transmission Provider’s evaluation, the 
Transmission Provider will deem the Interconnection Request withdrawn 
pursuant to Section 3.6 of this GIP. 
 
The Interconnection Facilities Study will be performed, if needed, and will 
be completed within ninety (90) Calendar Days.  If an Interconnection 
Facilities Study is necessary, the Transmission Provider shall tender a 
draft pro forma GIA within the later of thirty (30) Calendar Days after 
final Interconnection Facilities Study reports are issued or the date that the 
GIA for the Surplus Host Unit becomes effective.  If an Interconnection 
Facilities Study is not necessary, the Transmission Provider shall tender a 
draft pro forma GIA or an amended GIA that conforms to the currently 
effective pro forma GIA, as applicable by the later of thirty (30) Calendar 
Days after the Interconnection Customer communicates its election to 
proceed with Surplus Interconnection Service request, or the date that the 
GIA for the Surplus Host Unit becomes effective.  
 
 
Interconnection Customer shall submit an executed Energy Displacement 
Agreement and Monitoring and Consent Assignment to the Transmission 
Provider prior to the conclusion of negotiations for the associated GIA, 
pursuant to Section 11 of this GIP.  The executed Monitoring and Consent 
Agreement shall be in the form of Appendix 11 of the GIP to be effective 
upon execution of a GIA and must remain in effect during the term of the

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
GIA.    
 
 
The executed Energy Displacement Agreement shall be in the form of 
Appendix 12 of the GIP to be effective upon execution of a GIA and must 
remain in effect during the term of the GIA.  If the Interconnection 
Customer fails to provide an executed Energy Displacement Agreement 
and a Monitoring and Consent Agreement to the Transmission Provider 
prior to the conclusion of negotiations for the associated GIA, the 
Transmission Provider will deem the Interconnection Request withdrawn 
pursuant to Section 3.6 of this GIP. 
 
 
If at any time prior to execution of the GIA the Energy Displacement 
Agreement or Monitoring and Consent Agreement required above is no 
longer in effect, the Interconnection Request for Surplus Interconnection 
Service shall be deemed to have been withdrawn. 
 
3.3.1.3 Requirements for continuation of Surplus Interconnection Service 
after retirement or cessation of commercial operation of an Existing 
Generating Facility 
 
1. 
In the event that the Interconnection Customer seeks to continue Surplus 
Interconnection Service following the retirement and permanent cessation 
of commercial operation of the Existing Generating Facility associated 
with that Surplus Interconnection Service, Transmission Provider shall 
permit the Surplus Interconnection Service to continue for a limited period 
not to exceed one (1) year if the Existing Generating Facility retired and if 
the following conditions are met: 
 
(i) 
Transmission Provider studied the Surplus Interconnection Service 
Generating Facility for sole operation at that Point of

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Interconnection as a part of Interconnection Study for the Surplus 
Interconnection Service Generating Facility, and such studies 
confirm that the Surplus Interconnection Service Generating 
Facility can be solely and reliably operated after the retirement of 
the Existing Generating Facility; and 
 
(ii) 
The Existing Generating Facility Interconnection Customer must 
provide written consent to the continued operation of the Surplus 
Interconnection Service Generating Facility at either: (a) the 
limited level of Surplus Interconnection Service that is reflected in 
the Surplus Interconnection Service Generating Facility’s 
Generator Interconnection Agreement; or (b) at any level below 
such limit. 
 
3.3.1.4 Additional Requirements for Interconnection Requests Proposing to 
Share Interconnection Customer Interconnection Facilities  
 
Interconnection Customer may submit an Interconnection Request that proposes 
to share Interconnection Customer Interconnection Facilities with one or more 
existing projects or pending Interconnection Requests.  Interconnection Requests 
proposing such an arrangement shall so indicate in their Interconnection Request 
and attach a consent agreement executed by all Interconnection Customers with 
projects that propose to connect, or are connected, to the shared Interconnection 
Customer Interconnection Facilities.  After an Interconnection Request has been 
submitted, an Interconnection Customer may only propose to share 
Interconnection Customer Interconnection Facilities as part of a Point of 
Interconnection modification.  Such consent agreement shall, in accordance with 
the Business Practices Manuals, describe the proposed configuration of the 
projects, the proposed ownership of the Interconnection Customer Interconnection 
Facilities, the division of rights and responsibilities among the parties with respect

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
to operations, maintenance, and repair of the Interconnection Customer 
Interconnection Facilities, and such other information regarding the operation of 
the Generating Facilities under this arrangement as may be specified in the 
Generator Interconnection Business Practice Manual. The consent agreement 
shall indicate the parties’ consent to sharing the Interconnection Customer 
Interconnection Facilities in the manner described in the Interconnection 
Request(s).  Interconnection Requests from multiple Interconnection Customers 
for multiple Generating Facilities that share a site must include a contract or other 
agreement that allows for shared land use as specified in section 7.2.1.1.ii.b.3.  
 
3.3.1.5 Evaluation Process for Interconnection Requests Proposing to Share 
Interconnection Customer Interconnection Facilities 
  
Interconnection Requests proposing shared Interconnection Customer 
Interconnection Facilities shall require the consent of the Transmission Provider 
to proceed, which consent shall not be unreasonably withheld, conditioned, or 
delayed. The Transmission Provider shall review Interconnection Requests 
proposing to share Interconnection Customer Interconnection Facilities amongst 
multiple projects to confirm compliance with the requirements of Section 3.3.1.4 
of these Generator Interconnection Procedures, that all Interconnection Customer 
responsibilities have been appropriately accounted for, and that all parties have 
consented to the described arrangement.  The Transmission Provider shall 
complete this review and notify the parties whether the Transmission Provider 
consents to the proposed arrangement no later than five (5) days prior to the start 
of the Scoping Meeting in which their requests are discussed, or within ten (10) 
Business Days after receipt if the consent agreement is submitted as part of a 
Point of Interconnection modification.  In the event that the Transmission 
Provider does not consent, the Transmission Provider shall provide a written 
statement of the reasons for such decision to each of the parties.  Interconnection 
Requests that do not receive the Transmission Provider’s consent for the sharing

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
of Interconnection Customer Interconnection Facilities may be revised and 
resubmitted for inclusion in the applicable cycle prior to the start of DPP Phase I.  
In the event that the consent agreement is submitted as part of a Point of 
Interconnection modification, the consent for the sharing of Interconnection 
Customer Interconnection Facilities may be revised and resubmitted within five 
(5) Business Days of receiving the Transmission Provider’s written statement of 
reasons. 
 
Any Interconnection Customer that has an Interconnection Request pending in the 
DPP as of August 14, 2019 and that intends to share Interconnection Customer 
Interconnection Facilities for that Interconnection Request with one or more 
existing projects or other Interconnection Requests shall satisfy each of the terms 
of Sections 3.3.1.4 and 3.3.1.5 of these Generator Interconnection Procedures, 
prior to the start of GIA negotiations for any Interconnection Request that remains 
pending in the DPP and that will participate in the sharing arrangement. 
 
3.3.2 Acknowledgment of Interconnection Request. 
Transmission Provider shall acknowledge receipt of the Interconnection Request within 
five (5) Business Days of receipt of the Interconnection Request.  Transmission Provider 
shall tender to Interconnection Customer or MHVDC Connection Customer a copy of the 
countersigned Interconnection Study Agreement within ten (10) Business Days after the 
Transmission Provider notifies Interconnection Customer that it has accepted the 
Interconnection Request as valid pursuant to Section 3.3.3 of this GIP.  In addition, 
within ten (10) Business Days after notifying Interconnection Customer that an 
Interconnection Request is accepted as valid, Transmission Provider shall submit a 
summary of the Interconnection Request to Interconnection Customer or MHVDC 
Connection Customer and likely affected Transmission Owners.  All acknowledgments 
and other communications may be made via e-mail and/or other electronic means. 
 
3.3.3 Review of Interconnection Request and Cure of Deficiencies.

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
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Effective On: October 18, 2026
An Interconnection Request will not be considered to be a valid request until all items in 
Section 3.3.1 have been received by Transmission Provider.  If an Interconnection 
Request fails to meet the requirements set forth in Section 3.3.1, Transmission Provider 
shall notify Interconnection Customer or MHVDC Connection Customer within fifteen 
(15) Business Days of receipt of the initial Interconnection Request either that the 
Transmission Provider has accepted the Interconnection Request as valid or has 
determined that the Interconnection Request does not constitute a valid request due to one 
or more deficiencies.  In the event Transmission Provider determines that the 
Interconnection Request does not constitute a valid request, Transmission Provider shall 
also provide an explanation of the reasons for such determination. Interconnection 
Customer shall have ten (10) Business Days from the date that the Transmission Provider 
identifies the Interconnection Request as deficient to provide the additional requested 
information needed to constitute a valid request.  In the event Transmission Provider 
discovers or verifies a deficiency later in the GIP process, Transmission Provider will 
notify Interconnection Customer or MHVDC Connection Customer as soon as 
practicable.  At any time, if Transmission Provider finds that the technical data provided 
by Interconnection Customer is incomplete or contains errors, Transmission Provider will 
issue a deficiency notice to Interconnection Customer and Interconnection Customer and 
Transmission Provider shall work expeditiously and in good faith to remedy such issues.   
Interconnection Customer or MHVDC Connection Customer shall provide Transmission 
Provider the additional requested information needed to constitute a valid request no later 
than ten (10) Business Days after the request is made.  Failure by Interconnection 
Customer or MHVDC Connection Customer to comply with this Section 3.3.3 will result 
in the Interconnection Request not being processed until such deficiency is cured.  In the 
event that the deficiency is not cured within the required ten (10) business day period, the 
Interconnection Request shall immediately be deemed withdrawn as of the date of such 
deadline without any further cure period and the Non-Refundable Deposit 1 (D1) shall be 
forfeited.  The Transmission Provider shall provide written notice to Interconnection 
Customer or MHVDC Connection Customer of the deemed withdrawal and an 
explanation of the reasons for such deemed withdrawal upon the expiration of the ten

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
(10) business day period.  Any refunds of deposits other than the D1 will be processed in 
accordance with Section 3.6 of this GIP.  
 
3.3.4  Customer Engagement Window  
Immediately after the application deadline for a Group Study, Transmission Provider 
shall open a eighty-five (85) Calendar Day period (Customer Engagement Window).  
During the Customer Engagement Window, Transmission Provider, applicable 
Transmission Owner and Interconnection Customer shall conduct the activities set forth 
in sections 3.3.5 (Scoping Meeting), 7.1.1 (Screening Analysis Prior to Definitive 
Planning Phase I), and section 7.2.1.3 (Transmission Provider Review of Site Control 
Sufficiency).  Notwithstanding the preceding requirements and upon written consent of 
all Interconnection Customers within the Group, Transmission Provider may shorten the 
Customer Engagement Window and begin the Group Study.  Within thirty (30) Business 
Days of the opening of the Customer Engagement Window, Transmission Provider shall 
post on its OASIS a list of Interconnection Requests for that Group.  The list shall 
identify, for each anonymized Interconnection Request: (1) the requested amount of 
Interconnection Service; (2) the location by county and state; (3) the station or 
transmission line or lines where the interconnection will be made; (4) the projected In-
Service Date; (5) the type of Interconnection Service requested; and (6) the type of 
Generating Facility or Facilities to be constructed, including fuel types, such as coal, 
natural gas, solar, or wind.  The Transmission Provider must ensure that project 
information is anonymized and does not reveal the identity or commercial information of 
interconnection customers with submitted requests.  During the Customer Engagement 
Window, Transmission Provider shall provide to Interconnection Customer a non-binding 
updated good faith estimate of the cost and timeframe for completing the Group Study 
and a Interconnection Study Agreement to be executed prior to the close of the Customer 
Engagement Window. 
 
Transmission Provider shall initiate the Group Study described in Section 7 of this GIP 5 
Business Days following the close of the Customer Engagement Window.

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
 
3.3.5 Scoping Meeting. 
During the Customer Engagement Window, the Transmission Provider shall establish a 
date agreeable to Interconnection Customer and Transmission Owner for a Scoping 
Meeting, and such date shall be at least five (5) Business Days prior to and no more than 
forty-five (45) Calendar days prior to the kick-off of the Definitive Planning Phase, 
unless otherwise mutually agreed upon by Transmission Provider, Transmission Owner 
and Interconnection Customer or MHVDC Connection Customer.  The Transmission 
Provider, Interconnection Customer, or MHVDC Connection Customer, and 
Transmission Owner must attend the Scoping Meeting.  Transmission Provider shall use 
Reasonable Efforts to include any other Affected System Operators in the Scoping 
Meeting. 
 
The purpose of the Scoping Meeting shall be to discuss alternative interconnection 
options, to exchange information including any transmission data that would reasonably 
be expected to impact such interconnection options, to analyze such information and to 
determine the potential feasible Points of Interconnection.  For purposes of clustering 
Interconnection Requests, Transmission Provider or Transmission Owner may propose 
changes to the requested Point of Interconnection to facilitate efficient interconnection of 
Interconnection Customers at common Point(s) of Interconnection.  The requesting 
Transmission Provider or Transmission Owner shall notify Interconnection Customers in 
writing of any intended changes to the requested Point of Interconnection within two (2) 
Business Days after the conclusion of the Scoping Meeting, and the Point of 
Interconnection shall only change upon mutual agreement.  Transmission Provider, 
Transmission Owner and Interconnection Customer or MHVDC Connection Customer 
will bring to the meeting such technical data including, but not limited to, known:  (i) 
general facility loadings, (ii) general instability issues, (iii) general short circuit issues, 
(iv) general voltage issues including voltage and frequency ride-through capabilities for 
the Generating Facility, (v) general power quality issues including voltage flicker, 
harmonics, (vi) general reliability issues; and (vii) diagrams and/or layout of applicable

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
substations as may be reasonably required to accomplish the purpose of the meeting.  
Transmission Provider and Interconnection Customer or MHVDC Connection Customer 
will also bring to the meeting personnel and other resources as may be reasonably 
required to accomplish the purpose of the meeting in the time allocated for the meeting.  
On the basis of the meeting, Interconnection Customer or MHVDC Connection Customer 
may modify its Point of Interconnection/Connection.  Notwithstanding the foregoing, 
modifications to the Point of Interconnection are prohibited if the modification causes the 
project to move from one study region to another once the Transmission Provider has 
notified Interconnection Customers that its Interconnection Request will be included in a 
study group pursuant to Section 4.1.1.3 of this GIP.  Interconnection Customer or 
MHVDC Connection Customer will have until the beginning of DPP Phase I submit to 
Transmission Provider its modified Point of Interconnection/Connection as a result of the 
Scoping Meeting; if the modified Point of Interconnection includes shared 
Interconnection Customer Interconnection Facilities, the Interconnection Customer shall 
submit a consent agreement that meets requirements of Section 3.3.1.4 by the beginning 
of DPP Phase I.  The duration of the meeting shall be sufficient to accomplish its 
purpose. 
 
3.4 
OASIS Posting. 
3.4.1 Transmission Provider will maintain on its OASIS or its website a list of all 
Interconnection Requests.  If Transmission Provider posts this information on its website, 
a link to the information must be provided on Transmission Provider’s OASIS site.  The 
list will identify, for each Interconnection Request:  (i) the maximum summer and winter 
megawatt electrical output; (ii) the location by county and state; (iii) the substation or 
transmission line or lines where the interconnection will be made; (iv) the projected In-
Service Date; (v) the status of the Interconnection Request, and when applicable, 
Definitive Planning Phase Queue Position; (vi) the type of Interconnection Service being 
requested or whether the Interconnection Request is for Injection Rights; (vii) the 
availability of any studies related to the Interconnection Request; (viii) the date of the 
Interconnection Request; (ix) the type of Generating Facility to be constructed including

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
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technology and fuel type); (x) for Interconnection Requests that have not resulted in a 
completed interconnection, an explanation as to why it was not completed; (xi) associated 
Interconnection System Impact Study phase costs by Definitive Planning Phase; and (xii) 
for a Generating Facility Replacement, the planned date of cessation of operation for the 
Existing Generating Facility or actual date if the Existing Generating Facility already has 
ceased commercial operations, the expected Commercial Operation Date of the 
replacement facility and requested Interconnection Service.  Except for projects 
submitted through the ERAS process as noted in Section 3.9, the list will not disclose the 
identity of Interconnection Customer or MHVDC Connection Customer until 
Interconnection Customer or MHVDC Connection Customer executes a GIA or a TCA or 
requests that Transmission Provider file an unexecuted GIA or TCA with FERC.  
Transmission Provider shall post to its OASIS site or its website any deviations from the 
study timelines set forth herein.  Interconnection Study reports shall be posted to the 
Transmission Provider’s OASIS site or its website prior to the meeting between 
Interconnection Customer and Transmission Provider to discuss the applicable study 
results.  Transmission Provider shall also post any known deviations in the Generating 
Facility’s In-Service Date.  
 
Transmission Provider will also maintain on its OASIS or its website a Transmission 
Owner’s general non-binding indication as to whether the Transmission Owner intends to 
elect to fund the capital costs (self-fund) for Network Upgrades and System Protection 
Facilities.  If Transmission Provider posts this information on its website, a link to the 
information must be provided on Transmission Provider’s OASIS site. 
 
3.4.2 Transmission Provider will maintain on its OASIS or its website summary 
statistics related to processing Interconnection Studies pursuant to Interconnection 
Requests, updated quarterly. If Transmission Provider posts this information on its 
website, a link to the information must be provided on Transmission Provider’s OASIS 
site. For each calendar quarter, Transmission Providers must calculate and post the 
information detailed in sections 3.4.2.1 through 3.4.2.6.  For the Study Metrics provided

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
in Sections 3.4.2.2 and 3.4.2.3, if the relevant 10 Business Days includes one or more 
holidays, then the number of Business Days will be correspondingly extended and the 
study will not be considered untimely if completed within the extended period. 
 
3.4.2.1 Preliminary System Impact Studies in Definitive Planning Phase I 
Processing Time.  
 
(A)  
Number of Interconnection Requests that had Preliminary System Impact 
Studies in Definitive Planning Phase I completed within Transmission 
Provider’s coordinated region during the reporting quarter,  
(B)  
Number of Interconnection Requests that had Preliminary System Impact 
Studies in Definitive Planning Phase I completed within Transmission 
Provider’s coordinated region during the reporting quarter that were 
completed more than the sum of 10 Business Days for Model Review and 
65 Calendar Days for the Preliminary System Impact Study, as per the 
timelines listed in 7.3.1 of the Generator Interconnection Procedures 
(“GIP”) after the periodic, scheduled start of the Definitive Planning Phase 
I, which shall commence in conformity with Section 3.3.1 of the GIP, 
(C)  
At the end of the reporting quarter, the number of active valid 
Interconnection Requests with ongoing incomplete Preliminary System 
Impact Studies in Definitive Planning Phase I exceeding the sum of 10 
Business Days for Model Review and 65 Calendar Days for the 
Preliminary System Impact Study report as per the timelines listed in 7.3.1 
of the GIP, after the periodic, scheduled start of the Definitive Planning 
Phase I,  
(D)  
Mean time (in Calendar Days), for Preliminary System Impact Studies in 
Definitive Planning Phase I completed within Transmission Provider’s 
coordinated region during the reporting quarter, from the periodic, 
scheduled start of the Definitive Planning Phase I, to the date when 
Transmission Provider provided the completed Preliminary System Impact

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Study report to the Interconnection Customer, 
(E)  
Percentage of Interconnection Requests with Preliminary System Impact 
Studies in Definitive Planning Phase I exceeding the sum of 10 Business 
Days for Model Review and 65 Calendar Days for the Preliminary System 
Impact Study report to complete this reporting quarter, calculated as the 
sum of 3.4.2.1(B) plus 3.4.2.1(C) divided by the sum of 3.4.2.1(A) plus 
3.4.2.1(C)).  
 
3.4.2.2 Revised System Impact Studies in Definitive Planning Phase II 
Processing Time.  
 
(A)  
Number of Interconnection Requests that had Revised System Impact 
Study reports in Definitive Planning Phase II completed within 
Transmission Provider’s coordinated region during the reporting quarter, 
(B)  
Number of Interconnection Requests that had Revised System Impact 
Studies in Definitive Planning Phase II completed within Transmission 
Provider’s coordinated region during the reporting quarter that were 
completed more than the sum of 6 Business Days for Model Review and 
75 Calendar Days for the Revised System Impact Study report after the 
date the Interconnection Customer Decision Point I window expired, as 
per the timelines listed in Section 7.3.2 of the GIP, 
(C)  
At the end of the reporting quarter, the number of active valid 
Interconnection Requests with ongoing incomplete Revised System 
Impact Studies in Definitive Planning Phase II exceeding the sum of 6 
Business Days for Model Review and75 Calendar Days for the Revised 
System Impact Study report, as per the timelines listed in 7.3.2 of the GIP, 
after the Interconnection Customer Decision Point I window expired,  
(D)  
Mean time (in Calendar Days), for Revised System Impact Studies in 
Definitive Planning Phase II completed within Transmission Provider’s 
coordinated region during the reporting quarter, from the day after the

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Interconnection Customer Decision Point I window expired to the date 
when Transmission Provider provided the completed Revised System 
Impact Study report to the Interconnection Customer, 
(E)  
Percentage of Interconnection Requests with Revised System Impact 
Study reports in Definitive Planning Phase II exceeding the sum of 6 
Business Days for Model Review and 75 Calendar Days for the Revised 
System Impact Study, to complete this reporting quarter, calculated as the 
sum of 3.4.2.2(B) plus 3.4.2.2(C) divided by the sum of 3.4.2.2(A) plus 
3.4.2.2(C)).  
 
3.4.2.3 Final System Impact Studies in Definitive Planning Phase III 
Processing Time.  
 
(A)  
Number of Interconnection Requests that had Final System Impact Study 
reports in Definitive Planning Phase III completed within Transmission 
Provider’s coordinated region during the reporting quarter,  
(B)  
Number of Interconnection Requests that had Final System Impact Study 
reports in Definitive Planning Phase III completed within Transmission 
Provider’s coordinated region during the reporting quarter that were 
completed more than the sum of 6 Business Days for Model Review and 
50 Calendar Days as per the timelines listed in 7.3.3 of the GIP, after the 
Interconnection Customer Decision Point II window expired, 
(C)  
At the end of the reporting quarter, the number of active valid 
Interconnection Requests with ongoing incomplete Final System Impact 
Study reports in Definitive Planning Phase III exceeding the sum of 6 
Business Days for Model Review and 50 Calendar Days, as per the 
timelines listed in 7.3.3 of the GIP, after the Interconnection Customer 
Decision Point II window expired,  
(D)  
Mean time (in Calendar Days), for Final System Impact Studies in 
Definitive Planning Phase III completed within Transmission Provider’s

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
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coordinated region during the reporting quarter, from the day after the 
Interconnection Customer Decision Point II window expired to the date 
when Transmission Provider provided the completed Final System Impact 
Study to the Interconnection Customer,  
(E)  
Percentage of Interconnection Requests with Final System Impact Study 
reports in Definitive Planning Phase III exceeding the sum of 6 Business 
Days for Model Review and 50 Calendar Days to complete this reporting 
quarter, calculated as the sum of 3.4.2.3(B) plus 3.4.2.3(C) divided by the 
sum of 3.4.2.3(A) plus 3.4.2.3(C)).  
 
3.4.2.4 Interconnection Facilities Studies Processing Time.  
 
(A)  
Number of Interconnection Requests that had Interconnection Facilities 
Studies for Interconnection Facilities or Connection Facilities that are 
completed within Transmission Provider’s coordinated region during the 
reporting quarter,  
(B)  
Number of Interconnection Requests that had Interconnection Facilities 
Studies for Interconnection Facilities or Connection Facilities that are 
completed within Transmission Provider’s coordinated region during the 
reporting quarter that were completed more than 90 Calendar Days after 
the Interconnection Customer Decision Point I window expired, 
(C)  
At the end of the reporting quarter, the number of active valid 
Interconnection Requests with ongoing incomplete Interconnection 
Facilities Studies for Interconnection Facilities or Connection Facilities 
where such Interconnection Requests had exceeded more than 90 Calendar 
Days,  
(D)  
Mean time (in Calendar Days), for Interconnection Facilities Studies for 
Interconnection Facilities or Connection Facilities completed within 
Transmission Provider’s coordinated region during the reporting quarter, 
calculated from the day after the Interconnection Customer Decision Point

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
I window expired to the date when Transmission Provider provided the 
completed Interconnection Facilities Study report for Interconnection 
Facilities or Connection Facilities to the Interconnection Customer,  
(E)  
Percentage of Interconnection Requests with delayed Interconnection 
Facilities Study report for Interconnection Facilities or Connection 
Facilities this reporting quarter, calculated as the sum of 3.4.2.4(B) plus 
3.4.2.4(C) divided by the sum of 3.4.2.4(A) plus 3.4.2.4(C)). 
  
3.4.2.5 Interconnection Facilities Studies for Network Upgrades Processing 
Time.  
 
(A)  
Number of Interconnection Requests that had Interconnection Facilities 
Study reports for Network Upgrades that are completed within 
Transmission Provider’s coordinated region during the reporting quarter,  
(B)  
Number of Interconnection Requests that had Interconnection Facilities 
Study reports for Network Upgrades that are completed within 
Transmission Provider’s coordinated region during the reporting quarter 
that were completed more than 90 Calendar Days after completion of the 
Definitive Planning Phase III Final System Impact Study, 
(C)  
At the end of the reporting quarter, the number of active valid 
Interconnection Requests with ongoing incomplete Interconnection 
Facilities Study reports for Network Upgrades where such Interconnection 
Requests had exceeded more than 90 Calendar Days,  
(D)  
Mean time (in Calendar Days), for Interconnection Facilities Studies for 
Network Upgrades completed within Transmission Provider’s coordinated 
region during the reporting quarter, calculated from the day after 
completion of the Definitive Planning Phase III Final System Impact 
Study to the date when Transmission Provider provided the completed 
Interconnection Facilities Study report for Network Upgrades to the 
Interconnection Customer,

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
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(E)  
Percentage of Interconnection Requests with delayed Interconnection 
Facilities Studies for Network Upgrades this reporting quarter, calculated 
as the sum of 3.4.2.5(B) plus 3.4.2.5(C) divided by the sum of 3.4.2.5(A) 
plus 3.4.2.5(C).  
 
3.4.2.6 Interconnection Requests Withdrawn from Interconnection  
Queue.  
 
(A)  
Number of Interconnection Requests withdrawn from Transmission 
Provider’s interconnection queue during the reporting quarter,  
(B)  
Number of Interconnection Requests withdrawn from Transmission 
Provider’s interconnection queue during the reporting quarter before the 
start of the Definitive Planning Phase I, pursuant to Section 3.3.1 of the 
GIP,  
(C)  
Number of Interconnection Requests withdrawn from Transmission 
Provider’s interconnection queue during the reporting quarter from start of 
the Definitive Planning Phase I, pursuant to Section 3.3.1 of the GIP, to at 
or before the Interconnection Customer Decision Point I window expired, 
(D)  
Number of Interconnection Requests withdrawn from Transmission 
Provider’s interconnection queue during the reporting quarter after the 
Interconnection Customer Decision Point I window expired to at or before 
the Interconnection Customer Decision Point II window expired,  
(E)  
Number of Interconnection Requests withdrawn from Transmission 
Provider’s interconnection queue during the reporting quarter after the 
Interconnection Customer Decision Point II window expired to before 
execution of a Generator Interconnection Agreement or Interconnection 
Customer requests the filing of an unexecuted, new interconnection 
agreement  
(F) 
Number of Interconnection Requests withdrawn from Transmission 
Provider’s interconnection queue after execution of a Generator

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Interconnection Agreement or Interconnection Customer requests the 
filing of an unexecuted, new interconnection agreement,  
(G)  
Mean time (in Calendar Days), for all withdrawn Interconnection 
Requests, from the date when the request was determined to be valid to 
when Transmission Provider received the request to withdraw from the 
queue.  
 
3.4.3   Transmission Provider is required to post on OASIS or its website the measures in 
paragraph 3.4.2.1(A) through paragraph 3.4.2.6(G) for each calendar quarter within 30 
Calendar Days of the end of the calendar quarter.  Transmission Provider will keep the 
quarterly measures posted on OASIS or its website for three calendar years with the first 
required report to be in the first quarter of 2020. If Transmission Provider retains this 
information on its website, a link to the information must be provided on Transmission 
Provider’s OASIS site.  
 
3.4.4  In the event that any of the values calculated in paragraphs 3.4.2.1(E), 3.4.2.2(E), 
3.4.2.3(E), 3.4.2.4(E), or 3.4.2.5(E) exceeds 25 percent for two consecutive calendar 
quarters, Transmission Provider will have to comply with the measures below for the 
next four consecutive calendar quarters and must continue reporting this information until 
Transmission Provider reports four consecutive calendar quarters without the values 
calculated in 3.4.2.1(E), 3.4.2.2(E), 3.4.2.3(E), 3.4.2.4(E), or 3.4.2.5(E)) exceeding 25 
percent for two consecutive calendar quarters:  
 
(i) 
Transmission Provider must submit a report to the Commission describing the 
reason for each Group Study, individual Interconnection Facilities Study, or 
Restudy pursuant to one or more Interconnection Request(s) that exceeded its 
deadline completion  of each phase as specified in Sections 7.3.1, 7.3.2 and 7.3.3 
of this GIP, and Section 7.5 of this GIP for restudies. Transmission Provider must 
describe the reasons for each study delay and any steps taken to remedy these 
specific issues and, if applicable, prevent such delays in the future. The report

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Generator Interconnection Procedures (GIP)
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must be filed at the Commission within 45 Calendar Days of the end of the 
calendar quarter.  
 
(ii)  
Transmission Provider shall aggregate the total number of employee-hours and 
third party consultant hours expended towards interconnection studies within its 
coordinated region that quarter and post on OASIS or its website.  If Transmission 
Provider posts this information on its website, a link to the information must be 
provided on Transmission Provider’s OASIS site.  This information is to be 
posted within 30 Calendar Days of the end of the calendar quarter. 
 
3.5 
Coordination with Affected Systems. 
Except as modified by Sections 3.5.1 andthrough 3.5.23 of these GIP, Interconnection 
Customer or MHVDC Connection Customer, Transmission Provider, Transmission 
Owner and Affected System Operator shall each coordinate and cooperate on studies 
required to determine the impact of the Interconnection Request on Affected Systems.  
Transmission Provider will include such Affected System Operators, whose 
representatives either abide by FERC’s Standards of Conduct pursuant to 18 C.F.R 
Parts 37 and 358 or have executed a non-disclosure agreement with Transmission 
Provider, in all meetings held with Interconnection Customer as required by the GIP.  If 
the Affected System is not under the functional control of Transmission Provider, the 
Affected System Operator’s procedures shall be applicable.  Interconnection Customer or 
MHVDC Connection Customer will be separately responsible to adhere to the Affected 
Systems Operator’s procedures and costs related to studies and modifications to the 
Affected System.   
 
Interconnection Customer or MHVDC Connection Customer will cooperate with 
Transmission Provider in all matters related to the conduct of studies and the 
determination of modifications to Affected Systems.  Transmission Provider may limit 
Interconnection Service or Injection Rights for an Interconnection Request until needed 
reliability upgrades on an Affected System(s) are complete under separate agreements.

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Each Interconnection Customer or MHVDC Connection Customer shall provide notice to 
Transmission Owner and Transmission Provider that the facilities built under such 
agreements are in service. 
3.5.1 Additional Requirements for Interconnection Requests Subject to JTIQ. 
Transmission Provider shall use the rules and procedures contained in Section 
9.4.2 of Rate Schedule 6 (MISO-SPP JOA) to apply to Interconnection Customers 
and Interconnection Requests that have been designated for inclusion in a JTIQ 
Participation Group or a JTIQ Commitment Group. Interconnection Customers 
included in a JTIQ Screening Group, JTIQ Participation Group or a JTIQ  
Commitment Group shall be responsible for adhering to all applicable 
requirements set forth Section 9.4.2 of the Rate Schedule 6 (MISO-SPP JOA), 
these Generator Interconnection Procedures, the GIA, and applicable JTIQ 
Service Agreements. 
3.5.1.1:  Inclusion in a JTIQ Screening Group, JTIQ Participation Group, 
and JTIQ Commitment Group. 
(1) Interconnection Requests shall be included in the JTIQ Screening Group if 
they are submitted into a DPP study group or an ERAS that: (1) has a study 
commencement or kick off date that is after the date that the Parties’ respective 
Boards of Directors have approved a JTIQ Portfolio; and (2) has not commenced 
DPP Phase I studies or an ERAS as of the date that the Transmission Provider and 
SPP  have declared the JTIQ Portfolio fully subscribed. 
 
(2) Interconnection Requests shall be included in a JTIQ Participation Group if

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
they meet the following criteria: 
(a) 
the Interconnection Request is determined to have an impact 
greater than five percent (5%) distribution factor (OTDF or 
PTDF1) on one or more facilities of SPP’s transmission system modelled 
with all transmission facilities rated 100 kV and above; and 
(b) the Interconnection Request is determined to have greater than 
1.00 MW (positive) impact on at least one JTIQ Upgrade 
included in the JTIQ Portfolio. 
Any new Interconnection Request for an Existing Generating Facility that is 
seeking to convert to or increase the level of NRIS service will only be included 
in the JTIQ Participation Group to the extent of any additional ERIS service 
requested. 
(3) Interconnection Customers shall enter a JTIQ Commitment Group upon 
obtaining an effective GIA and JTIQ Commitment Agreement that obligate such 
Interconnection Customer to pay, and provide security for, JTIQ Generator 
Charges.   Placement into the applicable JTIQ Commitment Group shall be 
governed by the terms of the Commitment Agreement and Section 2 of 
Attachment JJJ to the Tariff.   
3.5.2. Application of Affected Systems Coordination Procedures to 
Interconnection Requests Included in an Expedited Resource 
 
1  
Power Transfer Distribution Factor (PTDF) - The percentage of power transfer flowing through a facility or 
a set of facilities for a particular transfer when there are no contingencies. Outage Transfer Distribution 
Factor (OTDF) - The percentage of a power transfer that flows through the monitored facility for a 
particular transfer when the contingency facility is switched out of service.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Addition Study 
The Transmission Provider shall apply to ERAS Interconnection Requests, 
and the ERAS Interconnection Customer shall adhere to, the same 
coordination procedures and same screening criteria applicable to 
Interconnection Requests included in a DPP Study Group with the 
following exceptions: (1) The Transmission Provider will submit all 
information necessary to enable an Affected System to study the impacts 
of an ERAS Interconnection Request not later than ten (10) Calendar Days 
prior to the kickoff of the applicable ERAS study for such project; (2) The 
Transmission Provider will provide any affected systems analysis received 
from the affected system to the ERAS Interconnection Customer promptly 
upon receipt; (3) In the event that affected systems studies and cost 
information are not available at the time the EGIA is tendered, such EGIA 
shall include an obligation to execute any agreements for the study, 
construction, or funding of Network Upgrades identified by the affected 
system within fifteen (15) Calendar Days after such agreement is tendered 
for execution to the Interconnection Customer; (4) The Transmission 
Provider shall submit ERAS Interconnection Requests to the applicable 
affected system individually and request that such affected system study 
the impacts of ERAS Interconnection Requests on a serial basis; and (5) 
For those affected systems where MISO and the affected system utilize a 
specified point in MISO’s multi-phase process such as a Decision Point or 
phase kickoff date to establish the queue priority date of MISO 
Interconnection Requests, MISO shall assert a queue priority date for 
ERAS projects as of the date MISO commences the ERAS System Impact 
Study unless the controlling agreement between MISO and the affected 
system expressly provide an alternate queue priority date for ERAS 
projects.  Interconnection requests with an earlier queue priority date as 
determined in accordance with this Section 9.4.3(a) will have a higher

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
relative queue priority than those with a later queue priority date. 
3.5.3. Application of Affected Systems Coordination Procedures to 
Interconnection Requests Seeking ZG Interconnection Service 
The Transmission Provider shall apply to ZG Interconnection Requests, 
and the ZG Interconnection Customer shall adhere to, the same 
coordination procedures and same screening criteria applicable to 
Interconnection Requests included in a DPP Study Group with the 
following exceptions:  (1) The Transmission Provider will submit all 
information necessary to enable an Affected System to study the impacts 
of a ZG Interconnection Request not later than ten (10) Calendar Days 
prior to the kickoff of the applicable ZG Impact Assessment for such 
project; (2) The Transmission Provider will provide any affected systems 
analysis received from the affected system to the ZG  Interconnection 
Customer promptly upon receipt; (3) In the event that affected systems 
studies and cost information are not available at the time the ZGIA is 
tendered, such ZGIA shall include an obligation to execute any 
agreements for the study, construction, or funding of Network Upgrades 
identified by the affected system within fifteen (15) Calendar Days after 
such agreement is tendered for execution to the Interconnection Customer; 
(4) The Transmission Provider shall submit ZG Interconnection Requests 
to the applicable affected system individually and request that such 
affected system study the impacts of ZG Interconnection Requests on a 
serial basis; and (5) For those affected systems where MISO and the 
affected system utilize a specified point in MISO’s multi-phase process 
such as a Decision Point or phase kickoff date to establish the queue 
priority date of MISO Interconnection Requests, MISO shall assert a 
queue 
priority 
date 
for 
Interconnection 
Requests 
seeking 
ZG 
Interconnection Service as of the date MISO commences the ZG Study 
unless the controlling agreement between MISO and the affected system 
expressly provide an alternate queue priority date for ZG projects.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Interconnection requests with an earlier queue priority date as determined 
in accordance with this Section 3.5.3 will have a higher relative queue 
priority than those with a later queue priority date. 
 
3.6 
Withdrawal. 
Interconnection Customer or MHVDC Connection Customer may withdraw its 
Interconnection Request at any time by written notice of such withdrawal to 
Transmission Provider.  In addition, if Interconnection Customer fails to adhere to all 
requirements of the GIP, except as provided in Section 13.5 (Disputes), Transmission 
Provider shall deem the Interconnection Request to be withdrawn and shall provide 
written notice to Interconnection Customer or MHVDC Connection Customer of the 
deemed withdrawal and an explanation of the reasons for such deemed withdrawal.  
Unless otherwise provided in this GIP, upon receipt of such written notice, 
Interconnection Customer or MHVDC Connection Customer shall have fifteen (15) 
Business Days in which to either respond with information or actions that cure the 
deficiency or to notify Transmission Provider of its intent to pursue Dispute Resolution. 
 
In the event that an MHVDC Transmission Connection Request is withdrawn or deemed 
withdrawn in accordance with the terms of Attachment GGG to the Tariff, then all 
Interconnection Requests associated with that MHVDC Transmission Connection 
Request will also be deemed withdrawn. 
 
Withdrawal prior to or during Interconnection Customer Decision Point I shall result in 
the loss of the Interconnection Customer’s or MHVDC Connection Customer’s 
Definitive Planning Phase Queue Position.  Withdrawal after Interconnection Customer 
Decision Point I, but prior to or during Interconnection Customer Decision Point II shall 
result in the loss of the Interconnection Customer’s or MHVDC Connection Customer’s 
Definitive Planning Phase Queue Position and forfeiture of the Definitive Planning Phase 
entry milestone (M2) payment.  Withdrawal after Interconnection Customer Decision 
Point II shall result in the loss of Interconnection Customer’s or MHVDC Connection

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Customer’s Definitive Planning Phase Queue Position and forfeiture of the M2, M3 and 
M4 milestone payments, except as otherwise provided in Section 7.6.2 and 7.8. 
 
If an Interconnection Customer or MHVDC Connection Customer disputes the 
withdrawal and loss of its applicable queue position, then during Dispute Resolution, the 
Interconnection Customer’s or MHVDC Connection Customer’s Interconnection Request 
is eliminated from the queue until such time that the outcome of Dispute Resolution 
would restore its applicable queue position.   
 
An Interconnection Customer or MHVDC Connection Customer that withdraws or is 
deemed to have withdrawn its Interconnection Request shall pay to Transmission 
Provider all costs that Transmission Provider prudently (i) incurs prior to the 
Transmission Provider’s receipt of notice described above and (ii) will incur as a result of 
the withdrawal.  Interconnection Customer or MHVDC Connection Customer must pay 
all monies due to Transmission Provider before it is allowed to obtain any 
Interconnection Study data or results.  
 
Transmission Provider shall (i) update the OASIS list of Interconnection Requests and 
(ii) refund to Interconnection Customer or MHVDC Connection Customer any portion of 
the Interconnection Customer’s or MHVDC Connection Customer’s study deposit that 
exceeds the costs that Transmission Provider has incurred or will incur as a result of the 
withdrawal as described in Section 13.3, including interest earned on the Interconnection 
Customer’s or MHVDC Connection Customer’s study deposit and Definitive Planning 
Phase entry milestone payment while held in Transmission Provider’s interest-bearing, 
money market account, or if such account does not exist, then the interest calculated in 
accordance with 18 C.F.R. Section 35.19a(a)(2)(iii).  In the event of such withdrawal, 
Transmission Provider, subject to the confidentiality provisions of Section 13.1, shall 
provide, at Interconnection Customer’s or MHVDC Connection Customer’s request, all 
information that Transmission Provider developed for any completed study conducted up 
to the date of withdrawal of the Interconnection Request.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
 
3.7 
Additional requirements for Generating Facility Replacement Requests. 
 
3.7.1 Requirements for Replacement Generating Facility Requests. 
i)  
Except as provided in Section 3.7.1(i)(a) of this Attachment X, any Replacement 
Generating Facility must connect to the Transmission System at the same 
electrical Point of Interconnection (i.e. same voltage level at the interconnecting 
substation) as the Existing Generating Facility. 
a. 
An Interconnection Customer shall perform, and Transmission Provider 
shall validate an evaluation study utilizing the latest available DPP phase 
model to ensure the Replacement Generating Facility connecting to a 
different Point of Interconnection will: (1) connect to the same voltage 
level unless the same voltage level is not available by the COD; (2) not 
cause new constraints, as demonstrated by a contingency analysis 
performed in accordance with BPM-015; (3) and change the Power 
Transfer Distribution Factor less than 5% on any branch unless it is a zero 
impedance element or a line on the shortest path without queued 
Interconnection Requests from the existing Point of Interconnection to the 
new Point of Interconnection. 
 
ii)  
The request for Generating Facility Replacement must be submitted to the 
Transmission Provider by the Interconnection Customer for its Existing 
Generating Facility at least one (1) year prior to the date that the Existing 
Generating Facility will cease operation unless the Existing Generating Facility is 
in suspension or approved for suspension pursuant to Section 38.2.7 of the Tariff 
or in Forced Outage, and at least one (1) year prior to the Commercial Operation 
Date for the Replacement Generating Facility.  An Interconnection Customer 
utilizing an extension to the Commercial Operation Date or In-Service Date as set 
forth in Section 4.4.4 of the GIP must submit the request for Generating Facility 
Replacement at least one (1) year prior to the extended Commercial Operation

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Date.  A unit with a surplus GIA may propose to replace its host Existing 
Generating Facility should the Surplus Host Unit retire and does not submit a 
timely replacement request.  The unit with a surplus GIA shall submit its 
replacement request one (1) year prior to the proposed Commercial Operation 
Date of the Replacement Generating Facility.  For the Existing Generating 
Facility approved for suspension or in forced outage, the request for Generating 
Facility Replacement must be submitted prior to 25th cumulative month of 
suspension or forced outage within 5 years period.  The request shall include the 
planned or actual date of cessation of operation for the Existing Generating 
Facility and the expected Commercial Operation Date for the Replacement 
Generating Facility.  The expected Commercial Operation Date of the 
Replacement Generating Facility must be at least one (1) Calendar Day after the 
date the Existing Generating Facility ceases operations. 
 
iii)  
The Interconnection Customer shall request only ER Interconnection Service for 
the Replacement Generating Facility if the Existing Generating Facility has only 
ER Interconnection Service. The request for NR Interconnection Service for the 
Replacement Generating Facility, when the Existing Generating Facility has only 
ER Interconnection Service, shall be submitted as a separate Interconnection 
Request and shall proceed through the Definitive Planning Phase cycle in the 
same manner as an Interconnection Request for a new Generating Facility. The 
Interconnection Customer may request either ER Interconnection Service or NR 
Interconnection Service for the Replacement Generating Facility if the Existing 
Generating Facility has NR Interconnection Service. Requests for ER or NR 
Interconnection Service that exceed the amount of Interconnection Service for the 
Existing Generating Facility shall be processed as a new Interconnection Request 
for the amount of such excess pursuant to Section 3.7.1.iv of this Attachment X to 
the Tariff. 
 
iv)  
If the Replacement Generating Facility requires Interconnection Service (MW) in

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
excess of that of the Existing Generating Facility that is being replaced, 
Interconnection Customer shall initiate a separate request for Interconnection 
Service in an amount (MW) equal to the excess. Such Interconnection Request 
shall be assigned a new Queue Position, and proceed through the Definitive 
Planning Phase cycle in the same manner as an Interconnection Request for a new 
Generating Facility. 
 
v)  
If the request for Generating Facility Replacement requests less Interconnection 
Service (MW) than that of the Existing Generating Facility that is being replaced, 
the owner shall be required to submit an Attachment Y Notice for the amount 
(MW) of such decrease in generating capacity to the Transmission Provider prior 
to the execution of the GIA of the Replacement Generating Facility or the election 
by the Interconnection Customer to proceed unexecuted.  If the Interconnection 
Customer indicates in its Interconnection Request that the Reliability Assessment 
Study shall include analysis of a retirement scenario, the timing of the associated 
Attachment Y will supersede the requirements of Section 38.2.7 of the Tariff, as 
the Reliability Assessment Study completed as part of generator replacement 
process will determine the system impacts for the loss of the generation. 
 
vi)  
Except as provided in Section 3.7.1(vi)(a) of this Attachment X, no request for 
Generating Facility Replacement may be made until twelve (12) months have 
elapsed from: (1) the date of any assignment of the Generator Interconnection 
Agreement applicable to the Existing Generating Facility, or (2) the date of sale or 
other transfer of such Existing Generating Facility. When an Existing Generating 
Facility is owned by more than one party and such coownership has existed for at 
least twelve (12) months prior to the date that the request for Generating Facility 
Replacement has been made, the restrictions described in this paragraph on 
transfers shall not preclude such co-owners from determining their respective 
ownership percentages in the Replacement Generating Facility, provided that the 
ownership interests in the Replacement Generating Facility is disclosed in the

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
request of the Interconnection Customer that owns or controls the Existing 
Generating Facility pursuant to an existing Generator Interconnection Agreement 
for Generating Facility Replacement. Upon submission of a request for 
Generating Facility Replacement, the Interconnection Customer shall not sell or 
otherwise transfer the Existing Generating Facility, the Replacement Generating 
Facility, nor assign the applicable Generator Interconnection Agreement except as 
provided in Section 3.7.1(vi)(a) of this Attachment X until such time as the 
Transmission Provider completes evaluation of the request for Generating Facility 
replacement unless the Interconnection Customer first withdraws such request for 
Generating Facility Replacement in writing. In the event that the Transmission 
Provider notifies Interconnection Customer that the request for Generating 
Facility Replacement has been granted, the prohibition on sales, transfers, or 
assignments not authorized by this Attachment X shall be extended in accordance 
with Section 3.7.5 of this Attachment X. For purposes of this Section 3.7.1 (vi), 
prohibited assignments include assignments to affiliates pursuant to Article 19.1 
of the pro forma Generator Interconnection Agreement or any analogous 
provision in the applicable GIA. 
a. An Interconnection Customer may: (1) sell or otherwise transfer its 
Existing Generating Facility, (2) assign its Generator Interconnection 
Agreement; or (3) sell or otherwise transfer a Replacement Generating 
Facility to an entity or entities meeting the requirements of Section 
3.7.1(vi)(a)(1) below without violating this Section 3.7.1(vi) if all of 
the following conditions are satisfied prior to such sale, assignment or 
transfer becoming effective: 
1. The Interconnection Customer that owns or controls the 
Existing Generating Facility pursuant to an existing Generator 
Interconnection Agreement demonstrates to the Transmission 
Provider that it both: 
i. 
Holds, directly or indirectly, not less than a 25% 
ownership interest in each entity receiving the

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
applicable assignment or transfer as demonstrated 
through documentation of: (1) shares or a partnership 
interests in the transferee/assignee; (2) a right to receive 
at least 25% of net proceeds from the sale of the 
transferred or assigned generating facility; or (3) 
another form of interest in the transferee/assignee that is 
recognized by the Commission as equivalent to an 
ownership interest; 
ii. 
Has the documented right to direct the performance of 
such entity with respect to any obligation under MISO’s 
Tariff  and Generator Interconnection Agreement 
applicable to the transferred Generating Facility; and 
2. The Interconnection Customer that owns or controls the 
Existing Generating Facility pursuant to an existing Generator 
Interconnection Agreement and the entity that received the 
assignment or transfer commit in documentation to be supplied 
to the Transmission Provider prior to the effective date of any 
sale, assignment or transfer: (i) that the Interconnection 
Customer shall retain the ownership and control required by 
Section 3.7.1(vi)(a)(1) of this Attachment X until the 
Replacement Generating Facility achieves commercial 
operation in accordance with Section 3.7.5 of this Attachment 
X, unless the request for Generating Facility Replacement is 
denied or withdrawn; (ii) that the entity receiving the 
assignment or transfer under this section 3.7.1(vi) of this 
Attachment X agrees not to further sell, transfer or assign its 
interests in the Existing Generating Facility, Replacement 
Generating Facility, or Generator Interconnection Agreement 
except in accordance with this Attachment X; and (iii) to 
provide the Transmission Provider upon request with

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
documentation demonstrating continued compliance with the 
requirements of Section 3.7.1(vi) of this Attachment X at any 
time prior to the date that the applicable Replacement 
Generating Facility achieves commercial operation; and 
3.    The Interconnection Customer receives the consent of the 
Transmission Provider, which consent shall be granted upon 
the Transmission Provider determining that the proposed 
transfer(s) or assignment(s) comply with the requirements of 
Section 3.7.1(vi)(a) of these Generator Interconnection 
Procedures. 
 
 
A transfer, sale, or assignment of the Existing Generating Facility, Replacement 
Generating Facility, or applicable GIA that violates this Section 3.7.1 (vi) or Section 
3.7.1(vi)(a) of Attachment X shall void the request for Generating Facility Replacement. 
 
3.7.1.1 Requirements for modification of Replacement Generating Facility Requests. 
The request to modify the Replacement Generating Facility shall be submitted any time 
prior to the commencement of the evaluation process for Generating Facility 
Replacement requests. 
 
1) 
If the revised planned date of cessation of operation for the Existing Generating 
Facility is prior to the planned date of cessation of operation specified in original 
request, a new request for Replacement Generating Facility must be submitted at 
least one (1) year prior to the date that the Existing Generating Facility is planned 
to cease operation.  
 
2) 
If the revised planned date of cessation of operation for the Existing Generating 
Facility is after the planned date of cessation of operation specified in original 
request, a notification for Replacement Generating Facility must be submitted to 
the MISO Resource Utilization team (resourceretirement@misoenergy.org) at least

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
thirty (30) Calendar Days prior to the original date that the Existing Generating 
Facility is planned to cease operation.  The revised planned date of cessation must 
be at least one (1) Calendar Day before the Commercial Operation Date of the 
Replacement Generating Facility, including any extension provided and utilized 
under Section 4.4.4 of the GIP. 
 
3) 
If the revised expected Commercial Operation Date for the Replacement 
Generating Facility is after the expected Commercial Operation Date for the 
Replacement Generating Facility in the original request, a new request for 
Replacement Generating Facility must be submitted at least one (1) year prior to 
the date that the Existing Generating Facility is planned to cease operation, unless 
the Existing Generating Facility is in suspension pursuant to Section 38.2.7 of the 
Tariff or in Forced Outage. 
 
3.7.2 Evaluation Process for Generating Facility Replacement Requests. 
The Transmission Provider will evaluate Generating Facility Replacement requests in the 
order in which they are submitted.  The evaluation will consist of two studies: i) a 
Replacement Impact Study as set forth in Section 3.7.2.1 of the GIP, and ii) a Reliability 
Assessment Study as set forth in Section 3.7.2.2 of the GIP.  
 
Transmission Provider shall use Reasonable Efforts to complete the Replacement Impact 
Study and Reliability Assessment Study and share results with the Interconnection 
Customer within one hundred eighty (180) Calendar Days of the request. 
 
3.7.2.1 Generating Facility Replacement—Replacement Impact Study. 
The Replacement Impact Study will include analyses to determine if the Replacement 
Generating Facility has a material adverse impact on the Transmission System when 
compared to Existing Generating Facility. The Replacement Impact Study may include 
steady-state (thermal/voltage), reactive power, short circuit/fault duty, and stability 
analyses, as necessary, to ensure that required reliability conditions are studied. If the

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Replacement Impact Study identifies any materially adverse impact from operating the 
Replacement Generating Facility when compared to the Existing Generating Facility, 
such impacts shall be deemed a Qualified Change, and in order to move forward, the 
Interconnection Customer must submit all information and milestone payments necessary 
for a valid Interconnection Request for a new Generating Facility pursuant to Section 3.3 
of this GIP, be assigned queue priority as of the date such information and milestones are 
provided, and proceed through the Definitive Planning Phase cycle as an Interconnection 
Request for a new Generating Facility.  In such event, the Interconnection Customer shall 
be subject to the timing and requirements of Section 38.2.7 of the Tariff for any 
retirement of the Existing Generating Facility. 
 
3.7.2.2 Generating Facility Replacement—Reliability Assessment Study 
The Reliability Assessment Study for the time period between the date that the Existing 
Generating Facility ceases commercial operations and the Commercial Operation Date 
including any extension provided under Section 4.4.4 of the GIP of the Replacement 
Generating Facility shall evaluate the performance of the Transmission System to 
determine if thermal and/or voltage violations of applicable the Electric Reliability 
Organization Standards and Transmission Owner planning criteria are caused by 
removing the Existing Generating Facility from service prior to the Commercial 
Operation Date of the Replacement Generating Facility. This study shall compare the 
conditions on the Transmission System that would exist if the Existing Generating 
Facility is taken offline to the conditions on the Transmission System as they exist when 
the Existing Generating Facility is online. The scope of Reliability Assessment Study 
may include stability analysis as necessary. The Existing Generating Facility shall be 
responsible for mitigating any reliability violation identified in the Reliability Assessment 
Study and may not cease operations until all mitigations are implemented or are in 
service. Mitigation for this interim period may, as applicable, include: (i) 
redispatch/reconfiguration through operator instruction; and (ii) remedial action scheme 
or any other operating steps depending upon the type of reliability violation identified.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
The Interconnection Customer may request in its Interconnection Request that the 
Reliability Assessment Study include an analysis equivalent to an Attachment Y study, as 
defined in Section 38.2.7 of the Tariff.  The Transmission Provider shall include such 
analysis in the Reliability Assessment Study when requested.  After completion of the 
Reliability Assessment Study with all reliability violations mitigated for the Existing 
Generating Facility, the Interconnection Customer may choose to submit an Attachment 
Y request to obtain suspension approval based on Reliability Assessment Study results 
before the GIA for the Replacement Generating Facility is executed or the 
Interconnection Customer elects to proceed unexecuted or sixty (60) days after the 
request for Generating Facility Replacement request is withdrawn.   
 
3.7.3 Generating Facility Replacement - Notice to Proceed 
Interconnection Customer requesting Generating Facility Replacement shall inform 
Transmission Provider within thirty (30) Calendar Days after having received results of 
the Replacement Impact Study and Reliability Assessment Study of its election to 
proceed and Transmission Provider will initiate an Interconnection Facilities Study or 
tender a draft GIA.  Interconnection Customer that fails to provide an election to proceed 
within thirty (30) Calendar Days will result in withdrawal of the Interconnection Request 
pursuant to Section 3.6 of this GIP. 
 
3.7.4 Scope of Interconnection Facilities Study 
Interconnection Facilities Study focusing on the Interconnection Facilities for the 
Replacement Generating Facility will start, if the Transmission Provider determines such 
a study is necessary, upon Interconnection Customer’s notice to proceed to the 
Transmission Provider after completion of the Replacement Impact Study and the 
Reliability Assessment Study.  This Interconnection Facilities Study will identify 
estimates for cost and the time required to construct the Interconnection Facilities.  
Transmission Provider shall use Reasonable Efforts to complete this portion of the 
Interconnection Facilities Study within ninety (90) Calendar Days.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
3.7.5 GIA for Generating Facility Replacement. 
 
Transmission Provider shall tender a draft pro forma GIA or GIAs or, if deemed 
appropriate, an amended GIA or GIAs that conforms to the pro forma GIA in effect at the 
time, within thirty (30) Calendar Days after the Interconnection Customer communicates 
its election to proceed with Generator Replacement if an Interconnection Facilities Study 
is not required or within thirty (30) Calendar Days after final Facility Study reports are 
provided to the Interconnection Customer. An Interconnection Customer that transferred 
or assigned a Replacement Generating Facility to one or more entities consistent with the 
requirements of 3.7.1(vi)(a) may elect for each such entity to receive a separate GIA for 
its Replacement Generating Facility. The draft pro forma GIA shall include updated 
appendices describing the timing of Generating Facility Replacement and a condition that 
the GIA or GIAs cannot be assigned and the Replacement Generating Facility cannot be 
transferred to any other Party, including an affiliate of the Interconnection Customer 
other than as allowed by Section 3.7.1(vi)(a) of this Attachment X, until such date as the 
applicable Replacement Generating Facility achieves commercial operation. A transfer, 
sale, or assignment of the Existing Generating Facility, Replacement Generating Facility, 
or applicable GIA that violates this Section 3.7.5 shall be void and constitute a material 
breach of the GIA. 
 
If the MW of a Generating Facility Replacement request is less than the MW of the 
Existing Generating Facility that is being replaced, the Interconnection Customer cannot 
make any additional Generating Facility Replacement requests after the first GIA for the 
Generating Facility Replacement is executed or the Interconnection Customer elects to 
proceed unexecuted. 
 
3.8 
Identification of Contingent Facilities. 
MISO identifies Contingent Facilities using the following three methods: 
i.  
Review all transmission facilities included in Interconnection System Impact 
Studies performed for an Interconnection Request that are: (1) listed in Appendix

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
A of the Transmission Provider’s Transmission Expansion Plan (MTEP) that are 
not yet in service, unless the Transmission Provider determines through the 
exercise of engineering judgment and after consultation with the applicable 
Transmission Owner(s), that such project does not address an existing overload 
and will not impact the injection of the Interconnection Request, such as age 
related line renewal projects that are not Baseline Reliability Project; or (2) 
identified as Network Upgrades through the System Impact Studies for higher 
queued Interconnection Requests that are not yet in service. Contingent Facilities 
shall be identified from this list as those facilities that meet the following criteria: 
a.  
Power Transfer Distribution Factor or Outage Transfer Distribution Factor 
≥ 5% and;  
b.  
MW impact (Power Transfer Distribution Factor or Outage Transfer 
Distribution Factor multiplied by generator output of the Interconnection 
Request) ≥ 5 MW, and; 
c.  
MW impact (Power Transfer Distribution Factor or Outage Transfer 
Distribution Factor multiplied by generator output of the Interconnection 
Request) ≥ 1% of the Facility Rating. 
ii. 
All Network Upgrades identified in the Final System Impact Study for a given 
Interconnection Request pursuant to Section 7.3.3.3 of this GIP. 
iii.  
Coordination with applicable Affected System parties to determine what 
Contingent Facilities have been identified through Affected System studies based 
on their respective criteria. 
 
The Contingent Facilities identified for a given Interconnection Request are the total of 
all facilities identified through each of the foregoing three methods as well as all JTIQ 
Upgrades included in a JTIQ Portfolio that meet one of these foregoing methods, for 
which the Interconnection Customer has been designated for inclusion in the JTIQ 
Participation Group.  Transmission Provider shall provide an initial list of Contingent 
Facilities at the start of the Interconnection Customer Decision Point II, which list shall 
include facilities identified in the Revised System Impact Study performed pursuant to

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Section 7.3.2.3, and the final list of Contingent Facilities shall be documented in 
Appendix A of the Generator Interconnection Agreement for such Interconnection 
Request.  The estimated Interconnection Facility and/or Network Upgrade costs and 
estimated in-service completion time of each identified Contingent Facility shall be 
provided in Appendix A of the Generator Interconnection Agreement for such 
Interconnection Request when this information is readily available and not commercially 
sensitive. 
 
3.9  
Expedited Resource Addition Study. 
 
3.9.1  Requirements for Expedited Resource Addition Study. 
A request for processing through the Expedited Resource Addition Study made by 
an Interconnection Customer must meet the requirements listed in Section 3.3.1 
above, plus the following requirements: 
1. 
The Interconnection Request shall be accompanied by a written 
verification from the RERRA (or its documented representative) where the 
load to be served by the Generating Facility is located, subject to the 
procedures or methods the RERRA requires, that either: 
 
i. the new, incremental load addition claimed by the Interconnection 
Customer is valid and not otherwise included in a resource plan or 
other process under the RERRA’s purview. 
a. 
The RERRA (or its documented representative) may 
provide such written verification in conjunction with 
another state or municipal agency or official (e.g. 
economic development authority or governor’s office) to 
verify the new, incremental load addition above. 
or

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
ii. the Generating Facility proposed by the Interconnection Customer will 
address a resource adequacy deficiency as determined by the RERRA, 
State, Load Serving Entity, or Interconnection Customer.  The 
determination can be supported by: 
a. A state energy forecast, or other forward-looking forecast; 
b. Commencement of a state proceeding; 
c. Review of a RERRA, LSE, or other state resource plan or 
document, which may include, but is not limited to: integrated 
resource plans, procurement plans, or other plan or study types;  
d. Response to a Request for Proposals (RFP); or 
e. Other process, or delegation of authority, as determined by the 
RERRA or RERRA regulations (including in retail choice 
states). 
 
 
or 
iii. If an Interconnection Customer’s new Generating Facility will address 
a resource adequacy deficiency and will either: 
(1) serve retail choice load located in a state that limits the amount of 
load that can select retail choice to a percentage of the electric utility’s 
average weather-adjusted retail sales;  
or  
(2) serve load in a retail choice state and will be located in a retail 
choice state other than one that limits the amount of load that can 
select retail choice to a percentage of the electric utility’s average 
weather adjusted retail sales, 
then the Interconnection Customer will indicate the specific load on the 
Interconnection Request in Section 4.s of Appendix 1 and provide the 
evidence of determination in (ii) above, but will not be required to include

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
a written verification from a RERRA as described in section 3.9.1(i) or 
(ii).  The Transmission Provider shall notify the respective RERRA that an 
Interconnection Request for a new Generating Facility has been submitted 
requesting processing through the Expedited Resource Addition Study 
process and transmit a copy of the Interconnection Request to the 
respective RERRA.  The RERRA shall have 10 Business Days from the 
date of the Transmission Provider’s notification and the simultaneous 
transmittal of the copy of the Interconnection Request to notify the 
Transmission Provider that the Interconnection Request should not be 
considered in the ERAS process. If no such notice is received at the end of 
10 Business Days or if the RERRA notifies the Transmission Provider of 
its non-opposition prior to the end of the 10 Business Days, the 
Interconnection Request shall be studied through the Expedited Resource 
Addition Study process provided it meets the requirements listed in 
Section 3.3.1 and Section 3.9.2. 
 
A RERRA’s written verification is not intended to constitute or provide evidence of any 
final determination of need or suitability of the project for any purpose by the issuing 
entity beyond requesting that the Transmission Provider apply the ERAS process for such 
project.  
 
and 
2.  
An executed agreement evidencing that the projects submitted for ERAS 
processing is intended to be used by the entity with the claimed resource 
adequacy and/or reliability need.  Such agreement shall take one of the 
following forms: 
a. 
A Load Serving Entity acknowledgement to self-supply; 
b. A Power Purchase Agreement (PPA) or similar off-take agreement 
between the Interconnection Customer submitting the project for

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
ERAS consideration and the entity with the load to be served 
(including, but not limited to, an Alternative Retail Electric Supplier or 
its Load Serving Entity); 
c. An agreement that calls for the Interconnection Customer to develop 
the Generating Facility described in the Interconnection Request and 
subsequently transfer ownership or control of such Generating Facility 
(Build-Own-Transfer Agreement) to the entity with the load to be 
served (including, but not limited to, an Alternative Retail Electric 
Supplier or its Load Serving Entity); or 
d. Other agreement between the entity submitting the Interconnection 
Request, including the RERRA verification letter as appropriate, and 
the entity with the load to be served (including, but not limited to, an 
Alternative Retail Electric Supplier or its Load Serving Entity), stating 
that the ERAS project will be used to meet an identified resource 
adequacy deficiency.  
 
No changes shall be made to the ERAS Interconnection Request after submission. 
 
3.9.2 Evaluation Process for Expedited Resource Addition Study. 
The Transmission Provider will evaluate Expedited Resource Addition Study 
requests in the order in which they are submitted using the time stamp from 
submission.  The Transmission Provider will limit the maximum number of the 
ERAS Interconnection Requests studied in the ERAS process to no more than 68 
projects total until the sunset date noted in Section 3.9.9.  The Transmission 
Provider has carved out a maximum of 8 Interconnection Requests of the total 68 
Interconnection Requests that may be submitted in accordance with 3.9.1.1(iii) to 
serve retail choice load and 10 Interconnection Requests of the total 68 
Interconnection Requests that may be submitted by Independent Power Producers 
(IPPs) with agreements with entities other than Load Serving Entities to ERAS

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
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until the sunset date noted in Section 3.9.9.  The remaining 50 Interconnection 
Requests of the total 68 Interconnection Requests may be submitted by IPPs or 
Load Serving Entities (LSEs) to serve non-retail choice load.   
Interconnection Requests submitted by IPPs with agreements with entities other 
than LSEs to ERAS will be counted first towards the 10 Interconnection Requests 
cap of the total 68 Interconnection Requests before the 50 Interconnection 
Requests to serve non-retail choice load.  After the 10 Interconnection Requests 
submitted by IPPs with agreements with entities other than LSEs are accepted by 
the Transmission Provider, any subsequent Interconnection Request submitted by 
IPPs will count toward the remaining 50 Interconnection Requests to serve non-
retail choice load. 
The Transmission Provider will limit the maximum size of each ERAS Quarterly 
Study Period to no more than 15 Interconnection Requests.  If more than 15 
Interconnection Requests are submitted for one ERAS Quarterly Study Period, 
those surpassing the limit will be studied in a subsequent ERAS study cycle in the 
order in which they were submitted. If an ERAS Interconnection Request is 
within a similar geographical area or impacts the same constraint as another 
ERAS Interconnection Request within the same ERAS Quarterly Study Period, as 
defined in the Generator Interconnection Business Process Manuals, then the later 
submitted request(s) will be studied in a subsequent ERAS study cycle.  
 
An Interconnection Request that does not meet the requirements of ERAS per 
Section 3.9.1 will be notified by the Transmission Provider and automatically 
moved to the standard Definitive Planning Phase queue unless the customer 
chooses to opt out by notifying Transmission Provider.  If deemed ineligible for 
the ERAS process, the project will forfeit its Non-Refundable Deposit D1. 
 
An Interconnection Customer submitting an Interconnection Request to a standard 
Definitive Planning Phase queue may also submit a request for ERAS for

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
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evaluation. If the request meets the requirements for ERAS processing set forth in 
Section 3.9.1, the Interconnection Request seeking processing through the 
standard Definitive Planning Phase queue must be withdrawn from the Definitive 
Planning Phase queue prior to ERAS kickoff.  Upon withdrawing from the 
Definitive Planning Phase queue, the project will forfeit its Non-Refundable 
Deposit D1 and will be subject to penalties per Sections 7.6.2.1.1 and 7.8. 
 
An Interconnection Request included in an active Definitive Planning Phase that 
has not reached Decision Point II may withdraw from the Definitive Planning 
Phase and move their Interconnection Request to the ERAS if they meet the 
requirements for ERAS processing.  The project will be subject to penalties per 
Sections 7.6.2.1.1. and 7.8 and must meet the ERAS requirements in Section 
3.9.1.  Verification of Site Control will be specified in the Generator 
Interconnection Business Practice Manual to authenticate applicability. An 
Interconnection request that has been withdrawn from the Definitive Planning 
Phase after completion of Decision Point II may be moved to ERAS after a period 
of one year from the withdrawal date. 
 
3.9.3 The Study. 
The Interconnection Study for ERAS will follow the same manner of NR 
Interconnection Study as noted in Sections 3.2.1.2 and 3.2.2.2 needed to integrate 
the Generating Facility in the same manner as for any Generating Facility being 
designated as a Network Resource.  Transmission Provider will use Reasonable 
Efforts to study ERAS Interconnection Requests from all Interconnection 
Customers regardless of Generating Facility within sixty (60) Calendar Days after 
the kickoff date for such study.  The study will be performed for each 
Interconnection Request individually in a serial fashion based on their submission 
date per ERAS Quarterly Study Period.  The study will result in a Final System 
Impact Study and any associated Interconnection Facilities Studies.

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
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Transmission Provider shall include in the final study any Affected System Study 
results and information regarding Network Upgrades from Affected Systems 
provided the Affected System Study Reports are available. If Affected Systems 
analysis is not available for inclusion in the final study, the Transmission Provider 
shall provide such analysis separately when received from the applicable Affected 
System. 
 
3.9.4 Notice to Proceed to EGIA. 
Interconnection Customer requesting to be included in ERAS shall inform 
Transmission Provider of its election to proceed within five (5) Calendar Days 
after receiving the draft results of the Expedited Resource Additions Study. 
Interconnection Customer that fails to provide an election to proceed within five 
(5) Calendar Days will result in withdrawal of the Interconnection Request 
pursuant to Section 3.6 of this GIP.  EGIA execution shall occur no later than 30 
Calendar days after receiving Interconnection Customer’s election to proceed. 
 
3.9.5 GIA for Expedited Resource Addition Study Projects (EGIA). 
Transmission Provider shall tender a draft pro forma EGIA, that conforms to the 
pro forma GIA in effect at the time, as modified for ERAS, within five (5) 
Business Days after the Customer provides notice to proceed to EGIA 
negotiations.  In the event that SPP’s JTIQ Service Agreement has not been 
provided to Interconnection Customer prior to tender of a draft EGIA, the draft 
EGIA shall include a milestone in Appendix B obligating Interconnection 
Customer to execute or request the unexecuted filing of SPP’s JTIQ Service 
Agreement not later than 15 Calendar Days after such agreement has been 
tendered to the Interconnection Customer.  Upon tender of the EGIA, the ERAS 
Interconnection Request shall be subject to the timing and procedures set forth in 
Sections 11.1 through 11. 4 of these GIP. 
 
Transmission Provider shall include in the final EGIA any Affected System Study

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
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results and information regarding Network Upgrades from Affected Systems 
provided the Affected System Study Reports are available.  If Affected System 
analysis is not available for inclusion in the final EGIA, the Transmission 
Provider shall provide such analysis separately when received from the 
applicable Affected System.  An Interconnection Request included in a JTIQ 
Participation Group shall adhere to all JTIQ procedures, and execute JTIQ 
Service Agreements as applicable. 
 
3.9.6 Expedited Resource Addition Study Refunds. 
3.9.6.1 Refunds of Expedited Resource Addition Study Deposits D2. 
Transmission Provider shall charge and Interconnection Customer shall 
pay the actual costs of the Expedited Resource Addition Study. Any 
difference between the study deposit and the actual cost of the applicable 
Interconnection Study shall be paid by or refunded to the Interconnection 
Customer as applicable. 
 
3.9.6.2 Refunds of Expedited Resource Addition Study Entrance Milestone 
(M2). 
Interconnection Customers are eligible to receive one hundred percent 
(100%) refund of the Expedited Resource Addition Study entry milestone 
(M2) upon withdrawal prior to execution of the EGIA. Interconnection 
Customers that terminate the EGIA after execution are eligible to receive a 
refund of the remaining M2 milestone payment. 
 
3.9.6.3 Applicability of Expedited Resource Addition Milestone Payment 
(M2) to Expedited Generator Interconnection Agreement Initial 
Payment. 
In the event the Interconnection Customer has elected to make its 
milestones in the form of cash, Transmission Provider will transfer the 
Expedited Resource Addition Study milestone to the appropriate

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
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Transmission Owner to satisfy the initial payment requirement of the 
Expedited Generator Interconnection Agreement, TCA or other applicable 
service agreement within forty-five (45) Calendar Days of the effective 
date of the Expedited Generator Interconnection Agreement, TCA or other 
applicable service agreement.  The Transmission Provider shall refund 
milestone cash payments exceeding the initial payment requirement to the 
Interconnection Customer upon Interconnection Customer’s request with 
Transmission Owner’s consent, within forty-five (45) Calendar Days of 
the effective date of the Generator Interconnection Agreement.  In the 
event the milestone payments are less than the initial payment 
requirement, the Interconnection Customer shall be responsible for the 
remaining payment to the Transmission Owner.   
 
In the event that the Interconnection Customer withdraws and terminates 
its EGIA after execution of the EGIA by all parties or after EGIA is filed 
unexecuted the Interconnection Customer will be liable for the Network 
Upgrades documented in the EGIA and corresponding FCAs or MPFCAs, 
including those Network Upgrades arising from the Affected System 
Study process.  
 
3.9.7 Transfer of Ownership of Expedited Resource Addition Study request. 
An Interconnection Customer participating in the Expedited Resource Addition 
Study may transfer its Interconnection Request to another entity only after 
execution of the EGIA or filing the EGIA unexecuted. The new entity must 
maintain the eligibility requirements per Sections 3.3.1 and 3.9.1. 
 
3.9.8 Modifications of Expedited Resource Addition Study request. 
After entering the Expedited Resource Addition Study as defined in Section 3.9.3, 
no changes to the In-Service Date or Commercial Operation Date of the 
Generating Facility is permitted via section 4.4.4. An ERAS Interconnection

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
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Request that is deferred to the next available ERAS Quarterly Study Period will 
be allowed to extend its In-Service Date or Commercial Operation Date to be no 
more than three calendar years from the kickoff of the ERAS Quarterly Study 
Period in which its application is studied.  At the completion of the Expedited 
Resource Addition Study, the Commercial Operation Date and In-Service Date 
shall be set forth in the EGIA.   
 
3.9.9 Sunset of Expedited Resource Addition Study process. 
Following the effective date of the Tariff revisions accepted in Commission 
Docket No. ER25-____, the Transmission Provider will terminate the ERAS 
process at the earlier of the completion of sixty-eight ERAS Interconnection 
Request studies or August 31, 2027. In the event the Transmission Provider 
determines the sunset date should be extended, the Transmission Provider shall 
submit an additional filing to the Commission pursuant to Section 205 of the 
Federal Power Act seeking such later sunset date. Upon termination of ERAS, the 
Transmission Provider will no longer accept new ERAS Interconnection 
Requests.  Any ERAS Interconnection Requests accepted but cannot be studied 
due to the sunset of the ERAS process will automatically move to the standard 
Definitive Planning Phase queue unless the customer chooses to withdraw.  If 
deemed ineligible for the ERAS process, the project will forfeit its Non-
Refundable Deposit D1. 
 
3.10  Penalties for Failure to Meet Study Deadlines. 
(1) Transmission Provider or Transmission Owner(s), as applicable, shall be subject to a 
penalty if it fails to complete a Group Study, Interconnection Facilities Study, Affected 
System Study, or Affected System Network Upgrade facilities study or a restudy of any 
of the foregoing by the applicable deadline as set forth in the GIP, applicable Joint 
Operating Agreement, Joint Planning Agreement, or any other agreements filed with the 
Commission.   
(2) For purposes of determining compliance with this Section and the calculation of

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
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penalties, the applicable study period is the time to complete the studies identified in 
Section 3.9(1), not including model review, Interconnection Customer review of draft 
study reports, and Decision Point as provided in Sections 7.1 through 7.3 of this GIP.  
Excluding the Interconnection Facilities Study, the study period for all applicable studies 
shall begin the day after the applicable study’s model review period ends, as set forth in 
Section 7 of this GIP.  The study period shall conclude when the draft study report for the 
applicable study is posted or otherwise transmitted to Interconnection Customers.  For 
Interconnection Facilities Study, the applicable study period shall be ninety (90) Calendar 
Days, starting when Transmission Provider submits to the applicable Transmission 
Owner(s) a statement of work and purchase order and ending when the draft study report 
is transmitted to Interconnection Customers pursuant to Sections 7.3.2.5 and 7.3.3.4.   
(3) Transmission Provider or applicable Transmission Owner(s) shall pay the penalty for 
each late Group Study, Group Restudy, or Interconnection Facilities Study on a pro rata 
basis per Interconnection Request to all Interconnection Customer(s) included in the 
relevant study that did not withdraw, or were not deemed withdrawn, from Transmission 
Provider’s interconnection queue before the conclusion of the applicable study in 
proportion to each Interconnection Customer’s final study costs.   
(4) Transmission Provider or applicable Transmission Owner(s) shall pay the penalty for 
a late Affected System Study or Affected System Network Upgrade facilities study on a 
pro rata basis per interconnection request to all Affected System Interconnection 
Customer(s) included in the relevant Affected System Study, or Affected System 
Network Upgrade facilities study that did not withdraw, or were not deemed withdrawn, 
from the host transmission provider’s interconnection queue before the missed study 
deadline in proportion to each Interconnection Customer’s final study costs.   
(5) For delayed studies performed by a Transmission Owner, or its subcontractor or 
delegee, the Transmission Provider shall invoice the applicable Transmission Owner(s) 
who performed the delayed study for the amount of the penalty calculated in accordance 
with Section 3.9(6) and (7). within fifteen (15) Business Days after the date that the final 
study report for the delayed study is posted to OASIS or MISO’s public website.   
The invoiced Transmission Owner(s) shall remit the invoiced amount to the Transmission

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
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Provider not later than forty-five (45) Calendar Days after the date of such invoice. 
Payment of such funds to the Transmission Provider shall not constitute an admission of 
liability for the delay or prejudice the ability of the applicable Transmission Owner(s) or 
Transmission Provider to seek relief from such penalties from the Commission or recover 
penalty amounts from others as provided in Section 3.9(8) of these GIP.  The 
Transmission Provider shall hold all penalty amounts collected pursuant to this 
subsection during the pendency of any appeal to the Commission or reassignment 
proceeding for such penalties authorized by Section 3.9(8) of these GIP or until the 
deadline for initiating such a proceeding has expired in the event such a proceeding has 
not been initiated.  Thereafter, the Transmission Provider shall distribute to the applicable 
Interconnection Customer(s) or refund to the paying Transmission Owner(s) all collected 
funds as required by this Section 3.9 or otherwise ordered by the Commission.  
(6) Any study delay penalty shall be distributed by forty-five (45) Calendar Days  after 
the later of: (a) the date that the final Interconnection Facilities Studies report has been 
posted at the end of Phase III for the applicable study group that experienced a study 
delay, (b) the conclusion of a proceeding regarding such study delay as provided in 
Section 3.9(9) of these GIP, or (c) the date MISO receives the full penalty payment(s) 
from the party(ies) responsible for the delay. 
(7) For penalties assessed in accordance with this Section, the penalty amount will be 
equal to: $1,000 per Business Day for delays of Group Studies beyond the applicable 
deadline set forth in this GIP; $2,000 per Business Day for delays of Group Re-Studies 
beyond the applicable deadline set forth in this GIP; $2,000 per Business Day for delays 
late Affected System Study or Affected System Network Upgrade facilities study beyond 
the applicable deadline as set forth in the GIP, applicable Joint Operating Agreement, 
Joint Planning Agreement, or other agreement filed with the Commission as provided in 
Section 8 of this GIP; and $2,500 per Business Day for delays of the Interconnection 
Facilities Studies beyond the applicable deadline set forth in this GIP.   
(8) The total amount of a penalty assessed under this Section shall not exceed: (a) one 
hundred percent (100%) of Study Deposit 2 (D2)  received for all of the Interconnection 
Requests in the Cluster for Group Studies and Group Restudies; (b) one hundred percent

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Generator Interconnection Procedures (GIP)
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(100%) of the Study Deposit 2 (D2) received for the single Interconnection Request in 
the study for Facilities Studies; and (c) one hundred percent (100%) of the study cost(s) 
that Transmission Provider collects for conducting the Affected System Study. 
(9) Transmission Provider or Transmission Owner(s), as applicable, may appeal to the 
Commission any penalties imposed under this Section.  Any such appeal must be filed no 
later than forty-five (45) Calendar Days after the posting of the final DPP Phase III Final 
System Impact Study results to OASIS or MISO’s public website for the study group that 
experienced a delayed study.  While an appeal to the Commission is pending, 
Transmission Provider or applicable Transmission Owner(s) shall remain liable for the 
penalty, but need not distribute the penalty until forty-five (45) Calendar Days after (1) 
the deadline for filing a rehearing request has ended, if no requests for rehearing of the 
appeal have been filed, or (2) the Commission’s final determination.  The Commission 
may excuse Transmission Provider or applicable Transmission Owner(s) from penalties 
under this Section for good cause.  Transmission Provider or Transmission Owner(s) 
assessed a penalty under this Section may submit a filing to the Commission under 
Section 205 of the Federal Power Act to recover costs of any study delay penalty 
imposed from a party or parties that contributed to the delay.    
(10) No penalty will be assessed under this Section where a study is delayed by ten (10) 
Business Days or less.  If the study is delayed by more than ten (10) Business Days, the 
penalty amount will be calculated from the first Business Day the Transmission Provider 
or applicable Transmission Owner(s) missed the applicable study deadline. 
(11) The deadline for a relevant study may be extended thirty (30) Business Days from 
the original, applicable study deadline if: (a) Transmission Provider or Transmission 
Owner(s), as applicable, needs to extend the deadline for a particular study subject to 
penalties under this Section and (b) all Interconnection Customers or Affected System 
Interconnection Customers included in the relevant study mutually agree to such an 
extension.  No penalty shall be assessed to Transmission Provider or applicable 
Transmission Owner(s) missing the original study deadline if the study deadline is 
extended pursuant to this subsection. 
(12) No penalties shall be assessed until the third Group Study cycle after the

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Generator Interconnection Procedures (GIP)
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Commission-approved effective date of Transmission Provider’s filing made in 
compliance with the Final Rule in Docket No. RM22-14-000. 
(13) Transmission Provider must maintain on its OASIS or its public website summary 
statistics related to penalties assessed under this Section, updated quarterly.  For each 
calendar quarter, Transmission Provider must calculate and post (1) the total amount of 
penalties assessed under this Section during the previous reporting quarter and (2) the 
highest penalty assessed under this Section paid to a single Interconnection Customer or 
Affected System Interconnection Customer during the previous reporting quarter.  
Transmission Provider must post on its OASIS or its website these penalty amounts for 
each calendar quarter within thirty (30) Calendar Days of the end of the calendar quarter.  
Transmission Provider must maintain the quarterly measures posted on its OASIS or its 
website for three (3) calendar years with the first required posting to be the third Group 
Study cycle with an application deadline after July 28, 2025. 
 
3.11  Additional Requirements for Interconnection Requests Seeking ZG Interconnection 
Service 
A request for ZG Interconnection Service made by an Interconnection Customer must 
meet the requirements listed in section 3.3.1 above, plus the following requirements: 
 
i. 
An Interconnection Request for seeking ZG Interconnection Service shall include a 
one line diagram showing the Generating Facility and associated electrical equipment 
with appropriate rating and impedance information and all the ZG Associated Load 
including all Point(s) of Withdrawal and the Point of Interconnection of the 
Generating Facility to the Transmission System for the Interconnection Request. 
ii. 
An Interconnection Request seeking ZG Interconnection Service shall include a 
detailed power flow model for the proposed Generating Facility that includes all ZG 
Associated Load, Point(s) of Withdrawal and the Point of Interconnections for the 
Interconnection Request, as well as any proposed system protection facilities.  
Any proposed Generating Facility requesting ZG Interconnection Service must have a 
Point of Interconnection that is located at the same voltage level of the same

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
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interconnection substation as the Point(s) of Withdrawal for the ZG Associated Load 
it will serve.   
iii. 
The proposed Generating Facility requesting ZG Interconnection Service must not 
require the construction of Network Upgrades beyond the substation where the Point 
of Interconnection is located other than System Protection Facilities.   
iv. 
The Interconnection Request for ZG Interconnection Service must be submitted to the 
Transmission Provider by the Interconnection Customer at least 180 days prior to the 
earlier of: (a) the Commercial Operation Date for the Generating Facility seeking ZG 
Interconnection Service or (b) for a ZG Associated Load not already in service as of 
the date the Interconnection Service is submitted, the need-by date for such ZG 
Associated Load.  The Interconnection Request for ZG Interconnection Service shall 
include the expected Commercial Operation Date for the Generating Facility and the 
need-by date for the ZG Associated Load.  
v. 
The amount of ZG Interconnection Service is limited to and shall not exceed the total 
Demand of the ZG Associated Load for that Generating Facility. 
vi. 
The Interconnection Request for ZG Interconnection Service must include the 
modeling and other technical data described in the Generator Interconnection 
Business Practices Manual for the ZG Associated Load to enable the Transmission 
Provider to model such Load in ZG Interconnection Service studies. 
vii. 
The Interconnection Request for ZG Interconnection Service shall be accompanied by 
an executed agreement evidencing that the full output of the Generating Facility for 
which ZG Interconnection Service is sought is intended to be used by the entity(s) 
with the ZG Associated Load.  Such agreement shall take one of the following forms 
and state an expected term of at least five years to align with MISO’s transmission 
planning horizon as described in Section I.D.1.b of Attachment FF to the Tariff: 
a. A Load Serving Entity acknowledgement to self-supply its ZG Associated Load; 
b. A Power Purchase Agreement (PPA) or similar off-take agreement between the 
Interconnection Customer submitting the Interconnection Request for ZG 
Interconnection Service and the entity with the ZG Associated Load to be served 
(including, but not limited to, an Alternative Retail Electric Supplier or its Load

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
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Serving Entity); 
c. An agreement that calls for the Interconnection Customer to develop the 
Generating Facility described in the Interconnection Request and subsequently 
transfer ownership or control of such Generating Facility (Build-Own-Transfer 
Agreement) to the entity with the ZG Associated Load to be served (including, 
but not limited to, an Alternative Retail Electric Supplier or its Load Serving 
Entity);  
d. Other agreement between the entity submitting the Interconnection Request, and 
the entity with the ZG Associated Load to be served (including, but not limited to, 
an Alternative Retail Electric Supplier or its Load Serving Entity), stating that the 
Generating Facility will be used to provide its full output to the ZG Associated 
Load; or  
e. An acknowledgement by the Interconnection Customer that it is the entity that 
owns the ZG Associated Load that such entity is both permitted by applicable law 
and intends to self-supply its ZG Associated Load through using onsite 
generation.  
ix. An Interconnection Request for ZG Interconnection Service shall not include a 
request for any other type of Interconnection Service (e.g., ERIS or NRIS).  This 
paragraph shall not be construed to prevent an Interconnection Customer from 
submitting a separate Interconnection Request for another type of Interconnection 
Service for the same Generating Facility using the process specified by these 
Generator Interconnection Procedures for such request type.  In the event that an 
Interconnection Customer obtains another form of Interconnection Service for the 
same Generating Facility, such service shall be deemed to supersede any previously-
granted ZG Interconnection Service upon its effective date. 
 
3.11.1 Requirements for modification of Interconnection Service Requests seeking 
ZG Interconnection Service 
No changes shall be made to an Interconnection Request seeking ZG 
Interconnection Service after submission except that in the event that the ZG

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Associated Load designates or changes its proposed Point(s) of Withdrawal 
subsequent to the Interconnection Customer submitting its Interconnection 
Request for ZG Interconnection Service such that the ZG Associated Load would 
not have a Point of Withdrawal at the same substation and voltage level as the 
Point of Interconnection, the Interconnection Customer shall be required to move 
its proposed Point of Interconnection to match the substation and voltage level of 
the Point(s) of Withdrawal as described in Section 4.4 of these GIP.  In the event 
that the POW changes after the Interconnection Customer receives an effective 
ZGIA, the parties shall amend such ZGIA to align the POI with the new location 
of the POW and change the Commercial Operation Date to a date no earlier than 
180 days after the date the Transmission Provider was notified of such POW 
change.  No delivery of Energy to the ZG Associated Load shall be allowed to 
occur prior to such revised date without the prior written consent of the 
Transmission Provider.  An Interconnection Customer seeking to make changes 
other than those authorized by this Section 3.11.1 may withdraw its ZG 
Interconnection Request and resubmit as a new application with new deposits. 
 
3.11.2 Evaluation Process for ZG Interconnection Service Interconnection Requests 
The Transmission Provider will evaluate Interconnection Service requests seeking 
ZG Interconnection Service in the order in which they are submitted.  The 
evaluation will consist of a ZG Impact Assessment as set forth in Section 
3.2.5.2.1 and a ZG Facilities Study as set forth in Section 3.2.5.2.2. 
 
The Transmission Provider will limit the maximum size of each ZG Quarterly 
Study Period to no more than 10 Interconnection Requests.  If more than 10 
Interconnection Requests are submitted for one ZG Quarterly Study Period, those 
surpassing the limit will be studied in a subsequent ZG Quarterly Study Period in 
the order in which they were submitted. 
 
The Transmission Provider shall use Reasonable Efforts to complete the ZG

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Impact Analysis and for all Interconnection Requests included in a ZG Quarterly 
Study Period and share results with the applicable Interconnection Customer 
within ninety (90) Calendar Days of the date that the Transmission Provider 
commences the applicable ZG Quarterly Study Period.  Transmission Provider 
shall use Reasonable Efforts to complete each portion of the ZG Facilities Study 
within ninety (90) Calendar Days of the date such portion commences. 
 
Transmission Provider shall include in the final study report for the ZG Impact 
Analysis any Affected System Study results and information regarding Network 
Upgrades from Affected Systems provided the Affected System Study Reports are 
available.  If Affected Systems analysis is not available for inclusion in the final 
study, the Transmission Provider shall provide such analysis separately when 
received from the applicable Affected System.  
 
An Interconnection Request included in an active Definitive Planning Phase that 
has not reached Decision Point II may withdraw from the Definitive Planning 
Phase and move their Interconnection Request to the ZG interconnection Service 
process if they meet the requirements for ZG Interconnection Service.  The 
project will be subject to penalties per Sections 7.6.2.1.1. and 7.8 and must meet 
the requirements for an Interconnection Request for ZG Interconnection Service 
set forth in Section 3.11.  Verification of Site Control will be specified in the 
Generator Interconnection Business Practice Manual to authenticate applicability.  
An Interconnection Request that has been withdrawn from the Definitive Planning 
Phase after completion of Decision Point II may be moved to the ZG 
Interconnection Service study process after a period of one year from the 
withdrawal date. 
 
3.11.3  ZG Interconnection Service - Notice to Proceed 
Interconnection Customer requesting ZG Interconnection Service shall inform 
Transmission Provider within five (5) Business Days after having received results

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
of the ZG Impact Analysis of its election to proceed and Transmission Provider 
will complete the ZG Facilities Study and then tender a draft ZG Interconnection 
Agreement.  If the Interconnection Customer fails to provide a notice of its 
election to proceed within five (5) Business Days after having received the results 
of the Transmission Provider’s evaluation, the Transmission Provider will deem 
the Interconnection Request withdrawn pursuant to Section 3.6 of this GIP. 
 
3.11.4 ZGIA for ZG Generating Facility  
Transmission Provider shall tender a draft pro forma ZGIA or ZGIAs or, if 
deemed appropriate, an amended ZGIA or ZGIAs that conforms to the pro forma 
ZGIA in effect at the time, within five (5) Business Days after the Interconnection 
Customer communicates its election to proceed with ZG Interconnection Service, 
and complete any unfinished portion of the Facilities Study and tender the results 
to Interconnection Customer within the timeframe specified in Section 3.11.2 of 
these GIP. 
 
 
SECTION 4. QUEUE POSITION. 
 
4.1 
General. 
Transmission Provider shall assign a Queue Position as follows: the Queue Position 
within the queue shall be assigned based upon the date and time of receipt of all items 
required pursuant to the provisions of Section 3.3 of this GIP.  All Interconnection 
Requests submitted and validated in a single Group Study shall be considered equally 
queued.  Transmission Provider shall assign a Queue Position based upon the initial date 
and time of receipt of the valid Interconnection Request; provided that, if the sole reason 
an Interconnection Request is not valid is the lack of required information or materials 
included with the application form, and Interconnection Customer or MHVDC 
Connection Customer provides such information in accordance with Section 3.3.1, then 
Transmission Provider shall assign Interconnection Customer or MHVDC Connection

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Customer a Queue Position based on the initial date and time of receipt of the 
Interconnection Request.  Moving a Point of Interconnection or Point of Connection shall 
result in a reassignment of the Queue Position except as otherwise noted in Section 4.4.   
 
The Definitive Planning Phase Queue Position will be established based upon the date 
and time Interconnection Customer or MHVDC Connection Customer initially submits 
its Interconnection Request provided that Interconnection Customer subsequently 
satisfies all of the requirements of Section 7.2 to enter the Definitive Planning Phase and 
the Interconnection Request is accepted as valid by the Transmission Provider.  The 
Definitive Planning Phase Queue Position will also be used for the determination of cost 
responsibility for the facilities necessary to accommodate the Interconnection Request, 
except for Group Studies.  The determination of cost responsibility for common facilities 
necessary to accommodate two or more Interconnection Requests participating in a 
Group Study may depend on factors other than the Definitive Planning Phase Queue 
Position.  A higher queued Interconnection Request is one that has been placed “earlier” 
in the queue in relation to another Interconnection Request that is lower queued.  All 
Interconnection Requests within the same Definitive Planning Phase cycle shall have 
equal priority (i.e. similarly queued). 
 
Transmission Provider may perform an Interconnection Study out of queue order at any 
time to the extent warranted by Good Utility Practice based upon:  1) the electrical 
remoteness of the Generating Facility or MHVDC Transmission Line or 2) the request of 
Interconnection Customer or MHVDC Connection Customer, if Transmission Provider 
concurs with the request and has the resources to do the study provided Interconnection 
Customer or MHVDC Connection Customer accepts the financial risk that study 
resources may be reassigned, that its Interconnection Request is subject to review and 
restudy in queue order, and that its GIA or TCA may be amended to reflect a 
reassignment of upgrades as Interconnection Studies of higher queued Interconnection 
Requests are completed.  Interconnection Customer or MHVDC Connection Customer 
may request the Transmission Provider’s concurrence 1) in connection with a resource

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
solicitation process, 2) when Interconnection Customer or MHVDC Connection 
Customer proposes to replace equipment due to catastrophic failure and such replacement 
is determined to be Qualified Change, and 3) for other reasons specific to Interconnection 
Customer or MHVDC Connection Customer. 
 
4.1.1  Limitation on queue study cycle size 
4.1.1.1 The Transmission Provider will determine the maximum size of each 
Definitive Planning Phase study cycle (in MW) on a study region basis.  
The limit will be based on fifty-percent (50%) of the subregional non-
coincident peak load in the summer peak study model.  Projects with 
approved exemptions as noted in Sections 4.1.2.1 through 4.1.2.3 shall 
have priority in each Definitive Planning Phase study cycle limit.  
 
The Transmission Provider shall post the MW value determined for a 
study group in accordance with this Section on the Transmission 
Provider’s website at least ten (10) Business Days prior to the application 
deadline of that Definitive Planning study cycle. 
 
4.1.1.2 The Interconnection Request shall be included in the Definitive Planning 
Phase study cycle based on the earliest date and time of submission of 
Interconnection Requests until the maximum MW cap for the applicable 
study region is met.  Five (5) Business Days after the applicable maximum 
MW limit has been met, the Transmission Provider shall post the initial 
list of Interconnection Requests included in the study group for the 
upcoming study cycle on Transmission Provider’s website.   
 
4.1.1.3 No later than thirty (30) Calendar Days prior to the scheduled DPP Phase 
1 kickoff date for a Definitive Planning Phase study cycle, the 
Transmission Provider shall replace any Interconnection Requests that 
have been withdrawn from such Definitive Planning Phase study cycle

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
after any applicable cure period with Interconnection Requests previously 
submitted but determined to exceed the maximum Definitive Planning 
Phase study cycle limit for that study region determined  pursuant to 
section 4.1.1.1 of this GIP.  The Transmission Provider shall select 
Interconnection Requests to replace withdrawn Interconnection Requests 
in the same study region based on the earliest date and time stamp of such 
Interconnection Requests until the maximum MW cap is met.  The 
Transmission Provider shall notify such Interconnection Customers that 
their Interconnection Requests will be included in the study group no later 
than thirty (30) Calendar Days prior to the scheduled DPP Phase 1 kickoff 
date for a Definitive Planning Phase study cycle. 
 
4.1.1.4 Projects that have submitted a complete application and required deposits 
and milestone payments that were not included in a given DPP study cycle 
will maintain their position, as long as the application remains valid, to 
enter the next available study cycle. 
 
4.1.1.5 Upon conclusion of the third DPP study cycle following the effective date 
of the Tariff revisions accepted in Commission Docket No. ER25-____, 
the Transmission Provider will conduct a review of the effectiveness of 
the limitation on queue study cycle size with stakeholders and determine 
whether to terminate or modify the queue size limitation.  In the event the 
Transmission Provider determines not to file modifications or a 
termination of the queue size limitation, the Transmission Provider shall 
submit an informational report to the Commission describing the results of 
this review upon completion of the stakeholder process.  
 
4.1.2  A valid Interconnection Request submitted for a DPP study cycle to which the 
provisions of Section 4.1.1 of this GIP apply, shall be included in such study 
cycle up to, but not to exceed, the limit, if the Transmission Provider receives

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
documentation included with Interconnection Request demonstrating that one of 
the following exemptions applies to such Interconnection Request:  
 
4.1.2.1 The Interconnection Request seeks to convert ERIS service previously 
granted to an Existing Generating Facility to NRIS for the same Existing 
Generating Facility without requesting any additional increase in the 
service levels. 
 
4.1.2.2 The Interconnection Request seeks to add incremental new service to a 
Replacement Generating Facility that has an effective GIA.  
 
4.1.2.3 The Interconnection Request is for a Generating Facility that has 
completed the requirements of this GIP, including the requirements of 
Section 7.9.1, to request a Provisional Generator Interconnection 
Agreement (PGIA).  In the event that an Interconnection Customer or 
MHVDC Connection Customer withdraws its requested PGIA after the 
thirty (30) Calendar Day timeline as noted in Section 4.1.1.3, then the 
Interconnection Request associated with that requested PGIA shall be 
withdrawn.  The Interconnection Request shall also forfeit milestones in 
accordance with Section 7.9.3. 
 
Transmission Provider may include the types of documentation required to 
demonstrate that one of the foregoing exemptions applies in the Generator 
Interconnection Business Practices Manual.  
 
4.2 
Group Study Organization of Interconnection Studies. 
Interconnection System Impact Studies shall, and Interconnection Facilities Studies may, 
be performed in a Group Study format, whenever applicable, in the Definitive Planning 
Phase, except when a particular Interconnection Request is sufficiently electrically 
remote from others that it cannot reasonably be grouped with other Interconnection

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Requests or where the Interconnection Request is not for a new Generating Facility or 
additional Interconnection Service.  Interconnection Requests for both ER 
Interconnection Service and NR Interconnection Service may be part of a Group Study at 
the option of Transmission Provider.  An Interconnection Request’s inclusion in a Group 
Study will not relieve Transmission Provider from meeting the timelines provided in the 
GIP. 
 
Grouping shall be implemented on the basis of electrical proximity.  Transmission 
Provider may elect to perform Group Studies:  (i) in connection with a resource 
solicitation process with the concurrence of Transmission Provider; (ii) when a 
coordinated study with an Affected System Operator will be performed that involve 
Interconnection Requests in the generator interconnection queue of Transmission 
Provider and of the Affected System Operator; (iii) to identify Common Use Upgrades; 
or (iv) at the request of a group of affected Interconnection Customers or MHVDC 
Connection Customers.  In all instances in which Transmission Provider elects to use 
subgroups in the Group Study process, Transmission Provider must publish the criteria 
used to define and determine subgroups on its OASIS or public website. 
 
If item (i) above applies and Transmission Owner concurs, the solicitor must (a) be 
authorized by Interconnection Customers participating in the solicitation to act as the 
agent for all the Interconnection Requests submitted by Interconnection 
Customers, (b) maintain valid Interconnection Requests, (c) submit all Interconnection 
Requests at the same time, (d) submit a reasonable number of study portfolios (i.e., a 
mixture of projects meeting the requirements of the solicitation that are studied in 
parallel), and (e) select one portfolio prior to the start of the Interconnection Facilities 
Study.  
 
Interconnection Requests included in a Group Study related to a resource solicitation 
process are subject to study according to their Definitive Planning Phase Queue Position 
in the process.  Interconnection Requests for projects that are not included in a Group

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
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Study related to a resource solicitation process are subject to study according to their 
Definitive Planning Phase Queue Position outside the process in accordance with the 
provision of the GIP, and such studies may not be delayed as a result of the resource 
solicitation process.  An Interconnection Customer may request that its Interconnection 
Request be included in a Group Study related to a resource solicitation process without 
having to abandon the existing Definitive Planning Phase Queue Position for such 
Interconnection Request.  Once the solicitor rejects a project in the resource solicitation 
process, the Interconnection Request associated with the rejected project loses the 
Definitive Planning Phase Queue Position it held as part of the resource solicitation 
process.  An Interconnection Customer that participates in a Group Study related to a 
resource solicitation process may at any time for the same project submit a separate 
Interconnection Request that is not included in the Group Study, provided, however, that 
Interconnection Customer shall be responsible for all Interconnection Study costs 
associated with its non-solicitation-related Interconnection Request in addition to any 
costs associated with Interconnection Customer’s bid into the resource solicitation.  
When the solicitor selects a project in the resource solicitation process, Interconnection 
Customer may no longer maintain more than one Definitive Planning Phase Queue 
Position for the selected project.  Interconnection System Impact Studies performed as 
Group Studies shall be conducted in such a manner to ensure the efficient implementation 
of the applicable regional transmission expansion plan in light of the Transmission 
System’s capabilities at the time of each study. 
 
 
4.2.1  
Cost Allocation for Interconnection Facilities and Network Upgrades. 
(1) For Network Upgrades identified in Group Studies, Transmission Provider 
shall calculate each Interconnection Customer’s share of the costs as follows: 
(a) Substation Network Upgrades, including all switching stations, shall be 
allocated first per capita to Interconnection Facilities interconnecting to 
the substation at the same voltage level, and then per capita to each 
Generating Facility sharing the Interconnection Facility interconnecting at

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
the same substation. 
(b) Network Upgrades other than Substation Network Upgrades, as 
described in section 4.2.1.(1).(a) shall be allocated based on the 
proportional impact of each individual Generating Facility in the Group 
Study on the need for a specific Network Upgrade. This proportional 
allocation methodology will apply, but is not limited to, the following 
categories: (i) thermal - Will be cost allocated per the pro rata share of 
MW impact of DPP projects on the constraints being alleviated by the 
upgrade, as further described in the Generator Interconnection Business 
Practices Manual, BPM 015; or (2) non-thermal - Will be cost allocated 
per the pro rata share of MW impact of DPP projects on the constraints 
being alleviated by the upgrade, as further described in the Generator 
Interconnection Business Practices Manual, BPM 015. 
(c) An Interconnection Customer that funds Network Upgrades shall be 
entitled to transmission credits to the extent provided in Article 11.4 of the 
GIA. 
(2) The costs of any needed Interconnection Facilities identified in the Group 
Study will be directly assigned to the Interconnection Customer(s) using such 
facilities.  Where Interconnection Customers in the Group agree to share 
Interconnection Facilities, the cost of such Interconnection Facilities shall be 
allocated based on the number of Generating Facilities sharing use of such 
Interconnection Facilities on an equal basis (i.e., on a per Generating Facility 
basis), unless Parties mutually agree to a different cost sharing arrangement. 
(3) The shared costs of Group Studies shall be allocated among the 
Interconnection Customers in the applicable Study Group: 50% of the costs shall 
be allocated to all Interconnection Customers in the Study Group on a per capita 
basis, and 50% of the costs shall be allocated to all Interconnection Customers in 
the Study Group on a pro rata basis by MW. 
 
4.3 
Transferability of Queue Position.

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
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Effective On: October 18, 2026
An Interconnection Customer or MHVDC Connection Customer may transfer either of 
its queue positions to another entity only if such entity acquires the specific Generating 
Facility or MHVDC Transmission Line identified in the Interconnection Request and the 
Point of Interconnection or Point of Connection does not change. 
 
4.4 
Modifications. 
Interconnection Customer or MHVDC Connection Customer shall submit to 
Transmission Provider modifications to any information provided in the Interconnection 
Request in the manner specified by the Generator Interconnection Business Practices 
Manual (BPM-015).  Interconnection Customer or MHVDC Connection Customer shall 
retain its Queue Position if the modifications proposed by Interconnection Customer or 
MHVDC Connection Customer are in accordance with Sections 4.4.1 or 4.4.4.  
Notwithstanding any modifications to information provided in the Interconnection 
Request, the applicable timing requirements of Section 7.2 to return study agreements 
and obligation to provide study deposits will not change. 
 
Notwithstanding the above, during the course and prior to the completion of the 
Interconnection Studies, Interconnection Customer or MHVDC Connection Customer, 
Transmission Owner or Transmission Provider may identify changes to the planned 
interconnection that may improve the costs and benefits (including reliability) of the 
interconnection, and the ability of the proposed change to accommodate the 
Interconnection Request.  If the Interconnection Customer is requesting to share 
Interconnection Customer Interconnection Facilities as part of the proposed change, the 
Interconnection Customer shall submit a consent agreement that meets the requirements 
of Section 3.3.1.4 along with the identification of changes to the planned interconnection.  
To the extent the identified changes are acceptable to Transmission Provider, 
Transmission Owner and Interconnection Customer or MHVDC Connection Customer, 
such acceptance not to be unreasonably withheld; Transmission Provider shall modify the 
Point of Interconnection or Point of Connection and/or configuration in accordance with 
such changes and proceed with any required Interconnection Studies.  Changes to the

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Point of Interconnection or Point of Connection requested by Interconnection Customer 
or MHVDC Connection Customer after the kick off of Definitive Planning Phase I, 
except as described in this paragraph, will result in the Interconnection Request having to 
be revalidated according to the procedures in Section 3.3.1, and a new Definitive 
Planning Phase Queue Position assigned based on the date and time of submission of 
such modification in accordance with the procedures in Section 4.1.   
For Interconnection Requests seeking ZG Interconnection Service, in the event that the 
ZG Associated Load specifies a location for its Point(s) of Withdrawal that is different 
from the Point(s) of Withdrawal identified in the Interconnection Request such that the 
Load would no longer have a Point of Withdrawal located at the same voltage level at  
the same substation as the Point of Interconnection, Interconnection Customer shall 
notify the Transmission Provider of such change prior to it taking effect and revise the 
Point of Interconnection of the Generating Facility to be identical to one of the Points of 
Withdrawal.  The request shall describe the planned change and include all data and 
analysis that Interconnection Customer wants the Transmission Provider to consider in 
determining whether the change results in material adverse impacts.  Such a requested 
change will result in the Interconnection Request having to be revalidated according to 
the procedures in Section 3.3.1 and restudied to determine whether such change has a 
material adverse impact on the Transmission System, Affected Systems, or on the cost or 
timing of any other Interconnection Request.  If such restudy indicates one or more 
material adverse impacts, Interconnection Customer will be assigned a new Queue 
position based on the date and time of submission of such modification in accordance 
with the procedures in Section 4.1.  If such change occurs after the applicable ZGIA has 
become effective, the parties to such ZGIA shall be required to amend the ZGIA to 
reflect the results of such restudy and associated costs within sixty (60) Calendar Days 
after the date that the Transmission Provider completes such restudy, or elect to terminate 
such ZGIA.  
 
4.4.1 During the Definitive Planning Phase and prior to the issuance of draft GIA, the 
modifications permitted shall include: (a) a change in the technical parameters

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
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associated with the Generating Facility or MHVDC Connection Customer 
technology other than a Permissible Technological Advancement; (b) a change to 
the Point of Interconnection or Point of Connection permitted under Section 4.4; 
and (c) a Permissible Technological Advancement for the Generating Facility or 
MHVDC Connection Customer.  For such permitted modification proposed by 
Interconnection Customer or MHVDC Connection Customer pursuant to 4.4.1(a) 
or 4.4.1(b), Interconnection Customer or MHVDC Connection Customer shall 
submit a detailed analysis demonstrating why they believe the change is not a 
Material Modification.  Transmission Provider must review such analysis and will 
determine, in its discretion, if the proposed modification is a Material 
Modification.  In the absence of such analysis, the modification shall be deemed a 
Material Modification.  Section 4.4.1.1 specifies a separate technological change 
procedure including the requisite information and process that will be followed to 
assess whether the Interconnection Customer’s proposed technological 
advancement under Section 4.4.1(c) is a Material Modification.  Section 1 
contains a definition of Permissible Technological Advancement. 
 
4.4.1.1 Technological Change Procedure. 
For permitted modification proposed by Interconnection Customer or MHVDC 
Connection Customer, Interconnection Customer or MHVDC Connection 
Customer shall submit a technological advancement request demonstrating that the 
proposed change is a Permissible Technological Advancement or submitting a 
detailed analysis to demonstrate that the proposed change is not a Material 
Modification. Such request shall include a description of the proposed change 
together with updated modeling data (power flow and stability), updated technical 
data as outlined in Attachment A of Appendix 1 of this GIP and a study deposit of 
$10,000.00. The detailed analysis to demonstrate that the proposed change is not a 
Material Modification shall include steady-state (thermal/voltage), reactive power, 
short circuit/fault duty, and stability analyses unless the Transmission Provider

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
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Effective On: October 18, 2026
deems one or more of these not necessary based on the nature of the change 
requested.  For a Generating Facility that includes at least one electric storage 
resource, and for which Transmission Provider approves operating assumptions 
pursuant to Section 3.1, Transmission Provider shall perform the detailed analysis 
using operating assumptions pursuant to Section 3.1.  The following criteria will 
be used to determine whether the proposed change is a Material Modification: 
a. 
Any change in expected output of the Generating Facility that 
is higher than what was studied in the interconnection process 
unless a control equipment is employed to limit the injection 
at the POI to the level of Interconnection Service originally 
requested; 
b. 
An increase in short circuit current that degrades transmission 
system reliability; 
c 
Angular stability performance and dynamic response that 
degrades transmission system reliability; 
d. 
Violation of steady-state thermal or voltage limits caused by 
the planned change utilizing the same criteria consistent with 
the Interconnection System Impact Study. 
Within 30 calendar days of receipt of a technological advancement request 
containing the information and security deposit required by Section 4.4.1.1, the 
Transmission Provider shall review such request and supporting documentation to 
determine if the proposed change is a Permissible Technological Advancement or 
otherwise not a Material Modification and communicate the results together with 
a written explanation to the Interconnection Customer of the Transmission 
Provider’s determination.  In the event that the Transmission Provider determines 
that the proposed change is a Material Modification, the Interconnection 
Customer or MHVDC Connection Customer shall have the option of: (i) 
withdrawing such technological advancement request and retaining its current

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
queue position; or (ii) resubmitting its proposed Generating Facility as a new 
Interconnection Request.  
 
4.4.2 After entering the Definitive Planning Phase as defined in Section 7.2, any 
modifications to the type of Interconnection Service selected by Interconnection 
Customer in the Interconnection Request, other than a change from NR 
Interconnection Service to ER Interconnection Service pursuant to Section 3.2 of 
this GIP, shall be deemed a Material Modification. 
 
4.4.3 After entering the Definitive Planning Phase as defined in Section 7.2, any 
modification to the size of the Interconnection Request, other than as allowed in 
Section 4.4.5, Section 7.3.1.4, or Section 7.3.2.4 of this GIP, shall be deemed a 
Material Modification. 
 
4.4.4 After entering the Definitive Planning Phase as defined in Section 7.2, any 
extension by Interconnection Customer or MHVDC Connection Customer to the 
original In-Service Date or Commercial Operation Date of the Generating Facility 
or MHVDC Transmission Line in the original Interconnection Request shall be 
deemed a Material Modification except that the Transmission Provider will not 
unreasonably withhold approval of an Interconnection Customer’s or MHVDC 
Connection Customer’s proposed change in the original In-Service Date or 
Commercial Operation Date of the Generating Facility or MHVDC Transmission 
Line if that change is the result of either (a) a change in milestones by another 
party to the GIA or TCA, (b) a change in a higher queued Interconnection 
Request, (c) delays in the completion of the Definitive Planning Phase Studies, or 
(d) Interconnection Customer demonstrates that engineering, permitting and 
construction of the Generating Facility will take longer than the process window 
for the Transmission Provider’s Definitive Planning Phase period. Where such 
exceptions apply, extensions to the Commercial Operation Date or In-Service 
Date shall not exceed three years beyond the original Commercial Operation Date

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or In-Service Date in the Interconnection Request.  A change to either of these 
dates that exceeds three years from the date in the original Interconnection 
Request is a Material Modification.  At the completion of the Definitive Planning 
Phase, the specified Commercial Operation Date and In-Service Date shall be set 
forth in Appendix B of a GIA.  Consistent with Article 2.3.1 of the GIA, once that 
GIA is executed or filed unexecuted, if the Generating Facility fails to reach 
Commercial Operation by the specified Commercial Operation Date set forth in 
the GIA, such specified Commercial Operation Date as set forth in the GIA may 
be extended by Interconnection Customer for a period up to three (3) consecutive 
years, after which Transmission Provider shall terminate the GIA if the 
Generating Facility has still failed to reach Commercial Operation.  
Notwithstanding the foregoing, in the limited circumstance that Transmission 
Owner Interconnection Facilities, Network Upgrades, or System Protection 
Facilities necessary to enable Trial Operation of a Generating Facility has an in-
service date that is farther out than the Commercial Operation Date permitted 
under this Section 4.4.4 or, has an in-service date that does not allow for a one-
hundred eighty (180) Calendar Day Trial Operation period, Transmission 
Provider shall only terminate the GIA for failure to achieve Commercial 
Operation by a Commercial Operation Date one-hundred eighty (180) Calendar 
Days after the in-service date of the Transmission Owner Interconnection 
Facilities, Network Upgrades, or System Protection Facilities necessary for Trial 
Operation. 
 
4.4.4.1 Transmission Owner In-Service Date extension. 
Prior to end of GIA negotiation and in the limited circumstance that a 
Transmission Owner determines it cannot complete Transmission Owner 
Interconnection Facilities, Network Upgrades, or System Protection 
Facilities specified in the GIA using Reasonable Efforts by the In-Service 
Date permitted under this Section 4.4.4, the specified In-Service Date may 
be extended at the Transmission Owner’s request for a period up to two

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(2) consecutive years and specified in the GIA. This provision does not 
alter Interconnection Customer’s Commercial Operation Date 
requirements of this Section 4.4.4 or other provisions set forth in 
Appendix 6 of these GIP regarding Commercial Operation Date or In-
Service Date. The Interconnection Customer is expected to construct 
facilities in parallel with the Transmission Owner’s construction activities.   
 
4.4.5 After entering the Definitive Planning Phase, any modification to the fuel source 
designated in the Interconnection Request, other than a modification to reduce the 
number of fuel source(s) of an Interconnection Request with two or more fuel 
sources before the kick-off of the Definitive Planning Phase I, shall be deemed a 
Material Modification. 
 
 
SECTION 5. PROCEDURES FOR INTERCONNECTION REQUESTS SUBMITTED 
PRIOR TO EFFECTIVE DATE OF GENERATOR INTERCONNECTION 
PROCEDURES.   
 
5.1 
Queue Position for Pending Requests. 
 
5.1.1 All Interconnection Requests that have entered a Definitive Planning Phase and 
the Definitive Planning Phase System Impact Study has been completed prior to 
January 4, 2017 will complete the Definitive Planning Phase pursuant to the 
approved GIP in effect on January 3, 2017.  The August 2015 Definitive Planning 
Phase cycle shall be completed pursuant to the approved GIP in effect on January 
3, 2017. 
 
5.1.2 All Interconnection Requests that have entered a Definitive Planning Phase and 
the System Impact Study has not been started, or started and not completed, as of 
January 4, 2017 will be required to conform to Section 7 of this GIP excluding

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Section 7.2 “Eligibility for the Definitive Planning Phase” and the Site Control 
provisions found in Section 7.3.2.4 so long as the Interconnection Customer has 
previously complied with the then existing Section 8.2 “Eligibility for the 
Definitive Planning Phase.”  All study deposits will be applied to studies 
performed under this transition plan and M2 milestone amounts previously paid 
will satisfy the M2 milestone requirement of Section 7.2. These projects will then 
follow all other sections of these Generator Interconnection Procedures in effect 
as of January 4, 2017. 
 
5.1.3 All Interconnection Requests that have been received but have not had an M2 
milestone calculated as of January 4, 2017, and have not met the requirements of 
Section 5.1.4, will be required to conform to Section 7 of these GIPs and will then 
follow all other sections of these Generator Interconnection Procedures in effect 
as of January 4, 2017. 
 
5.1.4 All Interconnection Requests that are in the System Planning and Analysis Phase 
of the GIPs in effect prior to January 4, 2017 may pay their M2 milestone 
payment prior to January 4, 2017 and shall be treated pursuant to section 5.1.2.  
Interconnection Requests that are in the System Planning and Analysis Phase 
prior to the effective date of these GIPs that have not paid an M2 milestone 
payment prior to January 4, 2017 shall be treated pursuant to section 5.1.3. 
Interconnection Requests that are in the System Planning and Analysis Phase may 
remain in the System Planning and Analysis Phase until 45 Calendar Days prior 
to the start of the first cycle under these GIPs which begins August 1, 2017.  
MISO shall deem withdrawn any Interconnection Requests that are in the System 
Planning and Analysis Phase that have not made their M2 milestone payment at 
least 45 Calendar Days prior to the start of the first cycle under these GIPs.  
Notwithstanding the foregoing, any request for HVDC facilities listed as being in 
the System Planning and Analysis Phase as of June 16, 2017 shall be deemed 
transferred into the Pre-Queue Phase.  Furthermore, any MHVDC projects in the

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Pre-Queue Phase as of the effective date of the MHCP shall be deemed 
transferred to the MHCP, as set forth in Section 4 of the MHCP.  
 
5.2 
Transition Period. 
An Interconnection Customer of a new transmission owning member of Transmission 
Provider shall transition to the revised GIP within a reasonable period of time not to 
exceed ninety (90) Calendar Days from the date when this GIP becomes applicable to 
that transmission owning member.  
 
5.3 
New Transmission Provider. 
If Transmission Provider transfers control of its Transmission System to a successor 
Transmission Provider during the period when an Interconnection Request is pending, the 
original Transmission Provider shall transfer to the successor Transmission Provider any 
amount of the deposit or payment with interest thereon that exceeds the cost that it 
incurred to evaluate the request for interconnection.  Any difference between such net 
amount and the deposit or payment required by the GIP shall be paid by or refunded to 
Interconnection Customer, as appropriate.  The original Transmission Provider shall 
coordinate with the successor Transmission Provider to complete any Interconnection 
Study, as appropriate, that the original Transmission Provider has begun but has not 
completed.  If Transmission Provider has tendered a draft GIA to Interconnection 
Customer but Interconnection Customer has not either executed the GIA or requested the 
filing of an unexecuted GIA with FERC, unless otherwise provided, Interconnection 
Customer must complete negotiations with the successor Transmission Provider. 
 
5.4 
Transition to Revised Scope of DPP Phase I Studies. 
With the exception of this provision, the Tariff revisions accepted in Docket Nos. ER18-
2049-000 and -001 shall not apply to any queue cycle(s) for which the Definitive 
Planning Phase Preliminary System Impact Study has started prior to September 19, 
2018.

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5.5 
Transitional Notice Requirements for Generating Facility Replacement. 
All requests for Replacement Generating Facility that are submitted to the Transmission 
Provider within 365 Calendar Days after May 16, 2019 shall have a date of cessation of 
operation for the Existing Generating Facility that is not earlier than May 16, 2021. 
 
5.6 
Transition to Revised Milestone Requirements Accepted in Docket No. ER20-41. 
 
All Interconnection Requests for which the application deadline to enter the Definitive 
Planning Phase was prior to April 29, 2019 shall be required to adhere to milestone 
requirements in GIP in effect prior to December 4, 2019. 
 
All Interconnection Requests for which the application deadline to enter the Definitive 
Planning Phase was on April 29, 2019 shall be required to adhere to the revised milestone 
requirements accepted in Docket No. ER20-41, but shall not be subject to the M2 refund 
provisions in Section 7.6.2.1 of this GIP.  All Interconnection Requests for which the 
application deadline to enter the Definitive Planning Phase was on April 29, 2019 shall 
be subject to M2 refund provisions in effect prior to December 4, 2019. 
 
All Interconnection Requests for which the application deadline to enter the Definitive 
Planning Phase is after April 29, 2019 shall be required to adhere to the revised milestone 
requirements accepted in Docket No. ER20-41. 
 
5.7 
Transition to Revised Site Control Requirements Accepted in Docket No. ER20-41. 
 
All Interconnection Requests for which the application deadline to enter the Definitive 
Planning Phase was prior to April 29, 2019 shall be required to adhere to Site Control 
requirements in GIP in effect prior to December 4, 2019. 
 
All Interconnection Requests for which the application deadline to enter the Definitive 
Planning Phase was on April 29, 2019 shall be required to provide proof of Site Control

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for the Generation Facility by the end of Interconnection Customer Decision Point II in 
accordance with the timing requirements established in Section 7.2.2.1.  Such 
Interconnection Requests shall not be required to provide proof of Site Control for the 
Generating Facility ninety (90) Calendar Days prior to the start of DPP Phase I in 
accordance with the timing requirements established in Section 7.2.1.  For such requests, 
the proof of Site Control for all applicable Interconnection Customer’s Interconnection 
Facilities, and, if applicable (i.e., when the Interconnection Customer is providing the site 
for such facilities), the Transmission Owner’s Interconnection Facilities and Network 
Upgrades at the POI shall be due in accordance with the terms of Sections 7.2.2.1 and 
7.2.2.2. 
 
All Interconnection Requests for which the application deadline to enter the Definitive 
Planning Phase is after April 29, 2019 will be subject to the Site Control requirements as 
set forth in Section 7.2. 
 
5.8 
Transition to Self-Fund Deadline Accepted in Docket No. ER20-2632. 
 
For all Network Upgrades and System Protection Facilities that were identified in a 
Revised System Impact Study that completed prior to November 5, 2020 and for which 
the Final System Impact Study was not completed as of November 5, 2020, the 
Transmission Owner shall make an election as to whether the Transmission Owner 
intends to self-fund each specific Network Upgrade and System Protection Facility 
identified in the Revised System Impact Study. Transmission Owner shall make its 
election prior to the completion of the Final System Impact Study. 
 
For all Network Upgrades and System Protection Facilities that were identified in a Final 
System Impact Study that completed prior to November 5, 2020 and for which the 
negotiation period for the GIA was not completed as of November 5, 2020, the 
Transmission Owner may make an election as to whether the Transmission Owner 
intends to self-fund each specific Network Upgrade and System Protection Facility prior

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to the completion of the GIA negotiation period. 
 
5.9  
Transition to revised DPP schedule in Docket No. ER22-661. 
 
Interconnection Requests for which Transmission Provider started the DPP Phase III 
Final System Impact Study before March 15, 2022 will be subject to the Tariff 
requirements in effect prior to March 15, 2022.  Interconnection Requests for which the 
DPP Phase III Final System Impact Study has not started as of March 15, 2022 will be 
subject to the revised Tariff accepted in Docket No. ER22-661.  
 
5.10 
Transition to DPP revisions in Docket No. ER24-___. 
 
All Interconnection Requests for which the application deadline to enter the Definitive 
Planning Phase is on or after January 22, 2024 will be subject to the revised Tariff 
requirements accepted in Docket Nos. ER24-____ and ER24-____.  All Interconnection 
Requests for which the application deadline to enter the Definitive Planning Phase is 
prior to January 22, 2024 will not be subject to the revised Tariff requirements accepted 
in Docket Nos. ER24-____ and ER24-____. 
 
5.11 
Transition to DPP revisions in Docket No. ER24-2046. 
 
All Interconnection Requests for which the application deadline to enter the Definitive 
Planning Phase is on or after June 1, 2025 will be subject to the revised Tariff 
requirements accepted in Docket No. ER24-2046 .  Except for the requirements in 
Section 7.3.2.3 and Section 11.2.1, all Interconnection Requests for which the application 
deadline to enter the Definitive Planning Phase is prior to June 1, 2025 will not be subject 
to the revised Tariff requirements accepted in Docket No. ER24-2046. 
 
5.12 
Transition to JTIQ Process. 
Interconnection Requests for which the application deadline to enter the Definitive

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Planning Phase is after the date that the Transmission Provider and SPP’s Boards have 
approved a JTIQ Portfolio shall be subject to the JTIQ process set forth in Section 9.4.2 
of Rate Schedule 6 (MISO-SPP JOA) and the JTIQ provisions of these GIP.   
 
5.13 
Transition to DPP revisions in Docket No. ER25-___. 
 
All Interconnection Requests for which the application deadline to enter the Definitive 
Planning Phase is on or after January 31, 2025, will be subject to the revised Tariff 
requirements accepted in Docket No. ER25-____.  All Interconnection Requests for 
which the application deadline to enter the Definitive Planning Phase is prior to January 
31, 2025, will not be subject to the revised Tariff requirements accepted in Docket No. 
ER25-____. 
 
5.14  Transition to ERAS Process. 
 
All requests for the Expedited Resource Addition Study that are submitted to the 
Transmission Provider after August 6, 2025 will be subject to the revised Tariff 
requirements accepted in Docket No. ER25-___. 
 
 
SECTION 6. PRE-QUEUE PHASE. 
 
6.1 
Pre-Queue Customer Education 
Transmission Provider will be available for consultation with Interconnection 
Customer to discuss potential Interconnection Requests for Generating Facilities 
or study and processing of HVDC facilities.  Such discussions may include, but 
are not limited to:  (i) general facility loadings; (ii) general instability issues; (iii) 
general short circuit issues; (iv) general voltage issues including voltage and 
frequency ride-through capabilities for the Generating Facility; (v) general power 
quality issues including voltage flicker, harmonics; (vi) general reliability issues

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as may be reasonably required to accomplish the purpose of the meeting; (vii) 
estimated timing of Interconnection Request proceeding to the Definitive 
Planning Phase; (viii) estimated in-service date for the request; and (ix) any 
process related questions.   
 
6.1.1  Publicly Posted Interconnection Information. 
Transmission Provider shall maintain and make publicly available:   
 
(1) an interactive visual representation of the estimated incremental 
injection capacity (in megawatts) available at each point of 
interconnection in Transmission Provider’s footprint under N-1 
conditions, and   
 
(2) a table of metrics concerning the estimated impact of a potential 
Generating Facility on Transmission Provider’s Transmission System 
based on a user-specified addition of a particular number of megawatts at 
a particular voltage level at a particular point of interconnection.   
 
At a minimum, for each transmission facility impacted by the user-
specified megawatt addition, the following information will be provided in 
the table:   
 
(1) the distribution factor;  
(2) the megawatt impact (based on the megawatt values of the 
proposed Generating Facility and the distribution factor);  
(3) the percentage impact on each impacted transmission facility (based on 
the megawatt values of the proposed Generating Facility and the facility 
rating);  
(4) the percentage of power flow on each impacted transmission facility 
before the injection of the proposed project;

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(5) the percentage power flow on each impacted transmission facility after 
the injection of the proposed Generating Facility.   
 
These metrics must be calculated based on the power flow model of the 
Transmission System with the transfer simulated from each point of 
interconnection to the whole Transmission Provider’s footprint (to approximate 
Network Resource Interconnection Service), and with the incremental capacity at 
each point of interconnection decremented by the existing and queued Generating 
Facilities (based on the existing or requested interconnection service limit of the 
generation).   
 
These metrics must be updated within thirty (30) Calendar Days after the 
completion of each Preliminary or Final System Impact Study, only for the most 
recent Definitive Planning Phase cycle and excluding earlier cycles.   
 
This information must be publicly posted, without a password or a fee.  
 
The website will define all underlying assumptions, including the name of the 
most recent  System Impact Study or Interconnection Study restudy used in the 
Base Case. 
 
6.2 
Interim Treatment of HVDC Facilities in Pre-Queue Phase:  All requests for 
HVDC facilities deemed transferred into the Pre-Queue Phase pursuant to Section 
5.1.4 of this GIP or which otherwise are permitted to enter the Pre-Queue Phase 
shall not be eligible to proceed to the Definitive Planning Phase until such time as 
additional procedures for processing such facilities are implemented. 
 
6.3 
Small Generating Facility Pre-Application Report. 
 
6.3.1 In addition to the information described in section 6.1, which may be

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provided in response to an informal request, an Interconnection Customer 
proposing to interconnect its Small Generating Facility may submit a 
formal written request form along with a non-refundable fee of $300 for a 
pre-application report on a proposed project at a specific site.  The 
Transmission Provider shall provide the pre-application data described in 
section 6.3.2 to the Interconnection Customer within twenty (20) Business 
Days of receipt of the completed request form and payment of the $300 
fee.  Should the Transmission Provider notify the Interconnection 
Customer that more than twenty (20) Business Days are necessary to 
provide the pre-application data described in section 6.3.2 below because 
the information is not readily available to the Transmission Provider, the 
Interconnection Customer shall notify the Transmission Provider that it 
desires more complete information and waives the twenty (20) Business 
Day timeline. The pre-application report produced by the Transmission 
Provider is non-binding, does not confer any rights, and the 
Interconnection Customer must still successfully apply to interconnect to 
the Transmission Provider’s system.  The written pre-application report 
request form shall include the information in sections 6.3.1.1 through 
6.3.1.8 below to clearly and sufficiently identify the location of the 
proposed Point of Interconnection. 
 
6.3.1.1 Project contact information, including name, address, phone 
number, and email address. 
 
6.3.1.2 Project location (street address with nearby cross streets and 
town) 
 
6.3.1.3 Meter number, pole number, or other equivalent information 
identifying proposed Point of Interconnection, if available.

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6.3.1.4 Generator Type (e.g., solar, wind, combined heat and power, etc.) 
 
6.3.1.5 Size (alternating current kW) 
 
6.3.1.6 Single or three phase generator configuration 
 
6.3.1.7 Stand-alone generator (no onsite load, not including station 
service – Yes or No?) 
 
6.3.1.8 Is new service requested?  Yes or No?  If there is existing service, 
include the customer account number, site minimum and 
maximum current or proposed electric loads in kW (if available) 
and specify if the load is expected to change. 
 
6.3.2 Using the information provided in the pre-application report request form 
in section 6.3.1, the Transmission Provider will identify the 
substation/area bus, bank or circuit likely to serve the proposed Point of 
Interconnection.  This selection by the Transmission Provider does not 
necessarily indicate, after application of the screens and/or study, that this 
would be the circuit the project ultimately connects to.  The 
Interconnection Customer must request additional pre-application reports 
if information about multiple Points of Interconnection is requested.  
Subject to section 6.3.3, the pre-application report will include the 
following information: 
 
6.3.2.1 Total capacity (in MW) of substation/area bus, bank or circuit 
based on normal or operating ratings likely to serve the proposed 
Point of Interconnection. 
 
6.3.2.2 Existing aggregate generation capacity (in MW) interconnected

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to a substation/area bus, bank or circuit (i.e., amount of 
generation online) likely to serve the proposed Point of 
Interconnection. 
 
6.3.2.3 Aggregate queued generation capacity (in MW) for a 
substation/area bus, bank or circuit (i.e., amount of generation in 
the queue) likely to serve the proposed Point of Interconnection. 
 
6.3.2.4 Available capacity (in MW) of substation/area bus or bank and 
circuit likely to serve the proposed Point of Interconnection (i.e., 
total capacity less the sum of existing aggregate generation 
capacity and aggregate queued generation capacity). 
 
6.3.2.5 Substation nominal distribution voltage and/or transmission 
nominal voltage if applicable. 
 
6.3.2.6 Nominal distribution circuit voltage at the proposed Point of 
Interconnection. 
6.3.2.7 Approximate circuit distance between the proposed Point of 
Interconnection and the substation. 
 
6.3.2.8 Relevant line section(s) actual or estimated peak load and 
minimum load data, including daytime minimum load as 
described in section 14.4.4.1.1 below and absolute minimum 
load, when available. 
 
6.3.2.9 Number and rating of protective devices and number and type 
(standard, bi-directional) of voltage regulating devices between 
the proposed Point of Interconnection and the substation/area.  
Identify whether the substation has a load tap changer.

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6.3.2.10 Number of phases available at the proposed Point of 
Interconnection.  If a single phase, distance from the three-phase 
circuit. 
6.3.2.11 Limiting conductor ratings from the proposed Point of 
Interconnection to the distribution substation. 
 
6.3.2.12 Whether the Point of Interconnection is located on a spot 
network, grid network, or radial supply. 
 
6.3.2.13 Based on the proposed Point of Interconnection, existing or 
known constraints such as, but not limited to, electrical 
dependencies at that location, short circuit interrupting capacity 
issues, power quality or stability issues on the circuit, capacity 
constraints, or secondary networks. 
 
6.3.3 The pre-application report need only include existing data.  A pre-
application report request does not obligate the Transmission Provider to 
conduct a study or other analysis of the proposed generator in the event 
that data is not readily available.  If the Transmission Provider cannot 
complete all or some of a pre-application report due to lack of available 
data, the Transmission Provider shall provide the Interconnection 
Customer with a pre-application report that includes the data that is 
available.  The provision of information on “available capacity” pursuant 
to section 6.3.2.4 does not imply that an interconnection up to this level 
may be completed without impacts since there are many variables studied 
as part of the interconnection review process, and data provided in the pre-
application report may become outdated at the time of the submission of 
the complete Interconnection Request.  Notwithstanding any of the 
provisions of this section, the Transmission Provider shall, in good faith,

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include data in the pre-application report that represents the best available 
information at the time of reporting. 
 
SECTION 7. DEFINITIVE PLANNING PHASE. 
 
7.1 
Purpose of the Definitive Planning Phase. 
The Definitive Planning Phase is designed to identify Network Upgrades that will 
reliably and efficiently integrate the proposed generation, including through 
Injection Rights requested by MHVDC Connection Customer, into the 
Transmission Provider’s Transmission System.  The Definitive Planning Phase 
will be composed of three distinct phases in which Interconnection System Impact 
Studies and Interconnection Facilities Studies will be performed. 
 
7.1.1 Screening Analysis Prior to Definitive Planning Phase I. 
Transmission Provider will perform an indicative non-binding screening 
analysis to identify potential thermal and voltage constraints and publish 
the results of that analysis for Interconnection Customers, MHVDC 
Connection Customers entering the Definitive Planning Phase and 
Affected System Operator(s) at least fifteen (15) Calendar Days prior to 
the kick-off of the Definitive Planning Phase I.  The Transmission 
Provider shall indicate with this screening analysis whether 
Interconnection Requests in the applicable DPP study group are expected 
to be included in a JTIQ Participation Group based on available 
information.  If the Interconnection Customer or MHVDC Connection 
Customer decides to withdraw its Interconnection Request before the start 
of the Definitive Planning Phase I, then the Transmission Provider will 
refund to Interconnection Customer or the MHVDC Connection Customer 
100% of Definitive Planning Phase entry milestone (M2) and any 
remaining study deposits pursuant to Section 7.6.

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7.2 
Eligibility for the Definitive Planning Phase. 
The Interconnection Request shall enter the Definitive Planning Phase upon the 
Transmission Provider accepting the Interconnection Request as valid pursuant to 
Section 3.3.3 of this GIP after the Interconnection Customer or MHVDC 
Connection Customer has met the requirements of Section 3.3.1. The Definitive 
Planning Phase will start on a periodic basis, where an Interconnection Customer 
or MHVDC Connection Customer may elect to enter the next scheduled 
Definitive Planning Phase. 
 
7.2.1 Requirements for Demonstrating Site Control for Generating Facility 
and Interconnection Facilities. 
Except as otherwise noted in Section 5.7, at the time of the submission of 
an Interconnection Request, the Interconnection Customer shall submit the 
following to the Transmission Provider: 
 
(i)  
Proof of Site Control for the Generating Facility demonstrating 
that the Interconnection Customer has obtained a right to develop 
the site, and that such Site Control:  
(a)  
is exclusive to the specific project referenced in the 
Interconnection Request and the site meets the total resource-
specific acreage requirements established in the Generator 
Interconnection Business Practices Manual; or  
(b)  
either is shared by multiple projects by mutual agreement 
or includes less acreage than the standard resource-specific acreage 
requirements established in the Generator Interconnection Business 
Practice but is nonetheless sufficient to accommodate the final 
design of the Generating Facility, and account for any other 
projects that will utilize all or part of the same site Interconnection 
Requests from multiple Interconnection Customers for multiple 
Generating Facilities that share a site must include a contract or

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other agreement that allows for shared Site Control; or 
  
(c) 
A financial security in lieu of Site Control and supporting 
documentation demonstrating regulatory restrictions in accordance 
with Section 7.2.1.2 of this GIP.  
 
(ii)  
Reasonable evidence of Site Control, as described in the Generator 
Interconnection Business Practices Manual, for at least fifty 
percent (50%) of the mileage of the Generating Facility’s or 
Facilities’ Interconnection Facilities, or in lieu of Site Control for 
the Generating Facility’s or Facilities’ Interconnection Facilities, 
additional financial security in the amount of $80,000 per line mile 
of right-of-way, on a straight line basis.  Interconnection 
Customer’s financial security provided in lieu of Site Control shall 
only be refunded once the Interconnection Customer satisfies the 
Site Control requirements or is withdrawn from the queue.  The 
security can be provided in the form of cash, irrevocable letter of 
credit or surety bond reasonably acceptable to Transmission 
Provider.  The surety bond must be issued by an insurer reasonably 
acceptable to Transmission Provider and must specify a reasonable 
expiration date.  The Transmission Provider may establish 
additional requirements for what constitutes a surety bond, 
including but not limited to, duration satisfaction, demand 
timeframe and issuer requirements through the Generator 
Interconnection Business Practices manual (BPM).  Reasonable 
evidence of Site Control for one hundred percent (100%) of the 
mileage of the Generating Facility’s Interconnection Facilities for 
the Expedited Resource Addition Study request must be received 
at the time the application is submitted.  The financial security in 
lieu of Site Control for the Generating Facility’s Interconnection 
Facilities will not be accepted for an Expedited Resource Addition

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Study request. 
 
Any advancement or postponement to the DPP Phase I kickoff date made 
after the application deadline for such cycle shall not alter the deadline for 
submitting proof of Site Control. 
 
Site Control for a Generating Facility and Interconnection Facility shall be 
demonstrated in accordance with Section 7.2.1.1 and Section 7.2.1.2 of 
this GIP.   
 
All documentation establishing proof of Site Control under Sections 7.2.1 
of this GIP shall be accompanied by a signed affidavit from an officer or 
from an agent of the Interconnection Customer stating either that the 
Interconnection Customer: (1) possesses Site Control in accordance with 
Section 7.2.1.1 of this GIP; or (2) is subject to regulatory restrictions that 
preclude Interconnection Customer from obtaining Site Control pursuant 
to Section 7.2.1.2 of this GIP.  Such affidavit shall adhere to the form 
specified in Attachment E of Appendix 1 of Attachment X.   
 
Before the kickoff of DPP Phase I, Interconnection Customer may modify 
up to 100% of the Site Control for the Generating Facility and up to 100% 
of its Interconnection Customer Interconnection Facilities as provided for 
in its Interconnection Request if (1) the Interconnection Customer does not 
move the POI; (2) the Transmission Owner determines a POI move is 
necessary to accommodate the Interconnection Request; or (3) the 
Interconnection Customer can demonstrate, based on sound engineering 
judgment, that Site Control modification is necessary to optimize the 
siting of the project. 
 
7.2.1.1 Site Control Demonstration.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
In order to demonstrate Site Control for a Generating Facility and 
Interconnection Facilities, an Interconnection Customer must submit the 
following:  
 
(i) 
To demonstrate that an Interconnection Customer has Site Control 
in accordance with Section 7.2.1(i)(a) and 7.2.1(ii) of this GIP, a 
Geographic Information System (GIS) site plan map, data files, 
and documentation that shows the following information: (a) 
sufficient land to meet the acreage requirements set forth in the 
Generator Interconnection Business Practices Manual; (b) 
boundary for the proposed project indicating the boundaries of the 
Interconnection Customer’s leasehold/ownership interests for the 
site; and (c) the proposed location of each of the following: the 
Collector Substation, the Point of Interconnection, and the 
Interconnection Facilities based on the Point of Interconnection. 
 
(ii) 
To demonstrate that an Interconnection Customer has obtained Site 
Control in accordance in accordance with Section 7.2.1(i)(b) of 
this GIP, Interconnection Customer must submit a Geographic 
Information System (GIS) site plan map, data files, and 
documentation that meets the requirements specified in Section 
7.2.1.1(i)(b) and (c) and show the following additional 
information:  
 
(a) Sufficient land to accommodate the proposed Generating 
Facility based on the location and approximate land utilization 
requirements of proposed electrical devices (i.e., turbine, solar 
panel, battery storage, inverter), local spacing and setback 
requirements, and the proposed location of the feeder routes to the 
Collector Substation; and

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
 
(b) In the event that Interconnection Customer elects to share a site 
with other projects in accordance with Section 7.2.1(i)(b) of this 
GIP, 
Interconnection 
Customer 
shall 
include 
with 
its 
Interconnection Request documentation demonstrating that the 
project referenced in the Interconnection Request is concurrently 
feasible with the development of any other projects that will share 
Site Control over all or a portion of the same site.  Such proof of 
concurrent feasibility shall include:  
 
(1) an identification of any other Interconnection Requests 
or projects that will share all or a portion of the same site; 
and  
 
(2) identification of the proposed location and space 
utilization of all projects that will share the site together 
with any related technical information specified in the 
Generator Interconnection Business Practices Manual to 
enable the Transmission Provider to determine that 
development of the project referenced in the submitted 
Interconnection 
Request 
is 
not 
inconsistent 
with 
development of any of the other projects that will share all 
or a portion of the same site.  
 
(3) Interconnection Requests from multiple Interconnection 
Customers for multiple Generating Facilities that share a 
site must include a contract or other agreement that allows 
for shared land use. 
 
Any GIS site plan map, and data files submitted in accordance with this

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Section 7.2.1.1 must be consistent with the modeling data submitted with 
the Interconnection Request. 
 
7.2.1.2 Financial Security in lieu of Site Control.  
If the Interconnection Customer is unable to obtain Site Control for its 
proposed Generating Facility as a result of regulatory restrictions, the 
Interconnection Customer shall provide a cash deposit in lieu of Site 
Control.  In order to demonstrate regulatory restrictions, Interconnection 
Customer must submit: (i) a signed affidavit from an officer of the 
company in accordance with the terms of Section 7.2.1 of this GIP 
indicating that Site Control is unobtainable due to regulatory requirements 
as such term is defined by the Transmission Provider; (ii) documentation 
sufficiently describing and explaining the source of and effects of such 
regulatory restrictions, including a description of any conditions that must 
be met in order to satisfy the regulatory restrictions and the anticipated 
time by which the Interconnection Customer expects to satisfy the 
regulatory restrictions.  The financial security provided in lieu of Site 
Control, as cash deposit, irrevocable letter of credit or surety bond 
reasonably acceptable to Transmission Provider, shall be $10,000 per MW 
of new Interconnection Service requested, and at least $500,000 but no 
more than $2,000,000.  The surety bond must be issued by an insurer 
reasonably acceptable to Transmission Provider and must specify a 
reasonable expiration date.  The Transmission Provider may establish 
additional requirements for what constitutes a surety bond, including but 
not limited to, duration satisfaction, demand timeframe and issuer 
requirements through the Generator Interconnection Business Practices 
manual (BPM).  In the event that Interconnection Customer needs to 
submit a financial security in lieu of Site Control as a result of regulatory 
restrictions, Interconnection Customer must provide proof of Site Control 
as soon as the Interconnection Customer satisfies the regulatory

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
requirements described in the Interconnection Customer’s affidavit and 
supporting documents.  Interconnection Customer’s financial security 
made in lieu of Site Control shall only be refunded once the 
Interconnection Customer satisfies the Site Control requirements in 
accordance with the terms of Sections 7.2.1(i), 7.2.1.1, and 7.2.2 of the 
GIP or is withdrawn from the queue.  
 
7.2.1.3 Transmission Provider Review of Site Control Sufficiency.  
The Transmission Provider shall review the Site Control documentation 
submitted by Interconnection Customer and determine whether the 
Interconnection Customer has satisfied the applicable Site Control 
requirements specified in Section 7.2.1, and 7.2.1.1 or 7.2.1.2 of this GIP, 
as applicable.  Transmission Provider shall evaluate the Site Control 
documentation using sound engineering judgement and in a non-
discriminatory manner.  In addition, Transmission Provider shall adhere to 
any guidelines for such analysis as may be included in the Generator 
Interconnection Business Practices Manual.  
 
In the event that the Transmission Provider determines that the 
Interconnection Customer does not demonstrate sufficient Site Control, 
Transmission Provider shall, consistent with Section 7.2.3(ii) of this GIP, 
provide a written explanation, including the technical reasons for such 
determination, to Interconnection Customer no later than sixty (60) 
Calendar Days from the Site Control submission deadline.  Any such 
deficiencies shall be processed as set forth in Section 7.2.3(ii) of this GIP.  
 
7.2.2  Continued Site Control for Generating Facilities; Site Control for 
Interconnection Facilities and Network Upgrades.  
 
7.2.2.1 Timing Requirements.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
 
(i)  
After the start and prior to the end of Interconnection Customer 
Decision Point II, Interconnection Customer shall submit proof 
that Interconnection Customer continues to maintain Site Control 
for the Generating Facility in accordance with terms in Section 
7.2.1.1 of this GIP.  Regarding Interconnection Customer’s 
Interconnection Facilities, in addition to the requirements specified 
in Section 7.2.1.ii of this GIP, the Interconnection Customer will 
be required to demonstrate fifty (50%) site control for the site on 
which a switchyard will be located, if requested by the 
Transmission Provider. 
 
(ii)  
Prior to conclusion of the Interconnection Customer’s GIA 
execution period, as defined in Section 11 of this GIP, or within 
180 days of GIA Effective Date with an approved exception by the 
Transmission Provider, Interconnection Customer shall submit 
proof of the following: (a) continued Site Control for the 
Generating Facility in accordance with terms in Section 7.2.1.1 of 
this GIP; and (b) 100% Site Control for all Interconnection 
Customer’s Interconnection Facilities (including demonstration of 
switchyard site control if requested by the Transmission Provider), 
and, if applicable (i.e., when the Interconnection Customer is 
providing the site for such facilities), the Transmission Owner’s 
Interconnection Facilities and Network Upgrades at the POI that 
the Interconnection Customer will develop. 
 
(iii) 
To the extent there is any change in the POI as a result of the 
Interconnection Facilities Study started in DPP Phase II and 
completed in DPP Phase III, the Transmission Provider shall 
provide the Interconnection Customer additional time to procure

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
land rights for the new Interconnection Customer’s Interconnection 
Facilities and, if applicable (i.e., when the Interconnection 
Customer is providing the site for such facilities), the Transmission 
Owner’s Interconnection Facilities and Network Upgrades at the 
POI that the Interconnection Customer will develop.  The amount 
of additional time awarded for this purpose shall be determined on 
a case-by-case basis and in accordance with Section 4.4 of this 
GIP.   
 
(iv) 
After the Interconnection Customer timely satisfies each of the 
requirements of this Section 7.2.2.1 and execution of the GIA, any 
changes made to the site layouts and interconnection facility routes 
shall not be construed as a failure to satisfy the requirements of this 
Section 7.2.2.1.  In the event that the Interconnection Customer 
makes any modifications to the design of the site layouts or 
Interconnection Facility routes after execution of this GIA, 
Interconnection Customer shall: (1) immediately notify the Parties 
of such changes; and (2) provide to Transmission Provider 
evidence of continued Site Control for land sufficient to 
accommodate the changes in site layouts and/or Interconnection 
Facility routes in accordance with the terms of its GIA. 
 
7.2.2.2 Content Requirements -- Demonstrating Site Control for 
Applicable Interconnection Facilities and Network Upgrades.  
In order to demonstrate Site Control for the Interconnection Customer’s 
Interconnection Facilities and, if applicable (i.e., when the Interconnection 
Customer is providing the site for such facilities), the Transmission 
Owner’s Interconnection Facilities and Network Upgrades at the POI, 
Interconnection Customer shall submit a site plan map by the deadline 
specified in Section 7.2.2.1 of this GIP.  Such site plan map shall

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
demonstrate land that is sufficient to accommodate 50% of the total land 
acreage required for the Interconnection Customer’s Interconnection 
Facilities for the proposed Generating Facility (including the total linear 
miles for the associated lead line required to electrically interconnect the 
Generating Facility to the Transmission System) and, if applicable (i.e., 
when the Interconnection Customer is providing the site for such 
facilities), 50% of the total land acreage required for the Transmission 
Owner’s Interconnection Facilities and the Network Upgrades at the POI 
for the proposed Generating Facility.  
 
The Site Plan submitted in accordance with Section 7.2.2 of this GIP shall 
identify the specific locations within the site for which Site Control is 
achieved, and those locations for which Site Control is not yet achieved. 
 
To the extent that the Interconnection Customer intends to locate its 
Interconnection Facilities in a public right of way, Interconnection 
Customer shall also submit proof of submission of all requisite state and 
local permits.   
 
Demonstration of Site Control pursuant to this Section 7.2.2.2 shall 
conform to any technical and documentation requirements as may be 
specified in the Generator Interconnection Business Practice Manual. 
 
7.2.3.  Effect of Deficiencies in Demonstration of Site Control  
 
In the event that the Interconnection Customer fails to timely satisfy any 
of the requirements of Sections 7.2.1 and 7.2.2 including subsections, as 
applicable, Interconnection Customer’s Interconnection Request shall be 
deemed withdrawn as set forth below:

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
(i)   
If Interconnection Customer fails to submit all of the 
documentation and information required by the applicable 
deadline, Interconnection Customer’s Interconnection Request 
shall immediately be deemed withdrawn as of the date of such 
deadline without any cure period.  Transmission Provider shall 
provide Interconnection Customer with notice of such withdrawal. 
 
(ii)   
If Interconnection Customer has timely submitted all information 
required by an applicable deadline but the Transmission Provider 
determines after review that such submission does not meet the 
requirements 
of 
this 
GIP, 
Interconnection 
Customer’s 
Interconnection Request shall be deemed withdrawn in accordance 
with Section 3.6 of this GIP.  
 
7.3 
Duration of the Definitive Planning Phase 
The Definitive Planning Phase will include the following three phases: 
(i) 
Definitive Planning Phase I 
(ii) 
Definitive Planning Phase II 
(iii) 
Definitive Planning Phase III. 
 
7.3.1 Definitive Planning Phase I 
The Definitive Planning Phase I will start on a defined, periodic basis.  
The Definitive Planning Phase I will include the following steps:  
(i) 
Attachment X, Appendix 10 Model Review (10 Business Days) 
(ii) 
Preliminary System Impact Study (65 Calendar Days) 
(iii) 
Interconnection Customer Decision Point I (15 Business Days) 
 
In addition, Interconnection Customer may request that the Transmission 
Provider or applicable Transmission Owner initiate the Interconnection 
Facilities Study during Definitive Planning Phase I.  If Interconnection

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Customer, Transmission Owner and Transmission Provider agree that 
such Interconnection Facilities Study should be performed during 
Definitive Planning Phase I, the Transmission Provider or Transmission 
Owner conducting the study shall begin the Interconnection Facilities 
Study during Definitive Planning Phase I. 
 
The Transmission Provider shall establish a date agreeable to 
Interconnection Customer and Transmission Owner for a Kick-Off 
Meeting, and such date shall be one (1) Business Day prior to the kick-off 
of the Definitive Planning Phase I of that cycle published on the MISO 
public website, unless mutually agreed upon by MISO, the Transmission 
Owner(s) and the Interconnection Customer(s). MISO, the Interconnection 
Customer(s), and the Transmission Owner(s) must attend the Kick-Off 
Meeting. MISO shall use Reasonable Efforts to include any other Affected 
Systems in the Kick-off Meeting. 
 
The Transmission Provider must ensure that project information during 
the Kick-Off meeting is anonymized and does not reveal the identity or 
commercial information of interconnection customers with submitted 
requests.   
 
All withdrawal and modification requests must be submitted within 24 
hours of the conclusion of the kick-off meeting prior to the start of the 
DPP process. 
 
During the Customer Engagement Window, Transmission Provider shall 
provide to Interconnection Customer a non-binding updated good faith 
estimate of the cost and timeframe for completing the Group Study.   
 
7.3.1.1 Purpose

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
The Definitive Planning Phase I is designed to provide Interconnection 
Customers or MHVDC Connection Customers with a preliminary detailed 
analysis of their Interconnection Request’s impact on the reliability of the 
Transmission System. Prior to the completion of the Preliminary System 
Impact Study, each impacted Transmission Owner shall make a non-
binding indication as to whether the Transmission Owner intends to self-
fund each specific Network Upgrade and System Protection Facility 
identified in the Preliminary System Impact Study. A Transmission 
Owner’s non-binding self-fund election will be included in the 
Preliminary System Impact Study. Upon completion of the Preliminary 
System Impact Study, Transmission Provider will provide a detailed 
reliability analysis, pursuant to Section 7.3.1.5, to each Interconnection 
Customer or MHVDC Connection Customer that has an Interconnection 
Request in the Definitive Planning Phase I.  Upon receipt of the 
Preliminary System Impact Study, the Interconnection Customer can 
either proceed to Definitive Planning Phase II or withdraw its 
Interconnection Request pursuant to Section 7.3.1.4 of this Attachment X.  
 
7.3.1.2 Model Building and Point of Interconnection Review  
Before starting the preliminary Interconnection System Impact Study, 
Transmission Provider will distribute the study models to Interconnection 
Customer or MHVDC Connection Customer and Transmission Owner.  
Interconnection Customer and Transmission Owner may recommend 
changes to the study model by providing a completed Interconnection 
Study Model Review Form, Appendix 10 to the GIP within ten (10) 
Business Days after receipt of the study models.  Proposed changes will be 
incorporated in the study models after mutual agreement between 
Interconnection Customer or MHVDC Connection Customer, 
Transmission Owner and Transmission Provider, such agreement not to be 
unreasonably withheld.  Transmission Provider shall thereafter begin the

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Preliminary System Impact Study.  Failure of Interconnection Customer or 
MHVDC Connection Customer to provide the completed Interconnection 
Study Model Review Form within ten (10) Business Days will result in 
withdrawal of the Interconnection Request pursuant to Section 3.6 of this 
GIP. 
 
7.3.1.3 Scope of the Preliminary System Impact Study  
The Preliminary System Impact Study shall evaluate the impact of the 
proposed Interconnection Request(s) in the Definitive Planning Phase I on 
the reliability and safety of the Transmission System.  The Preliminary 
System Impact Study will consider the Base Case as well as all generating 
and MHVDC facilities (and with respect to subpart iv below, any 
identified Network Upgrades, System Protection Facilities, Distribution 
Upgrades, Generator Upgrades, Common Use Upgrades, Shared Network 
Upgrades, or, if such upgrades have been determined, upgrades on 
Affected Systems, associated with such higher queued Interconnection 
Requests) that, on the date the Preliminary System Impact Study is 
commenced:  (i) are interconnected to the Transmission System or 
Distribution System; (ii) are interconnected or queued to interconnect to 
Affected Systems and may have an impact on the Interconnection 
Request; (iii) have Interconnection Request is part of the same group; and 
(iv) have executed a GIA or a pending unexecuted GIA on file at FERC or 
a TCA pursuant to which Transmission Provider has granted Injection 
Rights. 
 
The Preliminary System Impact Study will consist of a power flow 
analysis.  If Transmission Provider determines in accordance with Good 
Utility Practice that any voltage stability analysis is needed, the 
Preliminary System Impact Study may include voltage stability analysis.  
The Preliminary System Impact Study will also include analysis needed to

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
determine the Generating Facility’s reactive power capability required to 
maintain the Transmission Owner’s voltage schedule and power factor 
criteria at the Point of Interconnection. 
 
Determination of the full scope of the Preliminary System Impact Study in 
the Definitive Planning Phase I will be on a non-discriminatory basis per 
the methodologies listed in the Generator Interconnection Business 
Practices Manual.  The Transmission Provider or Transmission Owner 
performing the Preliminary System Impact Study shall complete such 
study within sixty-five (65) Calendar Days.  
 
The Preliminary System Impact Study will state the assumptions upon 
which it is based, state the results of the analyses, and provide the 
requirements or potential impediments to providing the requested 
Interconnection Service, including a preliminary indication of the cost and 
length of time that would be necessary to correct any problems identified 
in those analyses and implement the interconnection.  The Preliminary 
System Impact Study will provide a preliminary list of facilities (including 
Interconnection Facilities, Connection Facilities, Network Upgrades, 
Generator Upgrades, Common Use Upgrades, and Shared Network 
Upgrades) that are required as a result of the Interconnection Request and 
a preliminary non-binding good faith estimate of cost and a non-binding 
good faith estimated time to construct.  For purposes of determining 
necessary interconnection facilities and network upgrades, the Preliminary 
System Impact Study shall consider the level of Interconnection Service 
requested by the Interconnection Customer, unless otherwise required to 
study the full Generating Facility Capacity due to safety or reliability 
concerns. 
 
At the request of Interconnection Customer or MHVDC Connection

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Customer, or at any time Transmission Provider determines that it will not 
meet the required time frame for completing the Preliminary System 
Impact Study, Transmission Provider shall notify Interconnection 
Customer or MHVDC Connection Customer regarding the following: 
(i) 
Schedule status of the Preliminary System Impact Study  
(ii) 
Estimated completion date and an explanation of the reasons why 
additional time is required.   
(iii) 
Revised cost estimate of study deposits with an explanation of the 
reasons why cost estimates were revised.  Interconnection 
Customer or MHVDC Connection Customer shall then provide 
within thirty (30) Calendar Days of Transmission Provider’s 
notice, an additional deposit equal to the difference between the 
initial and revised cost estimate. Failure of Interconnection 
Customer or MHVDC Connection Customer to provide this 
additional deposit will result in withdrawal of the Interconnection 
Request pursuant to Section 3.6 of this GIP.   
 
A draft Preliminary System Impact Study will be posted for 
Interconnection Customers for a comment window.  Transmission 
Provider will address questions and comments that are submitted during 
the comment window regarding the report before finalizing the report and 
results.  The comment window will last for at least five (5) Business Days, 
but no more than ten (10) Business Days. 
 
7.3.1.4 Interconnection Customer Decision Point I 
All Interconnection Customers or MHVDC Connection Customers with 
Interconnection Requests in the Definitive Planning Phase I will pass 
through Interconnection Customer Decision Point I.  The Interconnection 
Customer Decision Point I will last for fifteen (15) Business Days 
beginning with the receipt of the Preliminary System Impact Study

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
analysis including estimated upgrades and costs, as applicable.  
Transmission Provider shall notify all Interconnection Customers or 
MHVDC Connection Customers at the beginning of Interconnection 
Customer Decision Point I that the Interconnection Customer or MHVDC 
Connection Customer shall have fifteen (15) Business Days to decide 
whether it wants to proceed to the Definitive Planning Phase II or 
withdraw its Interconnection Request.  The Transmission Provider shall 
provide written notice to each Interconnection Customer in a Definitive 
Planning Phase Group Study or ERAS confirming whether they are 
included in a JTIQ Screening Group and whether its Interconnection 
Request has qualified for inclusion in a JTIQ Participation Group prior to 
the beginning of Interconnection Customer Decision Point I. If the 
Transmission Provider determines that such Interconnection Request will 
be included in a JTIQ Participation Group, the notification shall include an 
estimate of the per-MW Generator Charge for such Interconnection 
Requests based on the latest available data on JTIQ Upgrade cost, the 
Potential MW Total projected for such JTIQ Portfolio.  During 
Interconnection Customer Decision Point I, an Interconnection Customer 
or MHVDC Connection Customer may waive its right to elect the option 
to build or may defer the decision to the deadlines specified in Sections 
7.3.2.5 & 7.3.3.5; failure to provide a written response will be deemed to 
be a deferral.  During Interconnection Customer Decision Point I, an 
Interconnection Customer or MHVDC Connection Customer may reduce 
the size of its Interconnection Request by as much as 100 percent through 
either (1) a decrease in plant size or (2) a decrease in Interconnection 
Service level (consistent with the process described in Section 3.1) 
accomplished by applying Transmission Provider-approved injection-
limiting equipment.  However, because NR Interconnection Service 
includes an equivalent amount of ER Interconnection Service, a reduction 
in NRIS level will not reduce the ERIS level unless a corresponding

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
reduction in ERIS level is requested. The total amount of NRIS requested 
shall not exceed the amount of ERIS requested. The required Definitive 
Planning Phase II Milestone calculation shall be based on the DPP Phase I 
results. If the Interconnection Customer or MHVDC Connection Customer 
decides to withdraw its Interconnection Request during, or any time 
before, the end of Interconnection Customer Decision Point I, then the 
Transmission Provider will refund Interconnection Customer 40% of 
Definitive Planning Phase I milestone (M2) and any remaining study 
deposits pursuant to Section 7.6.  Any withdrawal during the Definitive 
Planning Phase I, but prior to Interconnection Customer Decision Point I, 
will neither be processed nor deemed withdrawn until Interconnection 
Customer Decision Point I.  If an Interconnection Customer included in 
the JTIQ Participation Group reduces the size of Interconnection Request, 
the Transmission Provider shall determine whether such Interconnection 
Request continues to meet the criteria for inclusion in the JTIQ 
Participation Group and inform such Interconnection Customer of this 
determination not later than the start of Decision Point II.   
 
If the Interconnection Customer or MHVDC Connection Customer 
decides to proceed to the Definitive Planning Phase II, then it will be 
required to pay Definitive Planning Phase II milestone (M3), pursuant to 
Section 7.3.1.4.1, prior to the end of Interconnection Customer Decision 
Point I.   
 
If the Transmission Provider does not receive written confirmation from 
Interconnection Customer or MHVDC Connection Customer on whether it 
wants to proceed to the Definitive Planning Phase II or withdraw its 
Interconnection Request, during the Interconnection Customer Decision 
Point I, the Transmission Provider will deem the Interconnection Request 
as withdrawn without any cure period, provide written notice to

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Interconnection Customer or MHVDC Connection Customer of the 
deemed withdrawal and an explanation of the reasons for such deemed 
withdrawal, and refund Interconnection Customer’s Definitive Planning 
Phase I milestone (M2) less the amount of Automatic Withdrawal Penalty 
and any remaining study deposits pursuant to Section 3.6.  If the 
Transmission Provider does not receive Definitive Planning Phase II (M3) 
milestone payment during the Interconnection Customer Decision Point I, 
the Transmission Provider shall provide written notice to Interconnection 
Customer or MHVDC Connection Customer of such failure.  Upon receipt 
of such notice, the Interconnection Customer or MHVDC Connection 
Customer shall have three (3) Business Days to provide the Definitive 
Planning Phase II (M3) milestone payment after which period the 
Transmission Provider will deem the Interconnection Customer or 
MHVDC Connection Customers as withdrawn without any further cure 
period if the Definitive Planning Phase II (M3) milestone payment has not 
been received.  After Interconnection Customer or MHVDC Connection 
Customer enters the Definitive Planning Phase II, the Definitive Planning 
Phase I (M2) milestone payment becomes 100% non-refundable, pursuant 
to Section 7.8 and Section 7.6.2.1.  
 
Transmission Provider shall notify any Affected System Operator(s) of a 
potential Affected System impact caused by an Interconnection Request 
within ten (10) Business Days of the completion of Decision Point I. 
 
7.3.1.4.1 Definitive Planning Phase II Milestone (M3) 
Calculation. 
The Definitive Planning Phase II milestone (M3) will be in the 
form of either cash, irrevocable letter of credit or surety bond 
reasonably acceptable to Transmission Provider.  The surety bond 
must be issued by an insurer reasonably acceptable to

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Transmission Provider and must specify a reasonable expiration 
date.  The Transmission Provider may establish additional 
requirements for what constitutes a surety bond, including but not 
limited to, duration satisfaction, demand timeframe and issuer 
requirements through the Generator Interconnection Business 
Practices manual (BPM-015).  Interconnection Customers and 
MHVDC Connection Customers may replace cash milestone 
payments with a letter of credit or surety bond reasonably 
acceptable to Transmission Provider and may replace letters of 
credit or surety bonds with cash.  The Definitive Planning Phase II 
milestone (M3) will be the greater of twenty percent (20%) of the 
amount of Network Upgrades, excluding JTIQ Upgrades, 
identified in the Preliminary System Impact Study less the amount 
previously provided at M2 or $1,000/MW. 
 
7.3.2 Definitive Planning Phase II 
The Definitive Planning Phase II start the next day after the fifteen (15) 
Business Days Interconnection Customer Decision Point I window 
expires.  
The Definitive Planning Phase II will include the following steps:  
(i) 
Model Review Period (6 Business Days) 
(ii) 
Revised System Impact Study (75 Calendar Days) 
(iii) 
Interconnection Customer Decision Point II (15 Business Days) 
 
Transmission Owner shall complete the Interconnection Facilities Study 
within ninety (90) Calendar Days.  The Interconnection Facilities Study 
may be initiated during Definitive Planning Phase I, in accordance with 
Section 7.3.1 of this GIP.  To the extent the Interconnection Facilities 
Study is performed during Definitive Planning Phase II, such study shall 
be performed concurrently with tasks (i) – (iii).

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
 
7.3.2.1 Purpose 
The Definitive Planning Phase II is designed to provide Interconnection 
Customers and MHVDC Connection Customers a revised and a detailed 
analysis of their Interconnection Request’s impact on the reliability of the 
Transmission System after incorporating updated generation and MHVDC 
assumptions due to potential withdrawal of Interconnection Requests 
during Definitive Planning Phase I. Except as otherwise provided in 
Section 5.8, prior to the completion of the Revised System Impact Study, 
each impacted Transmission Owner shall indicate whether the 
Transmission Owner intends to self-fund each specific Network Upgrade 
and System Protection Facility identified in the Revised System Impact 
Study. A Transmission Owner’s self-fund election will be included in the 
Revised System Impact Study. Except as otherwise provided in Section 
5.8, the Transmission Owner’s failure to provide its indication prior to the 
completion of the Revised System Impact Study shall constitute a waiver 
of the Transmission Owner’s option to elect to self-fund each Network 
Upgrade and System Protection Facility identified in the Revised System 
Impact Study. Upon completion of the Revised System Impact Study, 
Transmission Provider will provide a detailed reliability analysis, pursuant 
to Section 7.3.2.5, to each Interconnection Customer or MHVDC 
Connection Customer that has an Interconnection Request in the 
Definitive Planning Phase II.  Upon receipt of the Revised System Impact 
Study, the Interconnection Customer or MHVDC Connection Customer 
can either proceed to Definitive Planning Phase III or withdraw its 
Interconnection Request pursuant to Section 7.3.2.4 of this Attachment X. 
 
7.3.2.2 Model Building  
Before starting the Revised System Impact Study, Transmission Provider 
will distribute the study models to Interconnection Customer or MHVDC

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Connection Customer and Transmission Owner. The Transmission 
Provider will update the study models built during Definitive Planning 
Phase I, pursuant to Section 7.3.1.2, by removing all Interconnection 
Requests that did not proceed to the Definitive Planning Phase II.  The 
Transmission Provider will distribute the revised study models to the 
Transmission Owner and Interconnection Customer or MHVDC 
Connection Customer for final review.  Any comments or corrections 
from the Transmission Owner or Interconnection Customer or MHVDC 
Connection Customer to the revised study models must be submitted to 
the Transmission Provider within six (6) Business Days after receipt of the 
revised study models.  Should the Transmission Owner or Interconnection 
Customer or MHVDC Connection Customer fail to provide feedback on 
the revised study models within six (6) Business Days, Transmission 
Provider will deem the models acceptable.  Transmission Provider shall 
thereafter begin the Revised System Impact Study. 
 
7.3.2.3 Scope of the Interconnection System Impact Study 
The Revised System Impact Study shall provide an updated, detailed 
analysis of their Interconnection Request’s impact on the reliability of the 
Transmission System after incorporating updated generation and MHVDC 
assumptions due to potential withdrawal of Interconnection Requests 
during Definitive Planning Phase I.  The Revised System Impact Study 
shall follow the procedures as the Preliminary System Impact Study 
described in Definitive Planning Phase I Section 7.3.1.3, as well as include 
a short circuit analysis and stability analysis.  Transmission Provider shall 
include in the Revised System Impact Study an analysis of the upgrades 
on Distribution System, if applicable, and Affected Systems if available.  
If Affected Systems analysis is not available for inclusion in the Revised 
System Impact Study, the Transmission Provider shall provide such 
analysis separately when received from the applicable Affected System.  If

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Transmission Provider determines in accordance with Good Utility 
Practice that any such analyses are needed, any stability analysis 
performed in a Revised System Impact Study may include transient 
stability, large and small signal, sub-synchronous stability, dynamic 
voltage stability, mid- and long-term stability, voltage flicker analyses and 
excessive neutral current.  Transmission Provider shall utilize existing 
studies to the extent practicable in performing the Revised System Impact 
Study.  For purposes of determining necessary Interconnection Facilities 
Network Upgrades, and responsibility for JTIQ Upgrades, the Revised 
System Impact Study shall consider the level of Interconnection Service 
requested by the Interconnection Customer, unless otherwise required to 
study the full Generating Facility Capacity due to safety or reliability 
concerns.  The Transmission Provider or Transmission Owner performing 
the Revised System Impact Study shall complete such study within 
seventy-five (75) Calendar Days. 
 
At the request of Interconnection Customer or MHVDC Connection 
Customer, or at any time Transmission Provider, or Transmission Owner 
where a Transmission Owner is performing the study, determines that it 
will not meet the required time frame for completing the Revised System 
Impact Study, Transmission Provider or Transmission Owner where a 
Transmission Owner is performing the study, shall notify Interconnection 
Customer or MHVDC Connection Customer regarding the following: 
(i) 
Schedule status of the Revised System Impact Study.  
(ii) 
Estimated completion date and an explanation of the reasons why 
additional time is required.   
(iii) 
Revised cost estimate of study deposits with an explanation of the 
reasons why cost estimates were revised.  Interconnection 
Customer or MHVDC Connection Customer shall then provide 
within thirty (30) Calendar Days of Transmission Provider or

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Transmission Owner’s notice, an additional deposit equal to the 
difference between the initial and revised cost estimate. Failure of 
Interconnection Customer or MHVDC Connection Customer to 
provide this additional deposit will result in withdrawal of the 
Interconnection Request pursuant to Section 3.6 of this GIP. 
 
A draft Revised System Impact Study will be posted for Interconnection 
Customers for a comment window.  Transmission Provider will address 
questions and comments that are submitted during the comment window 
regarding the report before finalizing the report and results.  The comment 
window will last for at least five (5) Business Days, but no more than ten 
(10) Business Days. 
 
7.3.2.3.1 Additional Analysis Applicable to Interconnection 
Requests in a JTIQ Screening Group. 
In addition to the analyses specified in Section 7.3.2.3 of this GIP, 
Interconnection Requests that: (1) are included in a JTIQ 
Screening Group (including ERAS projects not otherwise subject 
to Transmission Provider’s three-phase DPP) and not located in the 
MISO South Region as such region is defined by as the Generator 
Interconnection Business Practices Manual (BPM-015), and (2) are 
part of the JTIQ Participation Group and located in the MISO 
South Region: shall be subject to the following additional analysis. 
a. Expanded Scope Analysis: The Transmission Provider 
shall analyze the potential impacts of Interconnection 
Request on SPP’s transmission system  that are i) located 
within five (5) substations for facilities with a nominal 
operating voltage under 200kV, two (2) substations for 
facilities with a nominal operating voltage between 200 and 
300 kV, and one (1) substation for facilities with a nominal

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
operating voltage greater than 300 kV, from any substation 
that is part of the Transmission System; and ii) have greater 
than or equal to ten percent (10%) distribution factor on 
one or more facilities that are part of SPP’s transmission 
system. An Interconnection Request that qualifies for and is 
subject to this Expanded Scope Analysis shall not be 
required to undergo analysis by SPP of impacts to its 
transmission system beyond those identified in the 
Expanded Scope Analysis or the Supplemental Affected 
System Analysis as described in Section 7.3.2.3.1(b) of this 
GIP. 
 
If the Transmission Provider’s Expanded Scope Analysis 
identifies an Interconnection Request as having impacts to 
SPP’s transmission system that meets or exceed the 
foregoing distribution factor thresholds, the applicable 
Interconnection Customer(s) shall enter into an appropriate 
agreement with SPP or the applicable transmission owner 
to address such impacts in accordance with SPP’s rules and 
procedures.  
b. Supplemental Affected System Analysis: If the 
Transmission Provider determines that the Potential MW 
Total, including the current Group Study, exceeds the Target 
MW value for the applicable JTIQ Portfolio, SPP shall 
perform a study to determine if any Supplemental Upgrades 
are required to address impacts to its transmission system 
from one or more Interconnection Customers and provide the 
results of this analysis to the Transmission Provider prior to 
the beginning of Decision Point II. Calculation of the 
Potential MW Total and the Supplemental Affected System 
Analysis shall be performed in accordance with Section

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
9.4.2(e)(iii) of Rate Schedule 6 (MISO-SPP JOA). 
 
If the Supplemental Affected System Analysis indicates 
that Supplemental Affected System Upgrades are required 
for an Interconnection Request, then:  
(1) the applicable Interconnection Customer(s) shall 
enter into an appropriate agreement with SPP, or the 
applicable SPP transmission owner, to address such 
impacts in accordance with SPP’s rules and procedures; 
and 
(2) Transmission Provider shall compare the costs of 
such Supplemental Affected System Upgrades to the 
Threshold Charge in the manner described in Section 
9.4.2.(e)(iii)(a)(ii)(a)-(c) of Rate Schedule 6 (MISO-
SPP JOA).  
(3) The Transmission Provider, in coordination with 
SPP, shall establish a cost criterion in dollars per 
megawatt ($/MW) pursuant to Section 
9.4.2.(e)(iii)(a)(ii)(a)-(c) of Rate Schedule 6 (MISO-
SPP JOA). Where the costs assigned to an 
Interconnection Request for upgrades identified through 
the Supplemental Affected System Analysis, excluding 
costs identified through the Expanded Scope Analysis, 
exceed the cost criterion, the Interconnection Request 
shall be exempt from charges for the JTIQ Upgrades.  
Otherwise, the Interconnection Request shall be 
obligated to pay a portion of the JTIQ Upgrade. 
 
7.3.2.4 Interconnection Customer Decision Point II 
All Interconnection Customers and MHVDC Connection Customers with 
Interconnection Requests in the Definitive Planning Phase II will pass

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
through Interconnection Customer Decision Point II.  The Interconnection 
Customer Decision Point II will last for fifteen (15) Business Days 
beginning with the receipt of the Revised System Impact Study analysis, 
including Expanded Scope Analysis where applicable.  Transmission 
Provider shall provide to Interconnection Customers any Affected System 
analysis, including estimated upgrades and costs as applicable received 
from the applicable Affected System as of the date that the Transmission 
Provider is required to complete its Revised System Impact Study 
analysis.  In the event that Affected Systems analysis has not been 
received by the Transmission Provider by this time, the Transmission 
Provider shall provide such analysis to Interconnection Customers 
promptly upon receipt but shall not delay the Interconnection Customer 
Decision Point or Phase III studies.  Transmission Provider shall notify all 
Interconnection Customers and MHVDC Connection Customers at the 
beginning of Interconnection Customer Decision Point II that the 
Interconnection Customer or MHVDC Connection Customer shall have 
fifteen (15) Business Days to decide whether it wants to proceed to the 
Definitive Planning Phase III or withdraw its Interconnection Request.  
During Interconnection Customer Decision Point II, an Interconnection 
Customer or MHVDC Connection Customer may reduce the size of its 
Interconnection Request for ERIS by as much as an additional ten percent 
(10%) compared to what was studied in DPP Phase II, through either (1) a 
decrease in plant size or (2) a decrease in Interconnection Service level 
(consistent with the process described in Section 3.1) accomplished by 
applying Transmission Provider-approved injection-limiting equipment. 
Additionally, an Interconnection Customer may request to reduce the 
amount of NRIS by as much as 100% independent of any requested 
reduction in ERIS.  However, because NR Interconnection Service 
includes an equivalent amount of ER Interconnection Service, a reduction 
in NRIS level will not reduce the ERIS level unless a corresponding

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
reduction in ERIS level is requested.  The total amount of NRIS requested 
shall not exceed the amount of ERIS requested. The required M4 
milestone calculation shall be based on the DPP Phase II results.  If an 
Interconnection Customer included in the JTIQ Participation Group 
reduces the size of Interconnection Request, the Transmission Provider 
shall determine whether such Interconnection Request continues to meet 
the criteria for inclusion in the JTIQ Participation Group and inform such 
Interconnection Customer of this determination through the Revised 
System Impact Study report. 
 
If the Interconnection Customer or MHVDC Connection Customer 
decides to withdraw its Interconnection Request during, or any time 
before, the end of Interconnection Customer Decision Point II, then the 
Transmission Provider will refund Interconnection Customer’s Definitive 
Planning Phase II milestone (M3) and any remaining study deposits 
pursuant to Section 7.8.  Any withdrawal during the Definitive Planning 
Phase II, but prior to Interconnection Customer Decision Point II, will 
neither be processed nor deemed withdrawn until Interconnection 
Customer Decision Point II.  
 
If the Interconnection Customer or MHVDC Connection Customer 
decides to proceed to the Definitive Planning Phase III, then it will be 
required to pay Definitive Planning Phase III milestone (M4), pursuant to 
Section 7.3.2.4.1, as well as provide evidence of continued Site Control 
for the proposed Generating Facility prior to the end of Interconnection 
Customer Decision Point II pursuant to Section 7.2.2. 
 
If the Transmission Provider does not receive written confirmation from 
Interconnection Customer or MHVDC Connection Customer on whether it 
wants to proceed to the Definitive Planning Phase III or withdraw its

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Interconnection Request, during the Interconnection Customer Decision 
Point II, the Transmission Provider will deem the Interconnection Request 
as withdrawn without any cure period, provide written notice to 
Interconnection Customer or MHVDC Connection Customer of the 
deemed withdrawal and an explanation of the reasons for such deemed 
withdrawal, and refund Interconnection Customer’s Definitive Planning 
Phase II milestone (M3) and any remaining study deposits pursuant to 
Section 7.6.  If the Transmission Provider does not receive Definitive 
Planning Phase III (M4) milestone payment during the Interconnection 
Customer Decision Point II, the Transmission Provider shall provide 
written notice to Interconnection Customer or MHVDC Connection 
Customer of such failure.  Upon receipt of such notice, the Interconnection 
Customer or MHVDC Connection Customer shall have three (3) Business 
Days to provide the Definitive Planning Phase III (M4) milestone payment 
after which period the Transmission Provider will deem the 
Interconnection Customer or MHVDC Connection Customers as 
withdrawn without any further cure period if the Definitive Planning 
Phase III milestone (M4) payment has not been received.  After 
Interconnection Customer or MHVDC Connection Customer enters the 
Definitive Planning Phase III, the Definitive Planning Phase III (M4) 
milestone payment becomes 100% non-refundable, pursuant to Section 
7.8. 
 
Transmission Provider shall notify Affected System Operator(s) of a 
potential Affected System impact caused by an Interconnection Request 
within ten (10) Business Days of the completion of Decision Point II.  
 
7.3.2.4.1 Definitive Planning Phase III Milestone (M4) 
Calculation. 
The Definitive Planning Phase III milestone (M4) will be in the

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
form of either cash, irrevocable letter of credit or surety bond 
reasonably acceptable to Transmission Provider.  The surety bond 
must be issued by an insurer reasonably acceptable to 
Transmission Provider and must specify a reasonable expiration 
date.  The Transmission Provider may establish additional 
requirements for what constitutes a surety bond, including but not 
limited to, duration satisfaction, demand timeframe and issuer 
requirements through the Generator Interconnection Business 
Practices manual (BPM-015).  Interconnection Customers and 
MHVDC Connection Customers may replace cash milestone 
payments with a letter of credit or surety bonds and may replace 
letters of credit or surety bond with cash.  The Definitive Planning 
Phase III milestone (M4) will be thirty percent (30%) of the 
amount of Network Upgrades identified in the Revised System 
Impact Study, not including costs associated with JTIQ Upgrades, 
less any payments made as M2 and M3, but in no event shall the 
M4 be less than zero dollars. 
 
7.3.2.4.2 True-down of Milestone Payments. 
Within ten (10) Business Days from the start of Definitive 
Planning Phase III, Transmission Provider shall notify the 
Interconnection Customer if the total posted M3 and M4 milestone 
payments (i.e., the sum of the M3 and M4 payments) for the 
Interconnection Request exceed thirty percent (30%) of the total 
Network Upgrade cost assigned to such Interconnection Request in 
the Revised System Impact Study, excluding the JTIQ Generator 
Charge. Transmission Provider shall refund such excess amounts 
to the Interconnection Customer as soon as practicable.   
 
7.3.2.5 Scope of Interconnection Facilities Study.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
The first portion of the Interconnection Facilities Study focusing on the 
Interconnection Facilities or the Connection Facilities for the project will 
start no later than the first day of Definitive Planning Phase II in 
accordance with Section 7.3.2 of this GIP.  This portion of the 
Interconnection Facilities Study will identify estimates for cost and the 
time required to construct the Interconnection Facilities or the Connection 
Facilities, including cost estimates that the Transmission Owner will 
impose if the Interconnection Customer elects to build (e.g. oversight or 
management costs).  Within 10 Business Days of the Interconnection 
Customer’s receipt of the draft Interconnection Facilities Study, unless the 
Interconnection Customer has waived its option to build under Section 
7.3.1.4, the Interconnection Customer shall either elect the option to build 
or waive the option to build.  If the Interconnection Customer elects the 
option to build, at the same time it makes that election, it must also supply 
completed cost estimates for Exhibits A7 and A8 as described in Business 
Practices Manual 15 for the Interconnection Facilities and Stand-Alone 
Network Upgrades that it has elected to build.  Failure to provide a written 
response or a failure to provide the required cost estimates will be deemed 
to be a waiver of the Interconnection Customer’s option to build.  Nothing 
in this Section shall be interpreted to prohibit an Interconnection Customer 
from, with Transmission Owner’s consent, from waiving its option to 
build at a later time prior to GIA execution, but an Interconnection 
Customer is not entitled to reverse its waiver.  The Transmission Owner to 
whose facilities Interconnection Requests propose to connect or whose 
facilities are impacted by an Interconnection Request shall complete this 
portion of the Interconnection Facilities Study within ninety (90) Calendar 
Days.  The Transmission Provider or applicable Transmission Owner shall 
perform the detailed analysis.  The Interconnection Facilities Study will 
also identify any potential control equipment for (1) requests for 
Interconnection Service that are lower than the Generating Facility

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Capacity, and/or (2) requests to study a Generating Facility that includes at 
least one electric storage resource using operating assumptions according 
to the Transmission Provider’s fuel dispatch methodology in the manner 
specified by the Generator Interconnection Business Practices Manual 
(BPM-015). 
 
7.3.3 Definitive Planning Phase III 
The Definitive Planning Phase III will start the day after the expiration of the 
fifteen (15) Business Day Interconnection Customer Decision Point II. 
 
The Definitive Planning Phase III will include the following steps:  
(i) 
Model Review (6 Business Days) 
(ii) 
Final System Impact Study (50 Calendar Days) 
(iii) 
Interconnection Facilities Study for Network Upgrades (90 Calendar 
Days) 
 
7.3.3.1 Purpose 
The Definitive Planning Phase III is designed to provide Interconnection 
Customers and MHVDC Connection Customers a final, detailed analysis 
of their Interconnection Request’s impact on the reliability of the 
Transmission System after incorporating updated generation and MHVDC 
assumptions due to potential withdrawal of Interconnection Requests 
during Definitive Planning Phase II. For each specific Network Upgrade 
and System Protection Facility that the Transmission Owner did not elect 
to self-fund as a part of the Revised System Impact Study, the 
Transmission Owner shall not be permitted to further revise its election 
after the completion of the Revised System Impact Study. For each 
specific Network Upgrade and System Protection Facility that the 
Transmission Owner elected to self-fund as a part of the Revised System 
Impact Study, each impacted Transmission Owner shall confirm or revise

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
its self-fund election prior to the completion of the Final System Impact 
Study. In the event that a new Network Upgrade or System Protection 
Facility is identified in the Final System Impact Study that had not 
previously been identified in the Revised System Impact Study, each 
impacted Transmission Owner shall make a binding indication as to 
whether the Transmission Owner intends to self-fund the new Network 
Upgrade and System Protection Facility prior to the completion of the 
Final System Impact Study. A Transmission Owner’s self-fund election 
will be included in the Final System Impact Study. Except as otherwise 
provided in Section 5.8, a Transmission Owner’s failure to provide its 
self-fund election prior to the completion of the Final System Impact 
Study shall constitute a waiver of the Transmission Owner’s option to 
self-fund each Network Upgrade and System Protection Facility identified 
in the Final System Impact Study. Upon completion of the Final System 
Impact Study, the Transmission Owner(s) to whose facilities the 
Interconnection Customer or MHVDC Connection Customer proposes to 
interconnect will perform Facilities Study pursuant to Section 7.3.3.5.  
Upon completion of the Interconnection Facilities Study, Transmission 
Provider will tender a draft pro forma Generator Interconnection 
Agreement to the Interconnection Customer and Transmission Owner.   
 
7.3.3.2 Model Building 
Before starting the Final System Impact Study, Transmission Provider will 
distribute the study models to Interconnection Customer or MHVDC 
Connection Customer and Transmission Owner. The Transmission 
Provider will update the study models built during Definitive Planning 
Phase II, pursuant to Section 7.3.2.2, by removing all Interconnection 
Requests that did not proceed to the Definitive Planning Phase III.  The 
Transmission Provider will distribute the revised study models to the 
Transmission Owner and Interconnection Customer or MHVDC

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Connection Customer for final review.  Any comments or corrections 
from the Transmission Owner or Interconnection Customer or MHVDC 
Connection Customer to the revised study models must be submitted to 
the Transmission Provider within six (6) Business Days after receipt of the 
revised study models.  Should the Transmission Owner or Interconnection 
Customer or MHVDC Connection Customer fail to provide feedback on 
the revised study models within six (6) Business Days, Transmission 
Provider will deem the models acceptable.  Transmission Provider shall 
thereafter begin the Final System Impact Study.   
 
7.3.3.3 Scope of the Final System Impact Study 
The Final System Impact Study shall provide a final, detailed analysis of 
their Interconnection Request’s impact on the reliability of the 
Transmission System after incorporating updated generation assumptions 
due to potential withdrawal of Interconnection Requests during Definitive 
Planning Phase II.  The Final System Impact Study shall follow the 
procedures as the Revised System Impact Study described in Definitive 
Planning Phase II Section 7.3.2.3 and additional JTIQ analysis described 
in Section 7.3.2.3.1, where applicable.  Transmission Provider, or 
Transmission Owner if a Transmission Owner is conducting the study, 
shall include in the Final System Impact Study any Affected System 
results and information regarding network upgrades provided in the 
Affected System’s study report, if available from the applicable Affected 
System. If the Affected System’s study report is not available for inclusion 
in the Final System Impact Study, the Transmission Provider shall provide 
such analysis separately when received from the applicable Affected 
System.  For purposes of determining necessary Interconnection Facilities 
and Network Upgrades, the Final System Impact Study shall consider the 
level of Interconnection Service requested by the Interconnection 
Customer, unless otherwise required to study the full Generating Facility

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Capacity due to safety or reliability concerns.  Transmission Provider shall 
utilize existing studies to the extent practicable in performing the Final 
System Impact Study. 
 
If requested by the Interconnection Customer, the Transmission Provider 
or Transmission Owner performing the Preliminary, Revised, and Final 
System Impact Study shall evaluate, as part of the applicable System 
Impact Study, the use of static synchronous compensators, static VAR 
compensators, advanced power flow control devices, transmission 
switching, synchronous condensers, voltage source converters, advanced 
conductors, and tower lifting. The requesting Interconnection Customer 
shall timely provide Transmission Provider with the requisite model 
information to allow Transmission Provider to evaluate the requested 
technology.  The Transmission Provider or applicable Transmission 
Owner shall evaluate each requested alternative transmission technology 
and determine whether the above technologies should be used, consistent 
with Good Utility Practice, Applicable Reliability Standards, and 
Applicable Laws and Regulations, as an alternative to traditional network 
upgrades.  Transmission Provider shall include an explanation of the 
results of the Transmission Provider’s evaluation for each technology in 
the applicable System Impact Study report. The Transmission Provider or 
Transmission Owner’s evaluation will be completed pursuant to the 
provisions set forth in the Generator Interconnection Business Practices 
Manual. 
The Final System Impact Study will start the day after the completion of 
the Model Review in the Definitive Planning Phase III. Transmission 
Provider, or Transmission Owner if a Transmission Owner is performing 
the study, shall complete the Final System Impact Study within fifty (50) 
Calendar Days.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
At the request of Interconnection Customer or MHVDC Connection 
Customer, or at any time Transmission Provider determines that it will not 
meet the required time frame for completing the Final System Impact 
Study, Transmission Provider shall notify Interconnection Customer or 
MHVDC Connection Customer regarding the following: 
(i) 
Schedule status of the Final System Impact Study.   
(ii) 
Estimated completion date and an explanation of the reasons why 
additional time is required.   
(iii) 
Revised cost estimate of study deposits with an explanation of the 
reasons why cost estimates were revised.  Interconnection 
Customer or MHVDC Connection Customer shall then provide 
within thirty (30) Calendar Days of Transmission Provider’s 
notice, an additional deposit equal to the difference between the 
initial and revised cost estimate. Failure of Interconnection 
Customer or MHVDC Connection Customer to provide this 
additional deposit will result in withdrawal of the Interconnection 
Request pursuant to Section 3.6 of this GIP.   
 
A draft Final System Impact Study will be posted for Interconnection 
Customers for a comment window.  Transmission Provider will address 
questions and comments that are submitted during the comment window 
regarding the report before finalizing the report and results. The comment 
window will last for at least five (5) Business Days, but no more than ten 
(10) Business Days. 
 
7.3.3.4 Scope of Interconnection Facilities Study. 
The Transmission Owner to whose facilities Interconnection Requests 
propose to connect or whose facilities are impacted by an Interconnection 
Request may begin the second portion of the Interconnection Facilities 
Study for that Network Upgrade prior to the completion of the Final

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
System Impact Study. The Interconnection Customer(s) responsible for a 
Network Upgrade may request that the second portion of the 
Interconnection Facilities Study begin after the completion of 
Interconnection Customer Decision Point II and prior to the completion of 
the Final System Impact Study. The Transmission Owner to whose 
facilities Interconnection Requests propose to connect or whose facilities 
are impacted by an Interconnection Request Transmission Owner shall 
start the second portion of the Interconnection Facilities Study no later 
than the day following the posting of the Final System Impact Study report 
and, if applicable, the Affected System’s final study report, provided that 
Transmission Provider has submitted to the applicable Transmission 
Owner(s) an executed statement of work and purchase order.  This phase 
will identify estimates for the cost and time required to build necessary 
Network Upgrades that are identified in the Final System Impact Study.  
The Transmission Owner conducting the study shall complete this portion 
of the Interconnection Facilities Study within ninety (90) Calendar Days 
from the start date of the Interconnection Facilities Study. 
 
The Interconnection Facilities Study, in its entirety, shall specify and 
estimate the cost of the required equipment, engineering, procurement and 
construction work needed to implement the Network Upgrades and 
Interconnection Facilities or Connection Facilities identified in the Final 
System Impact Study in accordance with Good Utility Practice to 
physically and electrically connect the Interconnection Facilities or the 
Connection Facilities to the Transmission or Distribution System, as 
applicable, as well as that equipment, to the extent known and available in 
accordance with Section 3.5 of these GIP, required by Affected Systems to 
accommodate the interconnection of the Generating Facility or the 
MHVDC Transmission Line.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
The Interconnection Facilities Study shall also identify the electrical 
switching configuration of the connection equipment, including, without 
limitation: the transformer, switchgear, meters, and other station 
equipment; the nature and estimated cost of any Transmission Owner’s 
Interconnection Facilities or Connection Facilities and Network Upgrades, 
Distribution Upgrades, Generator Upgrades, Common Use Upgrades, and 
to the extent known and available in accordance with Section 3.5 of the 
GIP, upgrades on Affected Systems necessary to accomplish the 
interconnection; and an estimate of the time required to complete the 
construction and installation of such facilities.  The Interconnection 
Facilities Study will also identify any potential control equipment for 
requests for Interconnection Service that are lower than the Generating 
Facility Capacity. 
 
The Interconnection Customer shall enter into a facilities construction 
agreement with any neighboring transmission provider for network 
upgrades identified in the Affected System analysis. 
 
7.3.3.5 Interconnection Facilities Study Procedures. 
Transmission Provider shall coordinate the Interconnection Facilities 
Study with any Affected System pursuant to Section 3.5 of this GIP.  
Transmission Provider and applicable Transmission Owner shall utilize 
existing studies to the extent practicable in performing the Interconnection 
Facilities Study.  The Interconnection Facilities Study for an 
Interconnection Request shall be typically performed as a Group Study 
with respect to Common Use Upgrades and/or Interconnection Facilities 
or Connection Facilities common to more than one Interconnection 
Request.   
 
At the request of Interconnection Customer or MHVDC Connection

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ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Customer or at any time that the Transmission Provider or applicable 
Transmission Owner determines that it will not meet the required time 
frame for completing the Interconnection Facilities Study, Transmission 
Provider shall notify Interconnection Customer or MHVDC Connection 
Customer as to the schedule status of the Interconnection Facilities Study.  
If the applicable Transmission Owner is unable to complete the 
Interconnection Facilities Study within the time required, such 
Transmission Owner shall notify Interconnection Customer and provide an 
estimated completion date and an explanation of the reasons why 
additional time is required.  If the applicable Transmission Owner is 
unable to complete the Interconnection Facilities Study with the study 
deposit provided by Interconnection Customer or MHVDC Connection 
Customer, Transmission Provider shall notify Interconnection Customer or 
MHVDC Connection Customer and provide a revised cost estimate with 
an explanation of the reasons why.  Interconnection Customer or MHVDC 
Connection Customer shall then provide within fifteen (15) Calendar Days 
of Transmission Provider’s notice, an additional deposit equal to the 
difference between the initial and revised cost estimate.  Failure of 
Interconnection Customer or MHVDC Connection Customer to provide 
this additional deposit will result in withdrawal of the Interconnection 
Request pursuant to Section 3.6 of this GIP.  
 
Transmission Owner shall provide to Transmission Provider a draft 
Interconnection Facilities report at the conclusion of the Interconnection 
Facilities Study.  A draft Interconnection Facilities Study will be posted by 
Transmission Provider for Interconnection Customers for a comment 
window.  Transmission Provider and Transmission Owner will address 
questions and comments that are submitted during the comment window 
regarding the report before finalizing the report and results.  The comment 
window will last for at least five (5) Business Days, but no more than ten

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ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
(10) Business Days. 
 
Interconnection Customer or MHVDC Connection Customer and 
Transmission Owner may, within fifteen (15) Calendar Days after receipt 
of the draft Interconnection Facilities report and supporting 
documentation, provide written comments to Transmission Provider, 
which Transmission Provider shall include in the final Interconnection 
Facilities report.  If the draft Interconnection Facilities report contains a 
Stand-Alone Network Upgrade, unless the Interconnection Customer has 
waived its option to build under Section 7.3.1.4, the cost estimate shall 
include the cost that the Transmission Owner will impose if the 
Interconnection Customer elects to build (e.g. oversight or management 
costs).  Unless the Interconnection Customer has waived its option to build 
under Section 7.3.1.4, the Interconnection Customer shall either elect the 
option to build or waive the option to build Stand-Alone Network 
Upgrades identified in the second portion of the Interconnection Facilities 
Study within 15 calendar days of receiving the draft Interconnection 
Facilities report.  If the Interconnection Customer elects the option to 
build, at the same time it makes that election, it must also supply 
completed cost estimates for Exhibits A7 and A8 as described in the 
Business Practices Manual 15 for the Stand-Alone Network Upgrades that 
it has elected to build.  Failure to provide a written response or a failure to 
provide the required cost estimates will be deemed to be a waiver of the 
Interconnection Customer’s option to build.  Nothing in this Section shall 
be interpreted to prohibit an Interconnection Customer, with Transmission 
Owner’s consent, from waiving its option to build at a later time prior to 
GIA execution, but an Interconnection Customer is not entitled to reverse 
its waiver.  If Interconnection Customer elects to build, Transmission 
Provider shall include that election in the final Interconnection Facilities 
report.  Transmission Provider shall issue the final Interconnection

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Facilities report and supporting documentation within ten (10) Calendar 
Days of receiving the Interconnection Customer’s or the MHVDC 
Connection Customer’s comments or promptly upon receiving 
Interconnection Customer’s or the MHVDC Connection Customer’s 
statement that it will not provide comments.  Transmission Provider may 
reasonably extend such fifteen-day period upon notice to Interconnection 
Customer or MHVDC Connection Customer if the Interconnection 
Customer’s or the MHVDC Connection Customer’s comments require 
Transmission Provider or the applicable Transmission Owner to perform 
additional analyses or make other significant revisions prior to the 
issuance of the final Interconnection Facilities Report.  Upon request, 
Transmission Provider or the applicable Transmission Owner shall 
provide Interconnection Customer or MHVDC Connection Customer 
supporting documentation, work papers, and databases or data developed 
in the preparation of the Interconnection Facilities Study, subject to 
confidentiality arrangements consistent with Section 13.1.  
Interconnection Customer or MHVDC Connection Customer shall 
maintain as confidential any information that is provided by Transmission 
Provider or the applicable Transmission Owner and identified as Critical 
Energy Infrastructure Information (CEII), as that term is defined in 
18 C.F.R. Section 388.113(c).  Such confidentiality will be maintained in 
accordance with Section 13.1. 
 
7.4 
Meeting with Transmission Provider. 
Within ten (10) Business Days of providing draft GIA or TCA appendices and, as 
applicable, associated draft appendices for the related FCA(s) and/or MPFCA(s) 
and supporting documentation to Interconnection Customer, Transmission Owner 
and Interconnection Customer may meet to discuss the results of the 
Interconnection Facilities Study.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
7.5 
Interconnection Study Restudy. 
If a restudy of any Interconnection Study is required because an Interconnection 
Request withdraws or is deemed to have withdrawn prior to all GIAs, TCAs, 
FCAs, and/or MPFCAs, as applicable, for each respective Definitive Planning 
Phase cycle have been executed or filed unexecuted with the Federal Energy 
Regulatory Commission, Transmission Provider shall provide notice of restudy as 
necessary.  The Transmission Provider’s notice shall include a summary of a 
preliminary analysis supporting the need for an Interconnection Study restudy, an 
explanation of why an Interconnection Study restudy is required and a good faith 
estimate of the cost to perform the Interconnection Study restudy.  The 
Interconnection Study restudy shall be performed subject to the GIP and Business 
Practices Manuals in effect at the time notice is provided by Transmission 
Provider.  Interconnection Customer or MHVDC Connection Customer shall 
notify Transmission Provider within five (5) Business Days whether 
Interconnection Customer or MHVDC Connection Customer wishes to proceed 
with the Interconnection Study restudy or withdraw its Interconnection Request.  
Transmission Provider shall deem Interconnection Customer’s or MHVDC 
Connection Customer’s failure to notify Transmission Provider to proceed to 
perform the Interconnection Study restudy as Interconnection Customer’s or 
MHVDC Connection Customer’s withdrawal of its Interconnection Request in 
accordance with Section 3.6 of this GIP.  Transmission Provider or the applicable 
Transmission Owner shall complete such Interconnection Study restudy no later 
than sixty (60) Calendar Days from the date of notice.  Transmission Provider 
may elect to perform any Interconnection Study restudy of Network Upgrades 
common to more than one Interconnection Request as a Group Study.   
 
7.6 
Refunds 
 
7.6.1 Refunds of Study Deposits 
Transmission Provider shall charge and Interconnection Customer or

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ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
MHVDC Connection Customer shall pay the actual costs of the 
Interconnection Studies.  Any difference between the study deposit and 
the actual cost of the applicable Interconnection Study shall be paid by or 
refunded to, except as otherwise provided herein, the Interconnection 
Customer. Any invoices for Interconnection Studies shall include a 
detailed and itemized accounting of the cost of each Interconnection 
Study.  Interconnection Customer or MHVDC Connection Customer shall 
pay any such undisputed costs within thirty (30) Calendar Days of receipt 
of an invoice.  Transmission Provider shall not be obligated to perform or 
continue to perform any studies unless Interconnection Customer or 
MHVDC Connection Customer has paid all undisputed amounts in 
compliance herewith.   
 
All charges associated with performing Interconnection Studies, during all 
three phases of the Definitive Planning Phase, are the responsibility of 
Interconnection Customers or MHVDC Connection Customers with active 
Interconnection Requests during each respective Definitive Planning 
Phase.   
 
If the Interconnection Customer or MHVDC Connection Customer 
withdraws its Interconnection Request any time before the end of 
Interconnection Customer Decision Point I, the Transmission Provider 
will refund to the Interconnection Customer or MHVDC Connection 
Customer any unused portion of the study deposits.  Any Interconnection 
Customer or MHVDC Connection Customer that withdraws its 
Interconnection Request, or is deemed to be withdrawn, during Definitive 
Planning Phase I but before Interconnection Customer Decision Point I is 
responsible for its pro rata portion of the group Interconnection Study 
costs for Definitive Planning Phase I.  Any Interconnection Customer or 
MHVDC Connection Customer that withdraws its Interconnection

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Request, or is deemed to be withdrawn, prior to the expiration of 
Interconnection Customer Decision Point I will not be responsible to fund 
any Interconnection Studies that take place during or after the start of the 
Definitive Planning Phase II of the GIP.  
 
If the Interconnection Customer or MHVDC Connection Customer 
withdraws its Interconnection Request any time after Interconnection 
Customer Decision Point I, but before the expiration of the 
Interconnection Customer Decision Point II, then the Transmission 
Provider will refund to the Interconnection Customer or MHVDC 
Connection Customer any unused portion of the study deposits.  Any 
Interconnection Customer or MHVDC Connection Customer that 
withdraws its Interconnection Request, or is deemed to be withdrawn, 
during Definitive Planning Phase II but before Interconnection Customer 
Decision Point II is responsible for its pro rata portion of the group 
Interconnection Study costs for Definitive Planning Phase II.  Any 
Interconnection Customer or MHVDC Connection Customer that 
withdraws its Interconnection Request prior to the expiration of 
Interconnection Customer Decision Point II will not be responsible to fund 
any Interconnection Studies that take place during or after the start of 
Definitive Planning Phase III of the GIP. 
 
If the Interconnection Customer or MHVDC Connection Customer 
withdraws its Interconnection Request any time during Definitive 
Planning Phase III of the GIP, and if the Transmission Provider 
determines that an Interconnection Study restudy is required, then the 
withdrawing Interconnection Customer or MHVDC Connection Customer 
will be responsible to fund all such restudies in Definitive Planning Phase 
III of the GIP, up to the amount of that Interconnection Customer’s total 
study deposit.  However, if the Transmission Provider determines that no

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Interconnection Study restudy is required due to the withdrawal of 
Interconnection Customer’s or MHVDC Connection Customer’s 
Interconnection Request, then the withdrawing Interconnection Customer 
or MHVDC Connection Customer will not be responsible to fund any 
further Interconnection Studies during Definitive Planning Phase III of the 
GIP and the Transmission Provider shall refund to the Interconnection 
Customer or MHVDC Connection Customer any unused portion of the 
study deposit paid to enter the Definitive Planning Phase. 
 
7.6.2 Refunds of Definitive Planning Phase Milestones (M2, M3, M4) 
 
7.6.2.1 Refunds of Definitive Planning Phase entry milestone (M2) 
Interconnection Customers and MHVDC Connection Customers are 
eligible to receive one hundred percent (100%) refund of the Definitive 
Planning Phase entry milestone (M2) only when the Interconnection 
Request is withdrawn or deemed withdrawn prior to the start of Definitive 
Planning Phase I or when Transmission Provider has completed review of 
Site Control sufficiency pursuant to Section 7.2.1.3 of the GIP and the 
Interconnection Request is deemed withdrawn due to Site Control 
deficiencies.  Interconnection Customers and MHVDC Connection 
Customers are eligible to receive refund of forty percent (40%) of the 
Definitive Planning Phase entry milestone (M2) only when the 
Interconnection Request is withdrawn or deemed withdrawn during 
Definitive Planning Phase I or at any time before or at the end of 
Interconnection Customer Decision Point I.  The remaining 60% of the 
Definitive Planning Phase entry milestone (M2) becomes non-refundable 
pursuant to Section 7.6.2.1.1 and 7.8 of the GIP.  If the Interconnection 
Request is withdrawn any time after the Interconnection Customer 
Decision Point I, then the entire Definitive Planning Phase entry milestone 
(M2) becomes non-refundable pursuant to Section 7.6.2.1.1 and 7.8 of the

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
GIP. 
 
7.6.2.1.1 Calculation of the Automatic Withdrawal Penalty 
Interconnection Customer shall be subject to an Automatic 
Withdrawal Penalty if it withdraws its Interconnection Request, or 
the Interconnection request is deemed withdrawn pursuant to 
section 7.2.1.3 or section 3.6 of the GIP.  Interconnection 
Customer shall not be subject to an Automatic Withdrawal Penalty 
if it withdraws its Interconnection Request, or the Interconnection 
Request is deemed withdrawn prior to commencement of 
Definitive Planning Phase I. 
 
(a) If Interconnection Request is withdrawn or deemed withdrawn 
during Definitive Planning Phase I or at any time before or at 
the end of Interconnection Customer Decision Point I, the 
Interconnection Customer shall be charged ten percent (10%) 
of the Definitive Planning Phase entry milestone (M2). 
 
(b) If the Interconnection Request is withdrawn or deemed 
withdrawn after Interconnection Customer Decision Point I and 
before or at the end of Interconnection Customer Decision 
Point II, the Interconnection Customer shall be charged thirty-
five percent (35%) of the Definitive Planning Phase entry 
milestone (M2). 
 
(c) If the Interconnection Request is withdrawn or deemed 
withdrawn after Interconnection Customer Decision Point II 
and before the end of the Definitive Planning Phase III, the 
Interconnection Customer shall be charged seventy five percent

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
(75%) of the Definitive Planning Phase entry milestone (M2). 
 
(d) If the Interconnection Request is withdrawn or deemed 
withdrawn after start of the Generator Interconnection 
Agreement (GIA) negotiations (within 5 days of posting of the 
Final System Impact Study report) the Interconnection 
Customer shall be charged one hundred percent (100%) of the 
Definitive Planning Phase entry milestone (M2). 
 
7.6.2.2 Refund of Definitive Planning Phase II milestone (M3) 
Interconnection Customers and MHVDC Connection Customers are 
eligible to receive one hundred percent (100%) refund of the Definitive 
Planning Phase II milestone (M3) only when the Interconnection Request 
is withdrawn or deemed withdrawn after Interconnection Customer 
Decision Point I and before or at the end of Interconnection Customer 
Decision Point II.  If the Interconnection Request is withdrawn any time 
after the end of Interconnection Customer Decision Point II, then the 
Definitive Planning Phase II milestone (M3) becomes non-refundable 
pursuant to Section 7.8 of the GIP. 
 
7.6.2.3 Refund of Definitive Planning Phase II milestone (M4) 
If the Interconnection Customer or MHVDC Connection Customer 
decides to withdraw its Interconnection Request any time after entering 
the Definitive Planning Phase III, then the Definitive Planning Phase III 
milestone (M4) becomes non-refundable pursuant to Section 7.8 of the 
GIP. 
 
7.6.2.4 Withdrawal and refund due to increase in Network Upgrade 
costs 
Milestone payments will be refunded in the event the Interconnection

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Customer or MHVDC Connection Customer withdraws because the total 
Network Upgrade cost estimates in the Revised System Impact Study 
increased by more than fifty percent (50%) and more than $10,000 per 
MW over the Preliminary System Impact Study as a result of 
Transmission Provider, or Transmission Owner error that is identified 
prior to the finalization of the revised System Impact Study report.  To 
obtain a refund, Interconnection Customer must withdraw at the end of 
Interconnection Customer Decision Point II. 
 
Milestone payments will be refunded in the event the Interconnection 
Customer or MHVDC Connection Customer withdraws because the total 
Network Upgrade cost estimates in the Final System Impact Study 
increased by more than thirty-five percent (35%) and more than $10,000 
per MW over the Revised System Impact Study as a result of 
Transmission Provider, Affected System (to the extent available) or 
Transmission Owner error that is identified prior to the finalization of the 
Final System Impact Study report.  To obtain a refund, Interconnection 
Customer must withdraw within five Business Days of posting the results 
of the Final System Impact Study. 
 
Milestone payments less Automatic Withdrawal Penalty amount will also 
be refunded in the event the Interconnection Customer or MHVDC 
Connection Customer withdraws and the total Network Upgrade cost 
estimates in the Interconnection Facilities Study increased by more than 
thirty-five percent (35%) and more than $10,000 per MW over the 
Network Upgrade cost estimates in the Final System Impact Study.  To 
obtain a refund, Interconnection Customer must withdraw within five 
Business Days of posting the results of the Interconnection Facilities 
Study.

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ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Milestone payments less Automatic Withdrawal Penalty amount will also 
be refunded in the event the Interconnection Customer or MHVDC 
Connection Customer withdraws within the later of five (5) Business Days 
of the results of the study or at the end of an Interconnection Customer 
Decision Point, if applicable, of results indicating designated increases in 
estimated upgrade costs across the following intervals: 
1. DPP Phase I to DPP Phase II 
a. An increase in MISO Network Upgrade costs from Phase I to 
Phase II of  at least 50%, and more than $10,000 per MW from 
the Preliminary SIS to the Revised SIS. 
2. DPP Phase II to DPP Phase III 
a. An increase in the combined Network Upgrade and Affected 
System costs from Phase II to the start of GIA negotiation of 
thirty-five percent (35%) and more than $15,000 per MW from 
the Revised SIS (including and Affected Systems results 
received during DPP Phase II) to any Final SIS and Affected 
Systems results received prior to the start of GIA negotiations. 
 
7.7 
Applicability of Definitive Planning Phase Milestone Payments (M2, M3, and 
M4) to Generator Interconnection Agreement Initial Payment, Transmission 
Connection Agreement Initial Payment, or construction agreement security 
 
In the event the Interconnection Customer has elected to make its milestones in 
the form of cash, Transmission Provider will transfer the Definitive Planning 
Phase milestones to the appropriate Transmission Owner to satisfy the initial 
payment requirement of the Generator Interconnection Agreement, TCA or other 
applicable service agreement within forty-five (45) Calendar Days of the effective 
date of the Generator Interconnection Agreement, TCA or other applicable 
service agreement.   
 
Provided that the Interconnection Customer has not requested withdrawal, is

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ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
deemed withdrawn, or is pending termination of its applicable service agreement, 
the Transmission Provider shall refund Milestone cash payments exceeding the 
initial payment requirement to the Interconnection Customer, MHVDC 
Connection Customer or the applicable Transmission Owner upon 
Interconnection Customer’s or MHVDC Connection Customer’s request with 
Transmission Owner’s consent, within forty-five (45) Calendar Days of the later 
effective date of the Generator Interconnection Agreement, TCA, other applicable 
service agreements or construction agreements.  In the event the milestone 
payments are less than the initial payment requirement, the Interconnection 
Customer or MHVDC Connection Customer shall be responsible for the 
remaining payment to the Transmission Owner.  
 
In the event milestone payments were provided pursuant to an irrevocable letter of 
credit or surety bond such letter of credit or surety bond shall be released upon 
satisfaction of the later initial payment requirement in the Generator 
Interconnection Agreement, TCA, other applicable service agreements or 
construction agreements, and with Transmission Owner’s consent, provided that 
the Interconnection Customer has not requested withdrawal, is deemed 
withdrawn, or is pending termination of its applicable service agreement. 
 
7.8 
Use of Definitive Planning Phase Entry At Risk Milestone Payments (M2, M3 
and M4) or Payments of Withdrawn Projects 
 
Upon completion of the Definitive Planning Phase III and after any subsequent 
restudy performed after Definitive Planning Phase III, Transmission Provider will 
determine the financial impact of withdrawn projects on each remaining 
Interconnection Request in the same cycle.  This financial impact will be 
determined using the following two-step method. 
 
Step 1: Transmission Provider first determines the cost of upgrades that are 
shifted from withdrawn projects to remaining projects that were co-participants in

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Common Use Upgrades or Shared Network Upgrades. 
 
For projects that withdrew before the completion of Interconnection Customer 
Decision Point I with at-risk milestones, the Transmission provider will 
determine the costs that were shifted from withdrawn projects to remaining 
projects that were co-participants in Common Use Upgrades or Shared 
Network Upgrades. In order to determine whether a withdrawal caused overall 
financial impact to those remaining Interconnection Requests, the 
Transmission Provider shall compare the planning level cost allocation 
between the Preliminary System Impact Study and the Final System Impact 
Study. 
 
For projects that withdrew after the completion of Interconnection Customer 
Decision Point I but before the completion of Interconnection Customer 
Decision Point II with at-risk milestones, the Transmission Provider will 
determine the costs that were shifted from withdrawn projects to remaining 
projects that were co-participants in Common Use Upgrades or Shared 
Network Upgrades. In order to determine whether a withdrawal caused overall 
financial impact to those remaining Interconnection Requests, the 
Transmission Provider shall compare the planning level cost allocation 
between the Revised System Impact Study and the Final System Impact 
Study. 
 
For projects that withdrew after the completion of Interconnection Customer 
Decision Point II with at-risk milestones or payments, the Transmission 
Provider will determine the costs that were shifted from withdrawn projects to 
remaining projects that were co-participants in Common Use Upgrades or 
Shared Network Upgrades. In order to determine whether a withdrawal caused 
overall financial impact to those remaining Interconnection Requests, the 
Transmission Provider shall compare the planning level cost allocation

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
between the last study the withdrawing project was included in  and the 
subsequent study. 
 
For each of the step 1 comparisons, if the comparative planning level cost analysis 
indicates that a project withdrawal causes an increase in financial impact to any 
remaining co-participants, a financial impact analysis will be performed to 
determine if the overall costs to the remaining co-participants subsequently 
increased, those remaining co-participants will be credited using the milestones, 
and/or payment(s) made under a GIA, FCA, or MPFCA that were forfeited by the 
withdrawn Interconnection Customers or MHVDC Connection Customers in the 
same cycle. 
 
Step 2:  Transmission Provider will calculate the financial impact to each 
remaining Interconnection Request that is obligated to fund Network Upgrades 
other than Common Use Upgrades or Shared Network Upgrades.   
 
For projects that withdrew before the completion of Interconnection Customer 
Decision Point I with at-risk milestones, the Transmission provider will 
determine the costs that were shifted from withdrawn projects to remaining 
projects that fund Network Upgrades other than Common Use Upgrades or 
Shared Network Upgrades. In order to determine whether a withdrawal caused 
overall financial impact to those remaining Interconnection Requests, the 
Transmission Provider shall compare the planning level cost allocation 
between the Preliminary System Impact Study and the Final System Impact 
Study. 
 
For projects that withdrew after the completion of Interconnection Customer 
Decision Point I but before the completion of Interconnection Customer 
Decision Point II with at-risk milestones, the Transmission Provider will 
determine the costs that were shifted from withdrawn projects to remaining

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
projects that fund Network Upgrades other than Common Use Upgrades or 
Shared Network Upgrades. In order to determine whether a withdrawal caused 
overall financial impact to those remaining Interconnection Requests, the 
Transmission Provider shall compare the planning level cost allocation 
between the Revised System Impact Study and the Final System Impact 
Study. 
 
For projects that withdrew after the completion of Interconnection Customer 
Decision Point II with at-risk milestones or payments, the Transmission Provider 
will determine the costs that were shifted from withdrawn projects to remaining 
projects that fund Network Upgrades other than Common Use Upgrades or 
Shared Network Upgrades. In order to determine whether a withdrawal caused 
overall financial impact to those remaining Interconnection Requests, the 
Transmission Provider shall compare the planning level cost allocation between 
the Final System Impact Study and the subsequent restudy. For each of the Step 2 
comparisons, if any portion of the comparative analyses indicates that the 
withdrawal of a project causes an increase in the total cost of Network Upgrades, 
other than Common Use Upgrades or Shared Network Upgrades, for any of the 
remaining Interconnection Requests, the Transmission Provider will use the 
Definitive Planning Phase at-risk milestones (M2, M3 and M4), collected from 
the withdrawn Interconnection Requests in the current Definitive Planning Phase 
cycle and/or payment(s) made under a GIA, FCA, or MPFCA, to offset the cost 
difference for those remaining Interconnection Requests in the same cycle.  If any 
portion of the comparative analyses indicated that the withdrawal of a project 
causes a decrease in the total cost of Network Upgrades, other than Common Use 
Upgrades or Shared Network Upgrades, for any of the remaining Interconnection 
Requests, those remaining Interconnection Customers and MHVDC Connection 
Customers shall not receive any reimbursement from the collected Definitive 
Planning Phase milestones and/or payment(s) made under a GIA, FCA, or 
MPFCA.  If any portion of the comparative analyses indicates that the withdrawal

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
of a project causes the total cost of Network Upgrades, other than Common Use 
Upgrades or Shared Network Upgrades, for any of the remaining Interconnection 
Requests to remain the same, those remaining Interconnection Customers and 
MHVDC Connection Customers shall not receive any reimbursement from the 
collected Definitive Planning Phase milestones and/or payment(s) made under a 
GIA, FCA, or MPFCA.  
 
The total allocation to any remaining Interconnection Requests will not exceed 
the total Definitive Planning Phase milestones collected from the Interconnection 
Customers and MHVDC Connection Customers that withdrew their 
Interconnection Requests from the same Definitive Planning Phase cycle and/or 
the allowable amount from the payment(s) made under a GIA, FCA, or MPFCA.  
In instances where the total cost of Network Upgrades has increased for multiple 
Interconnection Requests, but the collected Definitive Planning Phase milestones 
and/or the allowable amount from the payment(s) made under a GIA, FCA, or 
MPFCA are insufficient to cover the increase in total cost of Network Upgrades 
for all affected Interconnection Requests, the Transmission Provider will allocate 
the collected Definitive Planning Phase milestones equally as a percentage of 
increased Network Upgrade costs. 
 
If any collected Definitive Planning Phase milestones and/or payment(s) made 
under a GIA, FCA, or MPFCA remain after allocating to remaining affected 
Interconnection Requests, the Transmission Provider will refund the remaining 
collected Definitive Planning Phase at-risk milestones to each Interconnection 
Customer and MHVDC Connection Customer in proportion to that customer’s 
forfeited milestone payments as a pro rata share of the total collected Definitive 
Planning Phase milestones and/or payments made under a GIA, FCA, or MPFCA. 
 
The amount of the payment(s) made under a GIA, FCA, or MPFCA that can be 
used to compensate for financial impact under this Section cannot exceed the

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
amount of the Interconnection Customer’s or MHVDC Connection Customer’s 
Definitive Planning Phase milestones. 
 
7.8.1 Use of the Automatic Withdrawal Penalty Payments 
 
For each DPP study group, Transmission Provider shall hold all Automatic 
Withdrawal Penalty funds until all Interconnection Customers in that study 
group have either: (1) withdrawn or been deemed withdrawn; (2) executed a 
GIA; or (3) requested a GIA to be filed unexecuted.  Any Automatic 
Withdrawal Penalty funds collected from each DPP study group shall be 
allocated towards studies cost and Network Upgrade costs for Interconnection 
Customers in the same study group that have executed the GIA or requested 
the GIA to be filed unexecuted.   
 
Automatic Withdrawal Penalty funds shall be distributed to the 
Interconnection Customers in the same DPP study group that executed their 
GIA or requested to have their GIA filed unexecuted following the last 
Effective Date of any GIA for an Interconnection Request in the study group.  
The amount of Automatic Withdrawal Penalty funds distributed to an 
Interconnection Customer shall not exceed the total study costs and Network 
Upgrade costs. 
 
Transmission Provider shall post the balance of Automatic Withdrawal 
Penalty funds held by Transmission Provider but not yet dispersed on its 
OASIS site and update this posting on a quarterly basis. 
 
7.9 
Provisional Generator Interconnection Agreement 
The Transmission Provider may provide a provisional Generator Interconnection 
Agreement for limited operation at the discretion of Transmission Provider based 
upon the results of available studies that indicate that there is a level of

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
interconnection that can occur without any additional Network Upgrades.  An 
Interconnection Customer may request such Provisional Generator 
Interconnection Agreement by providing written notice to the Transmission 
Provider beginning upon Interconnection Request submission and up to and 
through Interconnection Customer Decision Point II (Section 7.3.2.4 of this GIP).  
An Interconnection Customer that qualifies for inclusion in a JTIQ Participation 
Group shall execute or request the unexecuted filing of the JTIQ Commitment 
Agreement concurrently with their provisional GIA and, if tendered, the SPP 
JTIQ Service Agreement. If the SPP JTIQ Service Agreement has not been 
tendered to Interconnection Customer by the time such Interconnection Customer 
executes or rests the unexecuted filing of the provisional Generator 
Interconnection Agreement, the provisional Generator Interconnection Agreement 
shall include a milestone in Appendix B requiring the Interconnection Customer 
to execute or request the unexecuted filing of such agreement within fifteen (15 
days after it is tendered). 
 
If scheduled Interconnection Customer Decision Point I, Interconnection 
Customer Decision Point II, or the Interconnection Facilities Study for Network 
Upgrades becomes delayed by more than sixty (60) Calendar Days, 
Interconnection Customers may also request a Provisional Generator 
Interconnection Agreement from Transmission Provider.  A request for a 
Provisional Generator Interconnection Agreement at any other time shall be 
deemed invalid by the Transmission Provider.   
 
All provisions of the Definitive Planning Phase (Section 7 of this GIP) apply, 
except as provided in Section 7.9.1.  After receiving a request for a Provisional 
Generator Interconnection Agreement, the Transmission Provider will begin the 
first portion of the Interconnection Facilities Study as discussed in Section 7.3.3.4 
and will perform a Provisional Interconnection Study.  After completing required 
studies, the Transmission Provider will issue a draft Provisional Generator

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Interconnection Agreement pursuant to Section 11.2. 
 
7.9.1 Additional Definitive Planning Phase Requirements for Provisional 
Generator Interconnection Agreements 
Interconnection Customers seeking a Provisional Generator 
Interconnection Agreement must submit Definitive Planning Phase II and 
Definitive Planning Phase III Milestones (M3 and M4).  If M3 and M4 
have not been calculated at the time of Interconnection Customer’s request 
for a Provisional Generator Interconnection Agreement, M3 and M4 shall 
each be initially $8,000 per MW.  The Transmission Provider shall then 
calculate the M3 and M4 as provided in Sections 7.3.1.4.1 and 7.3.2.4.1.  
If the actually calculated M3 and M4 values are higher than the M3 and 
M4 previously paid, Interconnection Customer shall pay any difference 
between the M3 and M4 previously paid and the actually calculated values 
within thirty (30) Calendar Days of those amounts being calculated by the 
Transmission Provider.  Failure to pay any difference between the 
calculated M3 and M4 and the initially paid M3 and M4 within thirty (30) 
Calendar Days shall result in automatic withdrawal of the Interconnection 
Request.  If the actually calculated M3 and M4 values are lower than the 
M3 and M4 previously paid, Transmission Provider shall refund any 
difference between the M3 and M4 previously paid and the actually 
calculated values. 
 
7.9.2 Consent to Proceed Through Definitive Planning Phase Decision 
Points 
Interconnection Customers seeking a Provisional Generator 
Interconnection Agreement automatically consent to the Transmission 
Provider moving the Interconnection Request through Definitive Planning 
Phases II and III without regard to Interconnection Customer Decision 
Point II unless notification of withdrawal is provided to the Transmission

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Provider. 
 
7.9.3 Withdrawal 
Interconnection Customers seeking a Provisional Generator 
Interconnection Agreement are eligible to receive one hundred percent 
(100%) refund of all Definitive Planning Phase milestones (M2, M3, and 
M4) only when the Interconnection Request is withdrawn prior to the start 
of Definitive Planning Phase I and unencumbered study deposits 
remaining, except as noted in Section 4.1.2.3.  Interconnection Customers 
seeking a Provisional Generator Interconnection Agreement at the time of 
Interconnection Request submission may withdraw before the end of 
Interconnection Customer Decision Point I and Transmission Provider will 
refund forty percent (40%) of the Definitive Planning Phase entry 
milestone (M2), all of the Definitive Planning Phase Milestone payments 
M3 and M4, and unencumbered study deposits remaining.  Sixty percent 
(60%) of the Definitive Planning Phase entry Milestone (M2) becomes 
non – refundable pursuant to section 7.6.2.1.1 and Section 7.8 of the GIP.  
After Interconnection Customer Decision Point I, Interconnection 
Customers seeking a Provisional Generator Interconnection Agreement 
may withdraw from the Transmission Provider’s interconnection queue at 
any time, but all Definitive Planning Phase milestones (M2, M3, and M4) 
become non-refundable pursuant to section 7.6.2.1.1 and Section 7.8, and 
will be used in accordance to Section 7.8 and Section 7.8.1.  
Interconnection Customers seeking a Provisional Generator 
Interconnection Agreement shall not be eligible for any milestone 
payment refunds provided under Section 7.6.2.4. 
 
7.9.4 Reversion to Standard Definitive Planning Phase Process 
Interconnection Customers seeking a Provisional Generator 
Interconnection Agreement may notify Transmission Provider before and

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
during Interconnection Customer Decision Point I that the Interconnection 
Customer wishes to revert to the standard Definitive Planning Phase 
process.  Transmission Provider will subsequently refund the Definitive 
Planning Phase III (M4) milestone payment.  Interconnection Customer 
must then continue to abide by all Definitive Planning Phase requirements. 
 
SECTION 8.  TRANSMISSION PROVIDER AS AN AFFECTED SYSTEM 
8.1 
Applicability. 
 
This Section 8 outlines the duties of Transmission Provider when it receives 
notification that an Affected System Interconnection Customer’s proposed 
interconnection to its host transmission provider may impact Transmission 
Provider’s Transmission System.  If applicable, any Joint Operating Agreements 
(“JOA”), Joint Planning Agreements (“JPA”) or any other agreements filed with 
the Commission will govern Transmission Provider’s Affected System procedures 
when Transmission Provider performs an Affected System Study.  The sections 
below outline general procedures in absence of any such Agreement or 
documentation. 
 
8.2  
Response to Notification. 
 
Unless otherwise agreed with an existing JOA/JPA, and other agreements filed 
with the Commission, as noted in Section 8.1, when Transmission Provider 
receives notification that an Affected System Interconnection Customer’s 
proposed interconnection to its host transmission provider may impact 
Transmission Provider’s Transmission System, Transmission Provider will 
perform a screen to determine if a study is needed.   
 
Transmission Provider shall respond in writing within twenty (20) Business Days 
whether it intends to conduct an Affected System Study.  No later than fifteen

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
(15) Business Days after Transmission Provider responds with its affirmative 
intent to conduct an Affected System Study, Transmission Provider shall share 
with the host transmission provider a non-binding, good faith estimate of the cost 
and schedule to complete the Affected System Study.  If a study is determined 
necessary, Transmission Provider and host transmission provider will enter into 
an Affected System Study Agreement in the form of Appendix 16 to this GIP.  
Terms of this agreement will include cost, schedule and interconnection request 
list scope to complete the Affected System Study. 
 
Within fifteen (15) Business Days of receipt of notification of restudy, 
Transmission Provider shall send written notification to host transmission 
provider involved in the restudy that Transmission Provider intends to delay a 
planned or in-progress Affected System Study until after completion of the 
restudy.  If Transmission Provider decides to delay the Affected System Study, it 
is not required to meet its obligations under Section 8 of this GIP until the time 
that it receives notification from the host transmission provider that the restudy is 
complete.  If Transmission Provider decides to move forward with its Affected 
System Study despite the restudy, then it must meet all requirements under 
Section 8 of this GIP. 
 
8.3  
Affected System Queue Position. 
 
Transmission Provider must assign an Affected System Queue Position to 
Affected System Interconnection Customer(s) that require(s) an Affected System 
Study. Such Affected System Queue Position shall be determined based upon the 
queue priority date outlined in Joint Operating Agreements, or other affected 
system agreement accepted by the Commission. 
 
In the event there is no such document between the Transmission Provider and the 
host transmission provider, the queue priority date will be determined by the date

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
when all milestones for the Affected System Study Agreement are met.   
 
The queue priority date of Interconnection Requests submitted to the 
Transmission Provider shall be the date of Decision Point I completion of the 
cluster. 
 
The Affected System Queue Position of the Affected System Interconnection 
Customer(s) with an earlier queue priority date shall be higher-queued than any 
interconnection requests that has a later queue priority date. 
 
Consistent with Section 8.6 of this GIP, Transmission Provider shall study the 
Affected System Interconnection Customer(s) via cluster study methodology, and 
all Affected System Interconnection Customer(s) studied in the same cluster 
under Section 8.6 shall be equally queued. For Affected System Interconnection 
Customer(s) that are equally queued, the Affected System Queue Position shall 
have no bearing on the assignment of Affected System Network Upgrades 
identified in the applicable Affected System Study. 
 
The costs of the Affected System Network Upgrades shall be allocated among the 
Affected System Interconnection Customers in accordance with Section 8.7 of 
this GIP. 
 
8.4  
Affected System Study Agreement. 
 
Unless otherwise agreed with an existing JOA/JPA, and other agreements filed 
with the Commission as noted in Section 8.1, Transmission Provider will enter 
into an Affected System Study Agreement, in the form of Appendix 16 to this 
GIP, with the host transmission provider and the host transmission provider will 
provide payment for study in the form of a deposit.  This agreement will include 
cost, schedule, and interconnection request list scope to complete the Affected

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
System Study as well as payment terms such as deposit, invoicing and any further 
applicable terms.   
 
Host transmission provider shall execute the Affected System Study Agreement, 
deliver the executed Affected System Study Agreement to Transmission Provider, 
and provide the Affected System Study deposit within ten (10) Business Days of 
receipt.   
 
If Transmission Provider notifies the host transmission provider that it will delay 
the Affected System Study pursuant to Section 8.2 of this GIP, host transmission 
provider is neither required to execute and return the previously tendered Affected 
System Study Agreement nor provide the Affected System Study deposit for the 
previously tendered Affected System Study Agreement. 
 
If host transmission provider does not provide all required technical data when it 
delivers the Affected System Study Agreement, Transmission Provider shall 
notify the deficient host transmission provider of the technical data deficiency 
within five (5) Business Days of the receipt of the executed Affected System 
Study Agreement and the deficient host transmission provider shall cure the 
technical deficiency within ten (10) Business Days of receipt of the notice: 
provided, however, that such deficiency does not include failure to deliver the 
executed Affected System Study Agreement or deposit for the Affected System 
Study Agreement.  
 
If the host transmission provider fails to cure any technical data deficiency, 
execute its Affected System Study Agreement, or provide the deposit, the host 
transmission provider shall notify Transmission Provider of the specific Affected 
System Interconnection Customer(s) that caused the deficiency.  The deficient 
Affected System Interconnection Customer(s) shall lose its Affected System 
Queue Position, and the deficient Affected System Interconnection Customer(s)

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
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shall be removed from the Affected System Study Agreement. 
 
If a host transmission provider fails to pay its undisputed costs related to the 
Affected System Study within thirty (30) Calendar Days of the invoice, host 
transmission provider shall notify Transmission Provider of the specific Affected 
System Interconnection Customer(s) that have failed to pay its undisputed costs 
related to the Affected System Study.  The identified Affected System 
Interconnection Customer(s) shall lose its Affected System Queue Position, and 
Transmission Provider shall confirm with the host transmission provider of such 
failure to pay.  
 
8.5  
Scope of the Affected System Study. 
 
The Affected System Study Agreement will include interconnection request list as 
scope, further scope information, study methodology, and study deliverable 
details for the Affected System Study as well as payment terms such as deposit, 
invoicing and any further applicable terms.  The Affected System Study shall 
evaluate the impact that any Affected System Interconnection Customer(s) 
proposed interconnection to another transmission provider’s transmission system 
will have on the reliability of Transmission Provider’s Transmission System.  The 
Affected System Study shall consider the Base Case as well as all Generating 
Facilities (and with respect to (iii) below, any identified network upgrades 
associated with such higher-queued Interconnection Request) that, on the date the 
Affected System Study is commenced: (i) are directly interconnected to 
Transmission Provider’s Transmission System; (ii) are directly interconnected to 
another transmission provider’s transmission system and may have an impact on 
Affected System Interconnection Customer’s interconnection request; (iii) have a 
pending higher-queued Interconnection Request to interconnect to Transmission 
Provider’s Transmission System; and (iv) have no queue position but have 
executed a GIA or requested that an unexecuted GIA be filed with the

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Commission.  Transmission Provider has no obligation to study impacts of 
Affected System Interconnection Customers of which it is not notified. 
 
The Affected System Study shall consist of a power flow and stability analysis, as 
well as a short circuit screen.  The Affected System Study will: state the 
assumptions upon which it is based; state the results of the analyses; and provide 
the potential impediments to Affected System Interconnection Customer’s receipt 
if the interconnection service on its host transmission provider’s transmission 
system, including a preliminary indication of the cost for Affected System 
Network Upgrades.  For purposes of determining necessary Affected System 
Network Upgrades, the Affected System Study shall consider the level of 
interconnection service requested in megawatts by Affected System 
Interconnection Customer, unless otherwise required to study the full generating 
facility capacity due to safety or reliability concerns.  The Affected System Study 
results shall include a list of facilities that are required as a result of Affected 
System Interconnection Customer’s proposed interconnection to another 
transmission provider’s transmission system, as well as a nonbinding good faith 
estimate of cost responsibility, i.e. the Affected System Network Upgrades.  The 
Affected System Study results will be provided to the host transmission provider 
in the Affected System Study Report. 
 
8.6  
Affected System Study Procedures. 
Transmission Provider shall use cluster study methodology in conducting the 
Affected System Study and shall use existing studies to the extent practicable, 
when multiple Affected System Interconnection Customers that are part of a 
single cluster may cause the need for Affected System Network Upgrades.  
Transmission Provider shall complete the Affected System Study and provide the 
Affected System Study Report to the host transmission provider with whom 
interconnection has been requested within one hundred fifty (150) Calendar Days 
after the receipt of a valid Affected System Study Agreement and deposit.

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
 
Transmission Provider shall post regular status updates regarding all ongoing 
Affected System Study.  If Transmission Provider is unable to complete the 
Affected System Study within the requisite time period, it shall notify the host 
transmission provider and shall provide an estimated completion date with an 
explanation of the reasons why additional time is required.  If Transmission 
Provider does not meet the deadlines in this section, Transmission Provider shall 
be subject to the financial penalties as described in Section 3.9 of this GIP.  Upon 
request, Transmission Provider shall provide supporting documentation including 
power flow, short circuit and stability models for the Affected System Study, 
subject to confidentiality arrangements consistent with Section 13.1 of this GIP.   
 
Transmission Provider must use Energy Resource Interconnection Service 
modeling standard used for Interconnection Requests on its own Transmission 
System for Affected System Study(ies), regardless of the level of interconnection 
service that Affected System Interconnection Customer is seeking from the host 
transmission provider with whom it seeks to interconnect. 
 
Transmission Provider shall transmit a draft Affected System Study Report to the 
host transmission provider for Affected System Interconnection Customers for a 
comment window.  Transmission Provider will address questions and comments 
submitted during the comment window regarding the report before finalizing the 
report and results.  The comment window will last for at least five (5) Business 
Days, but no more than ten (10) Business Days. 
 
8.7  
Cost Allocation for Affected System Network Upgrades. 
Transmission Provider shall allocate costs for Affected System Network 
Upgrades identified during the Affected System Study by interconnection request, 
using a pro rata impact method, consistent with Section 4.2.1 of this GIP.  
Affected System Interconnection Customers will be responsible to pay their

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
portion of the Affected System Network Upgrades identified during the Affected 
System Study. 
 
8.8  
Restudy. 
Transmission Provider shall determine the need for restudy of the Affected 
System Study as the result of withdrawals of interconnection request from host 
transmission provider, loss of Affected System Queue Position, or withdrawal of 
Transmission Provider’s higher or equally queued clusters.  If restudy of the 
Affected System Study is required, Transmission Provider shall notify the host 
transmission provider in writing within thirty (30) Calendar Days of discovery of 
the need for restudy. Such restudy shall take no longer than ninety (90) Calendar 
Days from the date of notice. Any cost of restudy shall be borne by the Affected 
System Interconnection Customer(s) being restudied through the host 
transmission provider.  Transmission Provider will issue a new version of the 
Affected System Study Report. 
 
Transmission Provider shall transmit a draft Affected System Study Report to the 
host transmission provider for Affected System Interconnection Customers for a 
comment window.  Transmission Provider will address questions and comments 
submitted during the comment window regarding the report before finalizing the 
report and results.  The comment window will last for at least five (5) Business 
Days, but no more than ten (10) Business Days. 
 
8.9  
Interconnection Facilities Study. 
In accordance with Section 7.3.3.4 of this GIP, an Interconnection Facilities Study 
will be performed by Transmission Owner on any Affected System Network 
Upgrades identified through the Affected System Study.  The host transmission 
provider will fund the Affected System Network Upgrades facilities study and the 
study scope, timing and funding will be determined by the Affected System 
Network Upgrade facilities study agreement.  The Interconnection Facilities

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Study for such Affected System Network Upgrades shall start the day after 
Transmission Provider submits to the applicable Transmission Owner(s) an 
executed statement of work and purchase order. 
 
Unless otherwise agreed and in a timely manner, Transmission Provider, 
Transmission Owner, and host transmission provider will enter into an Affected 
System Network Upgrade facilities study agreement, in the form of Appendix 17 
to this GIP, and the host transmission provider will provide payment for study in 
the form of a deposit.  This agreement will include cost, schedule, and Affected 
System Network Upgrade(s) list scope to complete the Affected System Network 
Upgrade facilities study as well as payment terms such as deposit, invoicing and 
any further applicable terms.   
 
Upon receipt from the Transmission Owner, Transmission Provider shall transmit 
to the host transmission provider a draft Affected System Network Upgrade 
facilities study report for Affected System Interconnection Customers for a 
comment window.  A draft Affected System Network Upgrade facilities study 
report may be posted by the host transmission provider for Affected System 
Interconnection Customers for a comment window.  Transmission Provider and 
Transmission Owner will address questions and comments submitted during the 
comment window regarding the report before finalizing the report and results.  
The comment window will last for at least five (5) Business Days, but no more 
than ten (10) Business Days. 
 
8.10  Tender of Facilities Construction Agreement to Affected System 
Interconnection Customer/Multi-Party Facilities Construction Agreement to 
Affected System Interconnection Customer. 
 
Transmission Provider shall tender to Affected System Interconnection 
Customer(s) a Facilities Construction Agreement/Multi-Party Facilities

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Construction Agreement, as applicable, in the form of Appendix 8 or 9 to this GIP 
within thirty (30) Calendar Days of providing the final Interconnection Facilities 
Study report.  Affected System Interconnection Customer’s failure to execute the 
Facilities Construction Agreement or Multi-Party Facilities Construction 
Agreement, as applicable, or failure to request the agreement to be filed 
unexecuted with FERC, shall result in the loss of its Affected System Queue 
Position.  Transmission Provider will drive the negotiation process with 
Transmission Owner(s) and Affected System Interconnection Customer(s) in 
accordance with the processes and timelines set forth in Section 11 of this GIP. 
 
 
SECTION 9. ENGINEERING & PROCUREMENT (“E&P”) AGREEMENT. 
 
Prior to executing an GIA, an Interconnection Customer may, in order to advance 
the implementation of its interconnection, request and Transmission Provider 
shall offer Interconnection Customer, an E&P Agreement that authorizes 
Transmission Owner to begin engineering and procurement of long lead-time 
items necessary for the establishment of the interconnection.  However, 
Transmission Provider shall not be obligated to offer an E&P Agreement if 
Interconnection Customer is in Dispute Resolution as a result of an allegation that 
Interconnection Customer has failed to meet any milestones or comply with any 
prerequisites specified in other parts of the GIP.  The E&P Agreement is an 
optional procedure and it will not alter the Interconnection Customer’s Definitive 
Planning Phase Queue Position or In-Service Date.  The E&P Agreement shall 
provide for Interconnection Customer to pay the cost of all activities authorized 
by Interconnection Customer and to make advance payments or provide other 
satisfactory security for such costs. 
 
Interconnection Customer shall pay the cost of such authorized activities and any 
cancellation costs for equipment that is already ordered for its Interconnection

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
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Request, which cannot be mitigated as hereafter described, whether or not such 
items or equipment later become unnecessary.  If Interconnection Customer 
withdraws its application for interconnection or a Party to the E&P Agreement 
terminates the E&P Agreement, to the extent the equipment ordered can be 
canceled under reasonable terms, Interconnection Customer shall be obligated to 
pay the associated cancellation costs.  To the extent that the equipment cannot be 
reasonably canceled, Transmission Owner may elect:  (i) to take title to the 
equipment, in which event Transmission Owner shall refund Interconnection 
Customer any amounts paid by Interconnection Customer for such equipment and 
shall pay the cost of delivery of such equipment, or (ii) to transfer title to and 
deliver such equipment to Interconnection Customer, in which event 
Interconnection Customer shall pay any unpaid balance and cost of delivery of 
such equipment. 
 
SECTION 10. 
OTHER INTERCONNECTION STUDIES. 
 
10.1 
Optional Interconnection Study 
10.1.1 Optional Interconnection Study Agreement. 
Optional Interconnection Studies are for informational purposes only and 
are to be completed within an agreed upon time period using Reasonable 
Efforts.  The request for an Optional Interconnection Study can be made 
on a stand-alone basis or in parallel with the processing of valid 
Interconnection Request.  The request shall describe the assumptions that 
Interconnection Customer or MHVDC Connection Customer wishes 
Transmission Provider to study within the scope described in Section 
10.1.2.  Within five (5) Business Days after receipt of a request for an 
Optional Interconnection Study, Transmission Provider shall provide to 
Interconnection Customer an Optional Interconnection Study Agreement 
in the form of Appendix 5.

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
The Optional Interconnection Study Agreement shall:  (i) specify the 
technical data that Interconnection Customer or MHVDC Connection 
Customer must provide for each phase of the Optional Interconnection 
Study, and (ii) specify Interconnection Customer’s or MHVDC 
Connection Customer’s assumptions as to which Interconnection Requests 
with earlier queue priority dates will be excluded from the Optional 
Interconnection Study case and assumptions as to the type of 
Interconnection Service for Interconnection Requests remaining in the 
Optional Interconnection Study case.  Notwithstanding the above, 
Transmission Provider shall not be required as a result of an Optional 
Interconnection Study request to conduct any additional Interconnection 
Studies with respect to any other Interconnection Request and shall 
continue processing the Interconnection Request in accordance with these 
GIP. 
 
Interconnection Customer or MHVDC Connection Customer shall execute 
the Optional Interconnection Study Agreement within ten (10) Business 
Days of receipt and deliver the Optional Interconnection Study 
Agreement, the technical data and a deposit equal to sixty thousand dollars 
($60,000.00) to Transmission Provider. 
 
10.1.2 Scope of Optional Interconnection Study. 
The Optional Interconnection Study will consist of a sensitivity analysis 
based on the assumptions specified by Interconnection Customer or 
MHVDC Connection Customer in the Optional Interconnection Study 
Agreement.  The Optional Interconnection Study will also identify the 
Transmission Owner’s Interconnection Facilities, System Protection 
Facilities, Distribution Upgrades, Generator Upgrades, Common Use 
Upgrades, and the Network Upgrades, and the estimated cost thereof, that 
may be required to provide transmission service or Interconnection

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Service based upon the results of the Optional Interconnection Study.  The 
Optional Interconnection Study shall be performed solely for 
informational purposes.  Transmission Provider shall use Reasonable 
Efforts to coordinate the study with any Affected Systems that may be 
affected by the types of Interconnection Services that are being studied.  
Transmission Provider shall utilize existing studies to the extent 
practicable in conducting the Optional Interconnection Study. 
 
10.1.3 Optional Interconnection Study Procedures.   
The executed Optional Interconnection Study Agreement, the prepayment, 
and technical and other data called for therein must be provided to 
Transmission Provider within ten (10) Business Days of Interconnection 
Customer or MHVDC Connection Customer receipt of the Optional 
Interconnection Study Agreement.  Transmission Provider shall use 
Reasonable Efforts to complete the Optional Interconnection Study within 
a mutually agreed upon time period specified within the Optional 
Interconnection Study Agreement.  If Transmission Provider is unable to 
complete the Optional Interconnection Study within such time period, it 
shall notify Interconnection Customer or MHVDC Connection Customer 
and provide an estimated completion date and an explanation of the 
reasons why additional time is required.  Any difference between the study 
payment and the actual cost of the study shall be paid to Transmission 
Provider or refunded to Interconnection Customer, as appropriate.  Upon 
request, Transmission Provider shall provide Interconnection Customer or 
MHVDC Connection Customer supporting documentation and 
workpapers and databases or data developed in the preparation of the 
Optional Interconnection Study, subject to confidentiality arrangements 
consistent with Section 13.1.   
 
10.2 
Provisional Interconnection Study

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Generator Interconnection Procedures (GIP)
ATTACHMENTS 
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10.2.1 Scope of Provisional Interconnection Study 
The Provisional Interconnection Study will consist of stability, short 
circuit, and voltage analysis to identify issues that would result if the 
Generating Facility were interconnected without project modifications or 
system modifications.  The Provisional Interconnection Study will also 
identify the Transmission Owner’s Interconnection Facilities, System 
Protection Facilities, Distribution Upgrades, Generator Upgrades, 
Common Use Upgrades, and the Network Upgrades, and the estimated 
cost thereof, that may be required to provide Energy Resource 
Interconnection Service on a provisional basis based upon the results of 
the Provisional Interconnection Study.  Transmission Provider shall use 
Reasonable Efforts to coordinate the study with any affected systems that 
may be affected by the type of Interconnection Service that is being 
studied.  Transmission Provider shall utilize existing studies to the extent 
practicable in conducting the Provisional Interconnection Study. 
 
10.2.2 Provisional Interconnection Study Procedures 
Transmission Provider must receive the information and milestones as 
described in Sections 7.9 and 7.9.1 prior to beginning the Provisional 
Interconnection Study.  Transmission Provider shall use Reasonable 
Efforts to complete the Provisional Interconnection Study within a 
mutually agreed upon time.  If Transmission Provider is unable to 
complete the Provisional Interconnection Study within such time period, it 
shall notify Interconnection Customer or MHVDC Connection Customer 
and provide an estimated completion date and an explanation of the 
reasons why additional time is required.  Actual cost of the Provisional 
Interconnection Study shall be paid by Interconnection Customer or 
MHVDC Connection Customer pursuant to Section 7.6.1.  Upon request, 
Transmission Provider shall provide Interconnection Customer or

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
MHVDC Connection Customer supporting documentation and 
workpapers and databases or data developed in the preparation of the 
Provisional Interconnection Study, subject to confidentiality arrangements 
consistent with Section 13.1. 
 
SECTION 11. GENERATOR INTERCONNECTION AGREEMENT (GIA), 
FACILITIES CONSTRUCTION AGREEMENT (FCA), AND MULTI-
PARTY FACILITIES CONSTRUCTION AGREEMENT (MPFCA). 
 
11.1 
Tender. 
Except as provided in Section 11.1.1, Transmission Provider shall tender to the 
Interconnection Customer a draft GIA and, as applicable, draft JTIQ Service 
Agreement(s), FCA(s) and/or MPFCA(s), together with draft appendices 
completed to the extent practicable, within five (5) Business Days after issuance 
of the applicable first portion of the Interconnection Facilities Study report and 
Final System Impact Study report. 
 
Throughout this Section 11, the applicable Interconnection Facilities Study for a 
GIA shall be the Interconnection Facilities Study that was initiated for that project 
in DPP Phase II.  For EGIAs, this shall be the applicable Interconnection 
Facilities Study initiated through ERAS.  Throughout this Section 11, the 
applicable Interconnection Facilities Study for a Network Upgrade that is 
addressed in a FCA or MPFCA shall be the Interconnection Facilities Study 
performed for that Network Upgrade. 
 
At the request of any Party, and except for Interconnection Requests for an ERAS 
or ZG Interconnection Request, Transmission Provider shall tender to the 
Interconnection Customer a draft GIA and, as applicable, JTIQ Service 
Agreement(s), draft FCA(s), together with draft appendices completed to the 
extent practicable, within ten (10) Calendar Days of receiving such request,

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
provided such request is received after the completion of Interconnection 
Customer Decision Point II and issuance of the draft Phase II Interconnection 
Facilities Study.  The draft GIA and, as applicable, draft FCA and the 
Transmission Provider’s JTIQ Service Agreement(s), shall be in the form of the 
Transmission Provider’s current pro forma. In the event that SPP’s JTIQ Service 
Agreement has not been provided to Interconnection Customer prior to tender of a 
draft GIA, the draft GIA shall include a milestone in Appendix B obligating 
Interconnection Customer to execute or request the unexecuted filing of SPP’s 
JTIQ Service Agreement not later than 15 Calendar Days after such agreement 
has been tendered to the Interconnection Customer. 
 
11.1.1 Common Use Upgrades and Multi-Party Facilities Construction 
Agreements. 
 
In the event that the Final System Impact Study report indicates that more than 
one Interconnection Request causes the need for Network Upgrades or System 
Protection Facilities, Transmission Provider shall determine whether such 
Network Upgrades or System Protection Facilities are Common Use Upgrades 
requiring the use of a MPFCA.  No later than ten (10) Calendar Days after 
issuance of the Final System Impact Study report and the applicable final 
Interconnection Facilities Study reports for each of the projects that are a part of 
the MPFCA, Transmission Provider shall tender the draft MPFCA to all 
Interconnection Customers that create the need and share the responsibility for the 
Common Use Upgrade.  If Transmission Provider determines that an 
Interconnection Customer should be added to an MPFCA as a party, Transmission 
Provider shall tender a draft MPFCA to the prospective Interconnection Customer 
and include the prospective Interconnection Customer in Group Studies as 
applicable. 
 
Upon the written request of all Interconnection Customers that are Party to the

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
MPFCA, Transmission Provider shall tender the MPFCA within ten (10) 
Calendar Days of receiving such written request, provided such request is 
received after issuance of: (i) the Final System Impact Study report; and (ii) the 
applicable draft Interconnection Facilities Study reports for each of the projects 
that are a part of the MPFCA.     
 
11.2 
Negotiation. 
Interconnection Customer and Transmission Owner shall return comments on the 
draft GIA, and as applicable, JTIQ Service Agreement(s), draft FCA(s) and/or 
MPFCA(s) within twenty (20) Business Days, or for Interconnection Requests in 
an ERAS five (5) Business Days, of receipt of the draft GIA, and as applicable, 
draft FCA(s) and/or MPFCA(s), along with the completion of the parts of the 
appendices for which Interconnection Customer is responsible.  Within ten (10) 
Business Days after the comments are submitted, or for Interconnection Requests 
in an ERAS or seeking ZG Interconnection Service five (5) Business Days, 
Transmission Provider shall tender a revised draft GIA, and as applicable, draft 
FCA(s) and/or MPFCA(s) to the Parties, together with draft appendices. 
 
The Parties shall begin negotiations concerning the appendices to the GIA, and, as 
applicable, FCA(s) and/or MPFCA(s) upon tender of the draft GIA, and as 
applicable, draft FCA(s) and/or MPFCA(s) to the Parties in accordance with the 
terms of Section 11.1 of this GIP. Except as provided in Section 11.2.1 of this 
GIP, Transmission Provider, Transmission Owner, and Interconnection Customer 
shall negotiate the GIA for no more than forty (40) Business Days after issuance 
of the Final System Impact Study report.  For Interconnection Requests in an 
ERAS or those seeking ZG Interconnection Service twenty (20) Business Days 
from notice to proceed in Section 3.9.4 or 3.11.3 of these GIP.  Transmission 
Provider, Transmission Owner, and Interconnection Customer shall negotiate 
draft FCA(s) and/or MPFCA(s) for no more than forty (40) Business Days after 
issuance of the applicable final Interconnection Facilities Study reports applicable

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
to the FCA(s) and/or MPFCA(s) that are subject to negotiation and the Final 
System Impact Study report.   
 
If Interconnection Customer, Transmission Owner or Transmission Provider 
determines that negotiations are at an impasse, it may request termination of the 
negotiations by providing written notice to the other parties at any time after 
tender of the draft GIA, and, as applicable, JTIQ Service Agreement(s), draft 
FCA(s) and/or MPFCA(s) pursuant to Section 11.1 and request submission of the 
unexecuted GIA, and, as applicable, JTIQ Service Agreement(s), FCA(s) and/or 
MPFCA(s) with FERC or initiate Dispute Resolution procedures pursuant to 
Section 13.5. The Interconnection Customer, Transmission Owner or 
Transmission Provider may request such termination and request for an 
unexecuted filing during the negotiation period established in this Section 11.2 
and under the negotiation period established in Section 11.2.1 of this GIP, as 
applicable. If an Interconnection Customer requests termination of its 
negotiations, but within thirty (30) Calendar Days thereafter fails to request the 
filing of the unexecuted GIA, and, as applicable, tendered JTIQ Service 
Agreement(s), FCA(s) and/or MPFCA(s), it shall be deemed to have withdrawn 
its Interconnection Request.   
 
11.2.1 Optional negotiation period adjustment for Interconnection Facilities 
Study or Affected Systems Study results. 
Except for Interconnection Requests in an ERAS, the Interconnection Customer 
may postpone the start of the negotiation period for the GIA, and as applicable, 
draft FCA(s) and/or MPFCA(s), until the later of the issuance of the applicable 
final Interconnection Facilities Study report or the issuance of the Affected 
Systems Study Report. Interconnection Customer shall make such election by 
providing written notice to the Transmission Provider prior to the posting of the 
Final System Impact Study report. If Interconnection Customer makes such 
election, Transmission Provider, Transmission Owner, and Interconnection

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Customer shall negotiate the GIA and as applicable, JTIQ Commitment 
Agreements, draft FCA(s) and/or MPFCA(s), for no more than forty (40) 
Business Days after the later of the issuance of the final applicable 
Interconnection Facilities Study or issuance of the Affected System Study Report. 
 
11.3 
Execution and Filing.   
Transmission Provider shall provide to Interconnection Customer and 
Transmission Owner a final GIA, and, as applicable, final JTIQ Service 
Agreement(s), final FCA(s) and/or final MPFCA(s) prepared for execution by the 
parties within fifteen (15) Business Days after the completion of the forty (40) 
Business Day negotiation period in accordance with Section 11.2 of this GIP.  For 
Interconnection Requests for an ERAS or ZG Interconnection Service, the 
Transmission Provider shall provide to Interconnection Customer and 
Transmission Owner a final EGIA or ZGIA within ten (10) Business Days after 
the completion of the negotiation period in accordance with Section 11.2 of this 
GIP.  Within forty-five (45) Calendar Days of tender of the final GIA or ZGIA, 
and, as applicable, final JTIQ Service Agreement(s), final FCA(s) and final 
MPFCA(s), Interconnection Customer and Transmission Owner shall either: (i) 
execute the tendered GIA or ZGIA, and, as applicable, final JTIQ Service 
Agreement(s), FCA(s) and/or MPFCA(s); or (ii) request in writing that 
Transmission Provider file with FERC the GIA or ZGIA, and, as applicable, JTIQ 
Service Agreement(s), FCA(s) and/or MPFCA(s) in unexecuted form.   
 
If Interconnection Customer has neither executed the GIA or ZGIA, and, as 
applicable, tendered JTIQ Service Agreement(s), FCA(s) and/or MPFCA(s), nor 
requested filing of the GIA, and, as applicable, JTIQ Service Agreement(s), 
FCA(s) and/or MPFCA(s) in unexecuted form within forty-five (45) Calendar 
Days, or for Interconnection Requests in an ERAS ten (10) Business Days  of 
tender of the final GIA, and, as applicable, JTIQ Service Agreement(s), final 
FCA(s) and final MPFCA(s), Interconnection Customer shall be deemed to have

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
withdrawn its Interconnection Request.  The Interconnection Customer’s forty-
five (45) Calendar Day deadline for execution will not reset in the event that an 
additional change is made to the GIA or ZGIA, JTIQ Service Agreement(s), FCA, 
or MPFCA after circulation for execution. 
 
Within ten (10) Business Days after receiving from the Interconnection 
Customer(s) and the Transmission Owner either the executed tendered GIA or 
ZGIA, and, as applicable, tendered  JTIQ Service Agreement(s), FCA(s) and/or 
MPFCA(s)  or the request to file an unexecuted GIA or ZGIA, and, as applicable, 
tendered JTIQ Service Agreement(s), FCA(s) and/or MPFCA(s), Transmission 
Provider shall file the GIA or ZGIA, and, as applicable, tendered JTIQ Service 
Agreement(s), FCA(s) and/or MPFCA(s) with FERC, together with its 
explanation of any matters as to which Interconnection Customer, Transmission 
Owner and Transmission Provider disagree and support for the costs that 
Transmission Owner proposes to charge to Interconnection Customer under the 
GIA or ZGIA, and, as applicable, tendered JTIQ Service Agreement(s), FCA(s) 
and/or MPFCA(s).  An unexecuted GIA or ZGIA, and, as applicable, JTIQ 
Service Agreement(s), FCA(s) and/or MPFCA(s), shall contain terms and 
conditions deemed appropriate by Transmission Provider for the Interconnection 
Request.   
 
Within one-hundred and eighty (180) Calendar Days after receipt of the final GIA 
Interconnection Customer shall provide Transmission Provider with reasonable 
evidence that one or more of the following milestones in the development of the 
Generating Facility has been achieved:  (i) the execution of a contract for the 
supply or transportation of fuel to the Generating Facility; (ii) the execution of a 
contract for the supply of cooling water to the Generating Facility; (iii) execution 
of a contract for the engineering for, procurement of major equipment for, or 
construction of, the Generating Facility; (iv) execution of a contract for the sale of 
electric energy or capacity from the Generating Facility, or a statement signed by

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
an authorized officer from or agent of Interconnection Customer attesting that 
Interconnection Customer owns the Generating Facility and it is required to serve 
load; or (v) documentation of application for all necessary state and local air, 
water, land, federal nuclear, and/or Environmental Law permits and that the 
application is proceeding per regulations.   
 
11.4 
Commencement of Interconnection Activities.   
If Interconnection Customer executes the final GIA or ZGIA, and, as applicable, 
tendered JTIQ Service Agreement(s), FCA(s) and/or MPFCA(s) Transmission 
Provider, Transmission Owner and Interconnection Customer shall perform their 
respective obligations in accordance with the terms of the GIA or ZGIA, and, as 
applicable, tendered JTIQ Service Agreement(s), FCA(s) and/or MPFCA(s), 
subject to modification by FERC.  Unless otherwise agreed by all Parties, upon 
submission of an unexecuted GIA or ZGIA, and, as applicable, unexecuted 
tendered JTIQ Service Agreement(s), unexecuted FCA(s) and/or unexecuted 
MPFCA(s), the Parties shall promptly comply with the unexecuted GIA or ZGIA, 
and, as applicable, unexecuted JTIQ Service Agreement(s), unexecuted FCA(s) 
and/or unexecuted MPFCA(s), subject to modification by FERC.  As applicable, 
compliance with the terms of such unexecuted JTIQ Service Agreement(s), 
FCA(s) and/or MPFCA(s) or execution and performance under a JTIQ Service 
Agreement(s), FCA and/or MPFCA will be a requirement under the GIA. 
 
11.5 
Special Considerations. 
The maximum permissible output of the Generating Facility in the Provisional 
Generator Interconnection Agreement will be updated on a quarterly basis, and 
determined by finding the transfer limit of energy commensurate with the analysis 
for Energy Resource Interconnection Service.  This study shall be performed 
assuming the system topology represented by the base cases used to calculate 
Available Flowgate Capability as described in Attachment C of this Tariff with 
dispatch and optimization algorithms posted on the MISO internet site.  Limits

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ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
will be posted on the Transmission Provider’s OASIS site, and operation above 
those limits will be deemed as unauthorized use of the transmission system and 
subject to provisions in this Tariff surrounding that use.  Interconnection 
Customer assumes all risks and liabilities with respect to changes, which may 
impact the Generator Interconnection Agreement including, but not limited to, 
change in output limits and future Network Upgrade cost responsibilities. 
 
11.6 
Quarterly Operating Limit Studies. 
Interconnection Customers subject to Quarterly Operating Limits shall be 
responsible for the cost of performing the required quarterly studies. 
Interconnection Customers shall submit a Quarterly Operating Limit study deposit 
in the amount of $10,000 sixty (60) Calendar Days prior to the start of the first 
applicable binding quarter.  Any difference between the study deposit and the 
actual cost of the applicable Quarterly Operating Limit studies shall be paid by, or 
refunded to, the Interconnection Customer.  MISO will refund any difference the 
quarter following the Interconnection Customer no longer being subject to 
Quarterly Operating Limits. 
 
SECTION 12. CONSTRUCTION OF TRANSMISSION OWNER’S OR AFFECTED 
SYSTEM TRANSMISSION OWNER’S INTERCONNECTION 
FACILITIES, SYSTEM PROTECTION FACILITIES, DISTRIBUTION 
UPGRADES AND NETWORK UPGRADES. 
 
12.1 
Schedule. 
Transmission Owner, Interconnection Customer, and, as applicable, 
Interconnection Customers in an MPFCA and a Transmission Owner that is an 
Affected System and, at its election, Transmission Provider shall negotiate in 
good faith concerning a schedule for the construction of the Transmission 
Owner’s Interconnection Facilities, System Protection Facilities, Distribution 
Upgrades, Network Upgrades, Common Use Upgrades, and the Stand-Alone

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Network Upgrades, excluding JTIQ Upgrades.  Interconnection Customer and 
Transmission Owner shall each provide the other Parties its detailed construction 
schedule. 
 
12.2 
Construction Sequencing. 
 
12.2.1 
General 
In general, the In-Service Date of an Interconnection Customer seeking 
interconnection to the Transmission System will determine the sequence 
of construction of Transmission Owner’s Interconnection Facilities, 
System Protection Facilities, Distribution Upgrades, if any, and Network 
Upgrades, including any Common Use Upgrades.  If the time required to 
build the facilities described in the GIA, and, as applicable, FCA(s) 
and/or MPFCA(s), excluding JTIQ Upgrades, is greater than the time 
between execution of the GIA, and, as applicable, FCA(s) and/or 
MPFCA(s) and the requested In-Service Date, the In-Service Date will 
be adjusted through the milestones delineated in the GIA, and as 
applicable, FCA(s) and/or MPFCA(s) appendices prior to the execution 
of the Generator Interconnection Agreement.  
 
12.2.2 
Advance Construction of Network Upgrades, System Protection 
Facilities, Distribution Upgrades or Generator Upgrades that are an 
Obligation of an Entity other than Interconnection Customer 
An Interconnection Customer with a GIA, and, as applicable, FCA(s) 
and/or MPFCA(s), in order to maintain its In-Service Date, may request 
that Transmission Owner advance to the extent necessary the completion 
of Network Upgrades, System Protection Facilities or Distribution 
Upgrades that:  (i) were assumed in the Interconnection Studies for such 
Interconnection Customer, (ii) are necessary to support such In-Service 
Date, and (iii) would otherwise not be completed, pursuant to a

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
contractual obligation of an entity other than Interconnection Customer 
that is seeking interconnection to the Transmission System, in time to 
support such In-Service Date.  Upon such request, Transmission Owner 
will use Reasonable Efforts to advance the construction of such Network 
Upgrades, System Protection Facilities or Distribution Upgrades, to the 
extent it is obligated for any such construction, to accommodate such 
request; provided that Interconnection Customer commits to pay 
Transmission Owner:  (i) any associated expediting costs and (ii) the 
cost of such Network Upgrades, System Protection Facilities or 
Distribution Upgrades.  Transmission Owner will refund to 
Interconnection Customer both the expediting costs and the cost of 
Network Upgrades, in accordance with Article 11.4 of the GIA, and, as 
applicable, FCA(s) and/or MPFCA(s).  Consequently, the entity with a 
contractual obligation to construct such Network Upgrades shall be 
obligated to pay only that portion of the costs of the Network Upgrades 
that Transmission Owner has not refunded to Interconnection Customer.  
Payment by that entity shall be due on the date that it would have been 
due had there been no request for advance construction.  Transmission 
Owner shall forward to Interconnection Customer (with copy to 
Transmission Provider) the amount paid by the entity with a contractual 
obligation to construct the Network Upgrades as payment in full for the 
outstanding balance owed to Interconnection Customer.  Transmission 
Owner then shall refund to that entity the amount that it paid for the 
Network Upgrades, in accordance with Article 11.4 of the GIA, and, as 
applicable, FCA(s) and/or MPFCA(s). 
 
12.2.3 
Advancing Construction of Network Upgrades that are Part of an 
Expansion Plan of Transmission Provider 
An Interconnection Customer with a GIA, and, as applicable, FCA(s) 
and/or MPFCA(s), in order to maintain its In-Service Date, may request

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
that Transmission Owner advance to the extent necessary the completion 
of Network Upgrades, System Protection Facilities or Distribution 
Upgrades that:  (i) are necessary to support such In-Service Date, 
including those listed as a contingent element in the Interconnection 
Customer’s GIA, and, as applicable, FCA(s) and/or MPFCA(s); and (ii) 
would otherwise not be completed, pursuant to an expansion plan of 
Transmission Provider, in time to support such In-Service Date.  Upon 
such request, Transmission Owner will use Reasonable Efforts to 
advance the construction of such Network Upgrades, System Protection 
Facilities or Distribution Upgrades to accommodate such request; 
provided that Interconnection Customer commits to pay Transmission 
Owner any associated expediting costs.  Interconnection Customer shall 
be entitled to transmission credits, if any per Attachment FF, for any 
expediting costs paid associated with the Network Upgrades. 
 
12.2.4 
Amended Interconnection System Impact and/or Interconnection 
Facilities Study 
The Interconnection System Impact Study resulting from the Definitive 
Planning Phase and/or Interconnection Facilities Study(ies) will be 
amended to determine the facilities necessary to support the requested 
In-Service Date.  Any amended study will follow the procedures 
provided in the GIP, as applicable, regarding such study and study cost, 
and include those transmission and Generating Facilities that are 
expected to be in service on or before the requested In-Service Date. 
 
SECTION 13.  MISCELLANEOUS. 
 
13.1 
Confidentiality. 
Confidential Information shall include, without limitation, all information relating 
to a Party’s technology, research and development, business affairs, and pricing,

MISO 
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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
and any information supplied by any Party to another Party prior to the execution 
of a GIA or ZGIA, and, as applicable, FCA(s) and/or MPFCA(s). 
 
Information is Confidential Information only if it is clearly designated or marked 
in writing as confidential on the face of the document, or, if the information is 
conveyed orally or by inspection, if the Party providing the information orally 
informs the Party receiving the information that the information is confidential. 
 
If requested by the receiving Party, the disclosing Party shall provide in writing, 
the basis for asserting that the information referred to in this Section warrants 
confidential treatment, and the requesting Party may disclose such writing to the 
appropriate Governmental Authority.  Each Party shall be responsible for the 
costs associated with affording confidential treatment to its information. 
 
13.1.1 Scope 
Confidential Information shall not include information that the receiving 
Party can demonstrate: (1) is generally available to the public other than as 
a result of a disclosure by the receiving Party; (2) was in the lawful 
possession of the receiving Party on a non-confidential basis before 
receiving it from the disclosing Party; (3) was supplied to the receiving 
Party without restriction by a non-Party, who, to the knowledge of the 
receiving Party after due inquiry, was under no obligation to the disclosing 
Party to keep such information confidential; (4) was independently 
developed by the receiving Party without reference to Confidential 
Information of the disclosing Party; (5) is, or becomes, publicly known, 
through no wrongful act or omission of the receiving Party or Breach of 
the GIA or ZGIA, and, as applicable, FCA(s) and/or MPFCA(s); or (6) is 
required, in accordance with Section 13.1.6, Order of Disclosure, to be 
disclosed by any Governmental Authority or is otherwise required to be 
disclosed by law or subpoena, or is necessary in any legal proceeding

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
establishing rights and obligations under the GIA or ZGIA, and, as 
applicable, FCA(s) and/or MPFCA(s).  Information designated as 
Confidential Information will no longer be deemed confidential if the 
Party that designated the information as confidential notifies the receiving 
Party that it no longer is confidential. 
 
13.1.2 Release of Confidential Information 
No Party shall release or disclose Confidential Information to any other 
person, except to its Affiliates (limited by the Standards of Conduct 
requirements) employees, agents, consultants, or to non-parties who may 
be or considering providing financing to or equity participation with 
Interconnection Customer or MHVDC Connection Customer, or to 
potential purchasers or assignees of Interconnection Customer or MHVDC 
Connection Customer, on a need-to-know basis in connection with these 
procedures, unless such person has first been advised of the confidentiality 
provisions of this Section 13.1 and has agreed to comply with such 
provisions.  Notwithstanding the foregoing, a Party providing Confidential 
Information to any person shall remain primarily responsible for any 
release of Confidential Information in contravention of this Section 13.1. 
 
 
13.1.3 Rights 
Each Party retains all rights, title, and interest in the Confidential 
Information that it discloses to the receiving Party.  The disclosure by a 
Party to the receiving Party of Confidential Information shall not be 
deemed a waiver by the disclosing Party or any other person or entity of 
the right to protect the Confidential Information from public disclosure. 
 
13.1.4 No Warranties 
By providing Confidential Information, no Party makes any warranties or 
representations as to its accuracy or completeness.  In addition, by

MISO 
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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
supplying Confidential Information, no Party obligates itself to provide 
any particular information or Confidential Information to another Party 
nor to enter into any further agreements or proceed with any other 
relationship or joint venture. 
 
13.1.5 Standard of Care 
Each Party shall use at least the same standard of care to protect 
Confidential Information it receives as it uses to protect its own 
Confidential Information from unauthorized disclosure, publication or 
dissemination.  Each Party may use Confidential Information solely to 
fulfill its obligations to another Party under these procedures or its 
regulatory requirements. 
 
13.1.6 Order of Disclosure 
If a court or a Government Authority or entity with the right, power, and 
apparent authority to do so requests or requires any Party, by subpoena, 
oral deposition, interrogatories, requests for production of documents, 
administrative order, or otherwise, to disclose Confidential Information, 
that Party shall provide the disclosing Party with prompt notice of such 
request(s) or requirement(s) so that the disclosing Party may seek an 
appropriate protective order or waive compliance with the terms of the 
GIA. Notwithstanding the absence of a protective order or waiver, the 
Party may disclose such Confidential Information which, in the opinion of 
its counsel, the Party is legally compelled to disclose.  Each Party will use 
Reasonable Efforts to obtain reliable assurance that confidential treatment 
will be accorded any Confidential Information so furnished. 
 
13.1.7 Remedies 
The Parties agree that monetary damages would be inadequate to 
compensate a Party for another Party’s breach of its obligations under this

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ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Section 13.1.  Each Party accordingly agrees that the disclosing Party shall 
be entitled to equitable relief, by way of injunction or otherwise, if the 
receiving Party breaches or threatens to breach its obligations under this 
Section 13.1, which equitable relief shall be granted without bond or proof 
of damages, and the breaching Party shall not plead in defense that there 
would be an adequate remedy at law.  Such remedy shall not be deemed 
an exclusive remedy for the breach of this Section 13.1, but shall be in 
addition to all other remedies available at law or in equity.  The Parties 
further acknowledge and agree that the covenants contained herein are 
necessary for the protection of legitimate business interests and are 
reasonable in scope.  No Party, however, shall be liable for indirect, 
incidental, or consequential or punitive damages of any nature or kind 
resulting from or arising in connection with this Section 13.1. 
 
13.1.8 Disclosure to FERC, Its Staff, or a State. 
Notwithstanding anything in this Section 13.1 to the contrary, and 
pursuant to 18 C.F.R Section 1b.20, if FERC or its staff, during the course 
of an investigation or otherwise, requests information from a Party that is 
otherwise required to be maintained in confidence pursuant to these GIP, 
the Party shall provide the requested information to FERC or its staff, 
within the time provided for in the request for information.  In providing 
the information to FERC or its staff, the Party must, consistent with 18 
C.F.R. Section 388.112, request that the information be treated as 
confidential and non-public by FERC and its staff and that the information 
be withheld from public disclosure.  The Party is prohibited from notifying 
the other Parties prior to the release of the Confidential Information to the 
Commission or its staff.  The Party shall notify the other Parties to the 
GIA when it is notified by FERC or its staff that a request to release 
Confidential Information has been received by FERC, at which time any 
of the Parties may respond before such information would be made public,

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FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
pursuant to 18 C.F.R. Section 388.112.   
 
Requests from a state regulatory body conducting a confidential 
investigation shall be treated in a similar manner, consistent with 
applicable state rules and regulations. 
 
13.1.9 Subject to the exception in Section 13.1.8, any information that a 
disclosing Party claims is competitively sensitive, commercial or financial 
information (“Confidential Information”) shall not be disclosed by the 
receiving Party to any person not employed or retained by the receiving 
Party, except to the extent disclosure is (i) required by law; (ii) reasonably 
deemed by the disclosing Party to be required to be disclosed in 
connection with a dispute between or among the Parties, or the defense of 
litigation or dispute; (iii) otherwise permitted by consent of the disclosing 
Party, such consent not to be unreasonably withheld; or (iv) necessary to 
fulfill its obligations under the GIP or as the Regional Transmission 
Organization or a Local Balancing Authority operator including disclosing 
the Confidential Information to a subregional, regional or national 
reliability organization or planning group.  The Party asserting 
confidentiality shall notify the receiving Party in writing of the 
information that Party claims is confidential.  Prior to any disclosures of 
that Party’s Confidential Information under this subparagraph, or if any 
non-Party or Governmental Authority makes any request or demand for 
any of the information described in this subparagraph, the receiving Party 
agrees to promptly notify the disclosing Party in writing and agrees to 
assert confidentiality and cooperate with the disclosing Party in seeking to 
protect the Confidential Information from public disclosure by 
confidentiality agreement, protective order or other reasonable measures. 
 
13.1.10 This provision shall not apply to any information that was or is hereafter

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in the public domain (except as a result of a breach of this provision). 
 
13.1.11 At the Interconnection Customer’s or MHVDC Connection Customer’s 
election, Transmission Provider shall cause the party in lawful possession 
of Confidential Information to, destroy, in a confidential manner, or return 
the Confidential Information provided at the time of Confidential 
Information is no longer needed. 
 
13.2 
Delegation of Responsibility. 
Transmission Provider may use the services of subcontractors as it deems 
appropriate to perform its obligations under the GIP.  Transmission Provider shall 
remain primarily liable to Interconnection Customer or MHVDC Connection 
Customer for the performance of such subcontractors and compliance with its 
obligations of the GIP.  The subcontractor shall keep all information provided 
confidential and shall use such information solely for the performance of such 
obligation for which it was provided and for no other purpose. 
 
13.3 
Obligation for Study Costs. 
Transmission Provider shall charge and Interconnection Customer or MHVDC 
Connection Customer shall pay the actual costs of the Interconnection Studies.  
Any difference between the study deposit and the actual cost of the applicable 
Interconnection Study shall be paid by or refunded, except as otherwise provided 
herein, to Interconnection Customer or MHVDC Connection Customer or offset 
against the cost of any future Interconnection Studies associated with the 
applicable Interconnection Request prior to beginning of any such future 
Interconnection Studies.  Any invoices for Interconnection Studies shall include a 
detailed and itemized accounting of the cost of each Interconnection Study.  
Interconnection Customer or MHVDC Connection Customer shall pay any such 
undisputed costs within thirty (30) Calendar Days of receipt of an invoice.  
Transmission Provider shall not be obligated to perform or continue to perform

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any studies unless Interconnection Customer or MHVDC Connection Customer 
has paid all undisputed amounts in compliance herewith.   
 
In the event Interconnection Customer’s or MHVDC Connection Customer’s 
project is withdrawn, terminated or suspended, Transmission Provider shall not be 
required to refund any unused portion of the study deposit paid to enter the 
Definitive Planning Phase that is necessary to account for study costs associated 
with the project or restudy costs associated with any affected lower-queued 
projects, any other project with which Interconnection Customer’s or MHVDC 
Connection Customer’s project shares responsibility for funding a Common Use 
Upgrade, or, in the event the project is included in a Group Study, any other 
affected projects in the Group Study.  Unused study deposits from the Definitive 
Planning Phase that are not otherwise required due to the withdrawals, 
termination or suspension of the project will be refunded upon Commercial 
Operation. 
 
13.4 
Non-Parties Conducting Studies. 
If (i) at the time of the signing of an Interconnection Study Agreement there is 
disagreement as to the estimated time to complete an Interconnection Study, (ii) 
Interconnection Customer or MHVDC Connection Customer receives notice 
pursuant to the GIP that Transmission Provider will not complete an 
Interconnection Study within the applicable timeframe for such Interconnection 
Study, or (iii) Interconnection Customer or MHVDC Connection Customer 
receives neither the Interconnection Study nor a notice under the GIP within the 
applicable timeframe for such Interconnection Study, then Interconnection 
Customer or MHVDC Connection Customer may require Transmission Provider 
or its agent to utilize a consultant reasonably acceptable to Interconnection 
Customer or MHVDC Connection Customer and Transmission Provider to 
perform such Interconnection Study under the direction of Transmission Provider.  
At other times, Transmission Provider may also utilize a consultant to perform

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such Interconnection Study, either in response to a general request of 
Interconnection Customer or MHVDC Connection Customer, or on its own 
volition. 
 
In all cases, use of a consultant shall be in accord with Article 26 of the GIA or 
ZGIA (subcontractors), and, as applicable, FCA(s) and/or MPFCA(s) and limited 
to situations where Transmission Provider determines that doing so will help 
maintain or accelerate the study process for the Interconnection Customer’s or 
MHVDC Connection Customer’s pending Interconnection Request and not 
interfere with the Transmission Provider’s progress on Interconnection Studies for 
other pending Interconnection Requests.  In cases where Interconnection 
Customer or MHVDC Connection Customer requests use of a consultant to 
perform such Interconnection Study, Interconnection Customer or MHVDC 
Connection Customer and Transmission Provider shall negotiate all of the 
pertinent terms and conditions, including reimbursement arrangements and the 
estimated study completion date and study review deadline.  Transmission 
Provider shall convey all workpapers, data bases, study results and all other 
supporting documentation prepared to date with respect to the Interconnection 
Request as soon as soon as practicable upon Interconnection Customer’s or 
MHVDC Connection Customer’s request subject to the confidentiality provision 
in Section 13.1.  In any case, such consultant contract may be entered into with 
either Interconnection Customer or MHVDC Connection Customer or 
Transmission Provider at the Transmission Provider’s discretion.  In the case of 
(iii), Interconnection Customer or MHVDC Connection Customer maintains its 
right to submit a claim to Dispute Resolution to recover the costs of such 
consultant study.  Such consultant shall be required to comply with the GIP, 
Article 26 of the GIA (subcontractors), and, as applicable, FCA(s) and/or 
MPFCA(s), and the relevant Tariff procedures and protocols as would apply if 
Transmission Provider were to conduct the Interconnection Study and shall use 
the information provided to it solely for purposes of performing such services and

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for no other purposes.  Transmission Provider shall cooperate with such 
consultant and Interconnection Customer or MHVDC Connection Customer to 
complete and issue the Interconnection Study in the shortest reasonable time. 
 
13.5 
Disputes. 
 
13.5.1 Submission. 
In the event any Party has a dispute, or asserts a claim, that arises out of or 
in connection with the GIA or ZGIA, or, as applicable, FCA(s) and/or 
MPFCA(s), the GIP, or their performance, such Party (the “disputing 
Party”) shall provide the other Parties with written notice of the dispute or 
claim (“Notice of Dispute”).  Such dispute or claim shall be referred to a 
designated senior representative of each Party for resolution on an 
informal basis as promptly as practicable after receipt of the Notice of 
Dispute by the other Parties.  In the event the designated representatives 
are unable to resolve the claim or dispute through unassisted or assisted 
negotiations within thirty (30) Calendar Days of the other non-disputing 
Parties’ receipt of the Notice of Dispute, such claim or dispute shall be 
submitted in accordance with the dispute resolution procedures of the 
Tariff.  In the event the designated representatives are able to resolve the 
claim or dispute within the above-described thirty (30) Calendar Day 
period, the disputing Party shall submit a written explanation of the 
resolution to the non-disputing Parties and shall obtain the written 
acknowledgement and acceptance from each non-disputing Party. 
 
Disputes received after the GIA or ZGIA, or, as applicable, FCA(s) and/or 
MPFCA(s) has been tendered for execution pursuant to section 11.1 of this 
GIP will not affect any applicable deadline pursuant to Section 11.2 of this 
GIP.

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Generator Interconnection Procedures (GIP)
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13.5.2  Non-binding Dispute Resolution 
 
If a Party has submitted a Notice of Dispute pursuant to section 13.5.1, 
and the Parties are unable to resolve the claim or dispute through 
unassisted or assisted negotiations within the thirty (30) Calendar Days 
provided in that section, and the Parties cannot reach mutual agreement to 
pursue binding dispute resolution, a Party may request that Transmission 
Provider engage in non-binding dispute resolution pursuant to this section 
by providing written notice to the Transmission Provider and other Party 
(“Request for Non-binding Dispute Resolution”).  Such request shall not 
require the agreement of any other Party to proceed.  The process set forth 
in this section shall serve as an alternative to, and not a replacement of, 
any other dispute resolution procedures contained within Attachment HH 
or otherwise authorized by the Tariff.  Within 30 days of receipt of a 
Request for Non-binding Dispute Resolution pursuant to this Section, the 
Transmission Provider shall appoint a neutral decision-maker that is an 
independent subcontractor that shall not have any current or past 
substantial business or financial relationships with either Party. Unless 
otherwise agreed by the Parties, the decision-maker shall render a decision 
within sixty (60) Calendar Days of appointment and shall notify the 
Parties in writing of such decision and reasons therefore.  Such decision-
maker shall be authorized only to interpret and apply the provisions of the 
GIP, GIA or ZGIA, and as applicable, FCA(s) and/or MPFCA(s), and 
shall have no power to modify or change any provision of the GIP, GIA, 
ZGIA FCA(s) or MPFCA(s) in any manner.  The result reached in this 
process is not binding, but, unless otherwise agreed, the Parties may cite 
the record and decision in this Nonbinding Dispute Resolution Process in 
future dispute resolution processes under the Tariff, including in 
arbitration, or in a Federal Power Act section 206 complaint.  Each Party 
shall be responsible for its own costs incurred during the process and the

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cost of the decision-maker shall be divided equally among each Party to 
the dispute.  Non-binding dispute resolutions conducted pursuant to this 
section shall adhere to any procedural and timing requirements set forth in 
the Generator Interconnection Business Practices Manual unless all parties 
to such dispute agree to modify such rules. 
 
13.6 
Local Furnishing Bonds. 
 
13.6.1 Transmission Owners That Own Facilities Financed by Local 
Furnishing Bonds. 
This provision is applicable only to a Transmission Owner that has 
financed facilities for the local furnishing of electric energy with tax-
exempt bonds, as described in Section 142(f) of the Internal Revenue 
Code (“local furnishing bonds”).  Notwithstanding any other provision of 
the GIP or GIA, and, as applicable, ZGIA(s), FCA(s) and/or MPFCA(s), 
Transmission Provider and Transmission Owner shall not be required to 
provide Interconnection Service to Interconnection Customer or MHVDC 
Connection Customer pursuant to this GIA or ZGIA and GIP if the 
provision of such Transmission Service would jeopardize the tax-exempt 
status of any local furnishing bond(s) used to finance Transmission 
Owner’s facilities that would be used in providing such Interconnection 
Service. 
 
13.6.2 Alternative Procedures for Requesting Interconnection Service. 
If Transmission Provider determines that the provision of Interconnection 
Service requested by Interconnection Customer or MHVDC Connection 
Customer could jeopardize the tax-exempt status of any local furnishing 
bond(s) used to finance Transmission Owner’s facilities that would be 
used in providing such Interconnection Service.  Transmission Provider 
shall notify Transmission Owner who then shall confirm the tax-exempt

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status of any local furnishing bond(s) used by Transmission Owner and 
shall advise Interconnection Customer or MHVDC Connection Customer 
and Transmission Provider within thirty (30) Calendar Days of 
Transmission Provider’s notice to Transmission Owner.  Interconnection 
Customer or MHVDC Connection Customer thereafter may renew its 
request for interconnection using the process specified in Article 5.2(ii) of 
the Transmission Provider’s Tariff.  
 
SECTION 14. 
FAST TRACK PROCESS. 
 
14.1 
Applicability. 
The Fast Track Process is available to an Interconnection Customer proposing to 
interconnect its Small Generating Facility with the Transmission System if the 
Small Generating Facility is no larger than 5 MW and if the Interconnection 
Customer’s proposed Small Generating Facility meets the codes, standards, and 
certification requirements of Appendix 3 of this GIP, or Transmission Provider has 
reviewed the design or tested the proposed Small Generating Facility and is 
satisfied that it is safe to operate. 
 
14.1.1 Capacity of the Small Generating Facility 
The Interconnection Request shall be evaluated using the maximum capacity that 
the Small Generating Facility is capable of injecting into the Transmission 
Provider’s electric system.  However, if the maximum capacity that the Small 
Generating Facility is capable of injecting into the Transmission Provider’s 
electric system is limited (e.g., through use of a control system, power relay(s), or 
other similar device settings or adjustments), then the Interconnection Customer 
must obtain the Transmission Provider’s agreement, with such agreement not to be 
unreasonably withheld, that the manner in which the Interconnection Customer 
proposes to implement such a limit will not adversely affect the safety and 
reliability of the Transmission Provider’s system.  If the Transmission Provider

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does not so agree, then the Interconnection Request must be withdrawn or revised 
to specify the maximum capacity that the Small Generating Facility is capable of 
injecting into the Transmission Provider’s electric system without such limitations.  
Furthermore, nothing in this section shall prevent a Transmission Provider from 
considering an output higher than the limited output, if appropriate, when 
evaluating system protection impacts. 
 
14.2 
Initial Review. 
Within fifteen (15) Business Days after Transmission Provider notifies 
Interconnection Customer it has received a complete Interconnection Request, 
Transmission Provider shall perform an initial review using the screens set forth 
below, shall notify Interconnection Customer of the results, and include with the 
notification copies of the analysis and data underlying the Transmission Provider’s 
determinations under the screens. 
  
14.2.1 Screens. 
 
14.2.1.1 The proposed Small Generating Facility’s Point of Interconnection 
must be on a portion of the Transmission System or Distribution 
System that is subject to the Transmission Provider’s control under 
the Tariff. 
 
14.2.1.2 For interconnection of a proposed Small Generating Facility to a 
radial distribution circuit, the aggregated generation, including the 
proposed Small Generating Facility, on the circuit shall not exceed 
fifteen percent (15%) of the line section annual peak load as most 
recently measured at the relevant substation.  A line section is that 
portion of a Transmission Provider controlled electric system 
connected to a customer bounded by automatic sectionalizing 
devices or the end of the distribution line.

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14.2.1.3 For interconnection of a proposed Small Generating Facility to the 
load side of spot network protectors, the proposed Small 
Generating Facility must use an inverter-based equipment package 
and, together with the aggregated other inverter-based generation, 
shall not exceed the smaller of five percent (5%) of a spot 
network’s maximum load or 50 kW. 
 
14.2.1.4 The proposed Small Generating Facility, in aggregation with other 
generation on the distribution circuit, shall not contribute more 
than ten percent (10%) to the distribution circuit’s maximum fault 
current at the point on the high voltage (primary) level nearest the 
proposed point of change of ownership. 
 
14.2.1.5 The proposed Small Generating Facility, in aggregate with other 
generation on the distribution circuit, shall not cause any 
distribution protective devices and equipment (including, but not 
limited to, substation breakers, fuse cutouts, and line reclosers), or 
Interconnection Customer equipment on the system to exceed 
eighty-seven and one half percent (87.5%) of the short circuit 
interrupting capability; nor shall the interconnection proposed for a 
circuit that already exceeds eighty-seven and one half (87.5%) of 
the short circuit interrupting capability. 
 
14.2.1.6 Using the table below, determine the type of interconnection to a 
primary distribution line.  This screen includes a review of the type 
of electrical service provided to the Interconnecting Customer, 
including line configuration and the transformer connection to 
limit the potential for creating over-voltages on the Transmission 
Provider’s electric power system due to a loss of ground during the

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operating time of any anti-islanding function. 
 
Primary Distribution Line 
Type 
Type of Interconnection to Primary 
Distribution Line 
Result/Criteria 
Three-phase, three wire 
3-phase or single phase, phase-to-
phase 
Pass screen 
Three-phase, four wire 
Effectively-grounded 3 phase or 
Single-phase, line-to-neutral 
Pass screen 
 
14.2.1.7 If the proposed Small Generating Facility is to be interconnected 
on single-phase shared secondary, the aggregate generation 
capacity on the shared secondary, including the proposed Small 
Generating Facility, shall not exceed 20 kW. 
 
14.2.1.8 If the proposed Small Generating Facility is single-phase and is to 
be interconnected on a center tap neutral of a 240 volt service, its 
addition shall not create an imbalance between the two sides of the 
240 volt service of more than twenty percent (20%) of the 
nameplate rating of the service transformer. 
 
14.2.1.9 The Small Generating Facility, in aggregate with other generation 
interconnected to the transmission side of a substation transformer 
feeding the circuit where the Small Generating Facility proposes to 
interconnect shall not exceed 10 MW in an area where there are 
known, or posted, transient stability limitations to generating units 
located in the general electrical vicinity (e.g., three or four 
transmission busses from the Point of Interconnection). 
 
14.2.1.10 No construction of facilities by Transmission Provider on its own 
system shall be required to accommodate the Small Generating 
Facility.

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14.2.2 If the proposed interconnection passes the screens, the Interconnection 
Request shall be approved and Transmission Provider will provide 
Interconnection Customer an executable interconnection agreement within 
five (5) Business Days after the determination. 
 
14.2.3 If the proposed interconnection fails the screens, but Transmission Provider 
determines that the Small Generating Facility may nevertheless be 
interconnected consistent with safety, reliability, and power quality 
standards, Transmission Provider shall provide Interconnection Customer 
an executable interconnection agreement within five (5) Business Days 
after the determination. 
 
14.2.4 If the proposed interconnection fails the screens, but Transmission Provider 
does not or cannot determine from the initial review that the Small 
Generating Facility may nevertheless be interconnected consistent with 
safety, reliability, and power quality standards unless Interconnection 
Customer is willing to consider minor modifications or further study, 
Transmission Provider shall provide Interconnection Customer with the 
opportunity to attend a customer options meeting. 
 
14.3 Customer Options Meeting. 
If Transmission Provider determines the Interconnection Request cannot be 
approved without (1) minor modifications at minimal cost, (2) a supplemental 
study or other additional studies or actions, or (3) incurring significant cost to 
address safety, reliability, or power quality problems, the Transmission Provider 
shall notify Interconnection Customer of that determination within five (5) 
Business Days after that determination and provide copies of all data and analyses 
underlying its conclusion.  Within ten (10) Business Days of the Transmission 
Provider’s determination, Transmission Provider shall offer to convene a customer 
options meeting with Transmission Provider to review possible Interconnection

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Customer facility modifications or the screen analysis and related results, to 
determine what further steps are needed to permit the Small Generating Facility to 
be connected safely and reliably.  At the time of notification of the Transmission 
Provider’s determination, or at the customer options meeting, Transmission 
Provider shall: 
 
14.3.1 Offer to perform facility modifications or minor modifications to the 
Transmission System (e.g., changing meters, fuses, relay settings) and 
provide a non-binding good faith estimate of the limited cost to make such 
modifications to the Transmission System.  If the Interconnection 
Customer agrees to pay for the modifications to the Transmission System, 
the Transmission Provider will provide the Interconnection Customer with 
an executable interconnection agreement within ten (10) Business Days of 
the customer options meeting; or 
 
14.3.2 Offer to perform a supplemental review in accordance with Section 14.4 
and provide a non-binding good faith estimate of the costs of such review; 
or 
 
14.3.3 Obtain the Interconnection Customer’s agreement to continue evaluating 
the Interconnection Request under the Attachment X Generator 
Interconnection Procedures. 
 
14.4 
Supplemental Review. 
 
14.4.1 To accept the offer of a supplemental review, Interconnection Customer 
shall agree in writing and submit a deposit for the estimated costs of the 
supplemental review in the amount of the Transmission Provider’s good 
faith estimate of the costs of such review, both within 15 Business Days of 
the offer.  If the written agreement and deposit have not been received by

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the Transmission Provider within that timeframe, the Interconnection 
Request shall continue to be evaluated under the Attachment X Generator 
Interconnection Procedures unless it is withdrawn by the Interconnection 
Customer. 
 
14.4.2 The Interconnection Customer may specify the order in which the 
Transmission Provider will complete the screens in section 14.4.4. 
 
14.4.3 The Interconnection Customer shall be responsible for the Transmission 
Provider’s actual costs for conducting the supplemental review.  The 
Interconnection Customer must pay any review costs that exceed the 
deposit within 20 Business Days of receipt of the invoice or resolution of 
any dispute.  If the deposit exceeds the invoiced costs, the Transmission 
Provider will return such excess within 20 Business Days of the invoice 
without interest. 
 
14.4.4 Within thirty (30) Business Days following receipt of the deposit for a 
supplemental review, the Transmission Provider shall (1) perform a 
supplemental review using the screens set forth below; (2) notify in 
writing the Interconnection Customer of the results; and (3) include with 
the notification copies of the analysis and data underlying the 
Transmission Provider’s determinations under the screens.  Unless the 
Interconnection Customer provided instructions for how to respond to the 
failure of any of the supplemental review screens below at the time the 
Interconnection Customer accepted the offer of supplemental review, the 
Transmission Provider shall notify the Interconnection Customer 
following the failure of any of the screens, or if it is unable to perform the 
screen in section 14.4.4.1, within two Business Days of making such 
determination to obtain the Interconnection Customer’s permission to: (1) 
continue evaluating the proposed interconnection under this section

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14.4.4; (2) terminate the supplemental review and continue evaluating the 
Small Generating Facility (the Attachment X Generator Interconnection 
Procedures); or (3) terminate the supplemental review upon withdrawal of 
the Interconnection Request by the Interconnection Customer. 
 
14.4.4.1 Minimum Load Screen:  Where 12 months of line section 
minimum load data (including onsite load but not station service 
load served by the proposed Small Generating Facility) are 
available, can be calculated, can be estimated from existing data, 
or determined from a power flow model, the aggregate 
Generating Facility capacity on the line section is less than 100% 
of the minimum load for all line sections bounded by automatic 
sectionalizing devices upstream of the proposed Small 
Generating Facility. If minimum load data is not available, or 
cannot be calculated, estimated or determined, the Transmission 
Provider shall include the reason(s) that it is unable to calculate, 
estimate or determine minimum load in its supplemental review 
results notification under section 14.4.4. 
 
14.4.4.1.1 The type of generation used by the proposed Small 
Generating Facility will be taken into account when 
calculating, estimating, or determining circuit or line 
section minimum load relevant for the application of 
screen 14.4.1.1.  Solar photovoltaic (PV) generation 
systems with no battery storage use daytime minimum 
load (i.e. 10 a.m. to 4 p.m. for fixed panel systems and 8 
a.m. to 6 p.m. for PV systems utilizing tracking 
systems), while all other generation uses absolute 
minimum load.

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14.4.4.1.2 When this screen is being applied to a Small Generating 
Facility that serves some station service load, only the 
net injection into the Transmission Provider’s electric 
system will be considered as part of the aggregate 
generation. 
 
14.4.4.1.3 Transmission Provider will not consider as part of the 
aggregate generation for purposes of this screen 
generating facility capacity known to be already 
reflected in the minimum load data. 
 
14.4.4.2 Voltage and Power Quality Screen:  In aggregate with existing 
generation on the line section: (1) the voltage regulation on the 
line section can be maintained in compliance with relevant 
requirements under all system conditions; (2) the voltage 
fluctuation is within acceptable limits as defined by Institute of 
Electrical and Electronics Engineers (IEEE) Standard 1453, or 
utility practice similar to IEEE Standard 1453; and (3) the 
harmonic levels meet IEEE Standard 519 limits. 
 
14.4.4.3 Safety and Reliability Screen:  The location of the proposed 
Small Generating Facility and the aggregate generation capacity 
on the line section do not create impacts to safety or reliability 
that cannot be adequately addressed without application of the 
Study Process.  The Transmission Provider shall give due 
consideration to the following and other factors in determining 
potential impacts to safety and reliability in applying this screen. 
 
14.4.4.3.1 Whether the line section has significant minimum 
loading levels dominated by a small number of

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Generator Interconnection Procedures (GIP)
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customers (e.g., several large commercial customers). 
 
14.4.4.3.2 Whether the loading along the line section is uniform or 
even. 
 
14.4.4.3.3 Whether the proposed Small Generating Facility is 
located in close proximity to the substation (i.e., less 
than 2.5 electrical circuit miles), and whether the line 
section from the substation to the Point of 
Interconnection is a Mainline rated for normal and 
emergency ampacity. 
 
14.4.4.3.4 Whether the proposed Small Generating Facility 
incorporates a time delay function to prevent 
reconnection of the generator to the system until system 
voltage and frequency are within normal limits for a 
prescribed time. 
 
14.4.4.3.5 Whether operational flexibility is reduced by the 
proposed Small Generating Facility, such that transfer of 
the line section(s) of the Small Generating Facility to a 
neighboring distribution circuit/substation may trigger 
overloads or voltage issues. 
 
14.4.4.3.6 Whether the proposed Small Generating Facility 
employs equipment or systems certified by a recognized 
standards organization to address technical issues such 
as, but not limited to, islanding, reverse power flow, or 
voltage quality.

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14.4.5 If the proposed interconnection passes the supplemental screens in 
sections 14.4.4.1, 14.4.4.2, and 14.4.4.3 above, the Interconnection 
Request shall be approved and the Transmission Provider will provide the 
Interconnection Customer with an executable interconnection agreement 
within the timeframes established in sections 14.4.5.1 and 14.4.5.2 below.  
If the proposed interconnection fails any of the supplemental review 
screens and the Interconnection Customer does not withdraw its 
Interconnection Request, it shall continue to be evaluated under the 
Attachment X Generator Interconnection Procedures consistent with 
section 14.4.5.3 below. 
 
14.4.5.1 If the proposed interconnection passes the supplemental screens 
in sections 14.4.1.1, 14.4.1.2, and 14.4.1.3 above and does not 
require construction of facilities by the Transmission Provider on 
its own system, the interconnection agreement shall be provided 
within ten Business Days after the notification of the 
supplemental review results.  
 
14.4.5.2 If interconnection facilities or minor modifications to the 
Transmission Provider’s system are required for the proposed 
interconnection to pass the supplemental screens in sections 
14.4.1.1, 14.4.1.2, and 14.4.1.3 above, and the Interconnection 
Customer agrees to pay for the modifications to the Transmission 
Provider’s electric system, the interconnection agreement, along 
with a non-binding good faith estimate for the interconnection 
facilities and/or minor modifications, shall be provided to the 
Interconnection Customer within 15 Business Days after 
receiving written notification of the supplemental review results.  
 
14.4.5.3 If the proposed interconnection would require more than

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
interconnection facilities or minor modifications to the 
Transmission Provider’s system to pass the supplemental screens 
in sections 14.4.1.1, 14.4.1.2, and 14.4.1.3 above, the 
Transmission Provider shall notify the Interconnection Customer, 
at the same time it notifies the Interconnection Customer with the 
supplemental review results, that the Interconnection Request 
shall be evaluated under the Attachment X Generator 
Interconnection Procedures unless the Interconnection Customer 
withdraws its Small Generating Facility. 
 
SECTION 15. 
PROVISIONS FOR CONNECTION TO HVDC FACILITIES 
SUBJECT TO SECTION 27A OF THE TARIFF. 
 
Interconnection Requests to HVDC Facilities that are subject to Section 27A of the Tariff 
shall follow the same process as detailed in Sections 2 through 13 of the GIP, except as specified 
in this Section 15. 
 
15.1 
Availability of ER Interconnection Service and NR Interconnection Service 
for HVDC Facilities subject to Section 27A of this Tariff. 
 
ER Interconnection Service and NR Interconnection Service are both available for 
HVDC Facilities subject to Section 27A of this Tariff.  In the case where 
Interconnection Customer identified a point-to-point transmission service request 
under Section 27A of this Tariff, NR Interconnection Service will qualify the 
Generating Facility to be designated as a Network Resource so long as (and to the 
extent that) HVDC Service is confirmed across the HVDC Facilities.  NR 
Interconnection Service will be limited to the confirmed megawatts in the 
transmission service request.  When applicable, the HVDC Service requirement 
will be listed in Appendix A of the GIA, and such listing will be added during the 
negotiation phase of the document, as set forth in Section 11.2 of the GIP.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
 
SECTION 16.  
PROVISIONS FOR OBTAINING INJECTION RIGHTS AND 
THEIR CONVERSION TO EXTERNAL NETWORK RESOURCE 
INTERCONNECTION SERVICE  
 
16.1 
Request for Injection Rights 
 
MHDVC Connection Customers electing to request Injection Rights on the Transmission 
System pursuant to the procedures set forth in Section 3.2.3 of Attachment GGG to the Tariff 
shall make such requests for Injection Rights by submitting to Transmission Provider a 
completed Interconnection Request in the manner specified by the Generator Interconnection 
Business Practices Manual (BPM-015).  The MHVDC Connection Customer must select 
“Injection Rights” in Appendix 1 and shall include all other relevant information required by 
Appendix 1 and its attachments.  Requests for Injection Rights shall be studied and granted by 
Transmission Provider pursuant to the terms and conditions of the GIP, including requisite 
milestones and study deposits within the prescribed schedule deadlines. 
 
Injection Rights serve as a pre-certification of the Transmission System’s capability to 
receive capacity and energy from the MHVDC Transmission Line at the requested Point of 
Connection, in the specified MW quantity, without degrading the reliability of the Transmission 
System.  Injection Rights do not convey transmission service or Interconnection Service to the 
MHVDC Connection Customer or any other entity.  Any such Injection Rights granted by 
Transmission Provider, and any increases or reductions to those Injection Rights, shall be 
documented in Appendix F to the Transmission Connection Agreement.  Requests for Injection 
Rights will be treated similar to requests for Interconnection Service from a queue priority 
perspective. 
 
16.2 
Conversion of Injection Rights to External Network Resource 
Interconnection Service

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Before an Interconnection Customer with an Existing Generating Facility that is external 
to the Transmission System may offer energy or capacity across the MHVDC Transmission Line 
into the MISO markets, the Injection Rights granted pursuant to Section 3.2.3 of Attachment 
GGG to the Tariff and this Section 16 must be converted to external Network Resource 
Interconnection Service and transferred to that Interconnection Customer.  Upon the request of 
an Interconnection Customer with an Existing Generating Facility for external Network 
Resource Interconnection Service via the MHVDC Transmission Line, Transmission Provider 
will convert the Injection Rights to external Network Resource Interconnection Service in an 
amount up to, but not greater than, the capacity of the MHVDC Transmission Line, and transfer 
that amount of external Network Resource Interconnection Service to that Interconnection 
Customer, subject to the conditions set forth below. 
 
Prior to effectuating this conversion, Transmission Provider must receive the following 
information:  
(a) from the Interconnection Customer seeking conversion: 
(i) 
a request for external Network Resource Interconnection Service pursuant to 
Appendix 1 of Attachment X, by including the requested MW quantity to be 
converted and transferred; 
(ii) 
documentation of the agreement between the Interconnection Customer and 
the MHVDC Connection Customer authorizing the conversion and transfer of 
the requested amount of Injection Rights;  
(iii) 
documentation that the Interconnection Customer has long-term firm 
transmission service from the Existing Generating Facility to the Point of 
Connection, including any transmission service agreements over the MHVDC 
Transmission Line, that complies with the requirements included in the 
Service Agreement for Network Resources Interconnection Service for an 
Existing Generating Facility as set forth in Appendix 13 of Attachment X; and 
(b) from the MHVDC Connection Customer that holds the Injection Rights being 
converted: 
(i) 
documentation of the MHVDC Connection Customer’s procedures for the

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
allocation of Injection Rights to Interconnection Customers, which shall be 
non-discriminatory and consistent with the Commission’s approval of the 
MHVDC Connection Customer’s right to charge negotiated (market based) 
rates for service on the applicable MHVDC Transmission Line. 
 
Upon receipt of the required information, Transmission Provider will convert the 
requested amount of the MHVDC Connection Customer’s Injection Rights into external 
Network Resource Interconnection Service and grant the external Network Resource 
Interconnection Service to the Interconnection Customer, subject to the Interconnection 
Customer executing the Service Agreement for external Network Resource Interconnection 
Service for an Existing Generating Facility as set forth in Appendix 13 to Attachment X.  All 
terms and conditions of such Service Agreement for external Network Resource Interconnection 
Service for an Existing Generating Facility and all the terms and conditions of Attachment X, 
including the rights to termination of Interconnection Service, shall apply to the Interconnection 
Customer’s external Network Resource Interconnection Service granted under this Article 16.  
After conversion of the Injection Rights, Transmission Provider shall document any remaining 
Injection Rights in Appendix F of the MHVDC Connection Customer’s Transmission 
Connection Agreement and shall post the Interconnection Customer’s external Network 
Resource Interconnection Service pursuant to the posting guidelines contained in Attachment X. 
 
A request by an Interconnection Customer for a conversion of Injection Rights into 
external Network Resource Interconnection Service pursuant to this Section 16.2, shall not 
require any additional studies in the Definitive Planning Phase to the extent such studies have 
been performed as part of the MHVDC Connection Customer’s request for Injection Rights.  To 
the extent the MHVDC Connection Customer made the Definitive Planning Phase Milestone 
Payments (M2, M3, and M4) required in connection with its request for Injection Rights and 
evaluation, an Interconnection Customer obtaining a conversion to external Network Resource 
Interconnection Service based on the same request for Injection Rights shall not be required to 
make any additional Milestone Payments to Transmission Provider.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
Any conversion to external Network Resource Interconnection Service under this Section 
16.2 shall occur within three (3) years from the Commercial Operation Date for the MHVDC 
Transmission Line, as set forth in Appendix C of the Transmission Connection Agreement.  
Failure to convert any amount of the Injection Rights to external Network Resource 
Interconnection Service within the time period specified above shall result in termination of 
Injection Rights with respect to such unconverted amount.  In the event any external Network 
Resource Interconnection Service obtained pursuant to this Section 16 terminates more than 
three (3) years after the Commercial Operation Date for the MHVDC Transmission Line, as set 
forth in Appendix C of the Transmission Connection Agreement, such terminated external 
Network Resource Interconnection Service may not revert back to Injection Rights.  
 
SECTION 17.  
FACILITIES SERVICE AGREEMENT. 
In the event that the Transmission Owner elects to fund the capital for the Network 
Upgrades and the Transmission Owner’s System Protection Facilities, the Interconnection 
Customer, Transmission Owner, and Transmission Provider shall enter into a Facilities Service 
Agreement to memorialize the terms of repayment for those Network Upgrades and 
Transmission Owner’s System Protection Facilities that the Transmission Owner elected to self-
fund.  The Facilities Service Agreement shall take the form of the pro forma Facilities Service 
Agreement that is included as Appendix 14 of Attachment X of the MISO Tariff.  The Facilities 
Service Agreement shall be subject to the terms and conditions of Attachment X, including the 
rights to termination of Interconnection Service.  The Interconnection Customer and/or the 
Transmission Owner may request in writing that Transmission Provider file the Facilities Service 
Agreement with FERC in unexecuted form.

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
APPENDICES TO GIP 
 
APPENDIX 1 
INTERCONNECTION REQUEST FOR A GENERATING FACILITY  
APPENDIX 2 
RESERVED 
APPENDIX 3 
CERTIFICATION CODES AND STANDARDS AND CERTIFICATION 
OF SMALL GENERATOR EQUIPMENT PACKAGES 
APPENDIX 4 
APPLICATION, PROCEDURES, AND TERMS AND CONDITIONS 
FOR INTERCONNECTING A CERTIFIED INVERTER-BASED 
SMALL GENERATING FACILITY NO LARGER THAN 10 KW (“10 
KW INVERTER PROCESS”) 
APPENDIX 5 
OPTIONAL INTERCONNECTION STUDY AGREEMENT 
APPENDIX 6 
STANDARD GENERATOR INTERCONNECTION AGREEMENT 
APPENDIX 7 
INTERCONNECTION PROCEDURES FOR A WIND GENERATING 
PLANT 
APPENDIX 8 
FACILITIES CONSTRUCTION AGREEMENT 
APPENDIX 9 
MULTI-PARTY FACILITIES CONSTRUCTION AGREEMENT 
APPENDIX 10 
INTERCONNECTION STUDY MODEL REVIEW FORM 
APPENDIX 11 
MONITORING AND CONSENT AGREEMENT 
APPENDIX 12 
ENERGY DISPLACEMENT AGREEMENT 
APPENDIX 13 
EXTERNAL NETWORK RESOURCE INTERCONNECTION 
SERVICE AGREEMENT 
APPENDIX 14 
FACILITIES SERVICE AGREEMENT 
APPENDIX 15  
RESERVED 
APPENDIX 16 
AFFECTED SYSTEM STUDY AGREEMENT 
APPENDIX 17  
AFFECTED SYSTEM NETWORK UPGRADE FACILITIES STUDY

MISO 
ATTACHMENT X
FERC Electric Tariff 
Generator Interconnection Procedures (GIP)
ATTACHMENTS 
188.0.0, 190.0.0
Effective On: October 18, 2026
AGREEMENT 
APPENDIX 18 
JTIQ COMMITMENT AGREEMENT 
APPENDIX 19 
ZG INTERCONNECTION AGREEMENT

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
APPENDIX 1 TO GIP
INTERCONNECTION REQUEST
1.
[The undersigned Interconnection Customer submits this request to interconnect its 
Generating Facility, located in ______________ County, [             State], with the Transmission 
System pursuant to the Tariff.] or;
[The undersigned MHVDC Connection Customer submits this request for Injection Rights for its 
MHVDC Transmission Line, located in ______________ County, [             State], with the 
Transmission System pursuant to a Tariff.];
2.
This Interconnection Request is for (check one):
_____
Proposed new Generating Facility
_____
Increase in the generating capacity or a Material Modification of an Existing 
Generating Facility
_____
Replacement of Existing Generating Facility with no increase in capacity
_____
Interconnection Request made in connection with a Generating Facility 
proposed for inclusion in a resource solicitation process
_____
Network Resource Interconnection Service for a Generating Facility in 
Commercial Operation or with an executed GIA
_____
Generating Facility requesting Surplus Interconnection Service
_____
Fast Track Process for Small Generating Facility
_____
Injection Rights associated with a new MHVDC Transmission Line
_____
Expedited Resource Addition Study
_____
Generating Facility requesting ZG Interconnection Service; 
3.
The type of interconnection service requested is (check one as appropriate):
_____
Energy Resource Interconnection Service only
_____
Network Resource Interconnection Service (includes Energy Resource 
Interconnection Service)
_____
Network Resource Interconnection Service only for an Existing Generating

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
Facility
_____
Network Resource Interconnection Service in connection with a resource 
solicitation process
_____
Surplus Interconnection Service
_____
External Network Resource Interconnection Service (E-NRIS) for projects 
connecting to a Distribution System or non-MISO transmission system;
_____
ZG Interconnection Service for a Generating Facility with ZG Associated 
Load;
4.
Interconnection Customer provides the following definitive information:
a.
Specific address or location (use closest street or intersection if no address is 
available) for the proposed new Generating Facility site or, in the case of an 
Existing Generating Facility, the name and specific location of the Existing 
Generating Facility (provide a site map and GPS coordinates);
Address: 
City:
State:
Zip Code:
GPS Coordinates:
N
W
b.
The following specific information related to the Interconnection Service 
Requested:
Required Information Related to Interconnection 
Request
Additional 
Information/Documentation
Installed Generating 
Facility Capacity 
(Maximum Gross 
Output)
Summer 
(MW/MVAR): 
____/____
Winter 
(MW/MVAR): 
____/____
 
Existing 
Interconnection 
ERIS: 
(MW/MVAR):
NRIS: 
(MW/MVAR): 
Provide GIA, and SIS report for 
Existing Generating Facility

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
Service, if any
____/____
____/____
New Interconnection 
Service or Increase in 
Existing 
Interconnection 
Service Requested 
(Maximum Injection 
at POI)
ERIS (New)
(MW/MVAR): 
____/____
or
ERIS (Increase)
(MW/MVAR): 
____/____
NRIS (New)
(MW/MVAR): 
____/____
or
NRIS (Increase)
(MW/MVAR): 
____/____
Requested total ERIS must be less 
than or equal to Installed 
Generating Facility Capacity.  
Requested total NRIS must be less 
than or equal to total requested 
ERIS.
Station Service Load, 
if any
Summer 
(MW/MVAR): 
____/____
Winter 
(MW/MVAR): 
____/____
 
Surplus 
Interconnection 
Service Requested 
(No increase in 
Existing 
Interconnection 
Service)
Surplus 
Interconnection 
Service
(MW/MVAR):
____/____
SIS report for existing unit and 
written statement pursuant to 
Section 6 of this Interconnection 
Request
“NRIS only”/ 
External NRIS
 NRIS Only
(MW/MVAR):
____/____
External-NRIS
(MW/MVAR):
____/____
CP Node: 
____________                             
Point of Interconnection: 
____________                                
Bus Number in Power Flow 
Models: ____________
ZG Interconnection 
Service Requested
ZG 
Interconnection 
Service
(MW/MVAR):
____/____
The amount of ZG Interconnection 
Service is limited to and shall not 
exceed the total Demand of the 
ZG Associated Load for that 
Generating Facility.
c.
A description of the equipment configuration (i.e. Number of generators/inverters 
and number of Intermediate Step-up transformers, is this phase 2 of an existing

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
project, etc.) for the entire Generating Facility:
d.
Generating Facility Commercial Operation Date______________, 
Synchronization Date______________, and required Interconnection Facilities 
In-Service Date_______________ by day, month, and year;
e. 
Name, address, telephone number, and e-mail address of the Interconnection 
Customer.  If the Interconnection Customer has designated an agent, include its 
agent’s contact person:
Interconnection Customer
Company Name:_________________________________________________
Address:_______________________________________________________
City:_________________________ State:_____________ Zip:___________
Phone:________________________Email:____________________________
Interconnection Customer’s Agent (if applicable)
Company Name:________________________________________________
Address:_______________________________________________________
City:_________________________ State:_____________ Zip:___________
Phone:________________________Email:___________________________
Agent’s contact person:
    ;
f. 
An Internal Revenue Service Form W-9 or comparable state-issued document for 
the Interconnection Customer submitting this Interconnection Request;  
g. 
As applicable, documentation proving the existence of a legally-binding 
relationship between the Interconnection Customer and any entity with a vested 
interest in this Interconnection Request (e.g., a parent company, a subsidiary, or 
financing company acting as agent for the Interconnection Customer) that the

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
Interconnection Customer reasonably anticipates may claim rights or authority 
under this Interconnection Request.  Such documentation may include but is not 
limited to the Interconnection Customer’s Articles of Organization and Operating 
Agreement describing the nature of the legally-binding relationship;
h.
Interconnection Customer’s banking information, or the banking information of 
any entity with a legally-binding relationship to the Interconnection Customer, in 
accordance with Section 4(f) of this Appendix 1, that wishes to make payments 
and receive refunds on behalf of the Interconnection Customer and in association 
with this Interconnection Request;
Bank Name:
Account Holder Name:
ABA number:
Account Number:
Company:
Tax Reporting Name:
Tax ID:
Address:
City:
State:
Zip:
Phone:
Email:
i.
Location of the proposed Point of Interconnection including the substation name 
or the name of the line to be tapped (including the voltage), the estimated distance 
from the substation endpoints of a line tap, address, and GPS coordinates (Not 
applicable to External NRIS Applications) 
POI substation name:
 or

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
POI line name: 
(endpoint 1) to
(endpoint 2)
POI Distance from endpoint 1: 
miles
POI Distance from endpoint 2: 
miles
Interconnection voltage: 
kV
Address: 
City:
State:
Zip Code:
GPS Coordinates:
N
        W
j. 
Generating Facility Data (set forth in Attachment A);
k.
 Fuel Source(s) [Check all that are applicable]:
□ Coal 
□ Nuclear 
□ Storage, specify type: _________
□ Hydro 
□ Oil
□ Wind
□ Natural Gas
□ Solar
□ Other, specify type: _________
Describe the configuration of Generating Facility utilizing more than one fuel 
source:
___________________________________________
___________________________________________;
If the proposed Generating Facility includes storage device(s), indicate whether 
the storage device(s) will be charged using energy from the Transmission System 
at any time: Yes _____ or No _____. If Yes, specify maximum MW that will be 
withdrawn from the Transmission System at any time: _____MW.  If Yes, specify 
the peak load charging case (check one):
____ Will charge in the peak load study case 
____ Will not charge in the peak load study case;

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
l.
Qualifying Facility status including an indication of state and / or federal 
qualifications that have been met (optional); 
m.
If this Interconnection Request is made in connection with a resource solicitation 
process, attach a copy of a written agreement assigning the Interconnection 
Customer’s rights under the GIP to the solicitor of the process and granting the 
solicitor the right to act as the Interconnection Customer’s agent for all purposes 
in the GIP;
n.
If this Interconnection Request is for Surplus Interconnection Service, attach a 
copy of the MISO Interconnection System Impact Study performed for the 
Existing Generating Facility when the Generating Facility was originally 
proposed for interconnection to the MISO Transmission System or, for 
Generating Facilities studied under a predecessor transmission provider’s 
interconnection process, the original system impact study performed at the time 
such Generating Facility was originally studied for interconnection to the 
transmission system.  If no such study is available, indicate this by checking the 
appropriate box below.
□
Study Attached (if this box is checked, a copy of the study must be 
included as an attachment to this Interconnection Request); or
□
No previous study is available; 
o. 
Energy Displacement Agreement (Appendix 12) and Monitoring and Consent 
Agreement (Appendix 11).  In order for a surplus Interconnection Request to 
remain valid, the Energy Displacement Agreement and Monitoring and Consent 
Agreement must be submitted prior to the conclusion of Generator 
Interconnection Agreement negotiations, pursuant to Section 11 of this GIP;
p.
Primary frequency response operating range for electric storage resources;

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
q.
If this Interconnection Request is for Generating Facility Replacement, 
Interconnection Customer must submit: 
Planned or Actual date of cessation of operation for the Existing Generating 
Facility:______________________
Expected Commercial Operation Date for the Replacement Generating 
Facility:______________________
_____ (check if applicable) Interconnection Customer requests MISO to perform 
Attachment Y equivalent study in the Reliability Assessment Study;
r.
For Interconnection Requests proposing to share Interconnection Customer 
Interconnection Facilities with another Interconnection Request or existing 
project, a consent agreement meeting the requirements of Section 3.3.1.4 of the 
GIP and the Generator Interconnection Business Practices Manual executed by all 
Interconnection Customers affiliated with projects that propose to connect, or are 
connected, to the shared Interconnection Customer Interconnection Facilities.
_____ (check if applicable) Interconnection Customer proposes either to (1) 
share Interconnection Customer Interconnection Facilities with a separate 
Interconnection Request or existing project and has attached a fully 
executed consent agreement to this Interconnection Request or; (2) share a 
single Interconnection Request with another Interconnection Customer 
using a Shared Interconnection Request.
If Interconnection Customer Interconnection Facilities will be shared, the 
MISO Project Number(s) of other Existing Generating Facilities or 
Interconnection Requests with which Interconnection Customer 
Interconnection Facilities will be shared shall be listed below.  If no 
project number is available for any of the other Generating Facilities with 
which Interconnection Customer Interconnection Facilities will be shared, 
state the name of the Interconnection Customer and describe the 
applicable Generating Facilities below.

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
s.
For Interconnection Requests seeking processing through an Expedited Resource 
Addition Study, identify the resource adequacy deficiency (i.e. the county and 
state, the associated electrical bus location(s), the Local Resource Zone, and the 
peak MW demand of the load and/or reliability need) that the Generating Facility 
claims to address, the RERRA (if applicable), and include the location of the 
Generating Facility (i.e. county and state, the associated electrical bus location(s), 
and the Local Resource Zone).
__________________________________________________________________
__________________________________________________________________
________________________________________________________________
5.
Interconnection Customer shall provide the applicable deposit amount as specified in the 
GIP;
 6.
If this Interconnection Request is submitted to request Surplus Interconnection Service, 
the undersigned Interconnection Customer shall supply a written statement from an 
officer of the Existing Generating Facility that is associated with this request for Surplus 
Interconnection Service that confirms the following:
(i.)
the amount of Surplus Interconnection Service made available by the 
Interconnection Customer of the Existing Generating Facility;
(ii.)
the type of Interconnection Service (i.e., ERIS or NRIS) made available by the 
Interconnection Customer for the Existing Generating Facility in accordance with 
the provisions in Section 3.2.3.1 of GIP (Attachment X); and
(iii.)
the circumstances under which the proposed Surplus Interconnection Service

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
would be available, including an indication of whether the proposed 
Interconnection Service would be available on a continuous basis (i.e., a certain 
number of MW of Surplus Interconnection Service would always be available for 
use by a co-located generating facility) or on a scheduled, periodic basis (i.e., a 
specified number of MW of Surplus Interconnection Service that would be 
available intermittently);
7.
Evidence of Site Control as specified in the GIP (check one)
____
Is attached to this Interconnection Request 
____
Will be provided at a later date in accordance with the GIP;
8.
This Interconnection Request shall be submitted electronically to the Transmission 
Provider in the manner specified by the Generator Interconnection Business Practices 
Manual (BPM-015).; 
9. 
By submitting the Interconnection Request, the Interconnection Customer represents that 
the Generating Facility shall, upon Commercial Operation, connect exclusively to the 
Transmission Provider’s Transmission System.  Interconnection Customer shall not 
connect or seek to connect the Generating Facility to another transmission provider’s 
transmission system except as may be expressly allowed by the Transmission Provider’ 
Tariff.;
10.
For ZG Interconnection Service, a description of the ZG Associated Load and facilities to 
connect to, along with any System Protection Facilities and/or proposed operating 
procedures to prevent injections onto the Transmission System beyond the substation 
where the Point of Interconnection is located.  This shall include the need-by date for 
such ZG Associated Load.;
11.
Primary Representative of Interconnection Customer to contact:
[To be completed by Interconnection Customer]

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
Name:
Address:_______________________________________________
City:___________________ State:___________ Zip:___________
Phone:__________________ Email:_________________________;
1112. This Interconnection Request is submitted by:
[Name of Interconnection Customer Company]
By (signature):  
Name (type or print):  
Title:  
Date:

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
Attachment A to Appendix 1
Interconnection Request
GENERATING FACILITY DATA
A. Unit Ratings
1. Total Generator Rated Output (MW)
2. Rated MVA
3. Number of Generating units (repeat items 3-11 for each type of generator)
4. Individual generator rated output (MW) 
5. Individual generator rated MVA 
6. Manufacturer 
7. Year manufactured*
8. Nominal terminal voltage (kV)
9. Minimum Short Circuit Ratio for turbine operation
10. Rated power factor 
Refer:
i.
FERC Order No. 827
https://www.ferc.gov/whats-new/comm-meet/2016/061616/E-1.pdf 
ii.
MISO TO power factor requirements
https://cdn.misoenergy.org/Reactive_Generator_Requirements108137.p
df
11. Generator Voltage Regulation range (+/-)
12. Generator Power Factor Regulation range (+/-)
13. Primary frequency response operating range for electric storage resources:
i.
Minimum state of charge:
ii.
Maximum state of charge:
14. Type (Induction, Synchronous, D.C. with Inverter)
15. Connection (Delta, Grounded WYE, Undergrounded WYE, Impedance  
Grounded)
*If available

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
A-1.  Generator Short Circuit Information*
(Provide following reactances in p.u. on the generator base)
1. X’’1—Positive sequence sub transient reactance (p.u.)
2. X2—Negative sequence reactance (p.u.)
3. X0—Zero sequence reactance (p.u)
4. Generator grounding: 
      4.a. Solidly grounded (yes/no)
      4.b. Grounded through an impedance (yes/no) 
              If yes: R_____ p.u.    X_____p.u. 
      4.c. Ungrounded
A-2.  Main Generator Step-up Up (GSU) Transformer
(Please fill out data in table below for each GSU transformer)
Number of Transformers __________
RATINGS
Self-Cooled
Maximum 
Nameplate
Capacity (kVA)
Generator Side
System Side
Tertiary
Voltage Ratio (kV)
Low Voltage
High Voltage
Tertiary Voltage
Winding 
Connections (Delta 
or Wye)
IMPEDANCE
Primary-Secondary
Primary-Tertiary
Secondary-Tertiary
Positive Z1 (on 
self-cooled kVA 
rating)
         %         X/R
         %         X/R
         %         X/R
Zero Z0 (on self-
cooled kVA rating)
         %         X/R
         %         X/R
         %         X/R
Fixed Taps 
Available
Present Tap 
Available
TAP SETTING

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
A-3.  Pad Mount Transformer
(Please fill out data in table below for each GSU transformer)
Number of Transformers __________
RATINGS
Self-Cooled
Maximum 
Nameplate
Capacity (kVA)
Generator Side
System Side
Tertiary
Voltage Ratio (kV)
Low Voltage
High Voltage
Tertiary Voltage
Winding 
Connections (Delta 
or Wye)
IMEPDANCE
Primary-Secondary
Primary-Tertiary
Secondary-Tertiary
Positive Z1 (on 
self-cooled kVA 
rating)
         %         X/R
         %         X/R
         %         X/R
Zero Z0 (on self-
cooled kVA rating)
         %         X/R
         %         X/R
         %         X/R
Fixed Taps 
Available
Present Tap 
Available
TAP SETTING

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
A-4.  Interconnection Facilities Tie Line Information
(Only list data for lines that are to be added by the generation developer)
1. Nominal Voltage (kV) 
2.
Line length (miles)
3. Line termination points
1.
2.
4. Conductor Type/Size (kcm)
5. Phase Configuration (Vertical or Horizontal)
6. Summer line ratings in amperes (MVA)
7. Positive sequence resistance (R) for entire length (in p.u.*)
8. Positive sequence reactance (X) for entire length (in p.u.*)
9. Zero sequence resistance (R0) for entire length (in p.u.*)
10. Zero sequence reactance (X0) for entire length (in p.u.*)
11.  Positive sequence line charging (B) for the entire length (in 
p.u.*)
* On 100-MVA and nominal line voltage (kV) Base
For wind/photovoltaic plants, provide System Equivalence Impedance Data. (Provide 
values for each equivalence collector circuit at all voltage levels. Equivalent collector 
system impedance does not include pad mount impedance)
1. Nominal Voltage (kV) 
2.
Summer line ratings in amperes (MVA) 
3. Positive sequence resistance (R) for entire length (in p.u.*)
4. Positive sequence reactance (X) for entire length (in p.u.*)
5. Zero sequence resistance (R0) for entire length (in p.u.*)
6. Zero sequence reactance (X0) for entire length (in p.u.*)
7. Positive sequence line charging (B) for the entire length (in p.u.*)
* On 100-MVA and nominal line voltage (kV) Base

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
A-5.  Dynamic Modeling Information
For a synchronous Generating Facility, the Interconnection Customer is to provide the 
appropriate PSS/E library model in the form of a Siemens PTI PSS/E dyr file. A detailed model 
of a generator must include:
•
Generator Model
•
Excitation System Model
o
May be omitted if unit is operated under manual excitation control
•
Turbine-Governor Model
o
May be omitted if unit doesn’t regulate frequency
•
Power System Stabilizer Model
o
May be omitted if device is not installed or not active
•
Reactive Line Drop Compensation Model
o
May be omitted if device is not installed or not active
Models submitted must be allowable under the Acceptable Models Working Group (AMWG) 
Dynamic Model List facilitated by the Eastern Interconnection Reliability Assessment Group 
(ERAG) posted at:
https://www.rfirst.org/eastern-interconnection-reliability-assessment-group/.
The models must also comply with MISO’s MOD-032 Model Data Requirements and Reporting 
Procedures posted at: https://www.misoenergy.org/planning/planning-modeling/.
For a non-synchronous Generating Facility, Interconnection Customer shall provide (1) a 
validated user-defined root mean squared (RMS) positive sequence dynamics model; (2) an 
appropriately parameterized standard library RMS positive sequence dynamics model, including 
model block diagram of the inverter control and plant control systems allowable under the 
ERAG AMWG Dynamic Model List, and compliant with MISO’s MOD-032 Model Data 
Requirements and Reporting Procedures that corresponds to Interconnection Customer’s 
Generating Facility; and (3) if applicable, a validated electromagnetic transient model if 
Transmission Provider performs an electromagnetic transient study as part of the interconnection 
study process.

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
A user-defined model is a set of programming code created by equipment manufacturers or 
developers that captures the latest features of controllers that are mainly software based and 
represents the entities’ control strategies but does not necessarily correspond to any standard 
library model.  Interconnection Customer must also demonstrate that the model is validated by 
providing evidence that the equipment behavior is consistent with the model behavior (e.g., an 
attestation from Interconnection Customer that the model accurately represents the entire 
Generating Facility; attestations from each equipment manufacturer that the user defined model 
accurately represents the component of the Generating Facility; or test data).
An Interconnection Request seeking ZG Interconnection Service shall include a detailed power 
flow model for the proposed Generating Facility that includes all ZG Associated Loads, Point(s) 
of Withdrawal and the Point of Interconnections for the Interconnection Request, as well as any 
proposed system protection facilities.
A-6. ONE-LINE & MODEL INFORMATION
The Interconnection Customer shall provide a Power Flow model describing the generator in a 
format compatible with Siemens PTI PSS/E (.sav, .raw, .idev, .py, .prj, or equivalent format as 
specified by MISO).
The Interconnection Customer is to provide the definitive one-line diagram for the POI – 
Information shall include:
•
Breaker layout, bus configuration (if available) and number of generators
•
The zero sequence impedance (if applicable)
•
The distance from the collector substation to the POI referenced in miles and the line 
impedance
•
If the POI is a line tap, distance from the tap to the endpoints of the existing line 
referenced in miles
•
Generator step up (GSU) transformer data and collector substation transformer data, 
including impedances for each phase of the transformer (if applicable)

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
•
For inverter based generators, FERC Order 827 requires
o
Location and size of any dynamic and/or static VAR compensation devises
o
Equivalent collector system impedance
Models submitted should comply with MISO’s Model Data Requirements and Reporting 
Procedures posted at: https://www.misoenergy.org/planning/planning-modeling/mod-032-01
An Interconnection Request for seeking ZG Interconnection Service shall include a one line 
diagram showing the Generating Facility and associated electrical equipment with appropriate 
rating and impedance information and all the ZG Associated Loads including all Point(s) of 
Withdrawal and the Point of Interconnection of the Generating Facility to the Transmission 
System for the Interconnection Request.

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
B.  Synchronous Generator Information
(e.g. Biomass, Coal, Diesel, Hydro, Natural Gas, Nuclear, Oil)
1.(Repeat the following for each generator model) Rated Generator 
speed (rpm)
2.Maximum Turbine MW (ºF)
3. Moment-of-Inertia, WR2 (lb.ft.2 for combined Turbine-Generator-
Exciter-Inertia Data)
4. Inertia Constant, H (kW sec/kVA for combined Turbine-Generator-
Exciter-Inertia Data)
Reactance Data (Per Unit- Rated kVA)
Direct Axis
Quadrature Axis
Synchronous-saturated
Xdv:
Xqv:
Synchronous-unsaturated
Xdi
Xqi
Transient – saturated
Xdv:
Xqv:
Transient – unsaturated
Xdi:
Xqi:
Subtransient – saturated
Xdv:
Xqv:
Subtransient – unsaturated
Xdi:
Xqi:
Negative Sequence - saturated
X2v:
Negative Sequence - usaturated
X2i:
Zero Sequence – saturated
X0v:
Zero Sequence – unsaturated
X0i:
Leakage Reactance
Xlm:
Field Time Constant Data (sec)
Open Circuit
Td0:
Tq0:
Three-Phase Short Circuit Transient
Td3:
Tq:
Line-to-Line Short Circuit Transient
Td2:
Line-to-Neutral Short Circuit Transient
Td1:
Short Circuit Subtransient
Td:
Tq:
Open Circuit Subtransient
Td0:
Tq0:
Armature Time Constant Data (sec)
Three Phase Short Circuit
Ta3
Line-to-Line Short Circuit
Ta2
Line-to-Neutral Short Circuit
Ta1
Armature Winding Resistance Data (Per Unit)
Positive
R1
Negative
R2
Zero
R0
Rotor Short Time Thermal capacity I22t
Field Current Rated kVA, Armature 
Voltage and,  PF
=______________amps
Field Current Rated kVA, Armature 
Voltage and,  0 PF
=______________amps

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
Three Phase Armature Winding 
Capacitance
=______________microfarad
Field Winding Resistance
=______________ohms ____C
Armature Winding Resistance (per Phase)
=______________ohms ____C
5.Attach generator reactive capability curves
6.Attach a plot of generator terminal voltage versus field current showing the air gap 
line, open-circuit saturation curve, and saturation curve at full load and rated power 
factor, and power quality curves specifying percent total harmonic distortion vertically 
and percent power output horizontally from 25 – 100% power output for both current 
and voltages or specify that the unit is IEEE 519 compliant.  
B-1.  Excitation System Information
(Repeat the following for each generator model)
1. Manufacturer and Type of excitation system used for the generator. 
2. Excitation System Response Ratio (ASA)
3. Full load rated exciter output voltage
4. Maximum exciter output voltage (ceiling voltage)
5. Other comments regarding excitation system
6. Attach IEEE block diagram of the excitation system and power system stabilizer 
(PSS) for computer representation in power system stability simulations and the 
corresponding excitation system and PSS constants for use in the model.
B-2. Turbine Governor Information
(Repeat the following for each generator model and complete only section that applies to 
corresponding turbine type)
a.
Turbine manufacturer
b. Maximum turbine power output (MW)
c.
Minimum turbine power output while on-
line (MW)
d. Droop setting (speed regulation)
e.
Is the governor mechanical-hydraulic or 
electro-hydraulic? 
For all turbine types
f.
Other comments about turbine governor 
system? 
a. Unit type (Steam, Gas, Combined Cycle) 
Steam, gas or 
combined cycle
b. If steam or combined-cycle, does turbine 
system have re-heat process (both high and 
low pressure turbines)?

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
c. If steam with reheat process, or if 
combined cycle, indicate low/high pressure 
turbine gas/steam (%)
a. Turbine efficiency at rated load (%)
b. Length of penstock (ft)
c. Average cross-sectional area of penstock 
(ft2)
d. Typical maximum head (vertical distance 
from the bottom of the penstock, at the 
gate, to the water level (ft)
e. Water supply (run-of-the-river or reservoir)
f. Water flow rate at typical maximum head 
(ft3/sec)
g. Average energy rate (kWh/acre-ft)
Hydro Turbines
h. Estimated yearly energy production (kWh)
B-3.  Induction Generator Information
1. Motoring Power (kW) 
2. Neutral Grounding Resistor (If Applicable)
3. I22t or K (Heating Time Constant) 
4. Rotor Resistance
5. Stator Resistance
6. Stator Reactance:
7. Rotor Reactance:
8. Magnetizing Reactance:
9. Short Circuit Reactance:
10. Exciting Current:
11. Temperature Rise:
12. Frame Size:
13. Design Letter:
14. Reactive Power Required In Vars (No Load):
15. Reactive Power Required In Vars (Full Load):

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
16. Total Rotating Inertia, H:
______ in
Per Unit on KVA 
Base
C. Non-Synchronous Generator Information
C-1.  Wind Generators Information
1. Number of generators to interconnect pursuant to 
Interconnection Request 
2. Average site elevation 
3. Field Volts
4. Field Amperes
5. Heating time constant (I22t)
6. Rotor Resistance
7. Stator Resistance
8. Rotor Reactance
9. Stator Reactance
10. Exciting Current
11. Temperature Rise
12. Total Rotating inertia (H) (Per unit on 100 MVA 
Base)
13. List of adjustable set- points for protective 
equipment or software*
14. Generator type (e.g. GE doubly fed induction 
machine with back-to-back IGBT converters, or 
Micon induction generator)
15. Generator voltage ride through capability
Min low-voltage threshold in 
percent to enable tripping ____
Max low-voltage duration in 
seconds to enable tripping ____
16. Provide voltage flicker data, if available, for the wind generator model to be installed 
specified in percent of total voltage output.  The data may be provided at 25, 50, 75, 
and 100% of output or in the form of a curve with the Y-axis showing percent of 
flicker versus total output and the X-axis showing percent load output from at least 
25% to 100% of total output.
17. Provide voltage dropout limits expressed in voltage level versus time
18. Provide frequency dropout limits expressed in frequency versus time
19. Provide reactive power capability curve
20. Provide a validated user-defined RMS positive sequence dynamic model

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
*If available
C-2.  Inverter-Based Parameters (e.g. Solar,  Storage, Type 4 Wind Turbines)
1. Number of inverters to be interconnected 
2. Inverter Manufacturer
3. Inverter Model Name
4. Inverter Model Number
5. Inverter Version Number
6. List of adjustable set points for the protective equipment or software
7. Maximum design fault contribution current
8. Harmonics Characteristics
9. Start – up requirements
*PSCAD models may be required/requested for inverter based resources as needed during 
the Generator Interconnection Process. If available please provide with application 
materials.

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
ATTACHMENT B TO APPENDIX 1 TO GIP
INTERCONNECTION STUDY AGREEMENT (GENERATING FACILITY)
THIS AGREEMENT is made and entered into this        day of             , 20     by and 
between                         , a                  organized and existing under the laws of the State of  
____________________, (“Interconnection Customer,”) and the Midcontinent Independent 
System Operator, Inc., a non-profit, non-stock corporation organized and existing under the 
laws of the State of Delaware, sometimes hereinafter referred to as the “Transmission Provider.”  
Interconnection Customer and Transmission Provider each may be referred to as a “Party,” or 
collectively as the “Parties.”  Any capitalized term used herein but not defined herein shall have 
the meaning assigned to such term in the GIP and the GIA.
RECITALS
WHEREAS, Interconnection Customer is proposing to develop a Generating Facility or 
generating capacity addition to an Existing Generating Facility consistent with the 
Interconnection Request submitted by Interconnection Customer dated                 ; and
WHEREAS, Interconnection Customer desires to interconnect the Generating Facility 
with the Transmission System; and
WHEREAS, Interconnection Customer has requested Transmission Provider to perform 
Interconnection Studies and/or Provisional Interconnection Studies to assess interconnecting the 
proposed Generating Facility to the Transmission System, and of any Affected Systems; 
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained 
herein the Parties agreed as follows:
1.0
When used in this Agreement, with initial capitalization, the terms specified shall 
have the meanings indicated in the Transmission Provider’s Commission-

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
approved GIP. 
2.0
Interconnection Customer elects and Transmission Provider shall cause to be 
performed an Interconnection Study and/or an Provisional Interconnection Study 
consistent with the GIP in accordance with the Tariff, an Interconnection System 
Impact Study consistent with  the GIP and an Interconnection Facilities Study 
consistent with the GIP, collectively referred to as the “Studies.”
3.0
The Studies shall be based on the technical information provided by 
Interconnection Customer in the Interconnection Request, as may be modified as 
the result of the Scoping Meeting, study results, or any other reason identified in 
the GIP.  Transmission Provider reserves the right to request additional technical 
information from Interconnection Customer as such information may reasonably 
become necessary consistent with Good Utility Practice during the course of the 
Studies and as designated in accordance with Section 3.3.3 of the GIP.  If, after the 
designation of the Point of Interconnection pursuant to Section 3.3 of the GIP, 
Interconnection Customer modifies its Interconnection Request pursuant to 
Section 4.4, Transmission Provider may extend the time to complete The Studies.
4.0
{Reserved}
5.0
The Interconnection System Impact Study report shall provide the following 
information:
-
identification of any equipment short circuit capability limits exceeded as 
a result of the interconnection;
-
identification of any thermal overload or voltage limit violations resulting 
from the interconnection;

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
-
identification of any instability or inadequately damped response to 
system disturbances resulting from the interconnection (including as 
necessary, transient stability, both large and small signal, sub synchronous 
stability, dynamic voltage stability, mid and long-term stability, voltage 
flicker analyses, and excessive neutral current studies in accordance with 
Good Utility Practice), and
-
preliminary description and non-binding, good faith, planning level 
estimated cost of facilities required to interconnect the Generating Facility 
to the Transmission System and to address the identified short circuit, 
instability, and power flow issues.
6.0
The Interconnection Facilities Study shall provide draft GIA appendices and 
supporting documentation, which will:  (i)  provide a description, estimated cost 
of (consistent with Attachment A), and schedule for required facilities to 
interconnect the Generating Facility to the Transmission System and (ii) address 
the short circuit, instability, and power flow issues identified in the 
Interconnection System Impact Study.
7.0
Interconnection Customer shall provide deposits in the amount and timing 
outlined in Sections 3.3 of the GIP for the performance of the Studies.
Any difference between the deposit and the actual cost of The Studies shall be 
paid by or refunded to Interconnection Customer, as appropriate under Section 
13.3 of the GIP.
8.0
Interconnection Customer may request all Base Cases and work papers associated 
with this Interconnection Request, subject to Transmission Provider provisions 
around acquiring Critical Energy Infrastructure Information.

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
9.0
Indemnity.  To the extent permitted by law, each Party shall at all times 
indemnify, defend and hold the other Parties harmless from any and all damages, 
losses, claims, including claims and actions relating to injury to or death of any 
person or damage to property, demand, suits, recoveries, costs and expenses, court 
costs, attorney fees, and all other obligations by or to third parties, arising out of 
or resulting from the other Party’s performance, or non-performance of its 
obligations under this Agreement on behalf of the indemnifying Party, except in 
cases of gross negligence or intentional wrongdoing by the indemnified Party.
10.0
Limitation of Liability.  Except with respect to the duties of defense and 
indemnity expressly provided in this Agreement, a Party shall not be liable to 
another Party or to any third party or other person for any damages arising out of 
actions under this Agreement, including, but not limited to, any act or omission 
that results in an interruption, deficiency or imperfection of Interconnection 
Service, except as provided in the Tariff.  The provisions set forth in the Tariff 
shall be additionally applicable to any Party acting in good faith to implement or 
comply with its obligations under this Agreement, regardless of whether the 
obligation is preceded by a specific directive.
11.0
Miscellaneous.  Except as otherwise provided herein, this Agreement shall 
include standard miscellaneous terms including, but not limited to, 
representations, disclaimers, warranties, governing law, amendment, execution, 
waiver, enforceability and assignment, that reflect best practices in the electric 
industry, that are consistent with regional practices, Applicable Laws and 
Regulations and the organizational nature of each Party.  All of these provisions, 
to the extent practicable, shall be consistent with the provisions of the GIP and the 
GIA.
IN WITNESS THEREOF, the Parties have caused this Agreement to be duly executed 
by their duly authorized officers or agents on the day and year first above written.

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
Midcontinent Independent 
System Operator, Inc.
By: 
Name: 
Title: 
[Insert name of Interconnection Customer]
By: 
Name: 
Title:

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
INTERCONNECTION STUDY AGREEMENT (INJECTION RIGHTS)
THIS AGREEMENT is made and entered into this        day of             , 20     by and 
between                         , a                  organized and existing under the laws of the State of  
____________________, (“MHVDC Connection Customer,”) and the Midcontinent 
Independent System Operator, Inc., a non-profit, non-stock corporation organized and existing 
under the laws of the State of Delaware, sometimes hereinafter referred to as the “Transmission 
Provider.”  MHVDC Connection and Transmission Provider each may be referred to as a 
“Party,” or collectively as the “Parties.”  Any capitalized term used herein but not defined herein 
shall have the meaning assigned to such term in the GIP and the GIA.
RECITALS
WHEREAS, MHVDC Connection Customer is proposing to develop an MHVDC  
Transmission Line or capacity addition to an existing MHVDC Transmission Line consistent 
with the Interconnection Request submitted by MHVDC Connection Customer dated                 ; 
and
WHEREAS, MHVDC Connection Customer desires to interconnect the MHVDC 
Transmission Line with the Transmission System; and
WHEREAS, MHVDC Connection Customer has requested Transmission Provider to 
perform Interconnection Studies and/or Provisional Interconnection Studies to assess 
interconnecting the proposed MHVDC Transmission Line to the Transmission System, and of 
any Affected Systems; 
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained 
herein the Parties agreed as follows:
1.0
When used in this Agreement, with initial capitalization, the terms specified shall

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
have the meanings indicated in the Transmission Provider’s Commission-
approved GIP. 
2.0
MHVDC Connection Customer elects and Transmission Provider shall cause to 
be performed an Interconnection Study and/or an Provisional Interconnection 
Study consistent with the GIP in accordance with the Tariff, an Interconnection 
System Impact Study consistent with the GIP and an Interconnection Facilities 
Study consistent with the GIP, collectively referred to as the “Studies.”
3.0
The Studies shall be based on the technical information provided by MHVDC 
Connection Customer in the Interconnection Request, as may be modified as the 
result of the Scoping Meeting, study results, or any other reason identified in the 
GIP.  Transmission Provider reserves the right to request additional technical 
information from MHVDC Connection Customer as such information may 
reasonably become necessary consistent with Good Utility Practice during the 
course of the Studies and as designated in accordance with Section 3.3.3 of the 
GIP.  If, after the designation of the Point of Interconnection pursuant to Section 
3.3 of the GIP, MHVDC Connection Customer modifies its Interconnection 
Request pursuant to Section 4.4, Transmission Provider may extend the time to 
complete The Studies.
4.0
{Reserved}
5.0
The Interconnection System Impact Study report shall provide the following 
information:
-
identification of any equipment short circuit capability limits exceeded as 
a result of the interconnection;
-
identification of any thermal overload or voltage limit violations resulting

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
from the interconnection; 
-
identification of any instability or inadequately damped response to 
system disturbances resulting from the interconnection (including as 
necessary, transient stability, both large and small signal, sub synchronous 
stability, dynamic voltage stability, mid and long-term stability, voltage 
flicker analyses, and excessive neutral current studies in accordance with 
Good Utility Practice), and
-
preliminary description and non-binding, good faith, planning level 
estimated cost of facilities required to interconnect the MHVDC 
Transmission Line to the Transmission System and to address the 
identified short circuit, instability, and power flow issues.
6.0
The Interconnection Facilities Study shall provide draft TCA appendices and 
supporting documentation, which will:  (i)  provide a description, estimated cost 
of (consistent with Attachment A), and schedule for required facilities to 
interconnect the MHVDC Transmission Line to the Transmission System and (ii) 
address the short circuit, instability, and power flow issues identified in the 
Interconnection System Impact Study.
7.0
MHVDC Connection Customer shall provide deposits in the amount and timing 
outlined in Sections 3.3 of the GIP for the performance of the Studies.
Any difference between the deposit and the actual cost of The Studies shall be 
paid by or refunded to MHVDC Connection Customer, as appropriate under 
Section 13.3 of the GIP.
8.0
MHVDC Connection Customer may request all Base Cases and work papers 
associated with this Interconnection Request, subject to Transmission Provider

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
provisions around acquiring Critical Energy Infrastructure Information.
9.0
Indemnity.  To the extent permitted by law, each Party shall at all times 
indemnify, defend and hold the other Parties harmless from any and all damages, 
losses, claims, including claims and actions relating to injury to or death of any 
person or damage to property, demand, suits, recoveries, costs and expenses, court 
costs, attorney fees, and all other obligations by or to third parties, arising out of 
or resulting from the other Party’s performance, or non-performance of its 
obligations under this Agreement on behalf of the indemnifying Party, except in 
cases of gross negligence or intentional wrongdoing by the indemnified Party.
10.0
Limitation of Liability.  Except with respect to the duties of defense and 
indemnity expressly provided in this Agreement, a Party shall not be liable to 
another Party or to any third party or other person for any damages arising out of 
actions under this Agreement, including, but not limited to, any act or omission 
that results in an interruption, deficiency or imperfection of Interconnection 
Service, except as provided in the Tariff.  The provisions set forth in the Tariff 
shall be additionally applicable to any Party acting in good faith to implement or 
comply with its obligations under this Agreement, regardless of whether the 
obligation is preceded by a specific directive.
11.0
Miscellaneous.  Except as otherwise provided herein, this Agreement shall 
include standard miscellaneous terms including, but not limited to, 
representations, disclaimers, warranties, governing law, amendment, execution, 
waiver, enforceability and assignment, that reflect best practices in the electric 
industry, that are consistent with regional practices, Applicable Laws and 
Regulations and the organizational nature of each Party.  All of these provisions, 
to the extent practicable, shall be consistent with the provisions of the GIP and the 
GIA.

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
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IN WITNESS THEREOF, the Parties have caused this Agreement to be duly executed 
by their duly authorized officers or agents on the day and year first above written.
Midcontinent Independent 
System Operator, Inc.
By: 
Name: 
Title: 
[Insert name of MHVDC Connection Customer]
By: 
Name: 
Title:

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
ATTACHMENT C TO APPENDIX 1:  UNIVERSAL NON-DISCLOSURE AND 
CONFIDENTIALITY AGREEMENT
PROJECT NO. _____
This Universal Non-Disclosure and Confidentiality Agreement (the “Agreement”) is entered into 
on this _______ day of ___________________, 20____ and effective as of the ______ day of 
_____________________, 20____ (the “Effective Date”), by and between Midcontinent 
Independent System Operator, Inc. (“MISO”) and ______________________________, 
(“Company”) whose principal offices are located at ___________________________________.  
MISO and Company each may be referred to individually as a “Party” or collectively as the 
“Parties.”  
WHEREAS, MISO is prepared to disclose confidential information under this Agreement 
to Company in connection with MISO’s business with, or possible engagement of, Company (the 
“Purpose”);
WHEREAS, Company represents that it desires to receive confidential information 
pursuant to this Agreement; and,
WHEREAS, MISO and Company desire to set forth in writing the terms and conditions of 
their agreement.
NOW THEREFORE, in consideration of the mutual promises, covenants, representations 
and agreements contained in this Agreement and other good and valuable consideration, the 
receipt and sufficiency of which are hereby acknowledged, the Parties agree as follows:
1.0
Confidential Information.  “Confidential Information” as used in this Agreement means 
all information disclosed to Company by MISO or its employees, agents, contractors, 
representatives, consultants and advisors (collectively “Disclosing Party”) in connection

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
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Effective On: October 18, 2026
with the Purpose.  Confidential Information includes, without limitation, (i) any and all 
business, technical, marketing, financial or other information, whether in electronic, oral 
or written form; (ii) trade secrets, business plans, techniques, methods, or systems, data, 
know-how, formulae, compositions, designs, sketches, mock-ups, prototypes, 
photographs, charts, graphs, forms, documents, drawings, samples, inventions, ideas, 
research and development, customer and vendor lists (including, without limitation, the 
identity, characteristics, contact persons, product and service needs thereof), rates, price 
lists, computer software programs and systems, financial statements, and budgets; (iii) all 
memoranda, summaries, notes, analyses, compilations, studies or those portions of other 
documents prepared by Company to the extent they contain or reflect such information 
of, or the contents of discussions with the Disclosing Party (“Company’s Material”), 
including the contents or existence of discussions or negotiations related to the Purpose; 
(iv) information not generally known or readily ascertainable; (v) information that 
provides a competitive advantage for Disclosing Party; and (vi) information that is 
marked “Confidential” or nonpublic information which under the circumstances 
surrounding disclosure a reasonable person would conclude should be treated as 
confidential.  Confidential Information shall not include information that (a) is or 
becomes part of the public domain other than as a result of disclosure by Company, (b) 
becomes available to Company on a non-confidential basis from a source other than 
Disclosing Party, provided that, to the best of Company’s knowledge, such source is not 
prohibited from transmitting such information by a contractual, legal, or other obligation, 
or (c) was in Company’s possession prior to disclosure of the same by Disclosing Party.
2.0
Non-Use; Protection and Dissemination of Confidential Information.  Company 
agrees not to disclose, discuss, use, reproduce, duplicate, distribute, copy, reconstruct or 
in any way communicate, directly or indirectly, the Confidential Information for purposes 
other than in connection with the Purpose.  Company shall not disclose, discuss, use, 
reproduce, duplicate, distribute or in any way communicate, directly or indirectly, the 
Confidential Information to any other party and will use all reasonable efforts to protect 
the confidentiality of such information.  Company will require that Company’s 
employees, officers, directors, agents, contractors, representatives, consultants and

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
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Effective On: October 18, 2026
advisors who need to have access to such Confidential Information in order to assist 
Company in connection with the Purpose (1) are aware of the Company’s confidentiality 
obligation hereunder, and (2) agree to be bound by such confidentiality obligations.  
Company shall notify Disclosing Party immediately of any loss, misuse, or 
misappropriation of any Confidential Information of which Company becomes aware.
3.0
Ownership and Return.  All Confidential Information, including Company’s Material, 
shall be and remain the property of Disclosing Party, and no right or license is granted to 
Company with respect to any Confidential Information.  No transfer or creation of 
ownership rights in any intellectual property comprising Confidential Information is 
intended or shall be inferred by the disclosure of Confidential Information by Disclosing 
Party, and any and all intellectual property comprising Confidential Information 
disclosed and any derivations thereof, shall continue to be the exclusive intellectual 
property of Disclosing Party.  Upon the termination by any Party of the Purpose, or 
sooner if so requested, Company agrees to immediately return all Confidential 
Information, including Company’s Material, to Disclosing Party or to destroy all 
Confidential Information, including all copies of the same, however, Company shall not 
be required to destroy Confidential Information that has become embedded in Company’s 
planning models.  Upon request, the fact of any such destruction shall be certified in 
writing to Disclosing Party by Company.  Nothing in this Agreement obligates 
Disclosing Party to disclose any information to Company or creates any agency or 
partnership relation between them.
4.0
Compliance and Protection of Confidential Information.  Company represents and 
warrants that it has practices and procedures adequate to protect against the unauthorized 
release of Confidential Information received.  Company must educate its employees, 
agents, and assigns in the provisions of this Agreement and provide to Disclosing Party 
upon request any information necessary to determine compliance with the terms of this 
Agreement.
5.0
Indemnification.  To the extent permitted by law, Company agrees to indemnify, hold 
harmless and defend MISO, its employees, principals (owners, partners, shareholders or 
holders of an ownership interest, as the case may be), agents, contractors, representatives,

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
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Effective On: October 18, 2026
consultants and/or advisors against any and all liability, loss, costs, damages, expenses, 
claims or actions, joint or several, arising out of or by reason of any breach of this 
Agreement by Company and/or Company’s employees, agents, contractors, 
representatives or consultants, or arising out of or by reason of any act or omission of 
Company and/or Company’s employees, agents, contractors, representatives or 
consultants in the execution, performance, or failure to adequately perform their 
obligations under this Agreement.  For purposes of this Section, to “indemnify” means to 
defend and pay all expenses (including reasonable attorneys’ fees) and satisfy all 
judgments (including costs and reasonable attorneys’ fees) which may be incurred or 
rendered against MISO, its employees, principals (owners, partners, shareholders or 
holders of an ownership interest, as the case may be), agents, contractors, representatives, 
consultants and/or advisors.
6.0
Compelled Disclosure.  If Company is requested or required by legal or administrative 
process to disclose any Confidential Information, Company shall promptly notify 
Disclosing Party of such request or requirement so that Disclosing Party may seek an 
appropriate protective order or other relief.  In any case, Company will (a) disclose only 
that portion of the Confidential Information that its legal counsel advises is required to 
be disclosed, (b) use its reasonable efforts to ensure that such Confidential Information is 
treated confidentially, including seeking an appropriate protective order, and (c) notify 
Disclosing Party as soon as reasonably practicable of the items of Confidential 
Information so disclosed.
7.0
Remedies.  The Parties acknowledge that remedies at law may be inadequate to protect 
Disclosing Party against any actual or threatened breach of this Agreement by Company, 
and, without prejudice to any other rights and remedies otherwise available to Disclosing 
Party, agree to the immediate granting of preliminary and final injunctive relief (without 
prior notice and without posting any bond) in favor of Disclosing Party to enjoin and 
restrain any breach or violation, either actual or anticipatory, of this Agreement.
8.0
Purpose.  None of the Parties will be under any legal obligation of any kind whatsoever 
with respect to the Purpose by virtue of this Agreement, except for the matters 
specifically agreed to herein.  No representation or warranty is made by the Disclosing

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
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Effective On: October 18, 2026
Party as to the accuracy or completeness of any information provided to the Company.  
9.0
Term and Termination.  Company’s obligations under this Agreement shall be effective 
on the date set forth above and shall be perpetual, notwithstanding any expiration, 
cancellation or termination of this Agreement.  Upon termination of the Agreement, 
Company shall either promptly (1) deliver or cause to be delivered to Disclosing Party or 
(2) certify to the Disclosing Party the destruction of, all Confidential Information, 
including all copies of the Confidential Information in Company’s possession or control 
including, without limitation, originals and copies of documents, customer lists, prospect 
lists, price lists, operations manuals, and all other documents reflecting or referencing the 
Confidential Information, as well as all other materials furnished to or acquired by 
Company to facilitate the Purpose of the Agreement.
10.0
Agency.  This Agreement is binding on Company, its employees, agents, contractors, 
representatives, consultants, advisors, successors and assigns.  In the event of a dispute 
regarding liability for breach of this Agreement, common law agency principles apply.
11.0
Waiver.  No waiver of any of the provisions of this Agreement will be deemed or will 
constitute a waiver of any other provision, whether or not similar, nor will any waiver 
constitute a continuing waiver.  No waiver will be binding unless executed in writing by 
an authorized representative of the Party making the waiver.  The failure of either Party 
in any one or more instances to insist upon strict performance of any of the terms and 
conditions of this Agreement will not be construed as a waiver or relinquishment, to any 
extent, of the right to assert or rely upon any such terms or conditions on any future 
occasion.  
12.0
Modification.  This Agreement may not be amended except in a writing signed by 
authorized representatives of both Parties.
13.0
Governing Law.  Indiana law shall govern the interpretation and implementation of the 
Agreement and the resolution of any dispute between the parties regarding the effect of 
the Agreement without giving effect to principles of conflicts of law, and shall 
supplement, but not replace, the Uniform Trade Secrets Act as enacted by the State of 
Indiana.  Each Party hereby submits itself for the sole purpose of this Agreement and any 
controversy arising hereunder to the exclusive jurisdiction of the federal or state courts

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
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Effective On: October 18, 2026
located in the State of Indiana serving the counties of Hamilton and Marion, and any 
courts of appeal therefrom, and waives any objection (on the grounds of lack of 
jurisdiction, or forum not convenient or otherwise) to the exercise of such jurisdiction 
over it by any such courts.
14.0
Severability and Survival.  Should any clause, portion or paragraph of this Agreement 
be unenforceable or invalid for any reason, such unenforceability or invalidity will not 
affect the enforceability or validity of the remainder of this Agreement, and any court 
having jurisdiction is specifically authorized and encouraged by the Parties to hold 
inviolate all portions of this Agreement that are valid and enforceable without 
consideration of any invalid or unenforceable portions hereof.
15.0
The headings of the sections in this Agreement are for the purposes of convenient 
reference only and are not intended to be part of this Agreement, or to limit or affect the 
meaning or interpretation of any of the terms hereof.  
16.0
Assignment and Succession.  This Agreement shall inure to the benefit of and be 
binding upon the successors and permitted assigns of the Parties hereto.  Any successor 
to or assignee of MISO shall assume its rights and obligations under this Agreement with 
or without notice to Company.  Company may not assign its rights hereunder without the 
written permission of MISO.
17.0
Attorney’s Fees.  If Company breaches or defaults in the performance of any of the 
covenants, agreements, representations, or warranties described in this Agreement, then 
in addition to any and all of the rights and remedies which MISO may have against 
Company, Company will also be liable to and pay MISO its court costs and reasonable 
attorney’s fees incurred in enforcing MISO’s covenants, agreements, representations and 
warranties herein.
18.0
Employees Bound by Agreement.  The representative executing this Agreement hereby 
acknowledges and agrees that he/she is duly authorized to execute this Agreement on 
behalf of Company and that this Agreement shall bind and be enforceable by and against 
the employees, agents, or consultants of Company.  The authorized representative of 
Company further acknowledges and agrees that only those employees who are listed on 
the attached Appendix A incorporated herein shall be authorized to receive Confidential

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
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Effective On: October 18, 2026
Information directly from MISO and that he/she will notify MISO in writing of any 
modification to Appendix A prior to releasing Confidential Information to those 
employees listed on Appendix A.
19.0
Notices.  All notices and other communications hereunder shall be in writing and shall be 
deemed given if delivered personally or by commercial delivery service, or mailed by 
registered or certified mail (return receipt requested) or sent via facsimile (with 
acknowledgment of complete transmission) to the parties at the following addresses (or at 
such other address for a party as shall be specified by like notice):
if to MISO, to:
720 West City Center Drive
Carmel, Indiana  46032
Attn:  General Counsel
Facsimile No.:  (317) 249-5912
if to ___________, to: ________________________________
________________________________
________________________________
Facsimile No.:  _____________________
20.0
Entire Agreement.  The Parties agree that this Agreement, including Appendix A 
incorporated herein and as modified, constitute their entire agreement with respect to the 
subject matter hereof and that it supersedes any prior agreements or understandings 
between them, whether written or oral.

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
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Effective On: October 18, 2026
Company acknowledges that it has read the Agreement, had the opportunity to discuss it with 
counsel, and is executing it with an understanding of its provisions.  This Agreement may be 
executed in two or more counterparts, each of which will be deemed an original and all of which 
together will constitute one and the same document.
remainder of page left intentionally blank
[signatures appear on following page]

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
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Effective On: October 18, 2026
IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed, 
effective as of the day, month and year written above.
Midcontinent Independent System Operator, Inc.
Midcontinent Independent  System 
Operator, Inc.
Company:
____________________________________
By:  ______________________________
By:  ________________________________
Print name:  _______________________
Print Name:  _________________________
Title:  ____________________________
Title:  _______________________________
Date:
_______________________
Date:
_______________________
Phone: _______________________
Phone: _______________________
Fax:
_______________________
Fax:
_______________________

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
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Effective On: October 18, 2026
APPENDIX A TO ATTACHMENT C
TO MISO UNIVERSAL NON-DISCLOSURE AND 
CONFIDENTIALITY AGREEMENT
Company, ___________________________________________ Employees, Agents, or Consultants 
subject to Confidentiality Agreement as of this _______ day of _________________, 20____:
Transmission/Reliability or
 Print Name
Title
E-mail Address
Merchant/Market, or N/A*)
1.
2.
3.
4.
5.
6.
7.
8.
9.
10.
(Attach Additional Pages If Necessary)
* An individual who is an employee of a Transmission Provider (as defined in 18 C.F.R. § 
358.3(k) may not be subject to the FERC functional separation requirements (i.e., “N/A” 
designation) under certain circumstances in accordance with FERC Order No. 717 and the 
FERC regulations therein adopted.  If such an individual would receive information subject to 
this Amendment, the copy of this Appendix A executed for that individual must be 
accompanied by written confirmation from Company stating the following:  (1) the designated 
individual is not engaged in transmission or marketing functions (i.e., day-to-day duties and 
responsibilities for planning, directing, organizing or carrying out operations); (2) the 
individual has received training on the Standards of Conduct; and (3) the individual undertakes

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
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Effective On: October 18, 2026
to comply with such Standards, including in particular the “no conduit rule” set forth in 18 
C.F.R. § 358.6.
NOTE:  Any changes to the information on this Appendix A must be submitted electronically to the 
Transmission Provider in the manner specified by the Generator Interconnection Business Practices 
Manual (BPM-015).

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
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Effective On: October 18, 2026
ATTACHMENT D TO APPENDIX 1: CRITICAL ENERGY INFRASTRUCTURE 
INFORMATION GENERAL NON-DISCLOSURE AGREEMENT
WHEREAS, Midcontinent Independent  System Operator, Inc. (“MISO”) is prepared to 
disclose Critical Energy Infrastructure Information (“CEII”) under this Critical Energy 
Infrastructure Information General Non-Disclosure Agreement (“NDA”) to 
__________________ (“Recipient”), an individual (employee, manager or officer) employed 
with _______________________, in connection with a legitimate need for the CEII (the 
“Purpose”) (MISO and Recipient may be collectively referred to as “Parties” or singly as 
“Party”);
WHEREAS, Recipient represents that he/she has a legitimate purpose for requesting the 
CEII pursuant to this Agreement; and,
WHEREAS, MISO and Recipient desire to set forth in writing the terms and conditions 
of their agreement.
NOW THEREFORE, in consideration of the mutual promises, covenants, representations 
and agreements contained in this Agreement and other good and valuable consideration, the 
receipt and sufficiency of which are hereby acknowledged, the Parties agree as follows:
1.
Definitions - For purposes of these provisions:
a.
The term “CEII” shall include specific engineering, vulnerability, or detailed 
design information about proposed or existing critical infrastructure that:  (1) relates 
details about the production, generation, transportation, transmission, or distribution of 
energy; (2) could be useful to a person in planning an attack on critical infrastructure; (3) 
is exempt from mandatory disclosure under the Freedom of Information Act, 5 U.S.C. 
552 (2000); and (4) does not simply give the general location of the critical infrastructure.  
Narratives such as the descriptions of facilities and processes are generally not CEII 
unless they describe specific engineering and design details of critical infrastructure.
b.
The term “Recipient” means someone who has executed this NDA and is

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
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Effective On: October 18, 2026
approved to receive CEII.
2.
A Recipient certifies that it is his/her understanding that access to CEII is provided 
pursuant to the terms and restrictions of the provisions in this NDA, and that such Recipient has 
read the provisions and agrees to be bound by them.
3.
Recipient may only discuss CEII with another Recipient of the identical CEII.  A 
Recipient may check with MISO to determine whether another individual is a Recipient of the 
identical CEII.
4.
A Recipient of CEII may use CEII as foundation for advice provided to others, but may 
not disclose CEII to another individual unless that individual is an approved Recipient of the 
same CEII.
5.
A Recipient will not knowingly use CEII for an illegal or non-legitimate purpose.
6.
All CEII shall be maintained by Recipient in a secure place.  Access to those materials 
shall be limited to other Recipients of the identical material.  Recipients may make copies of 
CEII, but such copies become CEII and subject to these same procedures.  Recipients may make 
notes of CEII, which shall be treated as CEII notes if they contain CEII.
7.
Recipients must return CEII to MISO or destroy CEII within fifteen days of a written 
request by MISO to do so, except that CEII notes may be retained in accordance with Paragraph 
6, above.  Within such time period, each Recipient, if requested to do so, shall also submit to 
MISO an affidavit stating that, to the best of his or her knowledge, all CEII has been returned or 
destroyed and that CEII notes have either been returned, destroyed or are being maintained by 
Recipient in accordance with Paragraph 6.
8.
The Recipient remains bound by these provisions unless MISO rescinds the provisions or 
a court of competent jurisdiction finds that the information does not qualify as CEII.

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
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Effective On: October 18, 2026
9.
MISO may reasonably audit the Recipient’s compliance with this NDA.
10.
Violation of this NDA will be reported to the Federal Energy Regulatory Commission 
(the “Commission”) which in turn may result in criminal or civil sanctions against the Recipient.
11.
I hereby certify my understanding that access to CEII is provided to me pursuant to the 
terms and restrictions of the above CEII provisions, that I have been given a copy of and have 
read the provisions, and that I agree to be bound by them.  I understand that the contents of the 
CEII, any notes or other memoranda, or any other form of information that copies or discloses 
CEII shall not be disclosed to anyone other than another person who has been granted access to 
these same materials.  I acknowledge that a violation of this NDA may result in criminal or civil 
sanctions, including the suspension of my ability to appear before the Commission pursuant to 
18 C.F.R. § 385.2102.  I agree that my compliance with this NDA is subject to reasonable audit 
by MISO.
By: _____________________________________
Signature
Print Name: ______________________________
Title: ___________________________________
Representing: _____________________________
Date: ____________________________________

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
60.0.0, 61.0.0
Effective On: October 18, 2026
ATTACHMENT E TO APPENDIX 1: SITE CONTROL DEMONSTRATION 
Midcontinent Independent System Operator, Inc.
Attn: Manager, Queue Administration 
720 City Center Drive 
Carmel, IN 46032 
[Date]
Subject: Proof of Site Control Affidavit 
1.  
The undersigned (“Affiant”) is an officer or an agent of the Interconnection Customer for 
the Interconnection Request associated with [Project Name].
2. 
Affiant affirms that all of the Site Control documents for [Project Name] required 
pursuant to Section 7.2 of Attachment X of the MISO Tariff are submitted to MISO in 
their entirety.
3. 
Affiant has reviewed all such Site Control documents submitted for [Project Name] and 
has personal knowledge of its contents.
4.
Affiant hereby affirms that the Interconnection Customer [PLEASE SELECT FROM 
THE FOLLOWING:
____
 (1) possesses Site Control for (Project Name) in accordance with Sections 7.2.1.1 of 
this GIP; OR 
____ (2) is presently subject to regulatory restrictions that preclude Interconnection 
Customer from obtaining Site Control for (Project Name) pursuant to Section 7.2.1.2 of 
this GIP].
5. 
[TO THE EXTENT THAT REGULATORY RESTRICTIONS PRECLUDE SITE 
CONTROL PURSUANT TO GIP SECTION 7.2.1.2] In accordance with Section 
7.2.1.2 of the GIP, attached hereto the affiant provides a description of conditions that

MISO
Attachment X: Appendix 1
FERC Electric Tariff
Interconnection Request for a Generating Facility
ATTACHMENTS
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Effective On: October 18, 2026
must be met in order to satisfy the regulatory restrictions and the anticipated time by 
which the Interconnection Customer expects to satisfy the regulatory restrictions.
Sincerely,
[Affiant signature]
[Affiant printed name]
[Affiant title]
[Affiant company name]

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
APPENDIX 19 TO GIP 
ZG INTERCONNECTION AGREEMENT (ZGIA) 
 
THIS ZGINTERCONNECTION AGREEMENT (“ZGIA”) is made and entered into 
this ____ day of ________ 20__, by and between ________________, a 
______________________ organized and existing under the laws of the State/Commonwealth of 
_____________________ (“Interconnection Customer” with a Generating Facility), and  
__________________________, a [corporation] organized and existing under the laws of the 
State/Commonwealth of ____________ (“Transmission Owner”), and the Midcontinent 
Independent System Operator, Inc., a non-profit, non-stock corporation organized and existing 
under the laws of the State of Delaware (“Transmission Provider”).  Interconnection Customer, 
Transmission Owner and Transmission Provider each may be referred to as a “Party,” or 
collectively as the “Parties.” 
 
RECITALS 
 
WHEREAS, Transmission Provider has functional control of the operations of the 
Transmission System, as defined herein and according to NERC’s Rules of Procedure, and is 
responsible for providing Transmission Service and Interconnection Service on the transmission 
facilities under its control; and  
 
WHEREAS, Interconnection Customer intends to own, lease and/or control and operate 
the Generating Facility identified as a Generating Facility in Appendix A to this ZGIA; and 
 
WHEREAS, Interconnection Customer will use the output of its Generating Facility to 
serve the ZG Associated Load identified in Appendix A of this Agreement and otherwise will 
not inject energy onto the Transmission System; and 
 
WHEREAS, Transmission Owner owns or operates the Transmission System, whose 
operations are subject to the functional control of Transmission Provider, to which 
Interconnection Customer desires to connect the Generating Facility, and may therefore be

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
required to construct certain Interconnection Facilities and Network Upgrades, as set forth in this 
ZGIA; and 
 
WHEREAS, Interconnection Customer, Transmission Owner and Transmission Provider 
have agreed to enter into this ZGIA for the purpose of interconnecting the Generating Facility 
with the Transmission System; 
 
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained 
herein, it is agreed:

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
ARTICLE 1.  DEFINITIONS 
 
 
When used in this ZGIA, terms with initial capitalization that are not defined in Article 1 
shall have the meanings specified in the Article in which they are used.  Those capitalized terms 
used in this ZGIA that are not otherwise defined in this ZGIA have the meaning set forth in the 
Tariff. 
 
10 kW Inverter Process shall mean the procedure for evaluating an Interconnection 
Request for a certified inverter-based Small Generating Facility no larger than 10 kW that uses 
the screen set forth in Section 14. 
 
Adverse System Impact shall mean the negative effects due to technical or operational 
limits on conductors or equipment being exceeded that may compromise the safety and 
reliability of the electric system. 
 
Affected System(s) shall mean an electric transmission system or the electric system 
associated with an Existing Generating Facility or of a higher queued Generating Facility, which 
is an electric system other than the Transmission Provider’s Transmission System that is affected 
by the Interconnection Request.  An Affected System may or may not be subject to FERC 
jurisdiction. 
 
Affected System Interconnection Customer shall mean any entity that submits an 
interconnection request for a Generating Facility to a transmission system other than 
Transmission Provider’s Transmission System that may cause the need for Affected System 
Network Upgrades on the Transmission Provider’s Transmission System. 
 
Affected System Network Upgrades shall mean the additions, modifications, and 
upgrades to Transmission Provider’s Transmission System required to accommodate Affected 
System Interconnection Customer’s proposed interconnection to a transmission system other 
than Transmission Provider’s Transmission System.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
 
Affected System Operator shall mean the entity that operates an Affected System. 
 
Affected System Queue Position shall mean the queue position of an Affected System 
Interconnection Customer in Transmission Provider’s interconnection queue relative to 
Transmission Provider’s Interconnection Customers’ Queue Position. 
 
Affected System Study shall mean the evaluation of Affected System Interconnection 
Customers’ proposed interconnection(s) to a transmission system other than the Transmission 
Provider’s Transmission System that have an impact on Transmission Provider’s Transmission 
System, as described in Section 8 of this GIP. 
 
Affected System Study Agreement shall mean the agreement contained in Appendix 16 
to the GIP that is made between Transmission Provider and host transmission provider, in 
absence of a JOA, JPA, or other agreement filed with the Commission, as noted in Section 8 of 
the GIP. 
 
Affected System Study Report shall mean the report issued following completion of an 
Affected System Study. 
 
Affiliate shall mean, with respect to a corporation, partnership or other entity, each such 
other corporation, partnership or other entity that directly or indirectly, through one or more 
intermediaries, controls, is controlled by, or is under common control with, such corporation, 
partnership or other entity. 
 
Ancillary Services shall mean those services that are necessary to support the 
transmission of capacity and energy from resources to loads while maintaining reliable operation 
of the Transmission System in accordance with Good Utility Practice. 
 
Applicable Laws and Regulations shall mean all duly promulgated applicable federal, 
state and local laws, regulations, rules, ordinances, codes, decrees, judgments, directives, or

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judicial or administrative orders, permits and other duly authorized actions of any Governmental 
Authority having jurisdiction over the Parties, their respective facilities and/or the respective 
services they provide.  
 
Applicable Reliability Standards shall mean the requirements and guidelines of the 
Electric Reliability Organization and the Balancing Authority Area of the Transmission System 
to which the Generating Facility is directly interconnected. 
 
Balancing Authority shall mean an entity that integrates resource plans ahead of time, 
maintains demand and resource balance within a Balancing Authority Area, and supports 
interconnection frequency in real time. 
 
Balancing Authority Area shall mean the collection of generation, transmission, and 
loads within the metered boundaries of the Balancing Authority.  The Balancing Authority 
maintains load-resource balance within this area. 
 
Base Case shall mean the base case power flow, short circuit, and stability databases 
used for the Interconnection Studies by Transmission Provider or Interconnection Customer. 
 
Base Case Data shall mean base case power flow, short circuit and stability databases, 
including all underlying assumptions, and contingency lists.  Such databases and lists, hereinafter 
referred to as Base Cases, shall include all (1) generation projects and (2) transmission projects, 
including merchant transmission projects that are proposed for the Transmission System for 
which a transmission expansion plan has been submitted and approved by the MISO Board. 
 
Breach shall mean the failure of a Party to perform or observe any material term or 
condition of this GIA. 
 
Breaching Party shall mean a Party that is in Breach of this GIA.

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FERC Electric Tariff 
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ATTACHMENTS 
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Business Day shall mean Monday through Friday, excluding Federal Holidays. 
 
Calendar Day shall mean any day including Saturday, Sunday or a Federal Holiday.  In 
the event that a period specified in this GIA is calculated in Calendar Days ends on a non-
business day, such period shall be deemed to conclude on the following business day. 
 
Cluster shall mean a group of one or more Interconnection Requests that are studied 
together for the purpose of conducting a Group Study. 
 
Commercial Operation shall mean the status of a Generating Facility that has 
commenced generating electricity for sale, excluding electricity generated during Trial 
Operation. 
 
Commercial Operation Date (COD) of a unit shall mean the date on which the 
Generating Facility commences Commercial Operation as agreed to by the Parties pursuant to 
Appendix E to this GIA. 
 
Commitment Projection shall mean a projection of the number of MW expected to 
commit to the JTIQ Portfolio from ERAS and all DPP study clusters that already have passed 
DP1 as described in Section 9.4.2.e.ii of Rate Schedule 6 (MISO SPP-JOA).  
 
Common Use Upgrade (CUU) shall mean an Interconnection Facility, Network 
Upgrade, System Protection Facility, or any other classified addition, alteration, or improvement 
on the Transmission System or the transmission system of an Affected System, not classified 
under Attachment FF as a Baseline Reliability Project, Market Efficiency Project, or Multi-Value 
Project, that is needed for the interconnection of multiple Interconnection Customers’ Generating 
Facilities and which is the shared responsibility of such Interconnection Customers.   
 
Confidential Information shall mean any proprietary or commercially or competitively 
sensitive information, trade secret or information regarding a plan, specification, pattern,

MISO 
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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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procedure, design, device, list, concept, policy or compilation relating to the present or planned 
business of a Party, or any other information as specified in Article 22, which is designated as 
confidential by the Party supplying the information, whether conveyed orally, electronically, in 
writing, through inspection, or otherwise, that is received by another Party. 
 
Connection Facilities shall mean the Transmission Owner’s Connection Facilities and 
the MHVDC Connection Customer’s Connection Facilities, as defined in the MHCP. 
 
Contingent Facilities shall mean those unbuilt Interconnection Facilities and Network 
Upgrades upon which the Interconnection Request’s costs, timing and study findings are 
dependent, and if delayed or not built, could cause a need for restudies of the Interconnection 
Request or a reassessment of the Interconnection Facilities and/or Network Upgrades and/or 
costs and timing.  Contingent Facilities may include facilities identified in MTEP that if delayed 
or not built could impact the timing of the Interconnection Request. 
 
Customer Engagement Window shall mean the time period prior to the start of 
Definitive Planning Phase I set forth in Section 3.3.4 of the GIP. 
 
Default shall mean the failure of a Breaching Party to cure its Breach in accordance with 
Article 17 of this GIA. 
 
Definitive Planning Phase shall mean the Generator Interconnection Procedures process 
which leads to a Generator Interconnection Agreement.  An Interconnection Customer enters the 
Definitive Planning Phase pursuant to GIP Section 7.2.  The Definitive Planning Phase includes 
three distinct phases (Definitive Planning Phases I, II, and III) pursuant to Section 7 of the 
Generator Interconnection Procedures. 
 
Definitive Planning Phase Queue Position shall mean the order of a valid 
Interconnection Request, relative to all other pending valid Interconnection Requests, in the 
Definitive Planning Phase.  The Definitive Planning Phase Queue Position is established based 
upon the date Interconnection Customer satisfies all of the requirements of GIP Section 7.2 to

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ATTACHMENTS 
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enter the Definitive Planning Phase.  All Interconnection Requests within the same Definitive 
Planning Phase cycle shall have equal priority (i.e. similarly queued).   
 
Demonstrated Capability shall mean the continuous net real power output that the 
Generating Facility is required to demonstrate in compliance with Applicable Reliability 
Standards.   
 
Dispute Resolution shall mean the procedure for resolution of a dispute between or 
among the Parties in which they will first attempt to resolve the dispute on an informal basis. 
 
Distribution System shall mean the Transmission Owner’s facilities and equipment, or 
the Distribution System of another party that is interconnected with the Transmission Owner’s 
Transmission System, if any, connected to the Transmission System, over which facilities 
Transmission Service or Wholesale Distribution Service under the Tariff is available at the time 
Interconnection Customer has requested interconnection of a Generating Facility for the purpose 
of either transmitting electric energy in interstate commerce or selling electric energy at 
wholesale in interstate commerce and which are used to transmit electricity to ultimate usage 
points such as homes and industries directly from nearby generators or from interchanges with 
higher voltage transmission networks which transport bulk power over longer distances.  The 
voltage levels at which distribution systems operate differ among Local Balancing Authorities 
and other entities owning distribution facilities interconnected to the Transmission System.   
 
Distribution Upgrades shall mean the additions, modifications, and upgrades to the 
Distribution System at or beyond the Point of Interconnection to facilitate interconnection of the 
Generating Facility and render the delivery service necessary to affect Interconnection 
Customer’s wholesale sale of electricity in interstate commerce.  Distribution Upgrades do not 
include Interconnection Facilities. 
 
Effective Date shall mean the date on which this GIA becomes effective upon execution 
by the Parties subject to acceptance by the Commission, or if filed unexecuted, upon the date 
specified by the Commission.

MISO 
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FERC Electric Tariff 
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ATTACHMENTS 
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Electric Reliability Organization shall mean the North American Electric Reliability 
Corporation or its successor organization. 
 
Emergency Condition shall mean a condition or situation:  (1) that in the reasonable 
judgment of the Party making the claim is imminently likely to endanger, or is contributing to 
the endangerment of, life, property, or public health and safety; or (2) that, in the case of either 
Transmission Provider or Transmission Owner, is imminently likely (as determined in a non-
discriminatory manner) to cause a material adverse effect on the security of, or damage to the 
Transmission System, Transmission Owner’s Interconnection Facilities or the electric systems of 
others to which the Transmission System is directly connected; or (3) that, in the case of 
Interconnection Customer, is imminently likely (as determined in a non-discriminatory manner) 
to cause a material adverse effect on the security of, or damage to, the Generating Facility or 
Interconnection Customer’s Interconnection Facilities.  System restoration and blackstart shall be 
considered Emergency Conditions; provided that Interconnection Customer is not obligated by 
this GIA to possess blackstart capability.  Any condition or situation that results from lack of 
sufficient generating capacity to meet load requirements or that results solely from economic 
conditions shall not constitute an Emergency Condition, unless one of the enumerated conditions 
or situations identified in this definition also exists. 
 
Energy Displacement Agreement shall mean an agreement between an Interconnection 
Customer with an Existing Generating Facility on the Transmission Provider’s Transmission 
System and an Interconnection Customer with a proposed Generating Facility seeking to 
interconnect with Surplus Interconnection Service.  The Energy Displacement Agreement 
specifies the term of operation, the Generating Facility Interconnection Service limit, and the 
mode of operation for energy production (common or singular operation). 
 
Energy Resource Interconnection Service (ER Interconnection Service) shall mean 
an Interconnection Service that allows Interconnection Customer to connect its Generating 
Facility to the Transmission System or Distribution System, as applicable, to be eligible to 
deliver the Generating Facility’s electric output using the existing firm or non-firm capacity of

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the Transmission System on an as available basis.  Energy Resource Interconnection Service 
does not convey transmission service. 
 
Engineering & Procurement (E&P) Agreement shall mean an agreement that 
authorizes Transmission Owner to begin engineering and procurement of long lead-time items 
necessary for the establishment of the interconnection in order to advance the implementation of 
the Interconnection Request. 
 
Environmental Law shall mean Applicable Laws or Regulations relating to pollution or 
protection of the environment or natural resources. 
 
Existing Generating Facility shall mean a Generating Facility that is either under 
construction or is in service, and has an unsuspended interconnection agreement with its host 
transmission provider. 
 
Expanded Scope Analysis shall mean the analysis described in Section 9.4.2.d.iv.a of 
Rate Schedule 6 (MISO-SPP JOA). 
Expedited Resource Addition Study (ERAS) shall mean the temporary procedure for 
expediting interconnection projects identified for claimed resource adequacy and/or reliability 
needs. 
 
Expedited Generator Interconnection Agreement (EGIA) shall mean the 
interconnection agreement for the Expedited Resource Addition Study established between the 
Transmission Provider and/or the Transmission Owner and the Interconnection Customer as set 
forth in Section 3.9 of this Attachment X.  This agreement shall take the form of the 
Transmission Provider’s pro forma Generator Interconnection Agreement modified for the 
Expedited Resource Addition Study.  Unless otherwise provided in the GIP, all requirements 
applicable to the pro forma Generator Interconnection Agreement shall apply to the Expedited 
Generator Interconnection Agreement.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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Facilities Construction Agreement (FCA) shall mean the form of facilities construction 
agreement, set forth in Appendix 8 to these Generator Interconnection Procedures.  The FCA 
shall be used when an Interconnection Customer or an Affected System Interconnection 
Customer causes the need for the construction of Network Upgrades, Affected System Network 
Upgrades, or System Protection Facilities on the transmission system of the Transmission 
Provider.  
  
Fast Track Process shall mean the procedure for evaluating an Interconnection Request 
for a certified Small Generating Facility no larger than five MW that includes the screen set forth 
in Section 14, customer options meeting, and optional supplemental review. 
 
Federal Holiday shall mean a Federal Reserve Bank holiday for a Party that has its 
principal place of business in the United States and a Canadian Federal or Provincial banking 
holiday for a Party that has its principal place of business located in Canada. 
 
Federal Power Act shall mean the Federal Power Act, as amended, 16 U.S.C. §§ 791a 
et seq. 
 
FERC shall mean the Federal Energy Regulatory Commission, also known as 
Commission, or its successor. 
 
Final System Impact Study shall mean the Interconnection System Impact Study 
performed during Definitive Planning Phase III. 
 
Force Majeure shall mean any act of God, labor disturbance, act of the public enemy, 
war, insurrection, riot, fire, storm or flood, explosion, breakage or accident to machinery or 
equipment, any order, regulation or restriction imposed by governmental, military or lawfully 
established civilian authorities, or any other cause beyond a Party’s control.  A Force Majeure 
event does not include an act of negligence or intentional wrongdoing by the Party claiming 
Force Majeure.

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Generating Facility shall mean Interconnection Customer’s device(s) for the production 
and/or storage for later injection of electricity identified in the Interconnection Request, but shall 
not include the Interconnection Customer’s Interconnection Facilities. A Generating Facility 
consists of one or more generating unit(s) and/or storage device(s) which usually can operate 
independently and be brought online or taken offline individually. 
 
Generating Facility Capacity shall mean the net capacity of the Generating Facility and 
the aggregate net capacity of the Generating Facility where it includes  more than one device for 
the production and/or storage for later injection of electricity. 
 
Generating Facility Modification shall mean modification to an Existing Generating 
Facility, including comparable replacement of only a portion of its equipment at the Existing 
Generating Facility.  
 
Generating Facility Replacement shall mean replacement of one or more generating 
units and/or storage devices at the Existing Generating Facility with one or more new generating 
units or storage devices at the same electrical Point of Interconnection as the generating units 
and/or storage devices that is/are being decommissioned and electrically disconnected. 
 
Generator Interconnection Agreement (GIA) shall mean the form of interconnection 
agreement, set forth as Appendix 6 to Attachment X of the Tariff. 
 
Generator Interconnection Procedures (GIP) shall mean the interconnection 
procedures set forth in Attachment X of the Tariff. 
 
Generator Upgrades shall mean the additions, modifications, and upgrades to the 
electric system of an Existing Generating Facility or of a higher queued Generating Facility at or 
beyond the Point of Interconnection to facilitate interconnection of the Generating Facility and 
render the Transmission Service necessary to affect Interconnection Customer’s wholesale sale 
of electricity in interstate commerce.

MISO 
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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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Good Utility Practice shall mean any of the practices, methods and acts engaged in or 
approved by a significant portion of the electric industry during the relevant time period, or any 
of the practices, methods and acts which, in the exercise of reasonable judgment in light of the 
facts known at the time the decision was made, could have been expected to accomplish the 
desired result at a reasonable cost consistent with good business practices, reliability, safety and 
expedition.  Good Utility Practice is not intended to be limited to the optimum practice, method, 
or act to the exclusion of all others, but rather to be acceptable practices, methods, or acts 
generally accepted in the region. 
 
Governmental Authority shall mean any federal, state, local or other governmental 
regulatory or administrative agency, court, commission, department, board, or other 
governmental subdivision, legislature, rulemaking board, tribunal, or other governmental 
authority having jurisdiction over the Parties, their respective facilities, or the respective services 
they provide, and exercising or entitled to exercise any administrative, executive, police, or 
taxing authority or power; provided, however, that such term does not include Interconnection 
Customer, Transmission Provider, Transmission Owner, or any Affiliate thereof. 
 
Group Restudy shall mean a restudy of a Group Study conducted pursuant to Section 
7.5 of the GIP. 
 
Group Study(ies) shall mean the evaluation of one or more Interconnection Requests 
within a Cluster as described in Section 7 of the GIP.  Group Studies are divided into phases as 
described in section 7.3 of the GIP. 
 
Hazardous Substances shall mean any chemicals, materials or substances defined as or 
included in the definition of “hazardous substances,” “hazardous wastes,” “hazardous materials,” 
“hazardous constituents,” “restricted hazardous materials,” “extremely hazardous substances,” 
“toxic substances,” “radioactive substances,” “contaminants,” “pollutants,” “toxic pollutants” or 
words of similar meaning and regulatory effect under any applicable Environmental Law, or any 
other chemical, material or substance, exposure to which is prohibited, limited or regulated by 
any applicable Environmental Law.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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HVDC Facilities shall mean the high voltage direct current transmission facilities, 
including associated alternating current facilities, if any, that are subject to Section 27A of the 
Tariff and that are specifically identified in (i) any Agency Agreement pertaining to such 
facilities between Transmission Provider and Transmission Owner that owns or operates such 
facilities, or (ii) in any other arrangement that permits or will permit Transmission Provider to 
provide HVDC Service over such facilities as set forth in Section 27A of the Tariff. 
 
HVDC Service shall mean Firm and Non-Firm Point-To-Point Transmission Service 
provided by Transmission Provider on HVDC Facilities pursuant to Section 27A of the Tariff. 
 
Initial Synchronization Date shall mean the date upon which the Generating Facility is 
initially synchronized and upon which Trial Operation begins. 
 
Injection Rights shall mean the Transmission Provider’s pre-certification of the 
Transmission System’s capability to receive capacity and energy from the MHVDC 
Transmission Line at the requested Point of Connection, and in the specified MW quantity, 
without degrading the reliability of the Transmission System, as described in Section 16 of the 
GIP and Section 3.2.3 of the MHCP. 
 
In-Service Date (ISD) shall mean the date upon which Interconnection Customer 
reasonably expects it will be ready to begin use of the Transmission Owner’s Interconnection 
Facilities to obtain backfeed power. 
 
Interconnection Customer shall mean any entity, including Transmission Provider, 
Transmission Owner or any of the Affiliates or subsidiaries of either, that proposes to 
interconnect its Generating Facility with the Transmission System. 
 
Interconnection Customer Decision Point I shall mean the time period beginning when 
the Interconnection Customer is provided the Preliminary System Impact Study results including 
cost estimates for upgrades and concludes after fifteen (15) Business Days.

MISO 
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FERC Electric Tariff 
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Interconnection Customer Decision Point II shall mean the time period beginning 
when the Interconnection Customer is provided the Revised System Impact Study results 
including cost estimates for upgrades and concludes after fifteen (15) Business Days. 
 
Interconnection Customer’s Interconnection Facilities (ICIF) shall mean all facilities 
and equipment, as identified in Appendix A of this GIA, that are located between the Generating 
Facility and the Point of Change of Ownership, including any modification, addition, or upgrades 
to such facilities and equipment necessary to physically and electrically interconnect the 
Generating Facility to the Transmission System or Distribution System, as applicable.  
Interconnection Customer’s Interconnection Facilities are sole use facilities. 
 
Interconnection Facilities shall mean the Transmission Owner’s Interconnection 
Facilities and the Interconnection Customer’s Interconnection Facilities.  Collectively, 
Interconnection Facilities include all facilities and equipment between the Generating Facility 
and the Point of Interconnection, including any modification, additions or upgrades that are 
necessary to physically and electrically interconnect the Generating Facility to the Transmission 
System.  Interconnection Facilities shall not include Distribution Upgrades, Generator Upgrades, 
Stand Alone Network Upgrades or Network Upgrades. 
 
Interconnection Facilities Study(ies) shall mean a study conducted by Transmission 
Owner, or its agent, for Interconnection Customer(s) to determine a list of facilities (including 
Interconnection Customer’s Interconnection Facilities or Affected System Interconnection 
Customer’s interconnection facilities, Transmission Owner’s Interconnection Facilities, System 
Protection Facilities, and if such upgrades have been determined, Network Upgrades, 
Distribution Upgrades, Generator Upgrades, Common Use Upgrades, and Affected System 
Network Upgrades, as identified in the Interconnection System Impact Study, Affected System 
Study, or Affected System Operator’s applicable study), the cost of those facilities, and the time 
required to interconnect with the Transmission System or the Affected System Operator’s 
transmission system.

MISO 
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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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Interconnection Facilities Study Agreement shall mean the form of agreement 
contained in Appendix 4 of the Generator Interconnection Procedures for conducting the 
Interconnection Facilities Study. 
 
Interconnection Request shall mean (1) an Interconnection Customer’s request, in the 
form of Appendix 1 to the Generator Interconnection Procedures, to interconnect a new 
Generating Facility, or a request for the Expedited Resource Addition Study for new generation 
capacity, or to increase the capacity of, or make a Material Modification to the operating 
characteristics of, an Existing Generating Facility that is interconnected with the Transmission 
System, or to interconnect an Existing Generating Facility that is external to the Transmission 
System, or to change Energy Resource Interconnection Service to Network Resource 
Interconnection Service for an Existing Generating Facility; or (2) an MHVDC Connection 
Customer’s request, in the form of Appendix 1 to the Generator Interconnection Procedures, to 
obtain Injection Rights.. 
 
Interconnection Service shall mean the service provided by Transmission Provider 
associated with interconnecting the Generating Facility to the Transmission System, or external 
host transmission provider if applicable,  and enabling it to receive electric energy and capacity 
from the Generating Facility at the Point of Interconnection pursuant to the terms of this 
Generator Interconnection Agreement or Point of Delivery as set forth in the Service Agreement 
for Network Resource Interconnection Service for an External Generating Facility and, if 
applicable, the Tariff. 
 
Interconnection Study (or Study) shall mean any of the studies described in the 
Generator Interconnection Procedures. 
 
Interconnection Study Agreement shall mean the form of agreement contained in 
Attachment B to Appendix 1 of the Generator Interconnection procedures for conducting all 
studies required by the Generator Interconnection Procedures.

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FERC Electric Tariff 
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Interconnection System Impact Study shall mean an engineering study that evaluates 
the impact of the proposed interconnection on the safety and reliability of Transmission System 
and, if applicable, an Affected System.  The study shall identify and detail the system impacts 
that would result if the Generating Facility were interconnected without project modifications or 
system modifications, or to study potential impacts, including but not limited to those identified 
in the Scoping Meeting as described in the Generator Interconnection Procedures. 
 
Interconnection Study Agreement shall mean the forms of agreement contained in 
Attachment B to Appendix 1 of the Generator Interconnection Procedures for conducting all 
studies required by the Generator Interconnection Procedures. 
 
IRS shall mean the Internal Revenue Service. 
 
Joint Planning Agreement (“JPA”) shall mean an agreement between adjacent 
balancing authorities or transmission providers for the coordination of planning. 
 
Joint Operating Agreement between the Midcontinent Independent System 
Operator, Inc. and Southwest Power Pool, Inc. (MISO-SPP JOA) shall mean Rate Schedule 
6 to the MISO Tariff. 
 
Joint Planning Agreement (“JPA”) shall mean an agreement between adjacent 
balancing authorities or transmission providers for the coordination of planning. 
 
Joint Targeted Interconnection Queue (JTIQ) shall refer to the study and processes 
described in Section 9.4.2 of Rate Schedule 6 (MISO-SPP JOA). 
 
Joint Targeted Interconnection Queue Study (“JTIQ Study”) shall mean a 
transmission planning study conducted jointly by SPP and MISO to facilitate the interconnection 
of new generator capacity in both Parties’ regions.

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
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JTIQ Commitment Group Member shall mean any JTIQ Commitment Group Member 
included in a Commitment Group consistent with Section 9.4 of Rate Schedule 6 (MISO-SPP 
JOA). 
 
JTIQ Commitment Group or Commitment Group shall mean a group of JTIQ 
Commitment Group Members that have executed a JTIQ Generator Interconnection Agreement 
within the twelve (12) month period ending April 30th of each year.  The Commitment Group 
shall also include JTIQ Commitment Group Members for which a JTIQ Generator 
Interconnection Agreement has been filed unexecuted by SPP or the Transmission Provider and 
the Commission has accepted the agreement within the twelve (12) month period ending April 
30th of each year. 
 
JTIQ Generator Charge shall mean the charge to JTIQ Commitment Group Members 
to recover the JTIQ Commitment Group Member’s share of the JTIQ Monthly Revenue 
Requirement for each of the JTIQ Upgrades in the JTIQ Portfolio in the Transmission Provider’s 
Region. 
 
JTIQ Participation Group shall mean the group of Interconnection Requests that shall 
consist of all interconnection customers included in the JTIQ Screening Groups whose 
interconnection request meets the distribution factor and impact criteria specified in Section 
9.4.2(d)((ii) of Rate Schedule 6 (MISO-SPP JOA). 
 
JTIQ Portfolio shall mean a group of JTIQ Upgrades identified pursuant to Section 9.4 
of Rate Schedule 6 (MISO-SPP JOA). 
 
JTIQ Screening Group shall mean a group of MISO Interconnection Customers and 
SPP interconnection customers whose Interconnection Requests will be screened for inclusion in 
a JTIQ Participation Group. The JTIQ Screening Group shall consist of all interconnection 
customers who have submitted interconnection requests into a MISO ERAS, SPP ERAS, DPP 
study cluster, or SPP DISIS study cluster that: (1) has a study commencement or kick off date 
that is after the date that the Parties’ respective Boards of Directors have approved a JTIQ

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Portfolio; and (2) has not commenced DPP Phase I, a MISO ERAS, the SPP ERAS or DISIS 
Phase One studies pursuant to each party’s OATT as of the date that the Parties have declared 
the JTIQ Portfolio fully subscribed.  
 
JTIQ Service Agreements shall mean the JTIQ Commitment Agreement attached to the 
MISO GIA as Appendix 17 and the SPP’s pro forma agreement(s)  that obligate interconnection 
customers to provide security for and  pay the JTIQ Generator Charge for JTIQ Network 
Upgrades included in the applicable JTIQ Portfolio. 
 
JTIQ Upgrade shall mean a Network Upgrade included in a JTIQ portfolio pursuant to 
Section 9.4 of Rate Schedule 6 (MISO-SPP JOA).  
 
Local Balancing Authority shall mean an operational entity or a Joint Registration 
Organization which is (i) responsible for compliance with the subset of Electric Reliability 
Organization Balancing Authority Reliability Standards defined in the Balancing Authority 
Agreement for their local area within the MISO Balancing Authority Area, (ii) a Party to 
Balancing Authority Agreement, excluding MISO, and (iii) provided in the Balancing Authority 
Agreement. 
 
Local Resource Zone (LRZ) shall mean a geographic area within the Transmission 
Provider Region that is prescribed by the Transmission Provider, based upon the criteria in 
Section 68A.3, to address congestion that limits Planning Resource deliverability.   
 
Loss shall mean any and all damages, losses, claims, including claims and actions 
relating to injury to or death of any person or damage to property, demand, suits, recoveries, 
costs and expenses, court costs, attorney fees, and all other obligations by or to third parties, 
arising out of or resulting from the other Party’s performance, or non-performance of its 
obligations under this GIA on behalf of the indemnifying Party, except in cases of gross 
negligence or intentional wrongdoing, by the indemnified party.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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Material Modification shall mean: (1) modification to an Interconnection Request in the 
queue, that has a material adverse impact on the cost or timing of any other Interconnection 
Request with an equal or later queue priority date; or Qualified Change.   
 
Metering Equipment shall mean all metering equipment installed or to be installed at 
the Generating Facility, Interconnection Customer’s Interconnection Facilities, and/or 
Transmission Owner's Interconnection Facilities pursuant to this GIA at the metering points, 
including but not limited to instrument transformers, MWh-meters, data acquisition equipment, 
transducers, remote terminal unit, communications equipment, phone lines, and fiber optics. 
 
Monitoring and Consent Agreement shall mean an agreement that defines the terms 
and conditions applicable to a Generating Facility acquiring Surplus Interconnection Service.  
The Monitoring and Consent Agreement will list the roles and responsibilities of an 
Interconnection Customer seeking to interconnect with Surplus Interconnection Service and 
Transmission Owner to maintain the total output of the Generating Facility inside the parameters 
delineated in the GIA. 
 
Multi-Party Facilities Construction Agreement (MPFCA) shall mean the form of 
facilities construction agreement, set forth in Appendix 9 to these Generator Interconnection 
Procedures.  The MPFCA shall be used when multiple Interconnection Requests or 
interconnection requests from Affected System Interconnection Customers cause the need for the 
construction of Common Use Upgrades on the Transmission System and share cost 
responsibility for such Common Use Upgrades.   
 
Network Customer shall have that meaning as provided in the Tariff. 
 
Network Resource shall mean any designated generating resource owned, purchased, or 
leased by a Network Customer under the Tariff.  Network Resources do not include any 
resource, or any portion thereof, that is committed for sale to third parties or otherwise cannot be 
called upon to meet the Network Customer’s Network Load on a non-interruptible basis.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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Network Resource Interconnection Service (NR Interconnection Service) shall mean 
an Interconnection Service that allows Interconnection Customer to integrate its Generating 
Facility with the Transmission System in the same manner as for any Generating Facility being 
designated as a Network Resource.  Network Resource Interconnection Service does not convey 
transmission service.  Network Resource Interconnection Service shall include any network 
resource interconnection service established under an agreement with, or the tariff of, a 
Transmission Owner prior to integration into MISO, that is determined to be deliverable through 
the integration deliverability study process. 
 
Network Upgrades shall mean the additions, modifications, and upgrades to the 
Transmission System required at or beyond the point at which the Interconnection Facilities 
connect to the Transmission System or Distribution System, as applicable, to accommodate the 
interconnection of the Generating Facility(ies) to the Transmission System.  Network Upgrades 
shall not include any HVDC Facility Upgrades. 
 
Notice of Dispute shall mean a written notice of a dispute or claim that arises out of or in 
connection with this GIA or its performance. 
 
Optional Interconnection Study shall mean a sensitivity analysis based on assumptions 
specified by Interconnection Customer in the Optional Interconnection Study Agreement. 
 
Optional Interconnection Study Agreement shall mean the form of agreement 
contained in Appendix 5 of the Generator Interconnection Procedures for conducting the 
Optional Interconnection Study. 
 
Outage Transfer Distribution Factor (OTDF) Outage Transfer Distribution Factor, as 
defined by the Electric Reliability Organization. 
 
Party or Parties shall mean Transmission Provider, Transmission Owner, 
Interconnection Customer, or any combination of the above.

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
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Permissible Technological Advancement shall mean advancements to turbines, 
inverters, plant supervisory controls, excitation systems, or other technological advancements 
submitted to the Transmission Provider prior to the issuance of this draft Generator 
Interconnection Agreement for such project provided that such advancements does not: (1) 
degrade the electrical characteristics of the generating equipment; (2) does not cause any material 
adverse impact on the Transmission System with regard to short circuit capability limits, steady-
state thermal and voltage limits, or dynamic system stability and response; (3) does not increase 
the installed capacity of the Generating Facility; or (4) change the fuel source of the proposed 
Generating Facility.   
 
Point of Change of Ownership (PCO) shall mean the point, as set forth in Appendix A 
to the Generator Interconnection Agreement, where the Interconnection Customer’s 
Interconnection Facilities connect to the Transmission Owner’s Interconnection Facilities. 
 
Point of Interconnection (POI) shall mean the point, as set forth in Appendix A of the 
GIA, where the Interconnection Facilities connect to the Transmission System. 
 
Point(s) of Withdrawal (POW) shall mean the point(s) where a non-transmission 
facility used to withdraw Energy from the Transmission System to serve Load connects to the 
Transmission System.  
 
Potential MW Total shall mean a projection of the number of MW that may commit to 
the JTIQ Portfolio from all ERAS and study clusters to date, including the current study 
cluster(s).   
 
Preliminary System Impact Study shall mean the Interconnection System Impact Study 
performed during Definitive Planning Phase I. 
 
Pre-Queue Phase shall mean Interconnection Customer outreach and education effort 
undertaken prior to the submission of the Interconnection Request.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
 
Proportional Impact Method shall mean a technical analysis conducted by 
Transmission Provider to determine the degree to which each Generating Facility in the Group 
Study contributes to the need for a specific Network Upgrade. 
 
Provisional Generator Interconnection Agreement shall mean the interconnection 
agreement for Provisional Interconnection Service established between the Transmission 
Provider and/or the Transmission Owner and the Interconnection Customer as set forth in 
Section 7.9 of this Attachment X.  This agreement shall take the form of the Generator 
Interconnection Agreement modified for provisional purposes.  Unless otherwise provided in the 
GIP, all requirements applicable to the Generator Interconnection Agreement shall apply to the 
Provisional Generator Interconnection Agreement. 
 
Provisional Interconnection Service shall mean Interconnection Service provided by 
the Transmission Provider associated with interconnecting the Interconnection Customer’s 
Generating Facility to the Transmission Provider’s Transmission System and enabling that 
Transmission System to receive electric energy and capacity from the Generating Facility at the 
Point of Interconnection, pursuant to the terms of the Provisional Generator Interconnection 
Agreement and the Tariff. 
 
Provisional Interconnection Study shall mean an engineering study, performed at 
Interconnection Customer’s request, as a condition to entering into a Provisional Generator 
Interconnection Agreement,  that evaluates the impact of the proposed interconnection on the 
safety and reliability of the Transmission System and, if applicable, any Affected System.  The 
study shall identify and detail the impacts on the Transmission System and, if applicable, an 
Affected System, from stability, short circuit, and voltage issues that would result if the 
Generating Facility were interconnected without project modifications or system modifications. 
 
Qualified Change shall mean a planned modification to an Existing Generating Facility 
that is undergoing evaluation for a Generating Facility Modification or Generating Facility 
Replacement, and has a material adverse impact on the Transmission System with respect to: i)

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
steady-state thermal or voltage limits, ii) dynamic system stability and response, or iii) short-
circuit capability limit; compared to the impacts of the Existing Generating Facility prior to the 
modification or replacement. 
 
Queue Position shall mean the order of a valid Interconnection Request, relative to all 
other pending valid Interconnection Requests pursuant to Section 4.1 of the GIP. 
 
Reasonable Efforts shall mean, with respect to an action required to be attempted or 
taken by a Party under this Generator Interconnection Agreement, efforts that are timely and 
consistent with Good Utility Practice and are otherwise substantially equivalent to those a Party 
would use to protect its own interests. 
 
Relevant Electric Retail Regulatory Authority (RERRA) shall mean an entity that has 
jurisdiction over and establishes prices and/or policies for providers of retail electric service to 
end-customers, such as the city council for a municipal utility, the governing board of a 
cooperative utility, the state public utility commission or any such entity. 
 
Reliability Assessment Study shall mean an engineering study that evaluates the impact 
of a proposed Generating Facility Replacement on the reliability of Transmission System during 
the time period between the date that the Existing Generating Facility ceases commercial 
operations and the Commercial Operation Date of the Replacement Generating Facility. 
 
Replacement Generating Facility shall mean a Generating Facility that replaces an 
Existing Generating Facility, or a portion thereof, at the same electrical Point of Interconnection 
pursuant to Section 3.7 of this Attachment X. 
 
Replacement Impact Study shall mean an engineering study that evaluates the impact of 
a proposed Generating Facility Replacement on the reliability of the Transmission System. 
 
Revised System Impact Study shall mean the Interconnection System Impact Study 
performed during Definitive Planning Phase II.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
 
Scoping Meeting shall mean the meeting between representatives of Interconnection 
Customer, Transmission Owner, Affected System  and Transmission Provider conducted for the 
purpose of discussing the proposed Interconnection Request and any alternative interconnection 
options, exchanging information including any transmission data and earlier study evaluations 
that would be reasonably expected to impact such interconnection options,  refining information 
and models provided by Interconnection Customer(s), discussing the Group Study materials 
posted to OASIS pursuant to Section 3.4 of the GIP, and analyzing such information. 
 
Shared Interconnection Request shall mean (1) multiple Interconnection Customer’s 
request, in the form of Appendix 1 to the Generator Interconnection Procedures, to interconnect 
new Generating Facilities, or to increase the capacity of, or make a Material Modification to the 
operating characteristics of, Existing Generating Facilities that are interconnected with the 
Transmission System, or to interconnect Existing Generating Facilities that are external to the 
Transmission System, or to change Energy Resource Interconnection Service to Network 
Resource Interconnection Service for Existing Generating Facilities; or (2) multiple MHVDC 
Connection Customer’s request, in the form of Appendix 1 to the Generator Interconnection 
Procedures, to obtain Injection Rights. 
 
Shared Network Upgrade shall mean a Network Upgrade or Common Use Upgrade that 
is funded by an Interconnection Customer(s), including when the Transmission Owner elects to 
fund the capital cost of such a Network Upgrade or Common Use Upgrade under Section 11.3 of 
the GIA, and also benefits other Interconnection Customer(s) that are later identified as 
beneficiaries.  
 
Site Control shall mean a documented right for one or more parcels of land for the 
purpose of constructing a Generating Facility, Interconnection Customer’s Interconnection 
Facilities, and, if applicable (i.e., when the Interconnection Customer is providing the site for 
such facilities), the Transmission Owner’s Interconnection Facilities and Network Upgrades at 
the POI that the Interconnection Customer will develop.  Such documented right shall be one of 
the following:  (1) ownership of a site; (2) a leasehold interest in a site; or (3) an option to

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
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purchase or acquire a leasehold interest in a site; or (4) any other contractual or legal right to 
possess or occupy a site.  Transmission Provider will maintain acreage requirements for each 
Generating Facility type on its OASIS or public website. 
 
Small Generating Facility shall mean a Generating Facility that has an aggregate net 
Generating Facility Capacity of no more than five MW and meets the requirements of Section 14 
and Appendix 3 of the GIP.  
 
Southwest Power Pool (SPP) shall refer to the Southwest Power Pool, Inc. the Regional 
Transmission Organization that is the counterparty to Rate Schedule 6 (MISO-SPP JOA). 
 
Special Protection System (SPS) shall mean an automatic protection system or remedial 
action scheme designed to detect abnormal or predetermined system conditions, and take 
corrective actions other than and/or in addition to the isolation of faulted components, to 
maintain system reliability.  Such action may include changes in demand (MW and MVar), 
energy (MWh and MVarh), or system configuration to maintain system stability, acceptable 
voltage, or power flows.  An SPS does not include (a) underfrequency or undervoltage load 
shedding, (b) fault conditions that must be isolated, (c) out-of-step relaying not designed as an 
integral part of an SPS, or (d) Transmission Control Devices. 
 
Stand Alone Network Upgrades shall mean Network Upgrades, that are not part of an 
Affected System or a JTIQ Upgrade, that Interconnection Customer may construct without 
affecting day-to-day operations of the Transmission System during their construction.  
Transmission Provider, Transmission Owner and Interconnection Customer must agree as to 
what constitutes Stand Alone Network Upgrades and identify them in Appendix A to this GIA.  
If the Transmission Provider or Transmission Owner and Interconnection Customer disagree 
about whether a particular Network Upgrade is a Stand Alone Network Upgrade, the 
Transmission Provider or Transmission Owner that disagrees with the Interconnection Customer 
must provide the Interconnection Customer a written technical explanation outlining why the 
Transmission Provider or Transmission Owner does not consider the Network Upgrade to be a 
Stand Alone Network Upgrade within fifteen (15) Business Days of its determination.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
 
Supplemental Affected System Analysis shall mean the affected systems analysis 
described in Section 7.3.2.3.1 of this GIP and Section 9.4.2.e.iii.a.i of the Rate Schedule 6 
(MISO-SPP JOA) to determine if Supplemental Affected System Upgrades are required for one 
or more JTIQ Participation Group member(s). 
 
Substation Network Upgrades shall mean Network Upgrades that are required at or 
near the Point of Interconnection and are identified in the first portion of the Interconnection 
Facilities Study as described in GIP Section 7.3.2.5. 
 
Supplemental Affected System Upgrade shall mean a Network Upgrade in addition to 
those required to address the impact of interconnection requests in the current study cluster as 
described in Section 9.4.2.e.iii.a.i of Rate Schedule 6 (MISO-SPP-JOA). 
 
Surplus Interconnection Service shall mean any Interconnection Service that is derived 
from the unneeded portion of Interconnection Service established in a GIA or in agreement with, 
or under the tariff of, a Transmission Owner prior to integration into MISO, such that if Surplus 
Interconnection Service is utilized the total amount of Interconnection Service at the Point of 
Interconnection would remain the same. 
 
System Planning and Analysis Phase shall mean the phase of the Generator 
Interconnection Procedure process, prior to January 4, 2017, which consisted of an 
Interconnection System Impact Study for those Interconnection Requests that were studied in 
this phase.   
 
System Protection Facilities shall mean the equipment, including necessary protection 
signal communications equipment, required to protect (1) the Transmission System or other 
delivery systems or other generating systems from faults or other electrical disturbances 
occurring at the Generating Facility and (2) the Generating Facility from faults or other electrical 
system disturbances occurring on the Transmission System or on other delivery systems or other 
generating systems to which the Transmission System is directly connected.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
 
Target MW Value shall mean the projected new generation interconnection MW 
enabled by the JTIQ Portfolio.  The Target MW Value for each JTIQ Portfolio shall be identified 
in Section 9.4 and related subsections of Rate Schedule 6. 
 
Tariff shall mean the Transmission Provider’s Tariff through which open access 
transmission service and Interconnection Service are offered, as filed with the Commission, and 
as amended or supplemented from time to time, or any successor tariff.   
 
Threshold Charge shall mean the charge calculated using an estimate of plant in service 
value for the JTIQ Portfolio, excluding amounts funded under the GRIP Program, as described in 
Section 9.4.2 of Rate Schedule 6 (MISO-SPP JOA). 
 
Transient Tolerance Window shall mean the period of time after a reduction or loss of 
load by the ZG Associated Load by the end of which window the Generating Facility with ZG 
Interconnection Service must have reduced its injections to an amount not greater than the Load 
of the ZG Associated Load.  The Transient Tolerance Window shall be no greater than 20 
seconds, and is further described by the Business Practices Manual for Large Load.  The 
Transient Tolerance Window will be subject to Transmission Owner local planning criteria. 
 
Transmission Control Devices shall mean a generally accepted transmission device that 
is planned and designed to provide dynamic control of electric system quantities, and are usually 
employed as solutions to specific system performance issues.  Examples of such devices include 
fast valving, high response exciters, high voltage DC links, active or real power flow control and 
reactive compensation devices using power electronics (e.g., unified power flow controllers), 
static var compensators, thyristor controlled series capacitors, braking resistors, and in some 
cases mechanically-switched capacitors and reactors.  In general, such systems are not 
considered to be Special Protection Systems. 
 
Transmission Owner shall mean that Transmission Owner as defined in the Tariff, 
which includes an entity that owns, leases or otherwise possesses an interest in the portion of the

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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Transmission System at which Interconnection Customer proposes to interconnect or otherwise 
integrate the operation of the Generating Facility.  Transmission Owner should be read to include 
any Independent Transmission Company that manages the transmission facilities of 
Transmission Owner and shall include, as applicable, the owner and/or operator of distribution 
facilities interconnected to the Transmission System, over which facilities transmission service 
or Wholesale Distribution Service under the Tariff is available at the time Interconnection 
Customer requests Interconnection Service and to which Interconnection Customer has requested 
interconnection of a Generating Facility for the purpose of either transmitting electric energy in 
interstate commerce or selling electric energy at wholesale in interstate commerce. 
 
Transmission Provider shall mean the Midcontinent Independent System Operator, Inc. 
(“MISO”), the Regional Transmission Organization that controls or operates the transmission 
facilities of its transmission-owning members used for the transmission of electricity in interstate 
commerce and provides transmission service under the Tariff. 
 
Transmission Owner’s Interconnection Facilities (TOIF) shall mean all facilities and 
equipment owned by Transmission Owner from the Point of Change of Ownership to the Point 
of Interconnection as identified in Appendix A to this GIA, including any modifications, 
additions or upgrades to such facilities and equipment.  Transmission Owner’s Interconnection 
Facilities are sole use facilities and shall not include Distribution Upgrades, Generator Upgrades, 
Stand Alone Network Upgrades or Network Upgrades.  
 
Transmission System shall mean the facilities owned by Transmission Owner and 
controlled or operated by Transmission Provider or Transmission Owner that are used to provide 
Transmission Service (including HVDC Service) or Wholesale Distribution Service under the 
Tariff.  
 
Trial Operation shall mean the period during which Interconnection Customer is 
engaged in on-site test operations and commissioning of the Generating Facility prior to 
Commercial Operation.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
User-Defined Model shall mean any set of programming code created by equipment 
manufacturers or developers that captures the latest features of controllers that are mainly 
software-based and represent the entities’ control strategy but does not necessarily correspond to 
any particular generic library model, as contained in Attachment A to Appendix 1 of the GIP. 
 
Variable Energy Resource shall mean a device for the production of electricity that is 
characterized by an energy source that: (1) is renewable; (2) cannot be stored by the facility 
owner or operator; and (3) has variability that is beyond the control of the facility owner or 
operator. 
 
Wholesale Distribution Service shall have that meaning as provided in the Tariff.  
Wherever the term “transmission delivery service” is used, Wholesale Distribution Service shall 
also be implied. 
 
Zero Injection Generation (ZG) Associated Load shall mean a source of electrical load 
that has a Point of Withdrawal that is at the same substation as the Point of Interconnection to the 
Transmission System (i.e. same voltage level at the interconnecting substation) as the Generating 
Facility with ZG Interconnection Service that will serve it. 
 
Zero Injection Generation (ZG) Interconnection Service shall mean a limited form of 
Interconnection Service that allows an Interconnection Customer to connect its Generating 
Facility to the Transmission System or Distribution System, as applicable, for the limited 
purpose of delivering energy to ZG Associated Load.  ZG Interconnection Service does not grant 
any right to inject energy onto the Transmission System except as may be authorized by Section 
3.11 of the Generator Interconnection Procedures.  ZG Interconnection Service does not convey 
Transmission Service.  ZG Interconnection Service also does not provide a right to serve, or a 
right to Transmission Service to serve, a ZG Associated Load or retail customer except as 
allowed by applicable state law. 
 
Zero Injection Generation (ZG) Resource shall mean a generating resource with an 
Attachment X defined ZG Interconnection Agreement.  A ZG Resource may participate as a

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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Effective On: October 18, 2026
Generation Resource, Dispatchable Intermittent Resource, Electric Storage Resource, or Behind 
the Meter Generation resource. 
ZG Facilities Study shall mean the study described in Section 3.2.5.2.2 of these GIP that 
is used to identify any Network Upgrades or Interconnection Facilities that may be needed to for  
an Interconnection Request seeking ZG Interconnection Service. 
 
ZG Impact Assessment shall mean the study described in Section 3.2.5.2.1 of these GIP 
that is used to evaluate the impact of an Interconnection Request seeking ZG Interconnection 
Services. 
 
ZG Interconnection Agreement (ZGIA) shall mean the form of interconnection 
agreement governing the terms and conditions of ZG Interconnection Service, set forth in 
Appendix 19 to the GIP.  This agreement shall follow the form of the Transmission Provider’s 
pro forma Generator Interconnection Agreement with modifications to reflect ZG 
Interconnection Service and the ZG Interconnection Service study process.  Unless otherwise 
provided in the GIP, all requirements applicable to the pro forma Generator Interconnection 
Agreement shall apply to the ZGIA.  A ZGIA is a form of GIA and, where used in the Tariff, 
references to Generator Interconnection Agreements or GIAs encompasses ZGIAs. 
 
ZG Interconnection Process Quarterly Study Period shall mean the period of time in 
which Interconnection Requests seeking ZG Interconnection Service are submitted to the 
Transmission Provider and compiled for study.  There are four study periods in a year with the 
following start and end dates: 
Quarter 1: The first Business Day of March through the last Business Day of May; 
Quarter 2: The first Business Day of June through the last Business Day of August; 
Quarter 3: The first Business Day of September through the last Business Day of 
November; 
Quarter 4: The first Business Day of December through the last Business Day of 
February.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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Effective On: October 18, 2026
ARTICLE 2.  EFFECTIVE DATE, TERM AND TERMINATION 
 
2.1 
Effective Date.  This ZGIA shall become effective upon execution by the Parties subject 
to acceptance by FERC (if applicable), or if filed unexecuted, upon the date specified by 
FERC.  Transmission Provider shall promptly file this ZGIA with FERC upon execution 
in accordance with Article 3.1, if required. 
 
2.2 
Term of Agreement.  Subject to the provisions of Article 2.3, this ZGIA shall remain in 
effect for a period of ______ years from the Effective Date and shall be automatically 
renewed for each successive one-year period thereafter on the anniversary of the 
Effective Date. 
 
2.3 
Termination Procedures.  This ZGIA may be terminated as follows: 
 
2.3.1 Written Notice.  This ZGIA may be terminated by Interconnection Customer 
after giving Transmission Provider and Transmission Owner ninety (90) Calendar 
Days advance written notice.  This ZGIA shall be terminated by Transmission 
Provider if the Generating Facility or a portion of the Generating Facility fails to 
achieve Commercial Operation by the Commercial Operation Date established in 
accordance with Section 4.4.4 of Attachment X, including any extension provided 
thereunder, or has ceased Commercial Operation for three (3) consecutive years, 
beginning with the last date of Commercial Operation for the Generating Facility, 
after giving Interconnection Customer ninety (90) Calendar Days advance written 
notice.  Where only a portion of the Generating Facility fails to achieve 
Commercial Operation by the Commercial Operation Date established in 
accordance with Section 4.4.4 of Attachment X, including any extension provided 
thereunder, Transmission Provider shall only terminate that portion of the ZGIA.  
Notwithstanding the foregoing, in the limited circumstance that the 
Interconnection Request is served by a contingent Network Upgrade with an in-
service date that is farther out than the Commercial Operation Date permitted 
under Section 4.4.4 of Attachment X, Transmission Provider shall only terminate

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
this ZGIA for failure to achieve Commercial Operation by that later in-service 
date of the contingent Network Upgrade.  For the purposes of this ZGIA, 
Commercial Operation shall mean the supply of energy from the Generating 
Facility to the ZG Associated Load identified in Appendix A and exclude sales of 
energy, capacity, or other commercial arrangements regarding the output of the 
Generating Facility with any entity or load source other than the ZG Associated 
Load identified in Appendix A.  The Generating Facility will not be deemed to 
have ceased Commercial Operation for purposes of this Article 2.3.1 if 
Interconnection Customer can document that it has taken other significant steps to 
maintain or restore operational readiness of the Generating Facility for the 
purpose of returning the Generating Facility to Commercial Operation as soon as 
possible. 
 
2.3.1.1 Surplus Interconnection Service. Where this ZGIA provides for Surplus 
Interconnection Service and the Energy Displacement Agreement or the 
Monitoring and Consent Agreement required for Surplus Interconnection 
Service are no longer in effect, Interconnection Customer shall 
immediately cease Commercial Operation of the Generating Facility and 
this ZGIA shall be deemed terminated.  In the event that the Existing 
Generating Facility retires and/or permanently ceases commercial 
operation, the Surplus Interconnection Service provided under this ZGIA 
shall terminate except as provided in Section 3.3.1.3 of the GIP. 
 
2.3.2 Default.  Any Party may terminate this ZGIA in accordance with Article 17. 
 
2.3.3 Notwithstanding Articles 2.3.1 and 2.3.2, no termination shall become effective 
until the Parties have complied with all Applicable Laws and Regulations 
applicable to such termination, including the filing with FERC of a notice of 
termination of this ZGIA, if required, which notice has been accepted for filing by 
FERC.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
For EGIAs, no termination shall become effective until Interconnection Customer 
has provided all security as required by Section 2.4. 
 
 
2.4 
Termination Costs.  If a Party elects to terminate this ZGIA pursuant to Article 2.3 
above, each Party shall pay all costs incurred for which that Party is responsible 
(including any cancellation costs relating to orders or contracts for Interconnection 
Facilities, applicable upgrades, and related equipment) or charges assessed by the other 
Parties, as of the date of the other Parties’ receipt of such notice of termination, under this 
ZGIA. In the event that this ZGIA is terminated by Interconnection Customer, 
Interconnection Customer is responsible for all financial impact that is caused as a result 
of this termination or the termination of Interconnection Customer’s FCA(s) or 
MPFCA(s), such financial impact being determined through the financial impact analysis 
performed in accordance with Section 7.8 of Attachment X. In the event of termination 
by a Party, the Parties shall use commercially Reasonable Efforts to mitigate the costs, 
damages and charges arising as a consequence of termination.  Upon termination of this 
ZGIA, unless otherwise ordered or approved by FERC: 
 
In the event that this EGIA is terminated by Interconnection Customer that had an 
Interconnection Request studied in ERAS, Interconnection Customer is responsible for 
the full cost of all Network Upgrades identified in this EGIA as well as any Network 
Upgrades identified during the ERAS process that are to be memorialized in an 
agreement other that this EGIA, including any applicable FCA, MPFCA, or JTIQ Service 
Agreements.  If the Network Upgrade costs for Network Upgrades subject to an FCA, 
MPFCA, or JTIQ Service Agreement have not been finalized or the Interconnection 
Customer has not made the payment under such agreement as of the date that termination 
of this EGIA is sought, Interconnection Customer shall provide the payment or security 
for such Network Upgrades in the amount required by the applicable agreement.  If such 
agreement has not been executed and final costs are not available as of a date that 
termination is sought, Interconnection Customer shall provide such payment or security 
in an amount corresponding to the most recent estimate provided by the Transmission

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
Provider during the ERAS process.  Interconnection Customer shall pay or Transmission 
Provider shall refund, as applicable, to Interconnection Customer the difference between 
the amount of any estimated payment or security made pursuant to this Article and the 
final cost of such NU within ninety (90) Calendar Days after such final costs are invoiced 
to the Interconnection Customer. 
 
 
2.4.1 With respect to any portion of the Transmission Owner’s Interconnection 
Facilities, Network Upgrades, System Protection Facilities, Distribution 
Upgrades, Generator Upgrades, and if so determined and made a part of this 
ZGIA, upgrades on Affected Systems, that have not yet been constructed or 
installed, Transmission Owner shall to the extent possible and to the extent of 
Interconnection Customer’s written notice under Article 2.3.1, cancel any pending 
orders of, or return, any materials or equipment for, or contracts for construction 
of, such facilities; provided that in the event Interconnection Customer elects not 
to authorize such cancellation, Interconnection Customer shall assume all 
payment obligations with respect to such materials, equipment, and contracts, and 
Transmission Owner shall deliver such material and equipment, and, if necessary, 
assign such contracts, to Interconnection Customer as soon as practicable, at 
Interconnection Customer’s expense.  To the extent that Interconnection 
Customer has already paid Transmission Owner for any or all such costs of 
materials or equipment not taken by Interconnection Customer or upgrades not 
yet constructed, Transmission Owner shall promptly transfer such amounts to 
Transmission Provider, less any costs, including penalties incurred by 
Transmission Owner to cancel any pending orders of or return such materials, 
equipment, or contracts.  Except for agreements providing for ZG Interconnection 
Service, Transmission Provider will perform a financial impact analysis in 
accordance with Section 7.8 of Attachment X to determine the amount that should 
be refunded to Interconnection Customer.  Except for agreements providing for 
ZG Interconnection Service, Transmission Provider shall refund such remaining 
amounts to Interconnection Customer, less the amount of Automatic Withdrawal 
Penalty funds received by the Interconnection Customer in accordance with

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
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Section 7.8.1 of the Attachment X and less any financial impact caused by the 
termination of this ZGIA or Interconnection Customer’s FCA(s) or MPFCA(s), as 
determined through the analysis performed in accordance with Section 7.8 of 
Attachment X. If Interconnection Customer made its payment(s) through a letter 
of credit, surety bond, or parental guarantee, Transmission Owner will draw 
against that letter of credit, surety bond, or parental guarantee in an amount 
determined through the analysis performed in accordance with Section 7.8 of 
Attachment X plus the amount of any Automatic Withdrawal Penalty funds 
received by the Interconnection Customer in accordance with Section 7.8.1 of the 
Attachment X, and transfer that amount to Transmission Provider, unless 
Interconnection Customer funds the financial impact through another means. 
 
If an Interconnection Customer terminates this ZGIA, it shall be responsible for 
all costs incurred in association with that Interconnection Customer’s 
interconnection, including any cancellation costs relating to orders or contracts for 
Interconnection Facilities and equipment, and other expenses including any 
upgrades or related equipment for which Transmission Owner has incurred 
expenses and has not been reimbursed by Interconnection Customer. 
 
2.4.2 Transmission Owner may, at its option, retain any portion of such materials, 
equipment, or facilities that Interconnection Customer chooses not to accept 
delivery of, in which case Transmission Owner shall be responsible for all costs 
associated with procuring such materials, equipment, or facilities.  If 
Transmission Owner does not so elect, then Interconnection Customer shall be 
responsible for such costs. 
 
2.4.3 With respect to any portion of the Interconnection Facilities, and any other 
facilities already installed or constructed pursuant to the terms of this ZGIA, 
Interconnection Customer shall be responsible for all costs associated with the 
removal, relocation, reconfiguration or other disposition or retirement of such 
materials, equipment, or facilities, and such other expenses actually incurred by

MISO 
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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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Transmission Owner necessary to return the Transmission, Distribution or 
Generator System, as applicable, to safe and reliable operation. 
 
2.5 
Disconnection.  Upon termination of this ZGIA, the Parties will take all appropriate steps 
to disconnect the Generating Facility from the Transmission or Distribution System, as 
applicable.  All costs required to effectuate such disconnection shall be borne by the 
terminating Party, unless such termination resulted from the non-terminating Party’s 
Default of this ZGIA or such non-terminating Party otherwise is responsible for these 
costs under this ZGIA.  
 
2.6 
Survival.  This ZGIA shall continue in effect after termination to the extent necessary to 
provide for final billings and payments and for costs incurred hereunder, including 
billings and payments pursuant to this ZGIA; to permit the determination and 
enforcement of liability and indemnification obligations arising from acts or events that 
occurred while this ZGIA was in effect; and to permit each Party to have access to the 
lands of the other Party pursuant to this ZGIA or other applicable agreements, to 
disconnect, remove or salvage its own facilities and equipment. 
 
ARTICLE 3.  REGULATORY FILINGS 
 
3.1 
Filing.  Transmission Provider shall file this ZGIA (and any amendment hereto) with the 
appropriate Governmental Authority, if required.  A Party may request that any 
information so provided be subject to the confidentiality provisions of Article 22.  If that 
Party has executed this ZGIA, or any amendment thereto, the Party shall reasonably 
cooperate with Transmission Provider with respect to such filing and to provide any 
information reasonably requested by Transmission Provider needed to comply with 
applicable regulatory requirements.  
 
ARTICLE 4.  SCOPE OF SERVICE

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4.1 
Interconnection Product Options.  Interconnection Customer has selected the following 
(checked) type of Interconnection Service:  
 
 
Check: : ____ ZG or ____ SI or  ____ ER and/or ____ NR (See Appendix A for 
details) 
 
4.1.1 Energy Resource Interconnection Service (ER Interconnection Service). 
 
4.1.1.1 The Product.  ER Interconnection Service allows Interconnection 
Customer to connect the Generating Facility to the Transmission or 
Distribution System, as applicable, and be eligible to deliver the 
Generating Facility’s output using the existing firm or non-firm capacity 
of the Transmission System on an “as available” basis.  To the extent 
Interconnection Customer wants to receive ER Interconnection Service, 
Transmission Owner shall construct facilities consistent with the studies 
identified in Appendix A.   
 
An Interconnection Customer seeking ER Interconnection Service for 
new or added capacity at a Generating Facility may be granted 
conditional ER Interconnection Service status to the extent there is such 
capacity available on the Transmission System to accommodate the 
Interconnection Customer’s Generating Facility.  At the request of 
Interconnection Customer, conditional ER Interconnection Service status 
may be granted subject to the system being able to accommodate the 
interconnection without upgrades, until such time as a higher queued 
project(s) with a later service date affecting the same common elements 
is placed into service.  The conditional ER Interconnection Service shall 
be terminated in the event Interconnection Customer fails to fund the 
necessary studies and the Network Upgrades necessary to grant the 
Interconnection Customer’s ER Interconnection Service upon the

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completion of higher queued projects involving the same common 
elements. 
 
4.1.1.2 Transmission Delivery Service Implications.  Under ER 
Interconnection Service, Interconnection Customer will be eligible to 
inject power from the Generating Facility into and deliver power across 
the Transmission System on an “as available” basis up to the amount of 
MW identified in the applicable stability and steady state studies to the 
extent the upgrades initially required to qualify for ER Interconnection 
Service have been constructed.  After that date FERC makes effective 
MISO’s Energy Market Tariff filed in Docket No. ER04-691-000, 
Interconnection Customer may place a bid to sell into the market up to 
the maximum identified Generating Facility output, subject to any 
conditions specified in the Interconnection Service approval, and the 
Generating Facility will be dispatched to the extent the Interconnection 
Customer’s bid clears.  In all other instances, no transmission or other 
delivery service from the Generating Facility is assured, but 
Interconnection Customer may obtain Point-To-Point Transmission 
Service, Network Integration Transmission Service or be used for 
secondary network transmission service, pursuant to the Tariff, up to the 
maximum output identified in the stability and steady state studies.  In 
those instances, in order for Interconnection Customer to obtain the right 
to deliver or inject energy beyond the Point of Interconnection or to 
improve its ability to do so, transmission delivery service must be 
obtained pursuant to the provisions of the Tariff.  The Interconnection 
Customer’s ability to inject its Generating Facility output beyond the 
Point of Interconnection, therefore, will depend on the existing capacity 
of the Transmission or Distribution System as applicable, at such time as 
a Transmission Service request is made that would accommodate such 
delivery.  The provision of Firm Point-To-Point Transmission Service or

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Network Integration Transmission Service may require the construction 
of additional Network or Distribution Upgrades. 
 
4.1.2 Network Resource Interconnection Service (NR Interconnection Service). 
 
4.1.2.1 The Product.  Transmission Provider must conduct the necessary 
studies and Transmission Owner shall construct the facilities identified 
in Appendix A of this GIA, subject to the approval of Governmental 
Authorities, needed to integrate the Generating Facility in the same 
manner as for any Generating Facility being designated as a Network 
Resource.   
 
4.1.2.2 Transmission Delivery Service Implications.  NR Interconnection 
Service allows the Generating Facility to be designated by any Network 
Customer under the Tariff on the Transmission System as a Network 
Resource, up to the Generating Facility’s full output, on the same basis 
as existing Network Resources that are interconnected to the 
Transmission or Distribution System, as applicable, and to be studied as 
a Network Resource on the assumption that such a designation will 
occur.  Although NR Interconnection Service does not convey a 
reservation of Transmission Service, any Network Customer can utilize 
Network Integration Transmission Service under the Tariff to obtain 
delivery of energy from the Generating Facility in the same manner as it 
accesses Network Resources.  A Generating Facility receiving NR 
Interconnection Service may also be used to provide Ancillary Services 
after technical studies and/or periodic analyses are performed with 
respect to the Generating Facility’s ability to provide any applicable 
Ancillary Services, provided that such studies and analyses have been or 
would be required in connection with the provision of such Ancillary 
Services by any existing Network Resource.  However, if the 
Generating Facility has not been designated as a Network Resource by

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any Network Customer, it cannot be required to provide Ancillary 
Services except to the extent such requirements extend to all generating 
facilities that are similarly situated.  The provision of Network 
Integration Transmission Service or Firm Point-To-Point Transmission 
Service may require additional studies and the construction of additional 
upgrades.  Because such studies and upgrades would be associated with 
a request for delivery service under the Tariff, cost responsibility for the 
studies and upgrades would be in accordance with FERC’s policy for 
pricing transmission delivery services. 
 
NR Interconnection Service does not necessarily provide Interconnection 
Customer with the capability to physically deliver the output of its 
Generating Facility to any particular load on the Transmission System 
without incurring congestion costs.  In the event of transmission or 
distribution constraints on the Transmission or Distribution System, as 
applicable, the Generating Facility shall be subject to the applicable 
congestion management procedures in the Transmission System in the 
same manner as Network Resources. 
 
There is no requirement either at the time of study or interconnection, or 
at any point in the future, that the Generating Facility be designated as a 
Network Resource by a Network Customer or that Interconnection 
Customer identify a specific buyer (or sink).  To the extent a Network 
Customer does designate the Generating Facility as a Network Resource, 
it must do so pursuant to the Tariff. 
 
Once an Interconnection Customer satisfies the requirements for 
obtaining NR Interconnection Service, any future Transmission Service 
request for delivery from the Generating Facility within the 
Transmission System of any amount of capacity and/or energy, up to the 
amount initially studied, will not require that any additional studies be

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performed or that any further upgrades associated with such Generating 
Facility be undertaken, regardless of whether such Generating Facility is 
ever designated by a Network Customer as a Network Resource and 
regardless of changes in ownership of the Generating Facility.  To the 
extent Interconnection Customer enters into an arrangement for long 
term Transmission Service for deliveries from the Generating Facility to 
customers other than the studied Network Customers, or for any Point-
To-Point Transmission Service, such request may require additional 
studies and upgrades in order for Transmission Provider to grant such 
request.  However, the reduction or elimination of congestion or 
redispatch costs may require additional studies and the construction of 
additional upgrades. 
 
To the extent Interconnection Customer enters into an arrangement for 
long term Transmission Service for deliveries from the Generating 
Facility outside the Transmission System, such request may require 
additional studies and upgrades in order for Transmission Provider to 
grant such request. 
 
4.1.2.3 Conditional NR Interconnection Service.  An Interconnection Customer 
seeking NR Interconnection Service for new or added capacity at a 
Generating Facility may be granted conditional NR Interconnection 
Service status to the extent there is such capacity available on the 
Transmission System to accommodate the Interconnection Customer’s 
Generating Facility.  At the request of Interconnection Customer, 
conditional NR Interconnection Service status may be granted subject to 
the system being able to accommodate the interconnection without 
upgrades, until such time as higher queued project(s) with a later service 
date affecting the same common elements is placed into service.  The 
conditional NR Interconnection Service status may be converted to ER 
Interconnection Service if either of the following occurs:

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1)  
Interconnection Customer fails to fund necessary studies and 
Network Upgrades required to allow the Interconnection 
Customer’s Generating Facility to receive NR Interconnection 
Service upon the completion of higher queued projects involving 
the same common elements; or 
 
2)  
The higher queued project(s) or planned and required Network 
Upgrades are placed in service and the Network Upgrades required 
to provide NR Interconnection Service status to the 
Interconnection Customer’s Generating Facility are not in service. 
 
In the event Interconnection Customer fails to fund the necessary studies 
and Network Upgrades for NR Interconnection Service, the 
Interconnection Customer’s conditional NR Interconnection Service status 
shall be converted to ER Interconnection Service status unless 
Interconnection Customer makes a new Interconnection Request.  Such 
new Interconnection Request shall be evaluated in accordance with the 
GIP and its new queue position.  
 
Some or all of the conditional NR Interconnection Service status may be 
temporarily revoked if the Network Upgrades are not in service when the 
higher queued project(s) are placed in service.  The availability of 
conditional NR Interconnection Service status will be determined by 
Transmission Provider’s studies.  Upon funding and completion of the 
Network Upgrades required to establish the Generating Facility’s NR 
Interconnection Service status, the Generating Facility will be granted NR 
Interconnection Service status. 
 
The Parties agree that the portion of the Generating Facility classified as 
NR Interconnection Service is the first portion of the output of the

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combined output of all the units at the Generating Facility except in 
circumstances where Interconnection Customer otherwise elects this GIA, 
as amended, to allocate that portion to the output of specific unit(s) at the 
Generating Facility, the total of which will not exceed the output eligible 
for NR Interconnection Service as shown by the additional studies.  To the 
extent Interconnection Customer desires to obtain NR Interconnection 
Service for any portion of the Generating Facility in addition to that 
supported by such additional studies, Interconnection Customer will be 
required to request such additional NR Interconnection Service through a 
separate Interconnection Request in accordance with the GIP. 
 
4.1.3 Surplus Interconnection Service (SI). 
 
4.1.3.1 The Product.  Surplus Interconnection Service is restricted 
Interconnection Service that allows an Interconnection Customer to 
increase the gross generating capability at the same Point of 
Interconnection of an Existing Generating Facility without increasing the 
total amount of Interconnection Service at the Point of Interconnection.   
 
4.1.3.2 Transmission Delivery Service Implications.  Surplus Interconnection 
Service does not convey any right to deliver electricity to any specific 
customer or Point of Delivery.  
 
4.1.4 ZG Interconnection Service. 
 
4.1.4.1 The Product.  ZG Interconnection Service is restricted Interconnection 
Service that allows an Interconnection Customer to connect its Generating 
Facility to the Transmission System or Distribution System, as applicable, 
for the limited purpose of delivering Energy to a source of electrical load 
that is at the same substation as the Point of Interconnection to the 
Transmission System (i.e., same voltage level at the interconnecting

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substation) as the Generating Facility with ZG Interconnection Service 
that will serve it. 
 
 
This service is available only if the study required by Section 3.2.3.2 of 
the GIP determines that the proposed interconnection:   
(1) 
will not result in any injections of Energy onto the Transmission 
System beyond the substation identified in the Interconnection 
Request as the Point of Interconnection.  The restriction on Energy 
injection in this paragraph shall not apply to transient, limited 
injections associated with a reduction or loss of Load by the ZG 
Associated Load provided these remain within the Transient 
Tolerance Window established in the Business Practices Manual 
for Large Load.   
 
(2) 
will not require the construction or modification of any Network 
Upgrades to address impacts to the Transmission System with the 
exception of Network Upgrades located at the same substation as 
the POI and system protection facilities at adjacent substations.  
 
 
 
ZG Interconnection Service is specific to the ZG Associated Load(s) that the 
Generating Facility identifies in its Interconnection Request, and which shall be 
memorialized in the ZGIA.  The Generating Facility’s requesting ZG 
Interconnection Service will be dispatched, and granted service at a level not to 
exceed the total Demand of the ZG Associated Load. 
 
4.1.4.2 Transmission Delivery Service Implications.   
ZG Interconnection Service does not grant any right to inject energy onto 
the Transmission System beyond the Point of Interconnection except as 
may be authorized by Section 3.11.1(a) of these Generator Interconnection 
Procedures.  ZG Interconnection Service does not provide interconnection 
service for the purpose of serving Load other than the ZG Associated 
Load(s) identified in the Interconnection Request and memorialized in the

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ZGIA. ZG Interconnection Service does not convey transmission service, 
which is obtained through a separate process, and does not provide a right 
to serve, or a right to transmission service to serve, a ZG Associated Load 
or retail customer except as allowed by state laws and regulations.   
 
 
4.2 
Provision of Service.  Transmission Provider shall provide Interconnection Service for 
the Generating Facility at the Point of Interconnection. 
 
4.3 
Performance Standards.  Each Party shall perform all of its obligations under this ZGIA 
in accordance with Applicable Laws and Regulations, Applicable Reliability Standards, 
and Good Utility Practice.  To the extent a Party is required or prevented or limited in 
taking any action by such regulations and standards, or if the obligations of any Party 
may become limited by a change in Applicable Laws and Regulations, Applicable 
Reliability Standards, and Good Utility Practice after the execution of this ZGIA, that 
Party shall not be deemed to be in Breach of this ZGIA for its compliance therewith.  The 
Party so limited shall notify the other Parties whereupon Transmission Provider shall 
amend this ZGIA in concurrence with the other Parties and submit the amendment to the 
Commission for approval.  The ZG Interconnection Service product does not supersede 
any state or local laws or regulations nor does it authorize operations that would violate 
state or local laws and regulations, including those establishing which entities have the 
right or obligation to serve load.  Interconnection Customers are separately responsible 
for adhering to all Applicable Laws and Regulations. 
 
4.4 
No Transmission Delivery Service.  The execution of this ZGIA does not constitute a 
request for, or the provision of, any transmission delivery service under the Tariff, and 
does not convey any right to deliver electricity to any specific customer or Point of 
Delivery.

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4.5 
Interconnection Customer Provided Services.  The services provided by 
Interconnection Customer under this ZGIA are set forth in Article 9.6 and Article 13.4.1.  
Interconnection Customer shall be paid for such services in accordance with Article 11.7. 
 
ARTICLE 5.  INTERCONNECTION FACILITIES ENGINEERING, PROCUREMENT, 
AND CONSTRUCTION 
 
5.1 
Options.  Unless otherwise mutually agreed to between the Parties, Interconnection 
Customer shall select:  1) the In-Service Date, Initial Synchronization Date, and 
Commercial Operation Date based on a reasonable construction schedule that will allow 
sufficient time for design, construction, equipment procurement, and permit acquisition 
of Transmission System equipment or right-of-way; and 2) either the Standard Option or 
Alternate Option set forth below and such dates and selected option shall be set forth in 
Appendix B.  If the dates designated by Interconnection Customer are not acceptable to 
Transmission Owner, Transmission Owner shall so notify Interconnection Customer 
within thirty (30) Calendar Days.  Upon receipt of the notification that Interconnection 
Customer’s designated dates are not acceptable to Transmission Owner, the 
Interconnection Customer shall notify Transmission Owner within thirty (30) Calendar 
Days whether it elects to exercise the Option to Build if it has not already elected to 
exercise the Option to Build.   
 
5.1.1 Standard Option.  Transmission Owner shall design, procure, and construct the 
Transmission Owner’s Interconnection Facilities, Network Upgrades, System 
Protection Facilities, Distribution Upgrades, and Generator Upgrades using 
Reasonable Efforts to complete the Transmission Owner’s Interconnection 
Facilities, Network Upgrades, System Protection Facilities, Distribution Upgrades 
and Generator Upgrades by the dates set forth in Appendix B, Milestones, subject 
to the receipt of all approvals required from Governmental Authorities and the 
receipt of all land rights necessary to commence construction of such facilities, 
and such other permits or authorizations as may be required.  Transmission 
Provider or Transmission Owner shall not be required to undertake any action

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which is inconsistent with its standard safety practices, its material and equipment 
specifications, its design criteria and construction procedures, its labor 
agreements, Applicable Laws and Regulations and Good Utility Practice.  In the 
event Transmission Owner reasonably expects that it will not be able to complete 
the Transmission Owner’s Interconnection Facilities, Network Upgrades, System 
Protection Facilities, Distribution Upgrades and Generator Upgrades by the 
specified dates, Transmission Owner shall promptly provide written notice to 
Interconnection Customer and Transmission Provider and shall undertake 
Reasonable Efforts to meet the earliest dates thereafter. 
 
5.1.2 Alternate Option.  If the dates designated by Interconnection Customer are 
acceptable to Transmission Provider and Transmission Owner, Transmission 
Provider shall so notify Interconnection Customer within thirty (30) Calendar 
Days, and Transmission Owner shall assume responsibility for the design, 
procurement and construction of the Transmission Owner’s Interconnection 
Facilities by the designated dates. 
 
If Transmission Owner subsequently fails to complete the Transmission Owner’s 
Interconnection Facilities by the In-Service Date, to the extent necessary to 
provide back feed power; or fails to complete Network Upgrades by the Initial 
Synchronization Date to the extent necessary to allow for Trial Operation at full 
power output, unless other arrangements are made by the Parties for such Trial 
Operation; or fails to complete the Network Upgrades by the Commercial 
Operation Date, as such dates are reflected in Appendix B, Milestones; 
Transmission Owner shall pay Interconnection Customer liquidated damages in 
accordance with Article 5.3, Liquidated Damages, provided, however, the dates 
designated by Interconnection Customer shall be extended day for day for each 
Calendar Day that Transmission Provider refuses to grant clearances to install 
equipment. 
 
Transmission Owner and Interconnection Customer may adopt an incentive

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payment schedule that is mutually agreeable to encourage Transmission Owner to 
meet specified accelerated dates.  Such payment by Interconnection Customer is 
not subject to refund. 
 
 
5.1.3 Option to Build.  Pursuant to Section 7.3.2.5 & 7.3.3.5 of the GIP, Individual or 
Multiple Interconnection Customers shall have the option to assume responsibility 
for the design, procurement and construction of the Transmission Owner’s 
Interconnection Facilities and Stand Alone Network Upgrades by the dates 
originally designated by Interconnection Customer under Article 5.1.2, , if the 
requirements of this Article 5.1.3 are met. When multiple Interconnection 
Customers exercise this option, multiple Interconnection Customers may agree to 
exercise this option provided (1) all Transmission Owner’s Interconnection 
Facilities and Stand Alone Network Upgrades constructed under this option are 
only required for Interconnection Customers in a single Cluster and (2) all 
impacted Interconnection Customers execute and provide to Transmission 
Provider an agreement regarding responsibilities, and payment for, the 
construction of Transmission Provider’s Interconnection Facilities and Stand 
Alone Network Upgrades planned to be built under this option.  The Parties must 
agree as to what constitutes Stand Alone Network Upgrades and identify such 
Stand Alone Network Upgrades in Appendix A.  Except for Stand Alone Network 
Upgrades, Interconnection Customer shall have no right to construct Network 
Upgrades under this option. 
 
5.1.4 Negotiated Option.  If the dates designated by Interconnection Customer 
pursuant to Article 5.1 are not acceptable to Transmission Owner, the Parties shall 
in good faith attempt to negotiate terms and conditions (including revision of the 
specified dates and liquidated damages, the provision of incentives, or the 
procurement and construction of all facilities other than Transmission Owner’s 
Interconnection Facilities and Stand Alone Network Upgrades if the 
Interconnection Customer elects to exercise the Option to Build under Article 
5.1.3).  If the Parties are unable to reach agreement on such terms and conditions,

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then, pursuant to Article 5.1.1 (Standard Option), Transmission Owner shall 
assume responsibility for the design, procurement and construction of all facilities 
other than Transmission Owner’s Interconnection Facilities and Stand Alone 
Network Upgrades if Interconnection Customer has elected to exercise the Option 
to Build. 
 
Transmission Owner and Interconnection Customer may adopt an incentive 
payment schedule that is mutually agreeable to encourage Transmission Owner to 
meet specified accelerated dates.  Such payment by Interconnection Customer is 
not subject to refund. 
 
5.2 
General Conditions Applicable to Option to Build.  If Interconnection Customer 
assumes responsibility for the design, procurement and construction of the Transmission 
Owner’s Interconnection Facilities and Stand Alone Network Upgrades after receipt of 
all required approvals from Governmental Authorities necessary to commence 
construction, 
 
(1) Interconnection Customer shall engineer, procure equipment, and construct 
the Transmission Owner’s Interconnection Facilities and Stand Alone Network 
Upgrades (or portions thereof) using Good Utility Practice and using standards 
and specifications provided in advance by Transmission Owner, or as required by 
any Governmental Authority; 
 
(2) Interconnection Customer’s engineering, procurement and construction of the 
Transmission Owner’s Interconnection Facilities and Stand Alone Network 
Upgrades shall comply with all requirements of law or Governmental Authority to 
which Transmission Owner would be subject in the engineering, procurement or 
construction of the Transmission Owner’s Interconnection Facilities and Stand 
Alone Network Upgrades;

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(3) Transmission Provider, at Transmission Provider’s option, and Transmission 
Owner shall be entitled to review and approve the engineering design, equipment 
acceptance tests(including witnessing of acceptance tests), and the construction 
(including monitoring of construction) of the Transmission Owner’s 
Interconnection Facilities and Stand Alone Network Upgrades, and shall have the 
right to reject any design, procurement, construction or acceptance test of any 
equipment that does not meet the standards and specifications of Transmission 
Provider, Transmission Owner and any Governmental Authority; 
 
(4) prior to commencement of construction, Interconnection Customer shall 
provide to Transmission Provider and Transmission Owner a schedule for 
construction of the Transmission Owner’s Interconnection Facilities and Stand 
Alone Network Upgrades, and shall promptly respond to requests for information 
from Transmission Provider and Transmission Owner; 
 
(5) at any time during construction, Transmission Provider and Transmission 
Owner shall have unrestricted access to the construction site for the Transmission 
Owner’s Interconnection Facilities and Stand Alone Network Upgrades and to 
conduct inspections of the same; 
 
(6) at any time during construction, should any phase of the engineering, 
equipment procurement, or construction of the Transmission Owner’s 
Interconnection Facilities and Stand Alone Network Upgrades not meet the 
standards and specifications provided by Transmission Owner, Interconnection 
Customer shall be obligated to remedy deficiencies in that portion of the 
Transmission Owner’s Interconnection Facilities and Stand Alone Network 
Upgrades to meet the standards and specifications provided by Transmission 
Provider and Transmission Owner; 
 
(7) Interconnection Customer shall indemnify Transmission Provider and 
Transmission Owner for claims arising from the Interconnection Customer’s

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construction of the Transmission Owner’s Interconnection Facilities and Stand 
Alone Network Upgrades under the terms and procedures applicable to 
Article 18.1, Indemnity; 
 
(8) Interconnection Customer shall transfer control of the Transmission Owner’s 
Interconnection Facilities and Stand Alone Network Upgrades to Transmission 
Owner; 
 
(9) Unless Parties otherwise agree, Interconnection Customer shall transfer 
ownership of the Transmission Owner’s Interconnection Facilities and Stand 
Alone Network Upgrades to Transmission Owner in accordance with Appendix 
B; 
 
(10) Transmission Provider, at Transmission Provider’s option, and Transmission 
Owner shall approve and accept for operation and maintenance the Transmission 
Owner’s Interconnection Facilities and Stand Alone Network Upgrades to the 
extent engineered, procured, and constructed in accordance with this Article 5.2 
only if the Transmission Owner’s Interconnection Facilities and Stand Alone 
Network Upgrades meet the standards and specifications of Transmission 
Provider, Transmission Owner and any Governmental Authority. 
 
(11) Interconnection Customer shall deliver to Transmission Owner “as-built” 
drawings, information, and any other documents that are reasonably required by 
Transmission Owner to assure that the Interconnection Facilities and Stand-Alone 
Network Upgrades are built to the standards and specifications required by 
Transmission Owner. 
 
(12) If Interconnection Customer exercises the Option to Build pursuant to Article 
5.1.3, Interconnection Customer shall pay Transmission Owner the agreed upon 
amount of [$ PLACEHOLDER] for Transmission Owner to execute the 
responsibilities enumerated to Transmission Owner under Article 5.2.

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Transmission Owner shall invoice Interconnection Customer for this total amount 
to be divided on a monthly basis pursuant to Article 12. 
 
(13) If Interconnection Customer exercises the Option to Build pursuant to Article 
5.1.3, and the Transmission Owner has elected to fund the costs of Network 
Upgrades pursuant to Article 11.3, then prior to Interconnection Customer 
incurring any construction costs relating to the Option to Build and by the date 
specified in Appendix B, Interconnection Customer shall invoice the 
Transmission Owner for the estimated amount to be expended by the 
Interconnection Customer to construct any Stand Alone Network Upgrades for 
which the Interconnection Customer has exercised its Option to Build in 
accordance with Appendix B.  The Transmission Owner shall be required to 
reimburse Interconnection Customer for the full amount of such invoiced costs by 
the date specified in Appendix B, which shall be prior to the date by which 
Interconnection Customer must make any construction payment for such Stand 
Alone Network Upgrades.  After completion of the construction of Stand Alone 
Network Upgrades by the Interconnection Customer and by the date specified in 
Appendix B for the Interconnection Customer to transfer such Stand Alone 
Network Upgrades to the Transmission Owner, Interconnection Customer shall 
provide an invoice of the final cost of the construction of Stand Alone Upgrades 
and shall set forth such costs in sufficient detail to enable the Transmission Owner 
to compare the actual costs with the estimates and to ascertain deviations, if any, 
from the cost estimates.  In the event that the actual costs exceed the estimated 
costs previously invoiced by Interconnection Customer and paid by Transmission 
Owner, Transmission Owner shall pay to Interconnection Customer the difference 
between the amount previously paid and the actual costs within thirty (30) 
Calendar Days after receipt of a final construction invoice from Interconnection 
Customer.  In the event that the actual costs are less than the estimated costs 
previously invoiced by Interconnection Customer and paid by Transmission 
Owner, Interconnection Customer shall refund, with interest (calculated in 
accordance with 18 C.F.R. Section 35.19a(a)(2)(iii), to Transmission Owner any

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amount by which the actual payment by Transmission Owner for estimated costs 
exceeds the actual costs of construction within thirty (30) Calendar Days of the 
issuance of such final construction invoice.  Following the transfer of the Stand 
Alone Network Upgrades from the Interconnection Customer to the Transmission 
Owner, the Interconnection Customer shall make payments for such facilities to 
the Transmission Owner pursuant to an agreement between and among the 
Parties. 
 
5.3 
Liquidated Damages.  The actual damages to Interconnection Customer, in the event the 
Transmission Owner’s Interconnection Facilities or Network Upgrades are not completed 
by the dates designated by Interconnection Customer and accepted by Transmission 
Provider and Transmission Owner pursuant to subparagraphs 5.1.2 or 5.1.4, above, may 
include Interconnection Customer’s fixed operation and maintenance costs and lost 
opportunity costs.  Such actual damages are uncertain and impossible to determine at this 
time.  Because of such uncertainty, any liquidated damages paid by Transmission Owner 
to Interconnection Customer in the event that Transmission Owner does not complete any 
portion of the Transmission Owner’s Interconnection Facilities or Network Upgrades by 
the applicable dates, shall be an amount equal to ½ of 1 percent per day of the actual cost 
of the Transmission Owner’s Interconnection Facilities and Network Upgrades, in the 
aggregate, for which Transmission Owner has assumed responsibility to design, procure 
and construct. 
 
However, in no event shall the total liquidated damages exceed 20 percent of the actual 
cost of the Transmission Owner’s Interconnection Facilities and Network Upgrades for 
which Transmission Owner has assumed responsibility to design, procure, and construct.  
The foregoing payments will be made by Transmission Owner to Interconnection 
Customer as just compensation for the damages caused to Interconnection Customer, 
which actual damages are uncertain and impossible to determine at this time, and as 
reasonable liquidated damages, but not as a penalty or a method to secure performance of 
this ZGIA.  Liquidated damages, when the Parties agree to them, are the exclusive 
remedy for the Transmission Owner’s failure to meet its schedule.

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No liquidated damages shall be paid to Interconnection Customer if:  (1) Interconnection 
Customer is not ready to commence use of the Transmission Owner’s Interconnection 
Facilities or Network Upgrades to take the delivery of power for the Generating Facility’s 
Trial Operation or to export power from the Generating Facility on the specified dates, 
unless Interconnection Customer would have been able to commence use of the 
Transmission Owner’s Interconnection Facilities or Network Upgrades to take the 
delivery of power for Generating Facility’s Trial Operation or to export power from the 
Generating Facility, but for Transmission Owner’s delay; (2) the Transmission Owner’s 
failure to meet the specified dates is the result of the action or inaction of Transmission 
Provider, Interconnection Customer or any other earlier queued Interconnection 
Customer who has entered into an earlier GIA or ZGIA with Transmission Provider 
and/or a Transmission Owner or with an Affected System Operator, or any cause beyond 
Transmission Owner’s reasonable control or reasonable ability to cure; 
(3) Interconnection Customer has assumed responsibility for the design, procurement and 
construction of the Transmission Owner’s Interconnection Facilities and Stand Alone 
Network Upgrades; (4) the delay is due to the inability of Transmission Owner to obtain 
all required approvals from Governmental Authorities in a timely manner for the 
construction of any element of the Interconnection Facilities, Network Upgrades or Stand 
Alone Network Upgrades, or any other permit or authorization required, or any land 
rights or other private authorizations that may be required, and Transmission Owner has 
exercised Reasonable Efforts in procuring such approvals, permits, rights or 
authorizations; or (5) the Parties have otherwise agreed. 
 
5.4 
Power System Stabilizers.  Interconnection Customer shall procure, install, maintain 
and operate power system stabilizers in accordance with the guidelines and procedures 
established by the Electric Reliability Organization.  Transmission Provider and 
Transmission Owner reserve the right to reasonably establish minimum acceptable 
settings for any installed power system stabilizers, subject to the design and operating 
limitations of the Generating Facility.  If the Generating Facility’s power system 
stabilizers are removed from service or are not capable of automatic operation,

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Interconnection Customer shall immediately notify the Transmission Provider’s system 
operator, or its designated representative.  The requirements of this paragraph shall not 
apply to induction generators. 
 
5.5 
Equipment Procurement.  If responsibility for construction of the Transmission 
Owner’s Interconnection Facilities, Network Upgrades and/or Distribution Upgrades is to 
be borne by Transmission Owner, then Transmission Owner shall commence design of 
the Transmission Owner’s Interconnection Facilities, Network Upgrades and/or 
Distribution Upgrades, and procure necessary equipment as soon as practicable after all 
of the following conditions are satisfied, unless the Parties otherwise agree in writing: 
 
5.5.1 Transmission Provider has completed the Interconnection Facilities Study 
pursuant to the Interconnection Facilities Study Agreement; and 
 
5.5.2 Where applicable, Interconnection Customer has provided security to 
Transmission Owner in accordance with Article 11.6 by the dates specified in 
Appendix B, Milestones. 
 
5.6 
Construction Commencement.  Transmission Owner shall commence construction of 
the Transmission Owner’s Interconnection Facilities, Network Upgrades, Transmission 
Owner’s System Protection Facilities, Distribution Upgrades, and Generator Upgrades 
for which it is responsible as soon as practicable after the following additional conditions 
are satisfied: 
 
5.6.1 Approval of the appropriate Governmental Authority has been obtained for any 
facilities requiring regulatory approval; and 
 
5.6.2 Where applicable, Interconnection Customer has provided security to 
Transmission Owner in accordance with Article 11.6 by the dates specified in 
Appendix B, Milestones.

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5.7 
Work Progress.  Transmission Owner and Interconnection Customer will keep each 
other and Transmission Provider advised periodically as to the progress of their 
respective design, procurement and construction efforts.  Either Transmission Owner or 
Interconnection Customer may, at any time, request a progress report from the other, with 
a copy to be provided to the other Parties.  If, at any time, Interconnection Customer 
determines that the completion of the Transmission Owner’s Interconnection Facilities, 
Network Upgrades, or Transmission Owner’s System Protection Facilities will not be 
required until after the specified In-Service Date, Interconnection Customer will provide 
written notice to Transmission Provider and Transmission Owner of such later date upon 
which the completion of the Transmission Owner’s Interconnection Facilities, Network 
Upgrades or Transmission Owner’s System Protection Facilities will be required.  
Transmission Owner may delay the In-Service Date of its facilities accordingly. 
 
5.8 
Information Exchange.  As soon as reasonably practicable after the Effective Date, the 
Parties shall exchange information regarding the design and compatibility of the 
Interconnection Facilities and compatibility of the Interconnection Facilities with the 
Transmission System or Distribution System, as applicable, and shall work diligently and 
in good faith to make any necessary design changes.  
 
5.9 
Other Interconnection Options. 
 
5.9.1 Limited Operation.  If any of the Transmission Owner’s Interconnection 
Facilities, Network Upgrades, or Transmission Owner’s System Protection 
Facilities, Distribution Upgrades or Generator Upgrades are not reasonably 
expected to be completed prior to the Commercial Operation Date of the 
Generating Facility, Transmission Provider shall, upon the request and at the 
expense of Interconnection Customer, perform operating studies on a timely basis 
to determine the extent to which the Generating Facility and the Interconnection 
Customer’s Interconnection Facilities may operate prior to the completion of the 
Transmission Owner’s Interconnection Facilities, Network Upgrades, 
Transmission Owner’s System Protection Facilities, Distribution Upgrades or

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Generator Upgrades consistent with Applicable Laws and Regulations, 
Applicable Reliability Standards, Good Utility Practice, and this ZGIA.  
Transmission Provider and Transmission Owner shall permit Interconnection 
Customer to operate the Generating Facility and the Interconnection Customer’s 
Interconnection Facilities in accordance with the results of such studies; provided, 
however, such studies reveal that such operation may occur without detriment to 
the Transmission System as then configured and in accordance with the safety 
requirements of Transmission Owner and any Governmental Authority. 
 
The maximum permissible output of the Generating Facility will be updated on a 
quarterly basis if the Network Upgrades necessary for the interconnection of the 
Generating Facility pursuant to this ZGIA are not in service within six (6) months 
following the Commercial Operation Date of the Generating Facility as specified 
in Appendix B of this ZGIA.  These quarterly studies will be performed using the 
same methodology set forth in Section 11.5 of the GIP.  These quarterly updates 
will end when all Network Upgrades necessary for the interconnection of the 
Generating Facility pursuant to this ZGIA are in service. 
 
5.9.2 Provisional Interconnection Service. 
Upon the request of Interconnection Customer, and prior to completion of 
requisite Interconnection Facilities, Network Upgrades, Distribution Upgrades, or 
System Protection Facilities Transmission Provider may execute a Provisional 
Generator Interconnection Agreement or Interconnection Customer may request 
the filing of an unexecuted Provisional Generator Interconnection Agreement 
with the Interconnection Customer for limited interconnection service at the 
discretion of Transmission Provider based upon an evaluation that will consider 
the results of available studies.  Transmission Provider shall determine, through 
available studies or additional studies as necessary, whether stability, short circuit, 
thermal, and/or voltage issues would arise if Interconnection Customer 
interconnects without modifications to the Generating Facility or Transmission 
Provider’s system. Transmission Provider shall determine whether any

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Interconnection Facilities, Network Upgrades, Distribution Upgrades, or System 
Protection Facilities that are necessary to meet the requirements of the Electric 
Reliability Organization, or any applicable Regional Entity for the interconnection 
of a new, modified and/or expanded Generating Facility are in place prior to the 
commencement of interconnection service from the Generating Facility. Where 
available studies indicate that such Interconnection Facilities, Network Upgrades, 
Distribution Upgrades, and/or System Protection Facilities that are required for 
the interconnection of a new, modified and/or expanded Generating Facility are 
not currently in place, Transmission Provider will perform a study, at the 
Interconnection Customer’s expense, to confirm the facilities that are required for 
Provisional Interconnection Service. The maximum permissible output of the 
Generating Facility in the Provisional Generator Interconnection Agreement shall 
be studied and updated on a quarterly basis. Interconnection Customer assumes all 
risk and liabilities with respect to changes between the Provisional Generator 
Interconnection Agreement and the Generator Interconnection Agreement, 
including changes in output limits and Interconnection Facilities, Network 
Upgrades, Distribution Upgrades, and/or System Protection Facilities cost 
responsibilities. 
 
5.10 
Interconnection Customer’s Interconnection Facilities.  Interconnection Customer 
shall, at its expense, design, procure, construct, own or control, and install the ICIF, as set 
forth in Appendix A. 
 
5.10.1 
Interconnection Customer’s Interconnection Facility Specifications.  
Interconnection Customer shall submit initial design and specifications for the 
ICIF, including Interconnection Customer’s System Protection Facilities, to 
Transmission Provider and Transmission Owner at least one hundred eighty 
(180) Calendar Days prior to the Initial Synchronization Date; and final design 
and specifications for review and comment at least ninety (90) Calendar Days 
prior to the Initial Synchronization Date.  Transmission Provider at 
Transmission Provider’s option, and Transmission Owner shall review such

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specifications to ensure that the ICIF are compatible with their respective 
technical specifications, operational control, and safety requirements and 
comment on such design and specifications within thirty (30) Calendar Days of 
Interconnection Customer’s submission.  All specifications provided hereunder 
shall be deemed confidential. 
 
5.10.2 
Transmission Provider’s and Transmission Owner’s Review.  Transmission 
Provider’s and Transmission Owner’s review of Interconnection Customer’s 
final specifications shall not be construed as confirming, endorsing, or providing 
a warranty as to the design, fitness, safety, durability or reliability of the 
Generating Facility, or the ICIF.  Interconnection Customer shall make such 
changes to the ICIF as may reasonably be required by Transmission Provider 
and Transmission Owner, in accordance with Good Utility Practice, to ensure 
that the ICIF are compatible with the technical specifications, operational 
control and safety requirements of Transmission Provider and Transmission 
Owner. 
 
5.10.3 
ICIF Construction.  The ICIF shall be designed and constructed in accordance 
with Good Utility Practice.  Within one hundred twenty (120) Calendar Days 
after the Commercial Operation Date, unless the Parties agree on another 
mutually acceptable deadline, Interconnection Customer shall deliver to 
Transmission Provider and Transmission Owner “as-built” drawings, 
information and documents for the ICIF, such as: a one-line diagram, a site plan 
showing the Generating Facility and the ICIF, plan and elevation drawings 
showing the layout of the ICIF, a relay functional diagram, relaying AC and DC 
schematic wiring diagrams and relay settings for all facilities associated with the 
Interconnection Customer’s step-up transformers, the facilities connecting the 
Generating Facility to the step-up transformers and the ICIF, and the 
impedances (determined by factory tests) for the associated step-up transformers 
and the Generating Facility.  Interconnection Customer shall provide 
Transmission Provider and Transmission Owner with Interconnection

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Customer’s specifications for the excitation system, automatic voltage regulator, 
Generating Facility control and protection settings, transformer tap settings, and 
communications, if applicable. 
 
5.11 
Transmission Owner’s Interconnection Facilities Construction. The Transmission 
Owner’s Interconnection Facilities shall be designed and constructed in accordance with 
Good Utility Practice.  Upon request, within one hundred twenty (120) Calendar Days 
after the Commercial Operation Date, unless the Parties agree on another mutually 
acceptable deadline, Transmission Owner shall deliver to Transmission Provider (if 
requested) and Interconnection Customer the “as-built” drawings, information and 
documents for the Transmission Owner’s Interconnection Facilities specified in 
Appendix C to this ZGIA.   
 
Such drawings, information and documents shall be deemed Confidential Information. 
 
Upon completion, the Transmission Owner’s Interconnection Facilities and Stand Alone 
Network Upgrades shall be under the control of Transmission Provider or its designated 
representative. 
 
5.12 
Access Rights.  Upon reasonable notice by a Party, and subject to any required or 
necessary regulatory approvals, a Party (“Granting Party”) shall furnish at no cost to the 
other Party (“Access Party”) any rights of use, licenses, rights of way and easements with 
respect to lands owned or controlled by the Granting Party, its agents (if allowed under 
the applicable agency agreement), or any Affiliate, that are necessary to enable the 
Access Party to obtain ingress and egress to construct, operate, maintain, repair, test (or 
witness testing), inspect, replace or remove facilities and equipment to:  (i) interconnect 
the Generating Facility with the Transmission System; (ii) operate and maintain the 
Generating Facility, the Interconnection Facilities and the Transmission System; and 
(iii) disconnect or remove the Access Party’s facilities and equipment upon termination 
of this ZGIA.  In exercising such licenses, rights of way and easements, the Access Party 
shall not unreasonably disrupt or interfere with normal operation of the Granting Party’s

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business and shall adhere to the safety rules and procedures established in advance, as 
may be changed from time to time, by the Granting Party and provided to the Access 
Party.   
 
5.13 
Lands of Other Property Owners.  If any part of the Transmission Owner’s 
Interconnection Facilities, Network Upgrades, and/or Distribution Upgrades is to be 
installed on property owned by persons other than Interconnection Customer or 
Transmission Owner, Transmission Owner shall at Interconnection Customer’s expense 
use efforts, similar in nature and extent to those that it typically undertakes on its own 
behalf or on behalf of its Affiliates, including use of its eminent domain authority to the 
extent permitted and consistent with Applicable Laws and Regulations and, to the extent 
consistent with such Applicable Laws and Regulations, to procure from such persons any 
rights of use, licenses, rights of way and easements that are necessary to construct, 
operate, maintain, test, inspect, replace or remove the Transmission Owner’s 
Interconnection Facilities, Network Upgrades and/or Distribution Upgrades upon such 
property.   
 
5.14 
Permits.  Transmission Provider or Transmission Owner and Interconnection Customer 
shall cooperate with each other in good faith in obtaining all permits, licenses and 
authorizations that are necessary to accomplish the interconnection in compliance with 
Applicable Laws and Regulations.  With respect to this paragraph, Transmission Owner 
shall provide permitting assistance to Interconnection Customer comparable to that 
provided to the Transmission Owner’s own, or an Affiliate’s, generation to the extent that 
Transmission Owner or its Affiliate owns generation.  
 
5.15 
Early Construction of Base Case Facilities.  (Includes facilities required for all queued 
projects with interconnection agreements ).Interconnection Customer may request 
Transmission Owner to construct, and Transmission Owner shall construct, using 
Reasonable Efforts to accommodate Interconnection Customer’s In-Service Date, all or 
any portion of any Network Upgrades, Transmission Owner’s System Protection 
Facilities or Distribution Upgrades required for Interconnection Customer to be

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interconnected to the Transmission or Distribution System, as applicable, which are 
included in the Base Case of the Interconnection Facilities Study for Interconnection 
Customer, and which also are required to be constructed for another Interconnection 
Customer with a prior ZGIA, but where such construction is not scheduled to be 
completed in time to achieve Interconnection Customer’s In-Service Date.  Any such 
Network Upgrades, System Protection Facilities or Distribution Upgrades are included in 
the facilities to be constructed and as set forth in Appendix A to this ZGIA to the extent 
they are reasonably known. 
 
5.16 
Suspension.   
 
5.16.1  Interconnection Customer’s Right to Suspend for Force Majeure Event; 
Obligations.  Provided that such suspension is permissible under the 
authorizations, permits or approvals granted for the construction of such 
Interconnection Facilities, Network Upgrades or Stand Alone Network Upgrades, 
Interconnection Customer will not suspend unless a Force Majeure event occurs. 
 
 
Interconnection Customer must provide written notice of its request for 
suspension to Transmission Provider and Transmission Owner, and provide a 
description of the Force Majeure event that is acceptable to Transmission 
Provider.  Suspension will only apply to Interconnection Customer milestones and 
Interconnection Facilities described in the Appendices of this ZGIA.  Prior to 
suspension, Interconnection Customer must also provide security acceptable to 
Transmission Owner, equivalent to the higher of $5 million or the total cost of all 
Network Upgrades, Transmission Owner’s System Protection Facilities, and 
Distribution Upgrades listed in Appendix A of this ZGIA.  Network Upgrades and 
Transmission Owner’s Interconnection Facilities will be constructed on the 
schedule described in the Appendices of this ZGIA unless:  (1) construction is 
prevented by the order of a Governmental Authority; (2) the Network Upgrades 
are not needed by any other project; or (3) Transmission Owner or Transmission 
Provider determines that a Force Majeure event prevents construction.  In the

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event of (1), (2), or (3) security shall be released upon the determination that the 
Network Upgrades will no longer be constructed.    
 
 
 
If suspension occurs, the Transmission or Distribution System, as applicable, shall 
be left in a safe and reliable condition in accordance with Good Utility Practice 
and the Transmission Provider’s and Transmission Owner’s safety and reliability 
criteria.  In such event, Interconnection Customer shall be responsible for all 
reasonable and necessary costs which Transmission Provider and Transmission 
Owner (i) have incurred pursuant to this ZGIA prior to the suspension and (ii) 
incur in suspending such work, including any costs incurred to perform such work 
as may be necessary to ensure the safety of persons and property and the integrity 
of the Transmission or Distribution System, as applicable, during such suspension 
and, if applicable, any costs incurred in connection with the cancellation or 
suspension of material, equipment and labor contracts which Transmission 
Provider and Transmission Owner cannot reasonably avoid; provided, however, 
that prior to canceling or suspending any such material, equipment or labor 
contract, Transmission Provider and Transmission Owner shall obtain 
Interconnection Customer’s authorization to do so. 
 
Transmission Provider and Transmission Owner shall each invoice 
Interconnection Customer for such costs pursuant to Article 12 and shall use 
Reasonable Efforts to minimize its costs.  In the event Interconnection Customer 
suspends work by Transmission Owner required under this ZGIA pursuant to this 
Article 5.16, and has not requested Transmission Owner to recommence the work 
required under this ZGIA on or before the expiration of three (3) years following 
commencement of such suspension, this ZGIA shall be deemed terminated.  The 
three-year period shall begin on the date the suspension is requested, or the date 
of the written notice to Transmission Provider, if no effective date is specified. 
 
5.16.2 Effect of Missed Interconnection Customer Milestones.  If Interconnection 
Customer fails to provide notice of suspension pursuant to Article 5.16, and

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Interconnection Customer fails to fulfill or complete any Interconnection 
Customer Milestone provided in Appendix B (“Milestone”), this constitutes a 
Breach under this ZGIA.  Depending upon the consequences of the Breach and 
effectiveness of the cure pursuant to Article 17, the Transmission Owner’s 
Milestones may be revised, following consultation with Interconnection 
Customer, consistent with Reasonable Efforts, and in consideration of all relevant 
circumstances.  Parties shall employ Reasonable Efforts to maintain their 
remaining respective Milestones. 
 
5.16.3 Effect of Suspension; Parties Obligations.  In the event that Interconnection 
Customer suspends work pursuant to this Article 5.16, no construction duration, 
timelines and schedules set forth in Appendix B shall be suspended during the 
period of suspension unless ordered by a Governmental Authority, with such 
order being the Force Majeure event causing the suspension.  Should 
Interconnection Customer request that work be recommenced, Transmission 
Owner shall be obligated to proceed with Reasonable Efforts and in consideration 
of all relevant circumstances including regional outage schedules, construction 
availability and material procurement in performing the work as described in 
Appendix A and Appendix B.  Transmission Owner will provide Interconnection 
Customer with a revised schedule for the design, procurement, construction, 
installation and testing of the Transmission Owner’s Interconnection Facilities 
and Network Upgrades.  Upon any suspension by Interconnection Customer 
pursuant to Article 5.16, Interconnection Customer shall be responsible for only 
those costs specified in this Article 5.16.   
 
5.17 
Taxes. 
 
5.17.1 Interconnection Customer Payments Not Taxable.  The Parties intend that all 
payments or property transfers made by Interconnection Customer to 
Transmission Owner for the installation of the Transmission Owner’s 
Interconnection Facilities, Network Upgrades, Transmission Owner’s System

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Protection Facilities, Distribution Upgrades and Generator Upgrades shall be non-
taxable, either as contributions to capital, or as an advance, in accordance with the 
Internal Revenue Code and any applicable state income tax laws and shall not be 
taxable as contributions in aid of construction or otherwise under the Internal 
Revenue Code and any applicable state income tax laws.  To the extent that 
Transmission Owner is a limited liability company and not a corporation, and has 
elected to be taxed as a partnership, then the following shall apply:  Transmission 
Owner represents, and the Parties acknowledge, that Transmission Owner is a 
limited liability company and is treated as a partnership for federal income tax 
purposes.  Any payment made by Interconnection Customer to Transmission 
Owner for Network Upgrades is to be treated as an upfront payment in 
accordance with Rev Proc 2005-35.  It is anticipated by the parties that any 
amounts paid by Interconnection Customer to Transmission Owner for Network 
Upgrades will be reimbursed to Interconnection Customer in accordance with the 
terms of this ZGIA, provided Interconnection Customer fulfills its obligations 
under this ZGIA. 
 
5.17.2 
Representations and Covenants.  In accordance with IRS Notice 2016-36, 
Interconnection Customer represents and covenants that (i) ownership of the 
electricity generated at the Generating Facility will pass to another party prior 
to the transmission of the electricity on the Transmission  System, (ii) for 
income tax purposes, the amount of any payments and the cost of any property 
transferred to Transmission Owner for the Transmission Owner’s 
Interconnection Facilities will be capitalized by Interconnection Customer as 
an intangible asset and recovered using the straight-line method over a useful 
life of twenty (20) years, and (iii) any portion of the Transmission Owner’s 
Interconnection Facilities that is a “dual-use intertie,” within the meaning of 
IRS Notice 2016-36, is reasonably expected to carry only a de minimis amount 
of electricity in the direction of the Generating Facility.  For this purpose, “de 
minimis amount” means no more than 5 percent of the total power flows in 
both directions, calculated in accordance with the “5 percent test” set forth in

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IRS Notice 2016-36.  This is not intended to be an exclusive list of the relevant 
conditions that must be met to conform to IRS requirements for non-taxable 
treatment. 
 
At Transmission Owner’s request, Interconnection Customer shall provide 
Transmission Owner with a report from an independent engineer confirming its 
representation in clause (iii), above, with a copy to Transmission Provider.  
Transmission Owner represents and covenants that the cost of the Transmission 
Owner’s Interconnection Facilities paid for by Interconnection Customer will 
have no net effect on the base upon which rates are determined. 
 
5.17.3 
Indemnification for the Cost Consequences of Current Tax Liability Upon 
Transmission Owner.  Notwithstanding Article 5.17.1 and to the extent 
permitted by law, Interconnection Customer shall protect, indemnify and hold 
harmless Transmission Owner from the cost consequences of any tax liability 
imposed against Transmission Owner as the result of payments or property 
transfers made by Interconnection Customer to Transmission Owner under this 
ZGIA for Interconnection Facilities, as well as any interest and penalties, other 
than interest and penalties attributable to any delay caused by Transmission 
Owner. 
 
Transmission Owner shall not include a gross-up for the cost consequences of 
any current tax liability in the amounts it charges Interconnection Customer 
under this ZGIA unless (i) Transmission Owner has determined, in good faith, 
that the payments or property transfers made by Interconnection Customer to 
Transmission Owner should be reported as income subject to taxation or (ii) any 
Governmental Authority directs Transmission Owner to report payments or 
property as income subject to taxation; provided, however, that Transmission 
Owner may require Interconnection Customer to provide security for 
Interconnection Facilities, in a form reasonably acceptable to Transmission 
Owner (such as a parental guarantee or a letter of credit), in an amount equal to

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the cost consequences or any current tax liability under this Article 5.17. 
Interconnection Customer shall reimburse Transmission Owner for such costs 
on a fully grossed-up basis, in accordance with Article 5.17.4, within thirty (30) 
Calendar Days of receiving written notification from Transmission Owner of the 
amount due, including detail about how the amount was calculated. 
 
The indemnification obligation shall terminate at the earlier of (1) the expiration 
of the ten-year testing period and the applicable statute of limitation, as it may 
be extended by Transmission Owner upon request of the IRS, to keep these 
years open for audit or adjustment, or (2) the occurrence of a subsequent taxable 
event and the payment of any related indemnification obligations as 
contemplated by this Article 5.17. 
 
5.17.4 
Tax Gross-Up Amount.  Interconnection Customer’s liability for the cost 
consequences of any current tax liability under this Article 5.17 shall be 
calculated on a fully grossed-up basis.  Except as may otherwise be agreed to by 
the parties, this means that Interconnection Customer will pay Transmission 
Owner, in addition to the amount paid for the Interconnection Facilities, 
Network Upgrades, Transmission Owner’s System Protection Facilities, and/or 
Distribution Upgrades, an amount equal to (1) the current taxes imposed on 
Transmission Owner (“Current Taxes”) on the excess of (a) the gross income 
realized by Transmission Owner as a result of payments or property transfers 
made by Interconnection Customer to Transmission Owner under this ZGIA 
(without regard to any payments under this Article 5.17) (the “Gross Income 
Amount”) over (b) the present value of future tax deductions for depreciation 
that will be available as a result of such payments or property transfers (the 
“Present Value Depreciation Amount”), plus (2) an additional amount sufficient 
to permit Transmission Owner to receive and retain, after the payment of all 
Current Taxes, an amount equal to the net amount described in clause (1).

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For this purpose, (i) Current Taxes shall be computed based on Transmission 
Owner’s composite federal and state tax rates at the time the payments or 
property transfers are received and Transmission Owner will be treated as being 
subject to tax at the highest marginal rates in effect at that time (the “Current 
Tax Rate”), and (ii) the Present Value Depreciation Amount shall be computed 
by discounting Transmission Owner’s anticipated tax depreciation deductions as 
a result of such payments or property transfers by Transmission Owner’s current 
weighted average cost of capital.  Thus, the formula for calculating 
Interconnection Customer’s liability to Transmission Owner pursuant to this 
Article 5.17.4 can be expressed as follows: (Current Tax Rate x (Gross Income 
Amount – Present Value of Tax Depreciation))/(1-Current Tax Rate).  
Interconnection Customer’s estimated tax liability in the event taxes are 
imposed shall be stated in Appendix A, Interconnection Facilities, Network 
Upgrades and Distribution Upgrades. 
 
5.17.5 
Private Letter Ruling or Change or Clarification of Law.  At Interconnection 
Customer’s request and expense, Transmission Owner shall file with the IRS a 
request for a private letter ruling as to whether any property transferred or sums 
paid, or to be paid, by Interconnection Customer to Transmission Owner under 
this ZGIA are subject to federal income taxation.  Interconnection Customer 
will prepare the initial draft of the request for a private letter ruling, and will 
certify under penalties of perjury that all facts represented in such request are 
true and accurate to the best of Interconnection Customer’s knowledge.  
Transmission Owner and Interconnection Customer shall cooperate in good 
faith with respect to the submission of such request. 
 
Transmission Owner shall keep Interconnection Customer fully informed of the 
status of such request for a private letter ruling and shall execute either a privacy 
act waiver or a limited power of attorney, in a form acceptable to the IRS, that 
authorizes Interconnection Customer to participate in all discussions with the 
IRS regarding such request for a private letter ruling.  Transmission Owner shall

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allow Interconnection Customer to attend all meetings with IRS officials about 
the request and shall permit Interconnection Customer to prepare the initial 
drafts of any follow-up letters in connection with the request.   
 
5.17.6 
Subsequent Taxable Events.  If, within 10 years from the date on which the 
relevant Transmission Owner’s Interconnection Facilities are placed in service, 
(i) Interconnection Customer breaches the covenant contained in Article 5.17.2, 
(ii) a “disqualification event” occurs within the meaning of IRS Notice 88-129, 
or (iii) this ZGIA terminates and Transmission Owner retains ownership of the 
Interconnection Facilities, Network Upgrades, Transmission Owner’s System 
Protection Facilities, and/or Distribution Upgrades, Interconnection Customer 
shall pay a tax gross-up for the cost consequences of any current tax liability 
imposed on Transmission Owner, calculated using the methodology described 
in Article 5.17.4 and in accordance with IRS Notice 90-60. 
 
5.17.7 
Contests.  In the event any Governmental Authority determines that 
Transmission Owner’s receipt of payments or property constitutes income that 
is subject to taxation, Transmission Owner shall notify Interconnection 
Customer, in writing, within thirty (30) Calendar Days of receiving notification 
of such determination by a Governmental Authority.  Upon the timely written 
request by Interconnection Customer and at Interconnection Customer’s sole 
expense, Transmission Owner may appeal, protest, seek abatement of, or 
otherwise oppose such determination.  Upon Interconnection Customer’s written 
request and sole expense, Transmission Owner shall file a claim for refund with 
respect to any taxes paid under this Article 5.17, whether or not it has received 
such a determination.  Transmission Owner reserves the right to make all 
decisions with regard to the prosecution of such appeal, protest, abatement or 
other contest, including the selection of counsel and compromise or settlement 
of the claim, but Transmission Owner shall keep Interconnection Customer 
informed, shall consider in good faith suggestions from Interconnection 
Customer about the conduct of the contest, and shall reasonably permit

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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Interconnection Customer or an Interconnection Customer representative to 
attend contest proceedings. 
 
Interconnection Customer shall pay to Transmission Owner on a periodic basis, 
as invoiced by Transmission Owner, Transmission Owner’s documented 
reasonable costs of prosecuting such appeal, protest, abatement or other contest.  
At any time during the contest, Transmission Owner may agree to a settlement 
either with Interconnection Customer’s consent or after obtaining written advice 
from nationally-recognized tax counsel, selected by Transmission Owner, but 
reasonably acceptable to Interconnection Customer, that the proposed settlement 
represents a reasonable settlement given the hazards of litigation.  
Interconnection Customer’s obligation shall be based on the amount of the 
settlement agreed to by Interconnection Customer, or if a higher amount, so 
much of the settlement that is supported by the written advice from nationally-
recognized tax counsel selected under the terms of the preceding sentence.  The 
settlement amount shall be calculated on a fully grossed-up basis to cover any 
related cost consequences of the current tax liability.  Any settlement without 
Interconnection Customer’s consent or such written advice will relieve 
Interconnection Customer from any obligation to indemnify Transmission 
Owner for the tax at issue in the contest. 
 
5.17.8 
Refund.  In the event that (a) a private letter ruling is issued to Transmission 
Owner which holds that any amount paid or the value of any property 
transferred by Interconnection Customer to Transmission Owner under the 
terms of this ZGIA is not subject to federal income taxation, (b) any legislative 
change or administrative announcement, notice, ruling or other determination 
makes it reasonably clear to Transmission Owner in good faith that any amount 
paid or the value of any property transferred by Interconnection Customer to 
Transmission Owner under the terms of this ZGIA is not taxable to 
Transmission Owner, (c) any abatement, appeal, protest, or other contest results 
in a determination that any payments or transfers made by Interconnection

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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Customer to Transmission Owner are not subject to federal income tax, or (d) if 
Transmission Owner receives a refund from any taxing authority for any 
overpayment of tax attributable to any payment or property transfer made by 
Interconnection Customer to Transmission Owner pursuant to this ZGIA, 
Transmission Owner shall promptly refund to Interconnection Customer the 
following: 
 
any payment made by Interconnection Customer under this Article 5.17 
for taxes that is attributable to the amount determined to be non-taxable, 
together with interest thereon, 
 
(ii) interest on any amounts paid by Interconnection Customer to 
Transmission Owner for such taxes which Transmission Owner did not 
submit to the taxing authority, calculated in accordance with the 
methodology set forth in 18 C.F.R. Section 35.19a(a)(2)(iii) from the date 
payment was made by Interconnection Customer to the date Transmission 
Owner refunds such payment to Interconnection Customer, and 
 
(iii) with respect to any such taxes paid by Transmission Owner, any 
refund or credit Transmission Owner receives or to which it may be 
entitled from any Governmental Authority, interest (or that portion thereof 
attributable to the payment described in clause (i), above) owed to 
Transmission Owner for such overpayment of taxes (including any 
reduction in interest otherwise payable by Transmission Owner to any 
Governmental Authority resulting from an offset or credit); provided, 
however, that Transmission Owner will remit such amount promptly to 
Interconnection Customer only after and to the extent that Transmission 
Owner has received a tax refund, credit or offset from any Governmental 
Authority for any applicable overpayment of income tax related to the 
Transmission Owner’s Interconnection Facilities.

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
The intent of this provision is to leave both parties, to the extent 
practicable, in the event that no taxes are due with respect to any payment 
for Interconnection Facilities and Network Upgrades hereunder, in the 
same position they would have been in had no such tax payments been 
made. 
 
5.17.9 
Taxes Other Than Income Taxes.  Upon the timely request by Interconnection 
Customer, and at Interconnection Customer’s sole expense, Transmission 
Owner shall appeal, protest, seek abatement of, or otherwise contest any tax 
(other than federal or state income tax) asserted or assessed against 
Transmission Owner for which Interconnection Customer may be required to 
reimburse Transmission Owner under the terms of this ZGIA.  Interconnection 
Customer shall pay to Transmission Owner on a periodic basis, as invoiced by 
Transmission Owner, Transmission Owner’s documented reasonable costs of 
prosecuting such appeal, protest, abatement, or other contest.  Interconnection 
Customer and Transmission Owner shall cooperate in good faith with respect to 
any such contest.  Unless the payment of such taxes is a prerequisite to an 
appeal or abatement or cannot be deferred, no amount shall be payable by 
Interconnection Customer to Transmission Owner for such taxes until they are 
assessed by a final, non-appealable order by any court or agency of competent 
jurisdiction.  In the event that a tax payment is withheld and ultimately due and 
payable after appeal, Interconnection Customer will be responsible for all taxes, 
interest and penalties, other than penalties attributable to any delay caused by 
Transmission Owner. 
 
5.18 
Tax Status.  Each Party shall cooperate with the other Parties to maintain each Party’s 
tax status.  Nothing in this ZGIA is intended to adversely affect any Party’s tax-exempt 
status with respect to the issuance of bonds including, but not limited to, Local 
Furnishing Bonds. 
 
5.19 
Modification.

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Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
 
5.19.1 General.  Either Party may undertake modifications to its facilities.  If a Party 
plans to undertake a modification that reasonably may be expected to affect 
another Party’s facilities, that Party shall provide to the other Parties sufficient 
information regarding such modification so that the other Parties may evaluate 
the potential impact of such modification prior to commencement of the work.  
Such information shall be deemed to be Confidential Information hereunder and 
shall include information concerning the timing of such modifications and 
whether such modifications are expected to interrupt the flow of electricity from 
the Generating Facility.  The Party desiring to perform such work shall provide 
the relevant drawings, plans, and specifications to the other Parties at least ninety 
(90) Calendar Days in advance of the commencement of the work or such shorter 
period upon which the Parties may agree, which agreement shall not 
unreasonably be withheld, conditioned or delayed. 
 
In the case of Generating Facility modifications that do not require 
Interconnection Customer to submit an Interconnection Request, Transmission 
Provider shall provide, within thirty (30) Calendar Days (or such other time as 
the Parties may agree), an estimate of any additional modifications to the 
Transmission or Distribution System as applicable, Transmission Owner’s 
Interconnection Facilities, Network Upgrades, Transmission Owner’s System 
Protection Facilities, and/or Distribution Upgrades necessitated by such 
Interconnection Customer modification and a good faith estimate of the costs 
thereof which shall be the responsibility of Interconnection Customer. 
 
5.19.2 Standards.  Any additions, modifications, or replacements made to a Party’s 
facilities shall be designed, constructed and operated in accordance with this 
ZGIA and Good Utility Practice.  
 
 
5.19.3 
Modification Costs.  Interconnection Customer shall not be directly assigned 
the costs of any additions, modifications, or replacements that Transmission

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
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Owner makes to the Transmission Owner’s Interconnection Facilities, Network 
Upgrades, Transmission Owner’s System Protection Facilities, Distribution 
Upgrades, or the Transmission or Distribution System, as applicable, to 
facilitate the interconnection of a third party to the Transmission Owner’s 
Interconnection Facilities or the Transmission or Distribution System, as 
applicable, or to provide transmission service to a third party under the Tariff.  
Interconnection Customer shall be responsible for the costs of any additions, 
modifications, or replacements to the Interconnection Customer’s 
Interconnection Facilities that may be necessary to maintain or upgrade such 
Interconnection Customer’s Interconnection Facilities consistent with 
Applicable Laws and Regulations, Applicable Reliability Standards or Good 
Utility Practice. 
 
5.19.4 
Sole Interconnection: During the term of this ZGIA, Interconnection Customer 
shall not connect the Generating Facilities described in Appendix A of this 
ZGIA to the transmission facilities of any transmission provider other than the 
Transmission Provider, or a successor to the Transmission Provider, except as 
expressly allowed by the Transmission Provider’s Tariff.  Any connection that 
violates this Article 5.19.4 shall be deemed a breach of this ZGIA subject to 
default and termination pursuant to Articles 17 and 2 of this ZGIA.  In the event 
Interconnection Customer proposes to connect the Generating Facilities to the 
transmission system of another transmission provider, all Interconnection 
Service under this agreement shall terminate no later than the date on which 
such Generating Facilities achieve commercial operation over its connection to 
the other transmission provider.  Interconnection Customer shall adhere to the 
requirements of Attachment Y to the Tariff as applicable.  
 
ARTICLE 6.  TESTING AND INSPECTION 
 
6.1 
Pre-Commercial Operation Date Testing and Modifications.  Prior to the Commercial 
Operation Date, Transmission Owner shall test the Transmission Owner’s

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Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
Interconnection Facilities, Network Upgrades, Transmission Owner’s System Protection 
Facilities and Distribution Upgrades, and Interconnection Customer shall test each 
electric production device at the Generating Facility, Interconnection Customer’s System 
Protection Facilities, including control equipment to limit injection at the POI to the level 
of Interconnection Service set forth in Appendix A and the Interconnection Customer’s 
Interconnection Facilities to ensure their safe and reliable operation.  Similar testing may 
be required after initial operation.  Transmission Owner and Interconnection Customer 
shall make any modifications to their respective facilities that are found to be necessary 
as a result of such testing.  Interconnection Customer shall bear the cost of all such 
testing and modifications.  Interconnection Customer shall generate test energy at the 
Generating Facility only if it has arranged for the delivery of such test energy. 
 
6.2 
Post-Commercial Operation Date Testing and Modifications.  Each Party shall at its 
own expense perform routine inspection and testing of its facilities and equipment in 
accordance with Good Utility Practice as may be necessary to ensure the continued 
interconnection of the Generating Facility with the Transmission or Distribution System, 
as applicable, in a safe and reliable manner.  Each Party shall have the right, upon 
advance written notice, to require reasonable additional testing of the Interconnection 
Facilities, at the requesting Party’s expense, as may be in accordance with Good Utility 
Practice. 
 
6.3 
Right to Observe Testing.  Each Party shall notify the other Parties in advance of its 
performance of tests of its Interconnection Facilities.  The other Parties shall each have 
the right, at its own expense, to observe such testing. 
 
6.4 
Right to Inspect.  Each Party shall have the right, but shall have no obligation to: 
(i) observe Transmission Owner’s and Interconnection Customer’s tests and/or inspection 
of any of their respective System Protection Facilities and other protective equipment, 
including power system stabilizers and control equipment; (ii) review the settings of the 
System Protection Facilities and other protective equipment; and (iii) review the 
maintenance records relative to the Interconnection Facilities, the System Protection

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
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Facilities and other protective equipment.  A Party may exercise these rights from time to 
time as it deems necessary upon reasonable notice to the other Parties.  The exercise or 
non-exercise by a Party of any such rights shall not be construed as an endorsement or 
confirmation of any element or condition of the Interconnection Facilities or the System 
Protection Facilities or other protective equipment or the operation thereof, or as a 
warranty as to the fitness, safety, desirability, or reliability of same.  Any information that 
a Party obtains through the exercise of any of its rights under this Article 6.4 shall be 
deemed to be Confidential Information and treated pursuant to Article 22 of this ZGIA. 
 
ARTICLE 7.  METERING 
 
7.1 
General.  Each Party shall comply with the Electric Reliability Organization 
requirements.  Unless the Interconnection Customer is utilizing shared Interconnection 
Customer Interconnection Facilities, or unless otherwise agreed by the Parties, 
Transmission Owner, at its election, or otherwise Interconnection Customer, shall install 
Metering Equipment (the “Metering Party”) at the Point of Interconnection prior to any 
operation of the Generating Facility.  Transmission Owner, at its election, or otherwise 
Interconnection Customer shall own, operate, test and maintain such Metering 
Equipment.  Power flows to and from the Generating Facility shall be measured at or, at 
the Metering Party’s option, compensated to, the Point of Interconnection.  If 
Interconnection Customer will share Interconnection Facilities with any other projects, 
Interconnection Customer shall install Metering Equipment either on its own Generating 
Facility or its own non-shared facilities sufficient to measure the output of such 
Interconnection Customer’s Generating Facility separately from any other Generating 
Facilities with which it will share Interconnection Facilities.   The Metering Party shall 
provide metering quantities, in analog and/or digital form, to the other Parties upon 
request.  Interconnection Customer shall bear all reasonable documented costs associated 
with the purchase, installation, operation, testing and maintenance of the Metering 
Equipment.  Interconnection customer with a Generating Facility granted ZG 
Interconnection Service shall install and meter for its Generating Facility separate from 
any metering used for the ZG Associated Load.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
 
7.1.1: 
Market Registration:  An Interconnection customer with a Generating Facility 
granted ZG Interconnection Service greater than 5 MW shall submit a 
completed Market Participant Application pursuant to Section 38.2 et seq. of the 
Tariff (Module C) not later than thirty (30) Calendar Days after the executing or 
requesting the unexecuted filing of this Agreement  Interconnection Customer 
with ZG Interconnection Service shall take all steps required by the MISO 
Tariff and applicable Business Practices Manual to complete registration as a 
Generation Resource, Energy Storage Resource, or Dispatchable Intermittent 
Resource based on its applicable operating characteristics prior to its 
Commercial Operation Date and shall maintain such registration for the 
duration of its ZG Interconnection Service. 
 
7.2 
Check Meters.  Interconnection Customer, at its option and expense, may install and 
operate, on its premises and on its side of the Point of Interconnection, one or more check 
meters to check the Metering Equipment owned by the Metering Party.  Such check 
meters shall be for check purposes only and shall not be used for the measurement of 
power flows for purposes of this ZGIA, except as provided in Article 7.4 below.  The 
check meters shall be subject at all reasonable times to inspection and examination by 
Transmission Provider, Transmission Owner or their designees.  The installation, 
operation and maintenance thereof shall be performed entirely by Interconnection 
Customer in accordance with Good Utility Practice. 
 
7.3 
Standards.  The Metering Party shall install, calibrate, and test revenue quality Metering 
Equipment in accordance with applicable ANSI standards. 
 
7.4 
Testing of Metering Equipment.  The Metering Party shall inspect and test Metering 
Equipment upon installation and at least once every two (2) years thereafter.  If requested 
to do so by a Party, the Metering Party shall, at the requesting Party’s expense, inspect or 
test Metering Equipment more frequently than every two (2) years.  The Metering Party 
shall give reasonable notice to the other Parties of the time when any inspection or test

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
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shall take place, and the other Parties may have representatives present at the test or 
inspection.  If at any time Metering Equipment is found to be inaccurate or defective, it 
shall be adjusted, repaired or replaced at Interconnection Customer’s expense, in order to 
provide accurate metering, unless the inaccuracy or defect is due to the Metering Party’s 
failure to maintain, then the Metering Party shall pay.  If Metering Equipment fails to 
register, or if the measurement made by Metering Equipment during a test varies by more 
than two percent (2%) from the measurement made by the standard meter used in the test, 
the Metering Party shall adjust the measurements by correcting all measurements for the 
period during which Metering Equipment was in error by using Interconnection 
Customer’s check meters, if installed.  If no such check meters are installed or if the 
period cannot be reasonably ascertained, the adjustment shall be for the period 
immediately preceding the test of the Metering Equipment equal to one-half the time 
from the date of the previous test of the Metering Equipment. 
 
7.5 
Metering Data.  At Interconnection Customer’s expense, the metered data shall be 
telemetered to one or more locations designated by Transmission Provider and 
Transmission Owner and one or more locations designated by Interconnection Customer.  
Such telemetered data shall be used, under normal operating conditions, as the official 
measurement of the amount of energy delivered from the Generating Facility to the Point 
of Interconnection. 
 
ARTICLE 8.  COMMUNICATIONS 
 
8.1 
Interconnection Customer Obligations.  Interconnection Customer shall maintain 
satisfactory operating communications with Transmission Provider’s Transmission 
System dispatcher or representative designated by Transmission Provider.  
Interconnection Customer shall provide standard voice line, dedicated voice line and 
facsimile communications at its Generating Facility control room or central dispatch 
facility through use of either the public telephone system, or a voice communications 
system that does not rely on the public telephone system.  Interconnection Customer shall 
also provide the dedicated data circuit(s) necessary to provide Interconnection Customer

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
data to Transmission Provider as set forth in Appendix D, Security Arrangements Details.  
The data circuit(s) shall extend from the Generating Facility to the location(s) specified 
by Transmission Provider.  Any required maintenance of such communications 
equipment shall be performed by and at the cost of Interconnection Customer.  
Operational communications shall be activated and maintained under, but not be limited 
to, the following events:  system paralleling or separation, scheduled and unscheduled 
shutdowns, equipment clearances, and hourly and daily load data. 
 
 
Unless the Generating Facility is an Intermittent Resource not relying on wind or solar as 
a fuel source, Interconnection Customer shall install communication and control 
equipment such that the Generating Facility can receive and respond to the appropriate 
dispatch signals while operating under the Tariff. Where applicable, the requirements of 
the communication and control equipment will be enumerated in Appendix C to this 
ZGIA. 
 
8.2 
Remote Terminal Unit (RTU).  Prior to the Initial Synchronization Date of the 
Generating Facility, a remote terminal unit, or equivalent data collection and transfer 
equipment acceptable to both Parties, shall be installed by Interconnection Customer, or 
by Transmission Owner at Interconnection Customer’s expense, to gather accumulated 
and instantaneous data to be telemetered to the location(s) designated by Transmission 
Owner and Transmission Provider through use of a dedicated point-to-point data 
circuit(s) as indicated in Article 8.1.  The communication protocol for the data circuit(s) 
shall be specified by Transmission Owner and Transmission Provider.  Instantaneous bi-
directional analog real power and reactive power flow information must be telemetered 
directly to the location(s) specified by Transmission Provider and Transmission Owner. 
 
 
Each Party will promptly advise the other Parties if it detects or otherwise learns of any 
metering, telemetry or communications equipment errors or malfunctions that require the 
attention and/or correction.  The Party owning such equipment shall correct such error or 
malfunction as soon as reasonably feasible.

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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8.3 
No Annexation.  Any and all equipment placed on the premises of a Party shall be and 
remain the property of the Party providing such equipment regardless of the mode and 
manner of annexation or attachment to real property, unless otherwise mutually agreed by 
the Parties. 
 
8.4 
Provision of Data from a Variable Energy Resource.  Interconnection Customer 
whose Generating Facility contains at least one Variable Energy Resource shall provide 
meteorological and forced outage data to the Transmission Provider to the extent 
necessary for the Transmission Provider’s development and deployment of power 
production forecasts for that class of Variable Energy Resources.  Interconnection 
Customer with a Variable Energy Resource having wind as the energy source will, upon 
request by the Transmission Provider, be required to provide Transmission Provider with 
site-specific meteorological data including:  temperature, wind speed, wind direction, and 
atmospheric pressure.  Interconnection Customer with a Variable Energy Resource 
having solar as the energy source will, upon request by the Transmission Provider, be 
required to provide the Transmission Provider with site-specific meteorological data 
including:  temperature, atmospheric pressure, and irradiance.  Transmission Provider 
and Interconnection Customer whose Generating Facility contains a Variable Energy 
Resource shall mutually agree to any additional meteorological data that are required for 
the development and deployment of a power production forecast.  Interconnection 
Customer whose Generating Facility contains a Variable Energy Resource also shall 
submit data to Transmission Provider regarding all forced outages to the extent necessary 
for Transmission Provider’s development and deployment of power production forecasts 
for that class of Variable Energy Resources.  The exact specifications of the 
meteorological and forced outage data to be provided by Interconnection Customer to 
Transmission Provider, including the frequency and timing of data submittals, shall be 
made taking into account the size and configuration of the Variable Energy Resource, its 
characteristics, location, and its importance in maintaining generation resource adequacy 
and transmission system reliability in its area.  All requirements for meteorological and 
forced outage data must be commensurate with the power production forecasting 
employed by Transmission Provider.  Data requirements for meteorological and forced

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
outage data will be negotiated by Transmission Provider and Interconnection Customer, 
and will be set forth in Appendix C, Interconnection Details, of this ZGIA. 
 
ARTICLE 9.  OPERATIONS 
 
9.1 
General.  Each Party shall comply with the Electric Reliability Organization 
requirements.  Each Party shall provide to any Party all information that may reasonably 
be required by that Party to comply with Applicable Laws and Regulations and 
Applicable Reliability Standards.  
 
9.2 
Local Balancing Authority Notification.  At least three (3) months before Initial 
Synchronization Date, Interconnection Customer shall notify Transmission Provider and 
Transmission Owner in writing of the Local Balancing Authority in which the Generating 
Facility will be located.  If Interconnection Customer elects to locate the Generating 
Facility through dynamic metering/scheduling in a Local Balancing Authority other than 
the Local Balancing Authority in which the Generating Facility is physically located, and 
if permitted to do so by the relevant transmission tariffs, all necessary arrangements, 
including but not limited to those set forth in Article 7 and Article 8 of this ZGIA, and 
remote Local Balancing Authority generator interchange agreements, if applicable, and 
the appropriate measures under such agreements, shall be executed and implemented 
prior to the placement of the Generating Facility in the other Local Balancing Authority. 
 
9.3 
Transmission Provider and Transmission Owner Obligations.  Transmission Provider 
shall cause the Transmission System and the Transmission Owner’s Interconnection 
Facilities to be operated, maintained and controlled in a safe and reliable manner in 
accordance with this ZGIA.  Transmission Provider, or its designee, may provide 
operating instructions to Interconnection Customer consistent with this ZGIA and the 
Tariff and, if applicable, Transmission Owner’s operating protocols and procedures as 
they may change from time to time.  Transmission Provider will consider changes to its 
operating protocols and procedures proposed by Interconnection Customer.

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
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9.4 
Interconnection Customer Obligations.  Interconnection Customer shall at its own 
expense operate, maintain and control the Generating Facility and the Interconnection 
Customer’s Interconnection Facilities in a safe and reliable manner and in accordance 
with this ZGIA.  The Generating Facility must be operated in accordance with the 
operating limits, if any, in the Interconnection Facilities Study and specified in Appendix 
C of this ZGIA.  Interconnection Customer shall operate the Generating Facility and the 
Interconnection Customer’s Interconnection Facilities in accordance with all applicable 
requirements of Transmission Provider or its designated Local Balancing Authority 
Operator of which the Generating Facility is part, as such requirements are set forth in 
Appendix C, Interconnection Details, of this ZGIA.  Appendix C, Interconnection 
Details, will be modified to reflect changes to the requirements as they may change from 
time to time.  Any Party may request that a Party provide copies of the requirements set 
forth in Appendix C, Interconnection Details, of this ZGIA. 
 
9.5 
Start-Up and Synchronization.  Consistent with the Parties’ mutually acceptable 
procedures, Interconnection Customer is responsible for the proper synchronization of the 
Generating Facility to the Transmission or Distribution System, as applicable.  
 
9.6 
Reactive Power and Primary Frequency Response. 
 
9.6.1 Power Factor Design Criteria. 
 
9.6.1.1 Synchronous Generation.  Interconnection Customer shall design the 
Generating Facility to be capable of maintaining a composite power delivery at 
continuous rated power output at the Point of Interconnection at all power factors 
over 0.95 leading to 0.95 lagging, unless the Transmission Provider has 
established different requirements that apply to all synchronous generators in the 
Local Balancing Authority on a comparable basis.  The applicable Local 
Balancing Authority power factor requirements are listed on the Transmission 
Provider’s website at

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
https://cdn.misoenergy.org/Reactive_Generator_Requirements108137.pdf 
 
and may be referenced in the Appendices to this ZGIA.  The Generating Facility 
shall be capable of continuous dynamic operation throughout the power factor 
design range as measured at the Point of Interconnection.  Such operation shall 
account for the net effect of all energy production devices on the Interconnection 
Customer’s side of the Point of Interconnection.   
 
9.6.1.2 Inverter-Based Resource Plants.  Interconnection Customer shall design 
the Generating Facility to be capable of maintaining a composite power delivery 
at continuous rated power output at the high-side of the generator substation at all 
power factors over 0.95 leading to 0.95 lagging, unless the Transmission Provider 
has established different requirements that apply to all inverter-based resource 
plants in the Local Balancing Authority on a comparable basis.  The applicable 
Local Balancing Authority power factor requirements are listed on the 
Transmission Provider’s website at  
 
https://cdn.misoenergy.org/Reactive_Generator_Requirements108137.pdf 
 
and may be referenced in the Appendices to this ZGIA.  This power factor range 
standard shall be dynamic and can be met using, for example, power electronics 
designed to supply this level of reactive capability (taking into account any 
limitations due to voltage level, real power output, etc.) or fixed and switched 
capacitors, or a combination of the two.  This requirement shall only apply to 
newly interconnecting inverter-based resource plants that have not yet completed 
a System Impact Study as of the effective date of the Final Rule establishing this 
requirement (Order No. 827).  These requirements apply to existing inverter-
based resource plants making upgrades that require a new Generator 
Interconnection Agreement only where the Transmission Provider’s System 
Impact Study shows the need for reactive power as a result of an upgrade.  If 
applicable, these requirements will be memorialized in Appendix C to this ZGIA.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
 
Additional reactive power requirements for inverter-based resource plants are 
provided in Appendix G of this ZGIA. 
 
 
9.6.2 Voltage Schedules.  Once Interconnection Customer has synchronized the 
Generating Facility with the Transmission System, Transmission Provider shall 
require Interconnection Customer to operate the Generating Facility to produce or 
absorb reactive power within the design limitations of the Generating Facility set 
forth in Article 9.6.1 (Power Factor Design Criteria), to maintain the output 
voltage or power factor at the Point of Interconnection as specified by 
Transmission Provider.  Transmission Provider’s voltage schedules shall treat all 
sources of reactive power in the Local Balancing Authority in an equitable and 
not unduly discriminatory manner.  Transmission Provider shall exercise 
Reasonable Efforts to provide Interconnection Customer with such schedules at 
least one (1) Calendar Day in advance, and may make changes to such schedules 
as necessary to maintain the reliability of the Transmission or Distribution System 
as applicable.  Interconnection Customer shall operate the Generating Facility to 
maintain the specified output voltage or power factor at the Point of 
Interconnection within the design limitations of the Generating Facility set forth 
in Article 9.6.1 (Power Factor Design Criteria).  If Interconnection Customer is 
unable to maintain the specified voltage or power factor, it shall promptly notify 
Transmission Provider’s system operator, or its designated representative. 
 
9.6.2.1 Voltage Regulators.  Whenever the Generating Facility is operated in 
parallel with the Transmission or Distribution System as applicable and 
voltage regulators are capable of operation, Interconnection Customer 
shall operate the Generating Facility with its speed governors and 
voltage regulators in automatic operation.  If the Generating Facility’s 
voltage regulators are not capable of such automatic operation, 
Interconnection Customer shall immediately notify Transmission

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Provider’s system operator, or its designated representative, and ensure 
that such Generating Facility’s reactive power production or absorption 
(measured in MVARs) are within the design capability of the Generating 
Facility’s generating unit(s) and steady state stability limits.  
Interconnection Customer shall not cause its Generating Facility to 
disconnect automatically or instantaneously from the Transmission or 
Distribution System, as applicable, or trip any generating unit 
comprising the Generating Facility for an under or over frequency 
condition unless the abnormal frequency condition persists for a time 
period beyond the limits set forth in ANSI/IEEE Standard C37.106, or 
such other standard as applied to other generators in the Local Balancing 
Authority on a comparable basis. 
 
9.6.3 Payment for Reactive Power.  Payments for reactive power shall be pursuant to 
any tariff or rate schedule filed by Transmission Provider and approved by the 
FERC.  
 
9.6.4  Primary Frequency Response. This Section 9.6.4 shall only apply in the event 
that the Interconnection Request for the Generating Facility completed Definitive 
Planning Phase Interconnection Customer Decision Point 2 after May 15, 2018. 
 
 
Interconnection Customer shall ensure the primary frequency response capability 
of its Generating Facility by installing, maintaining, and operating a functioning 
governor or equivalent controls. The term “functioning governor or equivalent 
controls” as used herein shall mean the required hardware and/or software that 
provides frequency responsive real power control with the ability to sense 
changes in system frequency and autonomously adjust the Generating Facility’s 
real power output in accordance with the droop and deadband parameters and in 
the direction needed to correct frequency deviations. Interconnection Customer is 
required to install a governor or equivalent controls with the capability of 
operating: (1) with a maximum 5 percent droop and ±0.036 Hz deadband; or (2)

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in accordance with the relevant droop, deadband, and timely and sustained 
response settings from an approved Reliability Organization reliability standard 
providing for equivalent or more stringent parameters.  The droop characteristic 
shall be: (1) based on the nameplate capacity of the Generating Facility, and shall 
be linear in the range of frequencies between 59 to 61 Hz that are outside of the 
deadband parameter; or (2) based on an approved Electric Reliability 
Organization reliability standard providing for an equivalent or more stringent 
parameter.  The deadband parameter shall be: the range of frequencies above and 
below nominal (60 Hz) in which the governor or equivalent controls is not 
expected to adjust the Generating Facility’s real power output in response to 
frequency deviations.  The deadband shall be implemented: (1) without a step to 
the droop curve, that is, once the frequency deviation exceeds the deadband 
parameter, the expected change in the Generating Facility’s real power output in 
response to frequency deviations shall start from zero and then increase (for 
under-frequency deviations) or decrease (for over-frequency deviations) linearly 
in proportion to the magnitude of the frequency deviation; or (2) in accordance 
with an approved Electric Reliability Organization Reliability Standard providing 
for an equivalent or more stringent parameter. Interconnection Customer shall 
notify Transmission Provider that the primary frequency response capability of 
the Generating Facility has been tested and confirmed during commissioning. 
Once Interconnection Customer has synchronized the Generating Facility with the 
Transmission System, Interconnection Customer shall operate the Generating 
Facility consistent with the provisions specified in Articles 9.6.4.1 and 9.6.4.2 of 
this ZGIA. The primary frequency response requirements contained herein shall 
apply to both synchronous and inverter-based resource plant Generating Facilities. 
 
9.6.4.1  Governor or Equivalent Controls. Whenever the Generating Facility is 
operated in parallel with the Transmission System, Interconnection 
Customer shall operate the Generating Facility with its governor or 
equivalent controls in service and responsive to frequency. 
Interconnection Customer shall: (1) in coordination with Transmission

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Provider and/or the relevant balancing authority, set the deadband 
parameter to: (a) a maximum of ±0.036 Hz and set the droop parameter 
to a maximum of 5 percent; or (b) implement the relevant droop and 
deadband settings from an approved Regional Reliability Organization 
reliability standard that provides for equivalent or more stringent 
parameters. Interconnection Customer shall be required to provide the 
status and settings of the governor or equivalent controls to 
Transmission Provider and/or the relevant balancing authority upon 
request. If Interconnection Customer needs to operate the Generating 
Facility with its governor or equivalent controls not in service, 
Interconnection Customer shall immediately notify Transmission 
Provider and the relevant balancing authority, and provide both with the 
following information: (1) the operating status of the governor or 
equivalent controls (i.e., whether it is currently out of service or when it 
will be taken out of service); (2) the reasons for removing the governor 
or equivalent controls from service; and (3) a reasonable estimate of 
when the governor or equivalent controls will be returned to service. 
Interconnection Customer shall make Reasonable Efforts to return its 
governor or equivalent controls into service as soon as practicable. 
Interconnection Customer shall make Reasonable Efforts to keep 
outages of the Generating Facility’s governor or equivalent controls to a 
minimum whenever the Generating Facility is operated in parallel with 
the Transmission System. 
 
9.6.4.2  Timely and Sustained Response. Interconnection Customer shall 
ensure that the Generating Facility’s real power response to sustained 
frequency deviations outside of the deadband setting is automatically 
provided and shall begin immediately after frequency deviates outside of 
the deadband, and to the extent the Generating Facility has operating 
capability in the direction needed to correct the frequency deviation. 
Interconnection Customer shall not block or otherwise inhibit the ability

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of the governor or equivalent controls to respond and shall ensure that 
the response is not inhibited, except under certain operational constraints 
including, but not limited to, ambient temperature limitations, physical 
energy limitations, outages of mechanical equipment, or regulatory 
requirements. The Generating Facility shall sustain the real power 
response at least until system frequency returns to a value within the 
deadband setting of the governor or equivalent controls. A Commission-
approved reliability standard with equivalent or more stringent 
requirements shall supersede the above requirements. 
 
9.6.4.3  Exemptions. Generating Facilities that are regulated by the United 
States Nuclear Regulatory Commission shall be exempt from Articles 
9.6.4, 9.6.4.1, and 9.6.4.2 of this ZGIA. Generating Facilities that are 
behind the meter generation that is sized-to-load (i.e., the thermal load 
and the generation are near-balanced in real-time operation and the 
generation is primarily controlled to maintain the unique thermal, 
chemical, or mechanical output necessary for the operating requirements 
of its host facility) shall be required to install primary frequency 
response capability in accordance with the droop and deadband 
capability requirements specified in Article 9.6.4, but shall be otherwise 
exempt from the operating requirements in Articles 9.6.4, 9.6.4.1, 
9.6.4.2, and 9.6.4.4 of this ZGIA.   
 
9.6.4.4  Electric Storage Resources. Interconnection Customer interconnecting 
an electric storage resource shall establish an operating range in 
Appendix C that specifies a minimum state of charge and a maximum 
state of charge between which the electric storage resource will be 
required to provide primary frequency response consistent with the 
conditions set forth in Articles 9.6.4, 9.6.4.1, 9.6.4.2 and 9.6.4.3 of this 
ZGIA. Appendix C shall specify whether the operating range is static or 
dynamic, and shall consider (1) the expected magnitude of frequency

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deviations in the interconnection; (2) the expected duration that system 
frequency will remain outside of the deadband parameter in the 
interconnection; (3) the expected incidence of frequency deviations 
outside of the deadband parameter in the interconnection; (4) the 
physical capabilities of the electric storage resource; (5) operational 
limitations of the electric storage resource due to manufacturer 
specifications; and (6) any other relevant factors agreed to by 
Transmission Provider and Interconnection Customer, and in 
consultation with the relevant transmission owner or balancing authority 
as appropriate. If the operating range is dynamic, then Appendix C must 
establish how frequently the operating range will be reevaluated and the 
factors that may be considered during its reevaluation. 
 
 
Interconnection Customer’s electric storage resource is required to 
provide timely and sustained primary frequency response consistent with 
Article 9.6.4.2 of this ZGIA when it is online and dispatched to inject 
electricity to the Transmission System and/or receive electricity from the 
Transmission System. This excludes circumstances when the electric 
storage resource is not dispatched to inject electricity to the 
Transmission System and/or dispatched to receive electricity from the 
Transmission System. 
 
9.6.4.5 Inverter-Based Resource Plants. Additional primary frequency 
response requirements for inverter-based resource plants, including 
electric storage resources, are provided in Appendix G of this ZGIA. 
 
9.7 
Outages and Interruptions. 
 
9.7.1 Outages.

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9.7.1.1 Outage Authority and Coordination.  Interconnection Customer and 
Transmission Owner may each in accordance with Good Utility Practice 
in coordination with the other Party and Transmission Provider remove 
from service any of its respective Interconnection Facilities, System 
Protection Facilities, Network Upgrades, System Protection Facilities or 
Distribution Upgrades that may impact the other Party’s facilities as 
necessary to perform maintenance or testing or to install or replace 
equipment.  Absent an Emergency Condition, the Party scheduling a 
removal of such facility(ies) from service will use Reasonable Efforts to 
notify one another and schedule such removal on a date and time 
mutually acceptable to the Parties.  In all circumstances, any Party 
planning to remove such facility(ies) from service shall use Reasonable 
Efforts to minimize the effect on the other Parties of such removal.  
 
9.7.1.2 Outage Schedules.  Transmission Provider shall post scheduled outages 
of transmission facilities on the OASIS.  Interconnection Customer shall 
submit its planned maintenance schedules for the Generating Facility to 
Transmission Provider and Transmission Owner for a minimum of a 
rolling twenty-four (24) month period in accordance with the 
Transmission Provider’s procedures.  Interconnection Customer shall 
update its planned maintenance schedules as necessary.  Transmission 
Provider may request Interconnection Customer to reschedule its 
maintenance as necessary to maintain the reliability of the Transmission 
System; provided, however, adequacy of generation supply shall not be a 
criterion in determining Transmission System reliability. 
 
 
Transmission Provider shall compensate, pursuant to applicable 
Transmission Provider tariff or rate schedule, Interconnection Customer 
for any additional direct costs that Interconnection Customer incurs as a 
result of having to reschedule maintenance, including any additional 
overtime, breaking of maintenance contracts or other costs above and

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beyond the cost Interconnection Customer would have incurred absent 
the Transmission Provider’s request to reschedule maintenance.  
Interconnection Customer will not be eligible to receive compensation, if 
during the twelve (12) months prior to the date of the scheduled 
maintenance, Interconnection Customer had modified its schedule of 
maintenance activities. 
 
Costs shall be determined by negotiation between Transmission Provider 
and Interconnection Customer prior to implementation of the voluntary 
change in outage schedules, or if such request is made by or on behalf of 
a Transmission Customer requesting firm service, costs and recovery of 
costs shall be determined through a bilateral agreement between the 
Transmission Customer and Interconnection Customer.  Voluntary 
changes to outage schedules under this Article 9.7.1.2 are separate from 
actions and compensation required under Article 13 and for which costs 
are recovered in accordance with Transmission Provider’s applicable 
tariff or rate schedule. 
 
9.7.1.3 Outage Restoration.  If an outage on either the Interconnection 
Customer’s or Transmission Owner’s Interconnection Facilities, 
Network Upgrades, System Protection Facilities or Distribution 
Upgrades adversely affects a Party’s operations or facilities, the Party 
that owns or controls the facility that is out of service shall use 
Reasonable Efforts to promptly restore such facility(ies) to a normal 
operating condition consistent with the nature of the outage.  The Party 
that owns or controls the facility that is out of service shall provide the 
other Parties, to the extent such information is known, information on 
the nature of the Emergency Condition, an estimated time of restoration, 
and any corrective actions required.  Initial verbal notice shall be 
followed up as soon as practicable with written notice to the other 
Parties explaining the nature of the outage.

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9.7.2 Interruption of Service.  If required by Good Utility Practice to do so, 
Transmission Provider may require Interconnection Customer to interrupt or 
reduce deliveries of electricity if such delivery of electricity could adversely 
affect Transmission Provider’s ability to perform such activities as are necessary 
to safely and reliably operate and maintain the Transmission System.  The 
following provisions shall apply to any interruption or reduction permitted under 
this Article 9.7.2: 
 
9.7.2.1 The interruption or reduction shall continue only for so long as 
reasonably necessary under Good Utility Practice; 
 
9.7.2.2 Any such interruption or reduction shall be made on an equitable, non-
discriminatory basis with respect to all generating facilities directly 
connected to the Transmission or Distribution System, as applicable; 
 
9.7.2.3 When the interruption or reduction must be made under circumstances 
which do not allow for advance notice, Transmission Provider shall 
notify Interconnection Customer by telephone as soon as practicable of 
the reasons for the curtailment, interruption, or reduction, and, if known, 
its expected duration.  Telephone notification shall be followed by 
written notification as soon as practicable; 
 
9.7.2.4 Except during the existence of an Emergency Condition, when the 
interruption or reduction can be scheduled without advance notice, 
Transmission Provider shall notify Interconnection Customer in advance 
regarding the timing of such scheduling and further notify 
Interconnection Customer of the expected duration.  Transmission 
Provider shall coordinate with Interconnection Customer using Good 
Utility Practice to schedule the interruption or reduction during periods

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of least impact to Interconnection Customer, Transmission Owner and 
Transmission Provider; 
 
9.7.2.5 The Parties shall cooperate and coordinate with each other to the extent 
necessary in order to restore the Generating Facility, Interconnection 
Facilities, and the Transmission or Distribution System, as applicable to 
their normal operating state, consistent with system conditions and Good 
Utility Practice. 
 
9.7.3  Ride Through Capability and Performance.  The Transmission System is 
designed to automatically activate a load-shed program as required by the Electric 
Reliability Organization in the event of an underfrequency system disturbance.  
Interconnection Customer shall implement under-frequency and over-frequency 
relay set points for the Generating Facility as required by the Electric Reliability 
Organization to ensure frequency “ride through” capability of the Transmission 
System.  Generating Facility response to frequency deviations of pre-determined 
magnitudes, both under-frequency and over-frequency deviations, shall be studied 
and coordinated with Transmission Provider in accordance with Good Utility 
Practice.  Interconnection Customer shall also implement under-voltage and over-
voltage relay set points, or equivalent electronic controls, as required by the 
Electric Reliability Organization to ensure voltage “ride through” capability of the 
Transmission System.  The term “ride through” as used herein shall mean the 
ability of a Generating Facility to stay connected to and synchronized with the 
Transmission System during system disturbances within a range of under-
frequency, over-frequency, under-voltage, and over-voltage conditions, in 
accordance with Good Utility Practice and consistent with any standards and 
guidelines that are applied to other Generating Facilities in the Balancing 
Authority Area on a comparable basis.  For abnormal frequency conditions and 
voltage conditions within the “no trip zone” defined by Reliability Standard PRC-
024-3 or successor mandatory ride through reliability standards, the non-
synchronous Generating Facility must ensure that, within any physical limitations

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of the Generating Facility, its control and protection settings are configured or set 
to (1) continue active power production during disturbance and post disturbance 
periods at pre-disturbance levels, unless providing primary frequency response or 
fast frequency response; (2) minimize reductions in active power and remain 
within dynamic voltage and current limits, if reactive power priority mode is 
enabled, unless providing primary frequency response or fast frequency response; 
(3) not artificially limit dynamic reactive power capability during disturbances; 
and (4) return to pre-disturbance active power levels without artificial ramp rate 
limits if active power is reduced, unless providing primary frequency response or 
fast frequency response. 
 
9.7.4 System Protection and Other Control Requirements. 
 
9.7.4.1 System Protection Facilities.  Interconnection Customer shall, at its 
expense, install, operate and maintain its System Protection Facilities as 
a part of the Generating Facility or the Interconnection Customer’s 
Interconnection Facilities.  Transmission Owner shall install at 
Interconnection Customer’s expense any Transmission Owner’s System 
Protection Facilities that may be required on the Transmission Owner’s 
Interconnection Facilities or the Transmission Owner’s transmission or 
distribution facilities as a result of the interconnection of the Generating 
Facility and the Interconnection Customer’s Interconnection Facilities. 
 
9.7.4.2 Interconnection Customer’s and Transmission Owner’s System 
Protection Facilities shall be designed and coordinated with Affected 
Systems in accordance with Good Utility Practice. 
 
9.7.4.3 Each Party shall be responsible for protection of its facilities consistent 
with Good Utility Practice.

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9.7.4.4 Each Party’s protective relay design shall incorporate the necessary test 
switches to perform the tests required in Article 6. The required test 
switches will be placed such that they allow operation of lockout relays 
while preventing breaker failure schemes from operating and causing 
unnecessary breaker operations and/or the tripping of the Generating 
Facility. 
 
9.7.4.5 Each Party will test, operate and maintain their respective System 
Protection Facilities in accordance with Good Utility Practice.  
 
9.7.4.6 Prior to the In-Service Date, and again prior to the Commercial 
Operation Date, Interconnection Customer or Transmission Owner, or 
their respective agents, shall perform a complete calibration test and 
functional trip test of the System Protection Facilities.  At intervals 
suggested by Good Utility Practice and following any apparent 
malfunction of the System Protection Facilities, Interconnection 
Customer or Transmission Owner shall each perform both calibration 
and functional trip tests of their respective System Protection Facilities.  
These tests do not require the tripping of any in-service generating unit.  
These tests do, however, require that all protective relays and lockout 
contacts be activated. 
 
9.7.4.7  Obligation of a Generating Facility with ZG Interconnection Services to 
Reduce Production of Energy Under Certain Conditions.  A Generating 
Facility with ZG Interconnection Service shall: 
a.  Install communications and monitoring equipment to enable it to 
monitor the Demand of the ZG Associated Load. 
b. Install equipment to enable the Generating Facility with ZG 
Interconnection service to reduce its injections to a level that does 
not exceed the Demand of the ZG Associated Load within the 
Transient Tolerance Window.

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c. Cease all injection of Energy onto the Transmission System within 
the time permitted by the Transient Tolerance Window in the event 
that any Transmission Facility over which Energy must flow in order 
to reach the point of interconnection or Point of Withdrawal of the  
ZG Associated Load trips offline.  
The equipment to be used by the Generating Facility with ZG 
Interconnection Service to comply with the requirements of this 9.7.4.7 
shall be identified in Appendix A of this ZGIA.  Appendix A of this 
ZGIA shall include a one line diagram showing the Generating Facility 
and associated electrical equipment with appropriate rating and 
impedance information and all the ZG Associated loads including all 
Point(s) of Withdrawal and the Point of Interconnection of the 
Generating Facility to the Transmission System for the Interconnection 
Request. 
 
9.7.5 Requirements for Protection.  In compliance with Good Utility Practice, 
Interconnection Customer shall provide, install, own, and maintain relays, circuit 
breakers and all other devices necessary to remove any fault contribution of the 
Generating Facility to any short circuit occurring on the Transmission or 
Distribution System, as applicable, not otherwise isolated by Transmission 
Owner’s equipment, such that the removal of the fault contribution shall be 
coordinated with the protective requirements of the Transmission or Distribution 
System, as applicable.  Such protective equipment shall include, without 
limitation, a disconnecting device or switch with load-interrupting capability 
located between the Generating Facility and the Transmission or Distribution 
System, as applicable, at a site selected upon mutual agreement (not to be 
unreasonably withheld, conditioned or delayed) of the Parties.  Interconnection 
Customer shall be responsible for protection of the Generating Facility and 
Interconnection Customer’s other equipment from such conditions as negative 
sequence currents, over- or under-frequency, sudden load rejection, over- or 
under-voltage, and generator loss-of-field.  Interconnection Customer shall be

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solely responsible to disconnect the Generating Facility and Interconnection 
Customer’s other equipment if conditions on the Transmission or Distribution 
System, as applicable, could adversely affect the Generating Facility.  For a 
Generating Facility with ZG Interconnection Service the restriction on Energy 
injection in this paragraph shall not apply to transient, limited injections 
associated with a reduction or loss of Load by the ZG Associated Load provided 
these remain within the Transient Tolerance Window as may be further described 
in the Business Practices Manual for Large Load.   
 
9.7.6 Power Quality.  Neither Party’s facilities shall cause excessive voltage flicker 
nor introduce excessive distortion to the sinusoidal voltage or current waves as 
defined by ANSI Standard C84.1, in accordance with IEEE Standard 519, or any 
applicable superseding electric industry standard.  In the event of a conflict 
between ANSI Standard C84.1, and any applicable superseding electric industry 
standard, the applicable superseding electric industry standard shall control. 
 
9.8 
Switching and Tagging Rules.  Prior to the Initial Synchronization Date, each Party 
shall provide the other Parties a copy of its switching and tagging rules that are applicable 
to the other Parties’ activities.  Such switching and tagging rules shall be developed on a 
non-discriminatory basis.  The Parties shall comply with applicable switching and 
tagging rules, as amended from time to time, in obtaining clearances for work or for 
switching operations on equipment. 
 
9.9 
Use of Interconnection Facilities by Other Parties. 
 
9.9.1 Purpose of Interconnection Facilities.  Except as may be required by Applicable 
Laws and Regulations, or as otherwise agreed to among the Parties, the 
Interconnection Facilities shall be constructed for the sole purpose of 
interconnecting the Generating Facility to the Transmission or Distribution 
System, as applicable, and shall be used for no other purpose.

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9.9.2 Other Users.  If required by Applicable Laws and Regulations or if the Parties 
mutually agree, such agreement not to be unreasonably withheld or delayed, to 
allow one or more Parties to use the Transmission Owner’s Interconnection 
Facilities, or any part thereof, Interconnection Customer will be entitled to 
compensation for the capital expenses it incurred in connection with the 
Interconnection Facilities based upon the pro rata use of the Interconnection 
Facilities by Transmission Owner, all non-Party users, and Interconnection 
Customer, in accordance with Applicable Laws and Regulations or upon some 
other mutually-agreed upon methodology.  In addition, cost responsibility for 
ongoing costs, including operation and maintenance costs associated with the 
Interconnection Facilities, will be allocated between Interconnection Customer 
and any non-Party users based upon the pro rata use of the Interconnection 
Facilities by Transmission Owner, all non-Party users, and Interconnection 
Customer, in accordance with Applicable Laws and Regulations or upon some 
other mutually agreed upon methodology.  If the issue of such compensation or 
allocation cannot be resolved through such negotiations, it shall be submitted to 
Dispute Resolution pursuant to Section 12 of the Tariff. 
 
9.10 
Disturbance Analysis Data Exchange.  The Parties will cooperate with one another in 
the analysis of disturbances to either the Generating Facility or the Transmission System 
by gathering and providing access to any information relating to any disturbance, 
including information from oscillography, protective relay targets, breaker operations and 
sequence of events records, and any disturbance information required by Good Utility 
Practice. 
 
ARTICLE 10.  MAINTENANCE 
 
10.1 
Transmission Owner Obligations.  Transmission Owner shall maintain the 
Transmission Owner’s Interconnection Facilities in a safe and reliable manner and in 
accordance with this ZGIA and all Applicable Laws and Regulations.

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10.2 
Interconnection Customer Obligations.  Interconnection Customer shall maintain the 
Generating Facility and the Interconnection Customer’s Interconnection Facilities in a 
safe and reliable manner and in accordance with this ZGIA and all Applicable Laws and 
Regulations. 
 
10.3 
Coordination.  The Parties shall confer regularly to coordinate the planning, scheduling 
and performance of preventive and corrective maintenance on the Generating Facility and 
the Interconnection Facilities.   
 
10.4 
Secondary Systems.  Each Party shall cooperate with the other in the inspection, 
maintenance, and testing of control or power circuits that operate below 600 volts, AC or 
DC, including, but not limited to, any hardware, control or protective devices, cables, 
conductors, electric raceways, secondary equipment panels, transducers, batteries, 
chargers, and voltage and current transformers that directly affect the operation of a 
Party’s facilities and equipment which may reasonably be expected to impact another 
Party.  Each Party shall provide advance notice to the other Parties before undertaking 
any work on such circuits, especially on electrical circuits involving circuit breaker trip 
and close contacts, current transformers, or potential transformers. 
 
10.5 
Operating and Maintenance Expenses.  Subject to the provisions herein addressing the 
use of facilities by others, and except for operations and maintenance expenses associated 
with modifications made for providing Interconnection Service or Transmission Service 
to a non-Party and such non-Party pays for such expenses, Interconnection Customer 
shall be responsible for all reasonable expenses including overheads, associated with:  
(1) owning, operating, maintaining, repairing, and replacing Interconnection Customer’s 
Interconnection Facilities; and (2) operation, maintenance, repair and replacement of 
Transmission Owner’s Interconnection Facilities to the extent required by Transmission 
Owner on a comparable basis. 
 
ARTICLE 11.  PERFORMANCE OBLIGATION

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11.1 
Interconnection Customer’s Interconnection Facilities.  Interconnection Customer 
shall design, procure, construct, install, own and/or control the Interconnection 
Customer’s Interconnection Facilities described in Appendix A at its sole expense. 
 
11.2 
Transmission Owner’s Interconnection Facilities.  Transmission Owner shall design, 
procure, construct, install, own and/or control the Transmission Owner’s Interconnection 
Facilities described in Appendix A at the sole expense of Interconnection Customer. 
 
11.3 
Network Upgrades, System Protection Facilities and Distribution Upgrades.  
Transmission Owner shall design, procure, construct, install, and own the Network 
Upgrades, Transmission Owner’s System Protection Facilities and Distribution Upgrades 
described in Appendix A.  Interconnection Customer shall be responsible for all costs 
related to Distribution Upgrades and/or Generator Upgrades. As required by Section 
7.3.2.1 and 7.3.3.1 of Attachment X, Transmission Owner shall have provided 
Transmission Provider with written notice if Transmission Owner elects to fund the 
capital for the Network Upgrades and Transmission Owner’s System Protection 
Facilities; otherwise, such facilities, if any, shall be solely funded by Interconnection 
Customer. In the event that the Transmission Owner elects to fund the capital costs of the 
Network Upgrades and/or Transmission Owner’s System Protection Facilities, then the 
Parties shall enter into a Facilities Service Agreement.  The Facilities Service Agreement 
shall take the form of the pro forma Facilities Service Agreement that is included as 
Appendix 14 of Attachment X to the MISO Tariff.  Any Generating Facility with ZG 
Interconnection Service must have a Point of Interconnection that is located at the same 
voltage level of the same interconnection substation as the Point(s) of Withdrawal for the 
ZG Associated Load it will serve.   
 
A Generating Facility with ZG Interconnection Service must not require the construction 
of Network Upgrades beyond the substation where the Point of Interconnection is located 
other than System Protection Facilities.

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11.3.1 Contingencies Affecting Network Upgrades, System Protection Facilities and 
Distribution Upgrades.  Network Upgrades, System Protection Facilities and 
Distribution Upgrades that are required to accommodate the Generating Facility 
may be modified because (1) a higher queued Interconnection Request withdrew 
or was deemed to have withdrawn, (2) the interconnection agreement associated 
with a higher queued Interconnection Request was terminated prior to the 
project’s In-Service Date, (3) the Commercial Operation Date for a higher queued 
Interconnection Request is delayed, or the project itself is delayed (including due 
to suspension) such that facilities required to accommodate lower queued projects 
or the project itself may be altered, (4) the queue position is reinstated for a 
higher-queued Interconnection Request whose queue position was subject to 
dispute resolution, (5) changes occur in Transmission Provider or Transmission 
Owner equipment design standards or reliability criteria giving rise to the need for 
restudy, (6) the facilities required to accommodate a higher queued 
Interconnection Request were modified constituting a Material Modification 
pursuant to Section 4.4 of the GIP, (7) a ZGIA with an effective date prior to this 
ZGIA is terminated, (8) when ordered to restudy by FERC, or (9) the Network 
Upgrade Facilities Study for a Network Upgrade, which is to be included in this 
ZGIA, is completed after execution of this ZGIA.  The higher queued 
Interconnection Requests that could impact the Network Upgrades, System 
Protection Facilities and Distribution Upgrades required to accommodate the 
Generating Facility, and possible Modifications that may result from the above 
listed events affecting the higher queued Interconnection Requests, to the extent 
such modifications are reasonably known and can be determined, and estimates of 
the costs associated with such required Network Upgrades, System Protection 
Facilities and Distribution Upgrades, are provided in Appendix A.   
 
11.3.2 Agreement to Restudy and Cost Reallocation.  In the event that one of the 
contingencies listed in Article 11.3.1 occurs, at any time before the Network 
Upgrades, Common Use Upgrades, Shared Network Upgrades, System Protection 
Facilities and/or Distribution Upgrades associated with higher queued

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Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
Interconnection Requests with ZGIA in effect prior to this ZGIA are completed, 
Transmission Provider may determine, in its discretion, that a restudy is required.  
If a restudy is required, Transmission Provider will provide notice to 
Interconnection Customer and Interconnection Customer agrees to enter into an 
Interconnection Study Agreement for such restudy.  Transmission Provider will 
reevaluate the need for any Common Use Upgrade(s) and/or Shared Network 
Upgrade(s), and if still required, reallocate the cost and responsibility for any 
Common Use Upgrade and/or Shared Network Upgrade, without a restudy when 
possible, or with a restudy if the Transmission Provider deems it necessary in 
order to ensure reliability of the Transmission System.  The Parties agree to 
amend Appendix A to this ZGIA in accordance with Article 30.10 to reflect the 
results of any cost reallocation required under this Article 11.3.2.   
 
11.3.3 Agreement to Fund Shared Network Upgrades.  Interconnection Customer 
agrees to fund Shared Network Upgrades, as determined by Transmission 
Provider.  Where applicable, payments to fund Shared Network Upgrade(s) that 
are made to Transmission Provider by Interconnection Customer will be disbursed 
by Transmission Provider to the appropriate entities that funded the Shared 
Network Upgrades in accordance with Attachment X and Attachment FF of the 
Tariff.  In the event that Interconnection Customer fails to meet its obligation to 
fund Shared Network Upgrades, Transmission Owner and Transmission Provider 
shall not be responsible for the Interconnection Customer’s funding obligation.   
 
11.4 
Transmission Credits.   
 
11.4.1 
Repayment of Amounts Advanced for Network Upgrades.  Interconnection 
Customer shall be entitled to a cash repayment by Transmission Owner(s)  and 
the Affected System Owner(s) that own the Network Upgrades, of the amount 
paid respectively to Transmission Owner and Affected System Operator, if any, 
for the Network Upgrades, as provided under Attachment FF of this Tariff and 
including any tax gross-up or other tax-related payments associated with the

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Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
repayable portion of the Network Upgrades, and not repaid to Interconnection 
Customer pursuant to Article 5.17.8 or otherwise, to be paid to Interconnection 
Customer on a dollar-for-dollar basis for the non-usage sensitive portion of 
transmission charges, as payments are made under the Tariff and Affected 
System’s Tariff for Transmission Services with respect to the Generating 
Facility.  Any repayment shall include interest calculated in accordance with the 
methodology set forth in FERC’s regulations at 18 C.F.R. § 35.19 (a)(2)(iii) 
from the date of any payment for Network Upgrades through the date on which 
Interconnection Customer receives a repayment of such payment pursuant to 
this subparagraph.  Interest shall not accrue during periods in which 
Interconnection Customer has suspended construction pursuant to Article 11 or 
the Network Upgrades have been determined not to be needed pursuant to this 
Article 11.4.1.  Interconnection Customer may assign such repayment rights to 
any person.   
 
If the Generating Facility is designated a Network Resource under the Tariff, or 
if there are otherwise no incremental payments for Transmission Service 
resulting from the use of the Generating Facility by Transmission Customer, and 
in the absence of another mutually agreeable payment schedule any repayments 
provided under Attachment FF shall be established equal to the applicable rate 
for Firm Point-To-Point Transmission Service for the pricing zone where the 
Network Load is located multiplied by the portion of the demonstrated output of 
the Generating Facility designated as a Network Resource by the Network 
Customer(s) or in the absence of such designation, equal to the monthly firm 
single system-wide rate defined under Schedule 7 of the Tariff multiplied by the 
portion of the demonstrated output of the Generating Facility under contract to 
Network Customer(s) and consistent with studies pursuant to Section 3.2.2.2 of 
the GIP. 
 
Notwithstanding the foregoing, as applicable and consistent with the provisions 
of Attachment FF of this Tariff, Interconnection Customer, Transmission

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
Provider, Transmission Owner, and Affected System Operator may adopt any 
alternative payment schedule that is mutually agreeable so long as Transmission 
Owner and Affected System Operator take one of the following actions no later 
than five (5) years from the Commercial Operation Date:  (1) return to 
Interconnection Customer any amounts advanced for Network Upgrades not 
previously repaid, or (2) declare in writing that Transmission Owner or Affected 
System Operator will continue to provide payments to Interconnection 
Customer on a dollar-for-dollar basis for the non-usage sensitive portion of 
transmission charges, or develop an alternative schedule that is mutually 
agreeable and provides for the return of all amounts advanced for Network 
Upgrades not previously repaid; however, full reimbursement shall not extend 
beyond twenty (20) years from the Commercial Operation Date. 
 
If the Generating Facility is installed in phases, the amount eligible for refund as 
each phase achieves Commercial Operation will be reduced by the proportional 
amount of generation capacity not yet installed.  However, all facilities in 
Appendix A other than the Generating Facility shall be built without 
consideration for the phasing of the Generating Facility as though the entire 
Generating Facility will be placed in Commercial Operation for the full output 
or increased output of the Generating Facility constructed by Interconnection 
Customer under this ZGIA. 
 
If the Generating Facility fails to achieve Commercial Operation, but it or 
another generating facility is later constructed and makes use of the Network 
Upgrades, Transmission Owner and Affected System Operator shall at that time 
reimburse Interconnection Customer for the remaining applicable amounts that 
may be refundable pursuant to Attachment FF of this Tariff that were advanced 
for the Network Upgrades on their respective systems as described above.  
Before any such reimbursement can occur, Interconnection Customer, or the 
entity that ultimately constructs the Generating Facility, if different, is 
responsible for identifying the entity to which the reimbursement must be made.

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Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
 
11.4.2 
Special Provisions for Transmission Provider as an Affected System to be 
covered under Separate Agreements.  When the Transmission Owner’s 
Transmission or Distribution System (including for this Article 11.4.2 
independent distribution systems connected to the Transmission System) is an 
Affected System for an interconnection in another electric system, Transmission 
Provider will coordinate the performance of Interconnection Studies with the 
other system.  Transmission Provider will determine if any Network Upgrades 
or Distribution Upgrades, which may be required on the Transmission System 
as a result of the interconnection, would not have been needed but for the 
interconnection.  Unless Transmission Owner provides, under the 
interconnection agreement between Interconnection Customer and the other 
system, for the repayment of amounts advanced to Transmission Provider or an 
impacted Transmission Owner for Network Upgrades, Interconnection 
Customer, Transmission Provider, and the impacted  Transmission Owner(s) 
shall enter into an agreement that provides for such repayment by Transmission 
Owner(s) as directed by Transmission Provider.  The agreement shall specify 
the terms governing payments to be made by Interconnection Customer to the 
Affected System Operator as well as the payment of refunds by the Affected 
System Operator. 
 
11.4.3 
Notwithstanding any other provision of this ZGIA, nothing herein shall be 
construed as relinquishing or foreclosing any rights, including but not limited to 
firm transmission rights, capacity rights, transmission congestion rights, or 
transmission credits, that Interconnection Customer, shall be entitled to, now or 
in the future under any other agreement or tariff as a result of, or otherwise 
associated with, the transmission capacity, if any, created by the Network 
Upgrades, including the right to obtain cash reimbursement or transmission 
credits for transmission service that is not associated with the Generating 
Facility.

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Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
11.5 
Initial Payment.  For upgrades that the Transmission Owner has elected to self-fund, the 
Interconnection Customer is responsible for making the initial payment for the total cost 
of Network Upgrades (excluding JTIQ Upgrades) or Transmission Owner’s System 
Protection Facilities in the form of security pursuant to Article 11.6.  For upgrades where 
the Transmission Owner did not elect to self-fund, the Interconnection Customer shall 
elect (and provide its election to the Transmission Provider within five days of the 
commencement of negotiation of the ZGIA pursuant to Section 11.2 of the GIP) to make 
either 1) an initial payment equal to twenty (20) percent of the total cost of Network 
Upgrades (excluding JTIQ Upgrades), Transmission Owner Interconnection Facilities, 
Transmission Owner’s System Protection Facilities, Distribution Upgrades and/or 
Generator Upgrades (if the In-Service Date is less than or equal to five (5) years of the 
initial payment date); or 2) an initial payment equal to ten (10) percent of the total cost of 
Network Upgrades (excluding JTIQ Upgrades), Transmission Owner Interconnection 
Facilities, Transmission Owner’s System Protection Facilities, Distribution Upgrades 
and/or Generator Upgrades (if the In-Service Date exceeds the initial payment date by 
more than five (5) years); or 3) the total cost of Network Upgrades (excluding JTIQ 
Upgrades), Transmission Owner Interconnection Facilities, Transmission Owner’s 
System Protection Facilities, Distribution Upgrades and/or Generator Upgrades in the 
form of security pursuant to Article 11.6.  The initial payment shall be provided to 
Transmission Owner by Interconnection Customer pursuant to this Article 11.5 within the 
later of a) forty-five (45) Calendar Days of the execution of the ZGIA by all Parties, or b) 
forty-five (45) Calendar Days of acceptance by FERC if the ZGIA is filed unexecuted 
and the payment is being protested by Interconnection Customer, or c) forty-five (45) 
Calendar Days of the filing if the ZGIA is filed unexecuted and the initial payment is not 
being protested by Interconnection Customer.  If the Interconnection Customer made its 
milestone payments in the form of cash and the Interconnection Customer elects a cash 
initial payment, then the Transmission Provider shall transfer those funds to the 
Transmission Owner on the Interconnection Customer’s behalf. 
 
11.6 
Provision of Security.  Unless a milestone cash payment schedule is  provided in 
Appendix B, Interconnection Customer shall, at least forty-five (45) Calendar Days prior

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
to the commencement of the design, procurement, installation, or construction of a 
discrete portion of a facility, not otherwise funded under Article 11.5, provide additional 
security.  Additionally, the Interconnection Customer will be required to provide security 
more than forty-five (45) Calendar Days in advance if requested by Transmission Owner 
because regulatory approvals are required for the construction of such facilities.  
Interconnection Customer shall provide Transmission Owner, at Interconnection 
Customer’s selection, a guarantee, a surety bond, letter of credit or other form of security 
that is reasonably acceptable to Transmission Owner and is consistent with the Uniform 
Commercial Code of the jurisdiction identified in Article 14.2.1.  Such security for 
payment, as specified in Appendix B of this ZGIA, shall be in an amount sufficient to 
cover the applicable costs and cost commitments, in addition to those funded under 
Article 11.5,  required of the Party responsible for building the facilities pursuant to the 
construction schedule developed in Appendix B for designing, engineering, seeking 
regulatory approval from any Governmental Authority, constructing, procuring and 
installing the applicable portion of the Transmission Owner’s Interconnection Facilities, 
Transmission Owner’s System Protection Facilities, Network Upgrades, Distribution 
Upgrades or Stand-Alone Network Upgrades and shall be reduced on a dollar-for-dollar 
basis for payments made to Transmission Owner for these purposes.  Transmission 
Owner must use the milestone payments required under the GIP before requiring 
Interconnection Customer to submit additional security.  Transmission Owner must 
specify, in Appendix B of this ZGIA, the dates for which Interconnection Customer must 
provide additional security for construction of each discrete portion of Transmission 
Owner's Interconnection Facilities, Network Upgrades, or Distribution Upgrades and 
Interconnection Customer must provide such additional security.  
 
 
In addition: 
 
11.6.1 
The guarantee must be made by an entity that meets the creditworthiness 
requirements of Transmission Owner, and contain terms and conditions that

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ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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guarantee payment of any amount that may be due from Interconnection 
Customer, up to an agreed-to maximum amount.  
 
11.6.2 
The letter of credit must be issued by a financial institution reasonably 
acceptable to Transmission Owner and must specify a reasonable expiration 
date.   
 
11.6.3 
The surety bond must be issued by an insurer reasonably acceptable to 
Transmission Owner and must specify a reasonable expiration date.  
 
11.6.4 
If the Shared Network Upgrade is not in service, Interconnection Customer will 
not be required to make a payment under Schedule 26-B until the Shared 
Network Upgrade is in service, but Interconnection Customer will provide, as 
applicable, an Irrevocable Letter of Credit to fund any Shared Network Upgrade 
pursuant to Attachment FF of the Tariff.  The Irrevocable Letter of Credit shall 
be in an amount sufficient to cover the Interconnection Customer’s share of the 
applicable costs and cost commitments associated with the Shared Network 
Upgrades.  Transmission Provider may periodically adjust the Interconnection 
Customer’s share of the applicable costs and cost commitment of Shared 
Network Upgrades and may require Interconnection Customer to adjust the 
amount of the Irrevocable Letter of Credit accordingly.   
 
11.7 
Interconnection Customer Compensation.  If Transmission Provider requests or directs 
Interconnection Customer to provide a service pursuant to Article 13.4 of this ZGIA, 
Transmission Provider shall compensate Interconnection Customer in accordance with 
any tariff or rate schedule filed by Transmission Provider and approved by the FERC. 
 
11.8  Provision of Security for JTIQ Upgrades. If the Transmission Provider determines that 
the Interconnection Request meets the distribution factor and impact criteria specified in 
Section 9.4.2(d)((ii) of Rate Schedule 6 (MISO SPP JOA) and is included in the JTIQ 
Participation Group, Interconnection Customer shall be required to provide security in

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Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
accordance with Attachment X, Appendix 18 (MISO JTIQ Commitment Agreement) and 
SPP’s JTIQ Service Agreement. 
 
ARTICLE 12.  INVOICE 
 
12.1 
General.  Each Party shall submit to the other Party, on a monthly basis, invoices of 
amounts due, if any, for the preceding month.  Each invoice shall state the month to 
which the invoice applies and fully describe the services and equipment provided.  The 
Parties may discharge mutual debts and payment obligations due and owing to each other 
on the same date through netting, in which case all amounts a Party owes to the other 
Party under this ZGIA, including interest payments or credits, shall be netted so that only 
the net amount remaining due shall be paid by the owing Party. 
 
12.2 
Final Invoice.  Within six (6) months after completion of the construction of the 
Transmission Owner’s Interconnection Facilities, Transmission Owner’s System 
Protection Facilities, Distribution Upgrades and the Network Upgrades, Transmission 
Owner shall provide an invoice of the final cost of the construction of the Transmission 
Owner’s Interconnection Facilities, Transmission Owner’s System Protection Facilities, 
Distribution Upgrades and the Network Upgrades and shall set forth such costs in 
sufficient detail to enable Interconnection Customer to compare the actual costs with the 
estimates and to ascertain deviations, if any, from the cost estimates.  Transmission 
Owner shall refund, with interest (calculated in accordance with 18 C.F.R. Section 
35.19a(a)(2)(iii), to Interconnection Customer any amount by which the actual payment 
by Interconnection Customer for estimated costs exceeds the actual costs of construction 
within thirty (30) Calendar Days of the issuance of such final construction invoice.  
 
12.3 
Payment.  Invoices shall be rendered to the paying Party at the address specified in 
Appendix F.  The Party receiving the invoice shall pay the invoice within thirty (30) 
Calendar Days of receipt.  All payments shall be made in immediately available funds 
payable to the other Party, or by wire transfer to a bank named and account designated by

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
the invoicing Party.  Payment of invoices by a Party will not constitute a waiver of any 
rights or claims that Party may have under this ZGIA.  
 
12.4 
Disputes.  In the event of a billing dispute among the Parties, Transmission Provider 
shall continue to provide Interconnection Service under this ZGIA as long as 
Interconnection Customer:  (i) continues to make all payments not in dispute; and (ii) 
pays to Transmission Provider or Transmission Owner or into an independent escrow 
account the portion of the invoice in dispute, pending resolution of such dispute.  If 
Interconnection Customer fails to meet these two requirements for continuation of 
service, then Transmission Provider may or, at Transmission Owner’s request upon 
Interconnection Customer’s failure to pay, Transmission Owner, shall provide notice to 
Interconnection Customer of a Default pursuant to Article 17.  Within thirty (30) 
Calendar Days after the resolution of the dispute, the Party that owes money to another 
Party shall pay the amount due with interest calculated in accord with the methodology 
set forth in 18 C.F.R. § 35.19a(a)(2)(iii). 
 
ARTICLE 13.  EMERGENCIES 
 
13.1 
Obligations.  Each Party shall comply with the Emergency Condition procedures of 
Transmission Provider,  the Electric Reliability Organization, and Applicable Laws and 
Regulations. 
 
13.2 
Notice.  Transmission Provider or Transmission Owner shall notify the other Parties 
promptly when it becomes aware of an Emergency Condition that affects the 
Transmission Owner’s Interconnection Facilities or the Transmission or Distribution 
System, as applicable, that may reasonably be expected to affect Interconnection 
Customer’s operation of the Generating Facility or the Interconnection Customer’s 
Interconnection Facilities.   
 
Interconnection Customer shall notify Transmission Provider and Transmission Owner, 
which includes by definition if applicable, the operator of a Distribution System,

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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promptly when it becomes aware of an Emergency Condition that affects the Generating 
Facility or the Interconnection Customer’s Interconnection Facilities that may reasonably 
be expected to affect the Transmission or Distribution System, as applicable, or the 
Transmission Owner’s Interconnection Facilities.   
 
To the extent information is known, the notification shall describe the Emergency 
Condition, the extent of the damage or deficiency, the expected effect on the operation of 
Interconnection Customer’s or Transmission Provider’s or Transmission Owner’s 
facilities and operations, its anticipated duration and the corrective action taken and/or to 
be taken.  The initial notice shall be followed as soon as practicable with written notice. 
 
13.3 
Immediate Action.  Unless, in a Party’s reasonable judgment, immediate action is 
required, the Party exercising such judgment shall notify and obtain the consent of the 
other Parties, such consent to not be unreasonably withheld, prior to performing any 
manual switching operations at the Generating Facility or the Interconnection Customer’s 
Interconnection Facilities in response to an Emergency Condition either declared by 
Transmission Provider or otherwise regarding the Transmission or Distribution System, 
as applicable. 
 
13.4 
Transmission Provider and Transmission Owner Authority. 
 
13.4.1 
General.  Transmission Provider or Transmission Owner may take whatever 
actions or inactions with regard to the Transmission System or the Transmission 
Owner’s Interconnection Facilities it deems necessary during an Emergency 
Condition in order to (i) preserve public health and safety, (ii) preserve the 
reliability of the Transmission System or the Transmission Owner’s 
Interconnection Facilities, (iii) limit or prevent damage, and (iv) expedite 
restoration of service. 
 
Transmission Provider or Transmission Owner shall use Reasonable Efforts to 
minimize the effect of such actions or inactions on the Generating Facility or the

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
Interconnection Customer’s Interconnection Facilities.  Transmission Provider 
or Transmission Owner may, on the basis of technical considerations, require 
the Generating Facility to mitigate an Emergency Condition by taking actions 
necessary and limited in scope to remedy the Emergency Condition, including, 
but not limited to, directing Interconnection Customer to shut-down, start-up, 
increase or decrease the real or reactive power output of the Generating Facility; 
implementing a reduction or disconnection pursuant to Article 13.4.2; directing 
Interconnection Customer to assist with blackstart (if available) or restoration 
efforts; or altering the outage schedules of the Generating Facility and the 
Interconnection Customer’s Interconnection Facilities.  Interconnection 
Customer shall comply with all of Transmission Provider’s or Transmission 
Owner’s operating instructions concerning Generating Facility real power and 
reactive power output within the manufacturer’s design limitations of the 
Generating Facility’s equipment that is in service and physically available for 
operation at the time, in compliance with Applicable Laws and Regulations. 
 
13.4.2 
Reduction and Disconnection.  Transmission Provider or Transmission Owner 
may reduce Interconnection Service or disconnect the Generating Facility or the 
Interconnection Customer’s Interconnection Facilities, when such reduction or 
disconnection is necessary under Good Utility Practice due to Emergency 
Conditions.  These rights are separate and distinct from any right of curtailment 
of Transmission Provider pursuant to the Tariff.  When Transmission Provider 
can schedule the reduction or disconnection in advance, Transmission Provider 
shall notify Interconnection Customer of the reasons, timing and expected 
duration of the reduction or disconnection. Transmission Provider shall 
coordinate with Interconnection Customer and Transmission Owner using Good 
Utility Practice to schedule the reduction or disconnection during periods of 
least impact to Interconnection Customer, Transmission Owner and 
Transmission Provider.  Any reduction or disconnection shall continue only for 
so long as reasonably necessary pursuant to Good Utility Practice.  The Parties 
shall cooperate with each other to restore the Generating Facility, the

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
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Interconnection Facilities, and the Transmission System to their normal 
operating state as soon as practicable consistent with Good Utility Practice. 
 
13.5 
Interconnection Customer Authority.  Consistent with Good Utility Practice and this 
ZGIA and the GIP, Interconnection Customer may take whatever actions or inactions 
with regard to the Generating Facility or the Interconnection Customer’s Interconnection 
Facilities during an Emergency Condition in order to (i) preserve public health and 
safety, (ii) preserve the reliability of the Generating Facility or the Interconnection 
Customer’s Interconnection Facilities, (iii) limit or prevent damage, and (iv) expedite 
restoration of service.  Interconnection Customer shall use Reasonable Efforts to 
minimize the effect of such actions or inactions on the Transmission System and the 
Transmission Owner’s Interconnection Facilities.  Transmission Provider and 
Transmission Owner shall use Reasonable Efforts to assist Interconnection Customer in 
such actions.   
 
13.6 
Limited Liability.  Except as otherwise provided in Article 11.6 of this ZGIA, no Party 
shall be liable to any other for any action it takes in responding to an Emergency 
Condition so long as such action is made in good faith and is consistent with Good Utility 
Practice. 
 
13.7 Audit.  In accordance with Article 25.3, any Party may audit the performance of another 
Party when that Party declared an Emergency Condition. 
 
ARTICLE 14.  REGULATORY REQUIREMENTS AND GOVERNING LAW 
 
14.1 
Regulatory Requirements.  Each Party’s obligations under this ZGIA shall be subject to 
its receipt of any required approval or certificate from one or more Governmental 
Authorities in the form and substance satisfactory to the applying Party, or the Party 
making any required filings with, or providing notice to, such Governmental Authorities, 
and the expiration of any time period associated therewith.  Each Party shall in good faith 
seek, and if necessary assist the other Party and use its Reasonable Efforts to obtain such

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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other approvals.  Nothing in this ZGIA shall require Interconnection Customer to take 
any action that could result in its inability to obtain, or its loss of, status or exemption 
under the Federal Power Act, the Public Utility Holding Company Act of 2005, as 
amended, or the Public Utility Regulatory Policies Act of 1978. 
 
14.2 
Governing Law. 
 
14.2.1 
The validity, interpretation and performance of this ZGIA and each of its 
provisions shall be governed by the laws of the state where the Point of 
Interconnection is located, without regard to its conflicts of law principles.  
 
14.2.2 
This ZGIA is subject to all Applicable Laws and Regulations.  
 
14.2.3 
Each Party expressly reserves the right to seek changes in, appeal, or otherwise 
contest any laws, orders, rules, or regulations of a Governmental Authority. 
 
ARTICLE 15.  NOTICES 
 
15.1 
General.  Unless otherwise provided in this ZGIA, any notice, demand or request 
required or permitted to be given by any Party to the other Parties and any instrument 
required or permitted to be tendered or delivered by a Party in writing to the other Parties 
shall be effective when delivered and may be so given, tendered or delivered, by 
recognized national courier, or by depositing the same with the United States Postal 
Service with postage prepaid, for delivery by certified or registered mail, addressed to the 
Party, or personally delivered to the Party, at the address set out in Appendix F, 
Addresses for Delivery of Notices and Billings. 
 
Either Party may change the notice information in this ZGIA by giving five (5) Business 
Days written notice prior to the effective date of the change.

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15.2 
Billings and Payments.  Billings and payments shall be sent to the addresses set out in 
Appendix F. 
 
15.3 
Alternative Forms of Notice.  Any notice or request required or permitted to be given by 
any Party to the other and not required by this ZGIA to be given in writing may be so 
given by telephone, facsimile or email to the telephone numbers and email addresses set 
out in Appendix F. 
 
15.4 
Operations and Maintenance Notice.  Each Party shall notify the other Parties in 
writing of the identity of the person(s) that it designates as the point(s) of contact with 
respect to the implementation of Articles 9 and 10. 
 
ARTICLE 16.  FORCE MAJEURE 
 
16.1 
Force Majeure.   
 
16.1.1 
Economic hardship is not considered a Force Majeure event. 
 
16.1.2 
A Party shall not be considered to be in Default with respect to any obligation 
hereunder, (including obligations under Article 4 and 5), other than the 
obligation to pay money when due, if prevented from fulfilling such obligation 
by Force Majeure.  A Party unable to fulfill any obligation hereunder (other than 
an obligation to pay money when due) by reason of Force Majeure shall give 
notice and the full particulars of such Force Majeure to the other Parties in 
writing or by telephone as soon as reasonably possible after the occurrence of 
the cause relied upon.  Telephone, facsimile or email notices given pursuant to 
this Article shall be confirmed in writing as soon as reasonably possible and 
shall specifically state full particulars of the Force Majeure, the time and date 
when the Force Majeure occurred and when the Force Majeure is reasonably 
expected to cease.  The Party affected shall exercise Reasonable Efforts to 
remove such disability with reasonable dispatch, but shall not be required to

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ATTACHMENTS 
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accede or agree to any provision not satisfactory to it in order to settle and 
terminate a strike or other labor disturbance. 
 
ARTICLE 17.  DEFAULT 
 
17.1 
Default 
 
17.1.1 
General.  No Default shall exist where such failure to discharge an obligation 
(other than the payment of money) is the result of Force Majeure as defined in 
this ZGIA or the result of an act or omission of another Party.  Upon a Breach, 
the non-Breaching Party or Parties shall give written notice of such Breach to 
the Breaching Party with a copy to the other Party if one Party gives notice of 
such Breach.  Except as provided in Article 17.1.2, the Breaching Party shall 
have thirty (30) Calendar Days from receipt of the Breach notice within which 
to cure such Breach; provided however, if such Breach is not capable of cure 
within thirty (30) Calendar Days, the Breaching Party shall commence such cure 
within thirty (30) Calendar Days after notice and continuously and diligently 
complete such cure within ninety (90) Calendar Days from receipt of the Breach 
notice; and, if cured within such time, the Breach specified in such notice shall 
cease to exist. 
 
17.1.2 
Termination.  If a Breach is not cured as provided in this Article, or if a Breach 
is not capable of being cured within the period provided for herein, the non-
Breaching Party or Parties shall terminate this ZGIA, subject to Article 2.3.2 of 
this ZGIA, by written notice to the Breaching Party, with a copy to the other 
Party if one Party gives notice of termination, and be relieved of any further 
obligation hereunder and, whether or not that Party(ies) terminates this ZGIA, to 
recover from the Breaching Party all amounts due hereunder, plus all other 
damages and remedies to which it is (they are) entitled at law or in equity.  The 
provisions of this Article will survive termination of this ZGIA.

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17.1.3 
Cross-Default.  Pursuant to Article 11.3 of this ZGIA, the Parties shall enter into 
a Facilities Service Agreement if the Transmission Owner has elected to fund 
the capital for the Network Upgrades and/or Transmission Owner’s System 
Protection Facilities.  Notwithstanding anything to the contrary contained in this 
ZGIA, a breach by Interconnection Customer of any provision, covenant, or 
other term or condition contained in the Facilities Service Agreement shall be 
considered a breach under this ZGIA.  Such breach shall be subject to the terms 
of Article 17 of this ZGIA.  If a default under this ZGIA results from the 
Interconnection Customer’s breach of the Facilities Service Agreement and 
subsequent failure to cure, the Transmission Owner and Transmission Provider 
shall be entitled, but in no event required, to apply all rights and remedies 
available by reason of default under the Facilities Service Agreement and this 
ZGIA. 
 
 
Pursuant to Section 11.3 of the GIP, an Interconnection Customer included in a 
JTIQ Participation Group shall execute or request the unexecuted filing both of 
the Transmission Provider’s JTIQ Commitment Agreement and the JTIQ 
Service Agreement included in SPP’s tariff. Notwithstanding anything to the 
contrary contained in this ZGIA, a breach by Interconnection Customer of any 
provision, covenant, or other term or condition contained in the JTIQ 
Commitment Agreement or SPP’s JTIQ Service Agreement shall be considered 
a breach under this ZGIA.  Such breach shall be subject to the terms of Article 
17 of this ZGIA provided, however, that the manner and timing of cure of such 
breach shall adhere to the requirements of the applicable agreement and cure in 
accordance with the provisions of such agreement shall also cure the breach of 
this GI.  If a default under this ZGIA results from the Interconnection 
Customer’s breach of the JTIQ Commitment Agreement or SPP JTIQ Service 
Agreement and subsequent failure to cure, the Transmission Owner and 
Transmission Provider shall be entitled, but in no event required, to apply all 
rights and remedies available by reason of default under the JTIQ Commitment 
Agreement, SPP JTIQ Service Agreement, and this ZGIA.

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17.2 
Violation of Operating Assumptions for Generating Facilities.  If Transmission 
Provider requires Interconnection Customer to memorialize the operating assumptions for 
the charging behavior of the Generating Facility that includes at least one electric storage 
resource in Appendix A of this ZGIA, Transmission Provider may consider 
Interconnection Customer to be in Breach of the ZGIA if Interconnection Customer fails 
to operate the Generating Facility in accordance with those operating assumptions for 
charging behavior.  However, if Interconnection Customer operates contrary to the 
operating assumptions for charging behavior specified in Appendix A of this ZGIA at the 
direction of Transmission Provider, Transmission Provider shall not consider 
Interconnection Customer in Breach of this ZGIA.  
 
 
ARTICLE 18.  LIMITATION OF LIABILITY, INDEMNITY, CONSEQUENTIAL 
DAMAGES AND INSURANCE 
 
18.1 
Limitation of Liability.  A Party shall not be liable to another Party or to any third party 
or other person for any damages arising out of actions under this ZGIA, including, but 
not limited to, any act or omission that results in an interruption, deficiency or 
imperfection of Interconnection Service, except as provided in this Tariff.  The provisions 
set forth in the Tariff shall be additionally applicable to any Party acting in good faith to 
implement or comply with its obligations under this ZGIA, regardless of whether the 
obligation is preceded by a specific directive. 
 
18.2 
Indemnity.  To the extent permitted by law, an Indemnifying Party shall at all times 
indemnify, defend and hold the other Parties harmless from Loss. 
 
18.2.1 
Indemnified Party.  If an Indemnified Party is entitled to indemnification under 
this Article 18 as a result of a claim by a non-Party, and the Indemnifying Party 
fails, after notice and reasonable opportunity to proceed under Article 18.2, to 
assume the defense of such claim, such Indemnified Party may at the expense of

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the Indemnifying Party contest, settle or consent to the entry of any judgment 
with respect to, or pay in full, such claim. 
 
18.2.2 
Indemnifying Party.  If an Indemnifying Party is obligated to indemnify and 
hold any Indemnified Party harmless under this Article 18, the amount owing to 
the Indemnified Party shall be the amount of such Indemnified Party’s actual 
Loss, net of any insurance or other recovery. 
 
18.2.3 
Indemnity Procedures.  Promptly after receipt by an Indemnified Party of any 
claim or notice of the commencement of any action or administrative or legal 
proceeding or investigation as to which the indemnity provided for in 
Article 18.2 may apply, the Indemnified Party shall notify the Indemnifying 
Party of such fact.  Any failure of or delay in such notification shall not affect a 
Party’s indemnification obligation unless such failure or delay is materially 
prejudicial to the Indemnifying Party. 
 
The Indemnifying Party shall have the right to assume the defense thereof with 
counsel designated by such Indemnifying Party and reasonably satisfactory to 
the Indemnified Party.  If the defendants in any such action include one or more 
Indemnified Parties and the Indemnifying Party and if the Indemnified Party 
reasonably concludes that there may be legal defenses available to it and/or 
other Indemnified Parties which are different from or additional to those 
available to the Indemnifying Party, the Indemnified Party shall have the right to 
select separate counsel to assert such legal defenses and to otherwise participate 
in the defense of such action on its own behalf.  In such instances, the 
Indemnifying Party shall only be required to pay the fees and expenses of one 
additional attorney to represent an Indemnified Party or Indemnified Parties 
having such differing or additional legal defenses. 
 
The Indemnified Party shall be entitled, at its expense, to participate in any such 
action, suit or proceeding, the defense of which has been assumed by the

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Indemnifying Party.  Notwithstanding the foregoing, the Indemnifying Party 
(i) shall not be entitled to assume and control the defense of any such action, 
suit or proceedings if and to the extent that, in the opinion of the Indemnified 
Party and its counsel, such action, suit or proceeding involves the potential 
imposition of criminal liability on the Indemnified Party, or there exists a 
conflict or adversity of interest between the Indemnified Party and the 
Indemnifying Party, in such event the Indemnifying Party shall pay the 
reasonable expenses of the Indemnified Party, and (ii) shall not settle or consent 
to the entry of any judgment in any action, suit or proceeding without the 
consent of the Indemnified Party, which shall not be reasonably withheld, 
conditioned or delayed. 
 
18.3 Consequential Damages.  Other than the Liquidated Damages heretofore described, in 
no event shall either Party be liable under any provision of this ZGIA for any losses, 
damages, costs or expenses for any special, indirect, incidental, consequential, or punitive 
damages, including but not limited to loss of profit or revenue, loss of the use of 
equipment, cost of capital, cost of temporary equipment or services, whether based in 
whole or in part in contract, in tort, including negligence, strict liability, or any other 
theory of liability; provided; however, that damages for which a Party may be liable to the 
other Party under another agreement will not be considered to be special, indirect, 
incidental, or consequential damages hereunder. 
 
18.4 
Insurance.  Transmission Owner and Interconnection Customer shall, at their own 
expense, maintain in force throughout the period of this ZGIA pursuant to 18.4.9, and 
until released by the other Party, the following minimum insurance coverages, with 
insurers authorized to do business or an approved surplus lines carrier in the state where 
the Point of Interconnection is located: 
 
18.4.1 
Employers’ Liability and Workers’ Compensation Insurance providing statutory 
benefits in accordance with the laws and regulations of the state in which the 
Point of Interconnection is located.

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18.4.2 
Commercial General Liability Insurance including premises and operations, 
personal injury, broad form property damage, broad form blanket contractual 
liability coverage (including coverage for the contractual indemnification) 
products and completed operations coverage, coverage for explosion, collapse 
and underground hazards, independent contractors coverage, coverage for 
pollution to the extent normally available and punitive damages to the extent 
normally available and a cross liability endorsement, with minimum limits of 
One Million Dollars ($1,000,000) per occurrence/One Million Dollars 
($1,000,000) aggregate  combined single limit for personal injury, bodily injury, 
including death and property damage. 
 
18.4.3 
Comprehensive Automobile Liability Insurance, for coverage of owned and 
non-owned and hired vehicles, trailers or semi-trailers licensed for travel on 
public roads, with a minimum combined single limit of One Million Dollars 
($1,000,000) each occurrence for bodily injury, including death, and property 
damage. 
 
18.4.4 
Excess Public Liability Insurance over and above the Employer’s Liability, 
Commercial General Liability and Comprehensive Automobile Liability 
Insurance coverage, with a minimum combined single limit of Twenty Million 
Dollars ($20,000,000) per occurrence/Twenty Million Dollars ($20,000,000) 
aggregate for generators not eligible for the Fast Track Process in GIP Section 
14.  The requirement for generators eligible for the Fast Track Process in GIP 
Section 14 is a minimum combined single limit of Five Million Dollars 
($5,000,000) per occurrence/Five Million Dollars ($5,000,000) aggregate.. 
 
18.4.5 
The Commercial General Liability Insurance, Comprehensive Automobile 
Insurance and Excess Public Liability Insurance policies shall name the other 
Parties, their parents, associated and Affiliate companies and their respective 
directors, officers, agents, servants and employees (“Other Party Group”) as

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additional insured.  All policies shall contain provisions whereby the insurers 
waive all rights of subrogation in accordance with the provisions of this ZGIA 
against the Other Party Groups and provide thirty (30) Calendar Days’ advance 
written notice to the Other Party Groups prior to anniversary date of 
cancellation or any material change in coverage or condition. 
 
 
18.4.6 
The Commercial General Liability Insurance, Comprehensive Automobile 
Liability Insurance and Excess Public Liability Insurance policies shall contain 
provisions that specify that the policies are primary and shall apply to such 
extent without consideration for other policies separately carried and shall state 
that each insured is provided coverage as though a separate policy had been 
issued to each, except the insurer’s liability shall not be increased beyond the 
amount for which the insurer would have been liable had only one insured been 
covered.  Each Party shall be responsible for its respective deductibles or 
retentions. 
 
18.4.7 
The Commercial General Liability Insurance, Comprehensive Automobile 
Liability Insurance and Excess Public Liability Insurance policies, if written on 
a Claims First Made Basis, shall be maintained in full force and effect for two 
(2) years after termination of this ZGIA, which coverage may be in the form of 
tail coverage or extended reporting period coverage if agreed by Transmission 
Owner and Interconnection Customer. 
 
18.4.8 
The requirements contained herein as to the types and limits of all insurance to 
be maintained by Transmission Owner and Interconnection Customer are not 
intended to and shall not in any manner, limit or qualify the liabilities and 
obligations assumed by Transmission Owner and Interconnection Customer 
under this ZGIA. 
 
18.4.9 
As of the date set forth in Appendix B, Milestones, and as soon as practicable 
after the end of each fiscal year or at the renewal of the insurance policy and in

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any event within ninety (90) Calendar Days thereafter, Interconnection 
Customer and Transmission Owner shall provide the other Party with 
certification of all insurance required in this ZGIA, executed by each insurer or 
by an authorized representative of each insurer.   
 
18.4.10  Notwithstanding the foregoing, Transmission Owner or Interconnection 
Customer may self-insure to meet the minimum insurance requirements of 
Articles 18.4.1 through 18.4.8, to the extent it maintains a self-insurance 
program; provided that, Transmission Owner’s or Interconnection Customer’s 
senior secured debt is rated at investment grade, or better, by Standard & Poor’s 
and that its self-insurance program meets minimum insurance requirements 
under Articles 18.4.1 through 18.4.8.  For any period of time that a 
Transmission Owner’s or Interconnection Customer’s senior secured debt is 
unrated by Standard & Poor’s or is rated at less than investment grade by 
Standard & Poor’s, such Party shall comply with the insurance requirements 
applicable to it under Articles 18.4.1 through 18.4.9.  In the event that 
Transmission Owner or Interconnection Customer is permitted to self-insure 
pursuant to this article, it shall notify the other Party that it meets the 
requirements to self-insure and that its self-insurance program meets the 
minimum insurance requirements in a manner consistent with that specified in 
Article 18.4.9. 
 
18.4.11 Transmission Owner and Interconnection Customer agree to report to each other 
in writing as soon as practical all accidents or occurrences resulting in injuries to 
any person, including death, and any property damage arising out of this ZGIA. 
 
ARTICLE 19.  ASSIGNMENT 
 
19.1 
Assignment.  This ZGIA may be assigned by any Party only with the written consent of 
the other Parties; provided that a Party may assign this ZGIA without the consent of the 
other Parties to any Affiliate of the assigning Party with an equal or greater credit rating

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and with the legal authority and operational ability to satisfy the obligations of the 
assigning Party under this ZGIA; and provided further that Interconnection Customer 
shall have the right to assign this ZGIA, without the consent of either Transmission 
Provider or Transmission Owner, for collateral security purposes to aid in providing 
financing for the Generating Facility, provided that Interconnection Customer will 
promptly notify Transmission Provider of any such assignment.  Any financing 
arrangement entered into by Interconnection Customer pursuant to this Article will 
provide that prior to or upon the exercise of the secured party’s, trustee’s or mortgagee’s 
assignment rights pursuant to said arrangement, the secured creditor, the trustee or 
mortgagee will notify Transmission Provider of the  date and particulars of any such 
exercise of assignment right(s), including providing Transmission Provider and 
Transmission Owner with proof that it meets the requirements of Article 11.5 and 18.4.  
Any attempted assignment that violates this Article is void and ineffective.  Any 
assignment under this ZGIA shall not relieve a Party of its obligations, nor shall a Party’s 
obligations be enlarged, in whole or in part, by reason thereof.  Where required, consent 
to assignment will not be unreasonably withheld, conditioned or delayed. 
 
ARTICLE 20.  SEVERABILITY 
 
20.1 
Severability.  If any provision in this ZGIA is finally determined to be invalid, void or 
unenforceable by any court or other Governmental Authority having jurisdiction, such 
determination shall not invalidate, void or make unenforceable any other provision, 
agreement or covenant of this ZGIA; provided that if Interconnection Customer (or any 
non-Party, but only if such non-Party is not acting at the direction of either Transmission 
Provider or Transmission Owner) seeks and obtains such a final determination with 
respect to any provision of the Alternate Option (Article 5.1.2), or the Negotiated Option 
(Article 5.1.4), then none of these provisions shall thereafter have any force or effect and 
the Parties’ rights and obligations shall be governed solely by the Standard Option 
(Article 5.1.1).  
 
ARTICLE 21.  COMPARABILITY

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21.1 
Comparability.  The Parties will comply with all applicable comparability and code of 
conduct laws, rules and regulations including such laws, rules and regulations of 
Governmental Authorities establishing standards of conduct, as amended from time to 
time. 
 
ARTICLE 22.  CONFIDENTIALITY 
 
22.1 
Confidentiality.  Confidential Information shall include, without limitation, all 
information relating to a Party’s technology, research and development, business affairs, 
and pricing, and any information supplied by a Party to another Party prior to the 
execution of this ZGIA. 
 
Information is Confidential Information only if it is clearly designated or marked in 
writing as confidential on the face of the document, or, if the information is conveyed 
orally or by inspection, if the Party providing the information orally informs the Party 
receiving the information that the information is confidential.  The Parties shall maintain 
as confidential any information that is provided and identified by a Party as Critical 
Energy Infrastructure Information (CEII), as that term is defined in 18 C.F.R. 
Section 388.113(c).  Such confidentiality will be maintained in accordance with this 
Article 22. 
 
If requested by the receiving Party, the disclosing Party shall provide in writing, the basis 
for asserting that the information referred to in this Article warrants confidential 
treatment, and the requesting Party may disclose such writing to the appropriate 
Governmental Authority.  Each Party shall be responsible for the costs associated with 
affording confidential treatment to its information. 
 
22.1.1 
Term.  During the term of this ZGIA, and for a period of three (3) years after the 
expiration or termination of this ZGIA, except as otherwise provided in this 
Article 22 or with regard to CEII, each Party shall hold in confidence and shall

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not disclose to any person Confidential Information.  CEII shall be treated in 
accordance with Commission policy and regulations. 
 
22.1.2 
Scope.  Confidential Information shall not include information that the receiving 
Party can demonstrate:  (1) is generally available to the public other than as a 
result of a disclosure by the receiving Party; (2) was in the lawful possession of 
the receiving Party on a non-confidential basis before receiving it from the 
disclosing Party; (3) was supplied to the receiving Party without restriction by a 
non-Party, who, to the knowledge of the receiving Party after due inquiry, was 
under no obligation to the disclosing Party to keep such information 
confidential; (4) was independently developed by the receiving Party without 
reference to Confidential Information of the disclosing Party; (5) is, or becomes, 
publicly known, through no wrongful act or omission of the receiving Party or 
Breach of this ZGIA; or (6) is required, in accordance with Article 22.1.7 of this 
ZGIA, Order of Disclosure, to be disclosed by any Governmental Authority or 
is otherwise required to be disclosed by law or subpoena, or is necessary in any 
legal proceeding establishing rights and obligations under this ZGIA.  
Information designated as Confidential Information will no longer be deemed 
confidential if the Party that designated the information as confidential notifies 
the receiving Party that it no longer is confidential. 
 
22.1.3 
Release of Confidential Information.  No Party shall release or disclose 
Confidential Information to any other person, except to its Affiliates (limited by 
the Standards of Conduct requirements), subcontractors, employees, agents, 
consultants, or to non-parties who may be or are considering providing 
financing to or equity participation with Interconnection Customer, or to 
potential purchasers or assignees of Interconnection Customer, on a need-to-
know basis in connection with this ZGIA, unless such person has first been 
advised of the confidentiality provisions of this Article 22 and has agreed to 
comply with such provisions.  Notwithstanding the foregoing, a Party providing

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Confidential Information to any person shall remain primarily responsible for 
any release of Confidential Information in contravention of this Article 22. 
 
22.1.4 
Rights.  Each Party retains all rights, title, and interest in the Confidential 
Information that it discloses to the receiving Party.  The disclosure by a Party to 
the receiving Party of Confidential Information shall not be deemed a waiver by 
the disclosing Party or any other person or entity of the right to protect the 
Confidential Information from public disclosure. 
 
22.1.5 
No Warranties.  By providing Confidential Information, no Party makes any 
warranties or representations as to its accuracy or completeness.  In addition, by 
supplying Confidential Information, no Party obligates itself to provide any 
particular information or Confidential Information to another Party nor to enter 
into any further agreements or proceed with any other relationship or joint 
venture. 
 
22.1.6 
Standard of Care.  Each Party shall use at least the same standard of care to 
protect Confidential Information it receives as it uses to protect its own 
Confidential Information from unauthorized disclosure, publication or 
dissemination.  Each Party may use Confidential Information solely to fulfill its 
obligations to another Party under this ZGIA or its regulatory requirements. 
 
22.1.7 
Order of Disclosure.  If a court or a Governmental Authority or entity with the 
right, power, and apparent authority to do so requests or requires any Party, by 
subpoena, oral deposition, interrogatories, requests for production of documents, 
administrative order, or otherwise, to disclose Confidential Information, that 
Party shall provide the disclosing Party with prompt notice of such request(s) or 
requirement(s) so that the disclosing Party may seek an appropriate protective 
order or waive compliance with the terms of this ZGIA.  Notwithstanding the 
absence of a protective order or waiver, the Party may disclose such 
Confidential Information which, in the opinion of its counsel, the Party is

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legally compelled to disclose.  Each Party will use Reasonable Efforts to obtain 
reliable assurance that confidential treatment will be accorded any Confidential 
Information so furnished. 
 
22.1.8 
Termination of Agreement.  Upon termination of this ZGIA for any reason, each 
Party shall, within ten (10) Calendar Days of receipt of a written request from 
another Party, use Reasonable Efforts to destroy, erase, or delete (with such 
destruction, erasure, and deletion certified in writing to the requesting Party) or 
return to the requesting Party, without retaining copies thereof, any and all 
written or electronic Confidential Information received from the requesting 
Party, except that each Party may keep one copy for archival purposes, provided 
that the obligation to treat it as Confidential Information in accordance with this 
Article 22 shall survive such termination. 
 
22.1.9 
Remedies.  The Parties agree that monetary damages would be inadequate to 
compensate a Party for another Party’s Breach of its obligations under this 
Article 22.  Each Party accordingly agrees that the disclosing Party shall be 
entitled to equitable relief, by way of injunction or otherwise, if the receiving 
Party Breaches or threatens to Breach its obligations under this Article 22, 
which equitable relief shall be granted without bond or proof of damages, and 
the Breaching Party shall not plead in defense that there would be an adequate 
remedy at law.  Such remedy shall not be deemed an exclusive remedy for the 
Breach of this Article 22, but shall be in addition to all other remedies available 
at law or in equity.  The Parties further acknowledge and agree that the 
covenants contained herein are necessary for the protection of legitimate 
business interests and are reasonable in scope.  No Party, however, shall be 
liable for indirect, incidental, or consequential or punitive damages of any 
nature or kind resulting from or arising in connection with this Article 22. 
 
22.1.10  Disclosure to FERC, its Staff or a State.  Notwithstanding anything in this 
Article 22 to the contrary, and pursuant to 18 CFR § 1b.20, if FERC or its staff,

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during the course of an investigation or otherwise, requests information from a 
Party that is otherwise required to be maintained in confidence pursuant to this 
ZGIA, the Party shall provide the requested information to FERC or its staff, 
within the time provided for in the request for information.  In providing the 
information to FERC or its staff, the Party must, consistent with 18 CFR 
§ 388.112, request that the information be treated as confidential and non-public 
by FERC and its staff and that the information be withheld from public 
disclosure.  Parties are prohibited from notifying the other Parties to this ZGIA 
prior to the release of the Confidential Information to FERC or its staff.  The 
Party shall notify the other Parties to this ZGIA when it is notified by FERC or 
its staff that a request to release Confidential Information has been received by 
FERC, at which time any of the Parties may respond before such information 
would be made public, pursuant to 18 CFR § 388.112.  Requests from a state 
regulatory body conducting a confidential investigation shall be treated in a 
similar manner if consistent with the applicable state rules and regulations.  
 
22.1.11 Subject to the exception in Article 22.1.10, any information that a disclosing 
Party claims is competitively sensitive, commercial or financial information 
under this ZGIA shall not be disclosed by the receiving Party to any person not 
employed or retained by the receiving Party, except to the extent disclosure is (i) 
required by law; (ii) reasonably deemed by the receiving Party to be required to 
be disclosed in connection with a dispute between or among the Parties, or the 
defense of litigation or dispute; (iii) otherwise permitted by consent of the 
disclosing Party, such consent not to be unreasonably withheld; or (iv) 
necessary to fulfill its obligations under this ZGIA or as the Regional 
Transmission Organization or a Local Balancing Authority operator including 
disclosing the Confidential Information to a regional or national reliability 
organization.  The Party asserting confidentiality shall notify the receiving Party 
in writing of the information that Party claims is confidential.  Prior to any 
disclosures of that Party’s Confidential Information under this subparagraph, or 
if any non-Party or Governmental Authority makes any request or demand for

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any of the information described in this subparagraph, the Party who received 
the Confidential Information from the disclosing Party agrees to promptly notify 
the disclosing Party in writing and agrees to assert confidentiality and cooperate 
with the disclosing Party in seeking to protect the Confidential Information from 
public disclosure by confidentiality agreement, protective order or other 
reasonable measures. 
 
ARTICLE 23.  ENVIRONMENTAL RELEASES 
 
23.1 
Each Party shall notify the other Parties, first orally and then in writing, of the release of 
any Hazardous Substances, any asbestos or lead abatement activities, or any type of 
remediation activities related to the Generating Facility or the Interconnection Facilities, 
each of which may reasonably be expected to affect another Party.  The notifying Party 
shall:  (i) provide the notice as soon as practicable, provided such Party makes a good 
faith effort to provide the notice no later than twenty-four hours after such Party becomes 
aware of the occurrence; and (ii) promptly furnish to the other Parties copies of any 
publicly available reports filed with any Governmental Authorities addressing such 
events. 
 
ARTICLE 24.  INFORMATION REQUIREMENTS 
 
24.1 
Information Acquisition.  Transmission Provider, Transmission Owner and 
Interconnection Customer shall submit specific information regarding the electrical 
characteristics of their respective facilities to each other as described below and in 
accordance with Applicable Reliability Standards. 
 
24.2 
Information Submission by Transmission Provider and Transmission Owner   The 
initial information submission by Transmission Provider to Interconnection Customer, 
with copy provided to Transmission Owner, shall occur no later than one hundred eighty 
(180) Calendar Days prior to Trial Operation and shall include Transmission or 
Distribution System information, as applicable and available, necessary to allow

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Interconnection Customer to select equipment and meet any system protection and 
stability requirements, unless otherwise mutually agreed to by the Parties.  On a monthly 
basis, Transmission Owner shall provide Interconnection Customer a status report on the 
construction and installation of Transmission Owner’s Interconnection Facilities, 
Transmission Owner’s System Protection Facilities, Distribution Upgrades and Network 
Upgrades, including, but not limited to, the following information: (1) progress to date; 
(2) a description of the activities since the last report (3) a description of the action items 
for the next period; and (4) the delivery status of equipment ordered. 
 
24.3 
Updated Information Submission by Interconnection Customer.  The updated 
information submission by Interconnection Customer to Transmission Provider, with 
copy to Transmission Owner, including manufacturer information, shall occur no later 
than one hundred eighty (180) Calendar Days prior to the Trial Operation.  
Interconnection Customer shall submit to Transmission Provider and Transmission 
Owner a completed copy of the Generating Facility data requirements contained in 
Appendix 1 to the GIP.  It shall also include any additional information provided to 
Transmission Provider for the Interconnection Facilities Study.  Information in this 
submission shall be the most current Generating Facility design or expected performance 
data.  Information submitted for stability models shall be compatible with Transmission 
Provider standard models.  If there is no compatible model, Interconnection Customer 
will work with a consultant mutually agreed to by Transmission Provider and 
Interconnection Customer to develop and supply a standard model and associated 
information. 
 
If the Interconnection Customer’s data is materially different from what was originally 
provided to Transmission Provider pursuant to the Interconnection Study Agreement 
between Transmission Provider and Interconnection Customer, then Transmission 
Provider will conduct appropriate studies to determine the impact on the Transmission 
System based on the actual data submitted pursuant to this Article 24.3.  Interconnection 
Customer shall not begin Trial Operation until such studies are completed.

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24.4 
Information Supplementation.  Prior to the Commercial Operation Date, the Parties 
shall supplement their information submissions described above in this Article 24 with 
any and all “as-built” Generating Facility information or “as-tested” performance 
information that differs from the initial submissions or, alternatively, written 
confirmation that no such differences exist.  Interconnection Customer shall conduct tests 
on the Generating Facility as required by Good Utility Practice, such as an open circuit 
“step voltage” test on the Generating Facility to verify proper operation of the Generating 
Facility’s automatic voltage regulator.   
 
Unless otherwise agreed, the test conditions shall include:  (1) Generating Facility at 
synchronous speed; (2) automatic voltage regulator on and in voltage control mode; and 
(3) a five percent (5 %) change in Generating Facility terminal voltage initiated by a 
change in the voltage regulators reference voltage.  Interconnection Customer shall 
provide validated test recordings showing the responses in Generating Facility terminal 
and field voltages.  In the event that direct recordings of these voltages is impractical, 
recordings of other voltages or currents that mirror the response of the Generating 
Facility’s terminal or field voltage are acceptable if information necessary to translate 
these alternate quantities to actual Generating Facility terminal or field voltages is 
provided.  Generating Facility testing shall be conducted and results provided to 
Transmission Provider and Transmission Owner for each individual generating unit in a 
station.  
 
Subsequent to the Commercial Operation Date, Interconnection Customer shall provide 
Transmission Provider and Transmission Owner any information changes due to 
equipment replacement, repair, or adjustment.  Transmission Owner shall provide 
Interconnection Customer, with copy to Transmission Provider, any information changes 
due to equipment replacement, repair or adjustment in the directly connected substation 
or any adjacent Transmission Owner substation that may affect the Interconnection 
Customer’s Interconnection Facilities equipment ratings, protection or operating 
requirements.  The Parties shall provide such information no later than thirty (30) 
Calendar Days after the date of the equipment replacement, repair or adjustment.

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
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ARTICLE 25.  INFORMATION ACCESS AND AUDIT RIGHTS 
 
25.1 
Information Access.  Each Party (the “disclosing Party”) shall make available to the 
other Parties information that is in the possession of the disclosing Party and is necessary 
in order for the other Parties to:  (i) verify the costs incurred by the disclosing Party for 
which another Party is responsible under this ZGIA; and (ii) carry out its obligations and 
responsibilities under this ZGIA.  The Parties shall not use such information for purposes 
other than those set forth in this Article 25.1 and to enforce their rights under this ZGIA. 
 
25.2 
Reporting of Non-Force Majeure Events.  A Party (the “notifying Party”) shall notify 
the other Parties when the notifying Party becomes aware of its inability to comply with 
the provisions of this ZGIA for a reason other than a Force Majeure event.  The Parties 
agree to cooperate with each other and provide necessary information regarding such 
inability to comply, including the date, duration, reason for the inability to comply, and 
corrective actions taken or planned to be taken with respect to such inability to comply.  
Notwithstanding the foregoing, notification, cooperation or information provided under 
this Article shall not entitle any Party receiving such notification to allege a cause for 
anticipatory breach of this ZGIA.  
 
25.3 
Audit Rights.  Subject to the requirements of confidentiality under Article 22 of this 
ZGIA, each Party shall have the right, during normal business hours, and upon prior 
reasonable notice to the other Parties, to audit at its own expense the other Parties’ 
accounts and records pertaining to the Parties’ performance or the Parties’ satisfaction of 
obligations under this ZGIA.  Such audit rights shall include audits of the other Parties’ 
costs, calculation of invoiced amounts, the Transmission Provider’s efforts to allocate 
responsibility for the provision of reactive support to the Transmission or Distribution 
System, as applicable, the Transmission Provider’s efforts to allocate responsibility for 
interruption or reduction of generation, and each Party’s actions in an Emergency 
Condition.  Any audit authorized by this Article shall be performed at the offices where 
such accounts and records are maintained and shall be limited to those portions of such

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
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accounts and records that relate to each Party’s performance and satisfaction of 
obligations under this ZGIA.  Each Party shall keep such accounts and records for a 
period equivalent to the audit rights periods described in Article 25.4.  
 
25.4 
Audit Rights Periods. 
 
25.4.1 
Audit Rights Period for Construction-Related Accounts and Records.  
Accounts and records related to the design, engineering, procurement, and 
construction of the Transmission Owner’s Interconnection Facilities, 
Transmission Owner’s System Protection Facilities, Distribution Upgrades and 
Network Upgrades shall be subject to audit for a period of twenty-four months 
following Transmission Owner’s issuance of a final invoice in accordance with 
Article 12.2. 
 
25.4.2 
Audit Rights Period for All Other Accounts and Records.  Accounts and 
records related to a Party’s performance or satisfaction of all obligations under 
this ZGIA other than those described in Article 25.4.1 shall be subject to audit 
as follows:  (i) for an audit relating to cost obligations, the applicable audit 
rights period shall be twenty-four (24) months after the auditing Party’s receipt 
of an invoice giving rise to such cost obligations; and (ii) for an audit relating to 
all other obligations, the applicable audit rights period shall be twenty-four (24) 
months after the event for which the audit is sought.   
 
25.5 
Audit Results.  If an audit by a Party determines that an overpayment or an 
underpayment has occurred, a notice of such overpayment or underpayment shall be 
given to the Party or from whom the overpayment or underpayment is owed together with 
those records from the audit which support such determination.   
 
ARTICLE 26.  SUBCONTRACTORS

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26.1 
General.  Nothing in this ZGIA shall prevent a Party from utilizing the services of any 
subcontractor as it deems appropriate to perform its obligations under this ZGIA; 
provided, however, that each Party shall require its subcontractors to comply with all 
applicable terms and conditions of this ZGIA in providing such services and each Party 
shall remain primarily liable to the other Parties for the performance of such 
subcontractor. 
 
26.2 
Responsibility of Principal.  The creation of any subcontract relationship shall not 
relieve the hiring Party of any of its obligations under this ZGIA.  The hiring Party shall 
be fully responsible to the other Parties for the acts or omissions of any subcontractor the 
hiring Party hires as if no subcontract had been made; provided, however, that in no event 
shall Transmission Provider or Transmission Owner be liable for the actions or inactions 
of Interconnection Customer or its subcontractors with respect to obligations of 
Interconnection Customer under Article 5 of this ZGIA.  Any applicable obligation 
imposed by this ZGIA upon the hiring Party shall be equally binding upon, and shall be 
construed as having application to, any subcontractor of such Party. 
 
26.3 
No Limitation by Insurance.  The obligations under this Article 26 will not be limited in 
any way by any limitation of subcontractor’s insurance. 
 
ARTICLE 27.  DISPUTES 
 
27.1 
Submission.  In the event any Party has a dispute, or asserts a claim, that arises out of or 
in connection with this ZGIA or its performance, such Party (the “disputing Party”) shall 
provide the other Parties with written notice of the dispute or claim (“Notice of 
Dispute”).  Such dispute or claim shall be referred to a designated senior representative of 
each Party for resolution on an informal basis as promptly as practicable after receipt of 
the Notice of Dispute by the non-disputing Parties.  In the event the designated 
representatives are unable to resolve the claim or dispute through unassisted or assisted 
negotiations within thirty (30) Calendar Days of the non-disputing Parties’ receipt of the

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
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Notice of Dispute, such claim or dispute shall be submitted for resolution in accordance 
with the dispute resolution procedures of the Tariff. 
 
ARTICLE 28.  REPRESENTATIONS, WARRANTIES AND COVENANTS 
 
28.1 
General.  Each Party makes the following representations, warranties and covenants:  
 
28.1.1 
Good Standing.  Such Party is duly organized, validly existing and in good 
standing under the laws of the state in which it is organized, formed, or 
incorporated, as applicable; that it is qualified to do business in the state or 
states in which the Generating Facility, Interconnection Facilities and Network 
Upgrades owned by such Party, as applicable, are located; and that it has the 
corporate power and authority to own its properties, to carry on its business as 
now being conducted and to enter into this ZGIA and carry out the transactions 
contemplated hereby and perform and carry out all covenants and obligations on 
its part to be performed under and pursuant to this ZGIA.  
 
28.1.2 
Authority.  Such Party has the right, power and authority to enter into this 
ZGIA, to become a Party hereto and to perform its obligations hereunder.  This 
ZGIA is a legal, valid and binding obligation of such Party, enforceable against 
such Party in accordance with its terms, except as the enforceability thereof may 
be limited by applicable bankruptcy, insolvency, reorganization or other similar 
laws affecting creditors’ rights generally and by general equitable principles 
(regardless of whether enforceability is sought in a proceeding in equity or at 
law). 
 
28.1.3 
No Conflict.  The execution, delivery and performance of this ZGIA does not 
violate or conflict with the organizational or formation documents, or bylaws or 
operating agreement, of such Party, or any judgment, license, permit, order, 
material agreement or instrument applicable to or binding upon such Party or 
any of its assets.

MISO 
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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
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28.1.4 
Consent and Approval.  Such Party has sought or obtained, or, in accordance 
with this ZGIA will seek or obtain, each consent, approval, authorization, order, 
or acceptance by any Governmental Authority in connection with the execution, 
delivery and performance of this ZGIA, and it will provide to any Governmental 
Authority notice of any actions under this ZGIA that are required by Applicable 
Laws and Regulations. 
 
ARTICLE 29.  {RESERVED} 
 
ARTICLE 30.  MISCELLANEOUS 
 
30.1 
Binding Effect.  This ZGIA and the rights and obligations hereof, shall be binding upon 
and shall inure to the benefit of the successors and assigns of the Parties hereto. 
 
30.1.1 Reversion.  If offered pursuant to an Agency Agreement under which this ZGIA 
is executed by Transmission Provider as agent for the relevant Transmission 
Owner, in the event that the relevant Agency Agreement terminates, any HVDC 
Service offered by Transmission Provider under this ZGIA shall revert to the 
relevant Transmission Owner and Transmission Provider shall be released from 
all obligations and responsibilities under this ZGIA. 
 
30.2 
Conflicts.  In the event of a conflict between the body of this ZGIA and any attachment, 
appendices or exhibits hereto, the terms and provisions of the body of this ZGIA shall 
prevail and be deemed the final intent of the Parties.   
 
30.3 
Rules of Interpretation.  This ZGIA, unless a clear contrary intention appears, shall be 
construed and interpreted as follows:  (1) the singular number includes the plural number 
and vice versa; (2) reference to any person includes such person’s successors and assigns 
but, in the case of a Party, only if such successors and assigns are permitted by this 
ZGIA, and reference to a person in a particular capacity excludes such person in any

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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other capacity or individually; (3) reference to any agreement (including this ZGIA), 
document, instrument or tariff means such agreement, document, instrument, or tariff as 
amended or modified and in effect from time to time in accordance with the terms thereof 
and, if applicable, the terms hereof; (4) reference to any Applicable Laws and 
Regulations means such Applicable Laws and Regulations as amended, modified, 
codified, or reenacted, in whole or in part, and in effect from time to time, including, if 
applicable, rules and regulations promulgated thereunder; (5) unless expressly stated 
otherwise, reference to any Article, Section or Appendix means such Article of this ZGIA 
or such Appendix to this ZGIA, or such Section to the GIP or such Appendix to the GIP, 
as the case may be; (6) “hereunder”, “hereof”, “herein”, “hereto” and words of similar 
import shall be deemed references to this ZGIA as a whole and not to any particular 
Article or other provision hereof or thereof; (7) “including” (and with correlative 
meaning “include”) means including without limiting the generality of any description 
preceding such term; and (8) relative to the determination of any period of time, “from” 
means “from and including”, “to” means “to but excluding” and “through” means 
“through and including.” 
 
30.4 
Entire Agreement.  This ZGIA, including all Appendices and attachments hereto, 
constitutes the entire agreement between the Parties with reference to the subject matter 
hereof, and supersedes all prior and contemporaneous understandings or agreements, oral 
or written, between the Parties with respect to the subject matter of this ZGIA.  There are 
no other agreements, representations, warranties, or covenants, which constitute any part 
of the consideration for, or any condition to, any Party’s compliance with its obligations 
under this ZGIA. 
 
30.5 
No Third Party Beneficiaries.  This ZGIA is not intended to and does not create rights, 
remedies, or benefits of any character whatsoever in favor of any persons, corporations, 
associations, or entities other than the Parties, and the obligations herein assumed are 
solely for the use and benefit of the Parties, their successors in interest and, where 
permitted, their assigns.

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
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30.6 
Waiver.  The failure of a Party to this ZGIA to insist, on any occasion, upon strict 
performance of any provision of this ZGIA will not be considered a waiver of any 
obligation, right, or duty of, or imposed upon, such Party.  
 
Any waiver at any time by any Party of its rights with respect to this ZGIA shall not be 
deemed a continuing waiver or a waiver with respect to any other failure to comply with 
any other obligation, right, duty of this ZGIA.  Termination or Default of this ZGIA for 
any reason by Interconnection Customer shall not constitute a waiver of the 
Interconnection Customer’s legal rights to obtain Interconnection Service from 
Transmission Provider.  Any waiver of this ZGIA shall, if requested, be provided in 
writing. 
 
30.7 
Headings.  The descriptive headings of the various Articles of this ZGIA have been 
inserted for convenience of reference only and are of no significance in the interpretation 
or construction of this ZGIA.   
 
30.8 
Multiple Counterparts.  This ZGIA may be executed in two or more counterparts, each 
of which is deemed an original but all constitute one and the same instrument.  
 
30.9 
Amendment. The Parties may by mutual agreement amend this ZGIA by a written 
instrument duly executed by all of the Parties. 
 
30.10 Modification by the Parties.  The Parties may by mutual agreement amend the 
Appendices to this ZGIA by a written instrument duly executed by all of the Parties.  
Such amendment shall become effective and a part of this ZGIA upon satisfaction of all 
Applicable Laws and Regulations. 
 
30.11 Reservation of Rights. Transmission Provider shall have the right to make a unilateral 
filing with FERC to modify this ZGIA with respect to any rates, terms and conditions, 
charges, classifications of service, rule or regulation under Section 205 or any other 
applicable provision of the Federal Power Act and FERC’s rules and regulations

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
thereunder, and Transmission Owner and Interconnection Customer shall have the right 
to make a unilateral filing with FERC to modify this ZGIA pursuant to Section 206 or 
any other applicable provision of the Federal Power Act and FERC’s rules and 
regulations thereunder; provided that each Party shall have the right to protest any such 
filing and to participate fully in any proceeding before FERC in which such 
modifications may be considered.  Nothing in this ZGIA shall limit the rights of the 
Parties or of FERC under Sections 205 or 206 of the Federal Power Act and FERC’s 
rules and regulations thereunder, except to the extent that the Parties otherwise mutually 
agree as provided herein.  
 
30.12 No Partnership.  This ZGIA shall not be interpreted or construed to create an 
association, joint venture, agency relationship, or partnership among or between the 
Parties or to impose any partnership obligation or partnership liability upon any Party.  
No Party shall have any right, power or authority to enter into any agreement or 
undertaking for, or act on behalf of, or to act as or be an agent or representative of, or to 
otherwise bind, the other Parties.

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
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IN WITNESS WHEREOF, the Parties have executed this ZGIA in multiple originals; 
each of which shall constitute and be an original ZGIA among the Parties. 
 
 
Transmission Provider 
Midcontinent Independent System Operator, Inc. 
 
By:  
 
 
 
 
 
 
 
Name:  
 
 
 
 
 
 
Title:  
 
 
 
 
 
 
 
 
Transmission Owner 
[Insert name of Transmission Owner] 
 
By:  
 
 
 
 
 
 
 
Name:  
 
 
 
 
 
 
Title:  
 
 
 
 
 
 
 
 
Interconnection Customer 
[Insert name of Interconnection Customer] 
 
By:  
 
 
 
 
 
 
 
Name:  
 
 
 
 
 
 
Title:  
 
 
 
 
 
 
 
Project No. _____

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
APPENDICES TO ZGIA 
 
Appendix A Interconnection Facilities,  System Protection Facilities, Distribution 
Upgrades, Generator Upgrades and Network Upgrades 
Appendix B Milestones 
Appendix B-1 Pre-Certification Generation Test Notification Form 
Appendix C Interconnection Details 
Appendix D Security Arrangements Details 
Appendix E Commercial Operation Date 
Appendix F Addresses for Delivery of Notices and Billings 
Appendix G Interconnection Requirements for Inverter-Based Resource Plants 
Appendix H Interconnection Requirements for Provisional ZGIA 
Appendix I 
Requirements Applicable to Surplus Interconnection Service

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
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Appendix A to ZGIA 
 
Interconnection Facilities, System Protection Facilities, Distribution Upgrades, Generator 
Upgrades and Network Upgrades 
 
1. 
Description of Generating Facility 
 
 
Interconnection Customer shall install a [_____________] MVA facility, rated at [____] 
MW gross and [_____] MW net, with all studies performed at or below these outputs.  The 
Generating Facility is composed of [__] units in a [insert description – combined cycle, single 
coal-fired, wind farm, etc.] rated at [________] each.  Describe the interconnection service 
provided under this agreement [insert description – Network Resource or Energy Resource] and 
level of service [     ] MW.  [Insert operating assumptions that reflect the charging behavior of 
the Generating Facility that includes at least one electric storage resource] 
 
 
Interconnection Customer shall install a switchyard with the appropriate protection 
equipment coordinated per Appendix C to this ZGIA.  The Switchyard shall contain [____] 
generator step-up transformer(s), [_______] circuit breakers connected in [_______] fashion 
[describe or point to a single-line diagram]. 
 
2. 
Description of ZG Associated Load and Injection Limiting Equipment 
 
This ZG Interconnection Service is provided to serve ___ MWs with a Point of 
Withdrawal ___ with a Commercial Operations need-by-date of _________.  The equipment 
and/or configuration that prevent the Generating Facility from injecting Energy onto the 
Transmission System beyond the substation identified as the Point of Interconnection (other than 
transient, limited injections associated with a reduction or loss of Load by the ZG Associated 
Load within the Transient Tolerance Window are described below.   
[describe and include a single-line diagram illustrating the connections between the 
Generating Facility, ZG Associated Load, and the Transmissions System and identifying 
all relevant equipment utilized to limit injections]

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ATTACHMENTS 
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3. 
Interconnection Facilities 
 
(a) 
Point of Interconnection.  The Point of Interconnection shall be at the point 
where _____________________________________________.  See Exhibit 
A1___ Drawing No. _____________ dated _____________, which drawing is 
attached hereto and made a part hereof.  If not located at the Point of 
Interconnection, the metering point(s) shall be located at 
 
(b) 
Interconnection Facilities (including metering equipment) to be constructed 
by Interconnection Customer.  Interconnection Customer shall construct 
_________________________ and are detailed in Exhibit A1____.  These 
facilities are estimated to cost $_______ and are detailed in Exhibit A1____. 
 
(c) 
Transmission Owner Interconnection Facilities (including metering 
equipment) to be constructed by Transmission Owner.  Transmission Owner 
shall construct _____________________and are detailed in Exhibit A1___.  
These facilities are estimated to cost $_______ and are detailed in Exhibit A1___. 
 
4. 
Network Upgrades 
 
(a) 
Stand-Alone Network Upgrades to be installed by ____________________.  
Transmission Owner shall install _______________________, detailed in Exhibit 
A2___.  These facilities are estimated to cost $_____________ and are detailed in 
Exhibit A2___. 
 
(b) 
Network Upgrades to be installed by Transmission Owner.  Transmission 
Owner shall install _____________________________, detailed in Exhibit 
A2___.  These facilities are estimated to cost $_____________ and are detailed in 
Exhibit A2___.

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ATTACHMENTS 
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(c) 
Shared Network Upgrade(s) to be funded by Interconnection Customer.  
Alternatively, where Transmission Provider determines that Interconnection 
Customer benefits from one or more prior Network Upgrades or Common Use 
Upgrades, those Network Upgrades and/or Common Use Upgrades will be 
classified by Transmission Provider as Shared Network Upgrades under this 
ZGIA, and Interconnection Customer is responsible for costs as detailed below.  
Interconnection Customer may later be eligible for refund and/or contribution if 
subsequent Interconnection Customers are identified as also benefitting from the 
Shared Network Upgrade(s).  Interconnection Customer shall fund those Shared 
Network Upgrade(s) detailed in Exhibit A5.  Interconnection Customer’s cost 
share of the Share Network Upgrade(s) is estimated at $____________, as 
detailed in Exhibit A5.  Interconnection Customer’s cost share of the Shared 
Network Upgrade(s) may be reduced if later interconnection projects are 
determined to also benefit from the Shared Network Upgrade(s).  Interconnection 
Customer’s cost share of the Shared Network Upgrade(s) may also increase from 
this estimate where other projects are determined to adversely impact 
Interconnection Customer’s cost share of the Shared Network Upgrade(s).i) If a 
Shared Network Upgrade is not yet in service as of the date of execution of this 
ZGIA, if applicable, Interconnection Customer shall post an Irrevocable Letter of 
Credit in the amount of its estimated proportionate share of the estimated cost of 
that Shared Network Upgrade in accordance with Article 11.6.4 as of the date set 
forth in Appendix B to this ZGIA. 
 
(d) 
Substation Network Upgrades to be installed by ____________________.  
Transmission Owner shall install _______________________, detailed in Exhibit 
A2 ___.  These facilities are estimated to cost $_____________ and are detailed 
in Exhibit A2 ___. 
 
5. 
System Protection Facilities

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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(a) 
System Protection Facilities not listed in Section 2 or 3 to be constructed by 
Interconnection Customer.  Interconnection Customer shall construct 
__________________________ detailed in Exhibit A3___.  These facilities are 
estimated to cost $________ and are detailed in Exhibit A3___. 
 
(b) 
System Protection Facilities not listed in 2 or 3 to be constructed by 
Transmission Owner.  Transmission Owner shall construct 
_____________________ and detailed in Exhibit A3___.  These facilities are 
estimated to cost $____________ and are detailed in Exhibit A3___. 
 
6. 
Distribution Upgrades 
 
(a) 
Distribution Upgrades to be constructed by (Transmission/Distribution) 
Owner (select one for final version).  (Transmission/Distribution) Owner shall 
construct __________________________ detailed in Exhibit A4___.  These 
facilities are estimated to cost $________ and are detailed in Exhibit A4___. 
 
7. 
Contingency List [include higher queued Interconnection Requests with ZGIAs prior to 
this ZGIA and contingency Network Upgrades, System Protection Facilities or 
Distribution Upgrades of higher queued Interconnection Request with ZGIAs prior to this 
ZGIA pursuant to Article 11.3.1 that are subject to restudy in accordance with Article 
11.3.2] 
 
(a) 
Contingency List of MTEP Appendix B projects and contingent actions should 
Appendix B projects not proceed by listed date to Appendix A. 
 
8. 
Affected System Upgrades List (include higher queued Interconnection Requests with 
ZGIAs prior to this ZGIA) 
 
9. 
JTIQ Upgrades

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
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[To be included in ZGIA if Interconnection Customer is responsible for a portion of a 
portfolio of JTIQ Upgrades] Interconnection Customer is subject to the JTIQ Generator 
Charge in accordance with Attachment JJJ of the MISO Tariff and Appendix 18 of the 
Generator Interconnection Procedures. 
Initial JTIQ Security amount:  
A. 
Constructing MISO Transmission Owner 
 
1. ______________ 
2. ______________ 
3. ______________ 
4. ______________ 
 
 
B. 
SPP:

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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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Appendix B to ZGIA 
Milestones 
 
1. 
Selected Option pursuant to Article 5.1:  Interconnection Customer selects the 
[_____________] Option as described in Article 5.1.[ ], 5.1.[ ] and 5.1.[ ] shall not apply to this 
ZGIA. 
 
2. 
Milestones:  The description and date entries listed in the following tables are provided 
solely for the convenience of the Parties in establishing their applicable Milestones consistent 
with the provisions of this ZGIA and the GIP. 
 
A. 
Interconnection Customer Milestones 
 
 
 
 
 
 
No. 
Description 
Date 
1a. 
Provide initial payment to Transmission Owner (ZGIA 
11.5) 
Within the later of a) 45 
Calendar Days of the 
execution of the ZGIA by all 
Parties, or b) 45 Calendar 
Days of acceptance by 
FERC if the ZGIA is filed 
unexecuted and the payment 
is being protested by 
Interconnection Customer, or 
c) 45 Calendar Days of the 
filing if the ZGIA is filed 
unexecuted and the initial 
payment is not being

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protested by Interconnection 
Customer. 
1b. 
Provide security, i.e., a guarantee, surety bond, letter of 
credit or other reasonably acceptable form of security 
to Transmission Owner (ZGIA 11.6). 
45 Calendar Days prior to 
design, procurement and 
construction. 
1c. 
Enter into a Facilities Service Agreement (“FSA”) as 
may be applicable, with Transmission Owner for the 
Network Upgrades associated with this ZGIA. 
Within 90 Calendar Days of 
the Effective Date of the 
ZGIA and prior to in-service 
date of Network Upgrades 
associated with this ZGIA. 
1d. 
Enter into amendment of this ZGIA, if required, for 
Interconnection Requests that did not elect optional 
negotiation period adjustment for Interconnection 
Facilities Study pursuant to ZGIA Section 11.3.1. 
Within 90 days of the 
posting of the final 
Interconnection Facilities 
report. 
1e. 
Demonstrate 100% Site Control (if not provided earlier 
due to qualifying regulatory limitations) or the ZGIA 
may be terminated per Article 2 of this ZGIA and the 
Interconnection Customer may be subject to 
Withdrawal Penalties per Section 7.6.2.1.1 of the GIP 
(Calculation of the Automatic Withdrawal Penalty). 
Within 180 Calendar Days  
of the Effective Date. 
1f. 
Enter into SPP JTIQ Service Agreement (if included in 
JTIQ Participation Group) pursuant to GIP Section 
11.1. 
Within 15 Calendar Days 
after tender. 
1g.  
Enter into any agreement required by an Affected 
System for the study, construction, or funding of a 
network upgrade to mitigate impacts (for 
Interconnection Requests processed through ERAS) 
pursuant to GIP Section 3.5.2.  
Within 15 Calendar Days 
after tender.  
1h. 
For ZGIAs that grant ZG Interconnection Service, 
greater than 5 MW, submit a completed Market 
Participant Application pursuant to Section 38.2 et seq. 
Within 30 Calendar Days 
after execution or requesting 
an unexecuted filing of this

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FERC Electric Tariff 
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ATTACHMENTS 
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of the Tariff (Module C). (ZGIA 7.1.1) 
Agreement. 
2. 
Provide Certificate of Insurance (ZGIA 18.4.9). 
The earlier of the 
construction work 
commencement date or the 
milestone date; thereafter, 
within 90 Calendar Days of 
end of fiscal year or 
insurance renewal date. 
3. 
Provide evidence of one or more of the following 
milestones being achieved: (1) execution of 
contract for (a) fuel supply or transport; (b) cooling 
water supply; (c) engineering procurement of major 
equipment or construction; (d) execution of a 
contract for the sale of electric energy or capacity 
from the Generating Facility, or a statement signed 
by an officer or authorized agent of Interconnection 
Customer attesting that the Generating Facility is 
included in an applicable state resource adequacy 
plan; or other information that Transmission 
Provider deems to be reasonable evidence that the 
Generating Facility will qualify as a designated 
network resource; or (2) documentation of 
application for state or local air, water, land, or 
federal nuclear or hydroelectric permits and that the 
application is proceeding per regulations (GIP 
11.3). 
Within 180 Calendar Days 
of Effective Date. 
4. 
Provide security in the amount of $_______ to 
Transmission Owner to commence design, equipment 
procurement and construction for Interconnection 
Facilities (ZGIA 5.5 and 5.6). 
As may be agreed to by the 
Parties. 
5. 
Invoice Transmission Owner for the estimated amount 
As may be agreed to by the

MISO 
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to be expended by the Interconnection Customer to 
construct any Stand Alone Network Upgrades for 
which the Interconnection Customer has exercised its 
Option to Build if the Transmission Owner has elected 
to Self Fund (ZGIA 5.2.13). 
Parties, but in no event later 
than 45 Calendar Days prior 
to the date the 
Interconnection Customer 
must make any construction 
payment. 
6. 
Pre-construction meeting. 
As may be agreed to by the 
Parties. 
7. 
Provide initial design and specifications for 
Interconnection Customer’s Interconnection Facilities 
to Transmission Owner and Transmission Provider for 
comment (ZGIA 5.10.1). 
180 Calendar Days prior to 
initial synchronization date. 
8. 
Provide final design and specifications for 
Interconnection Customer’s Interconnection Facilities 
to Transmission Owner and Transmission Provider for 
comment (ZGIA 5.10.1). 
90 Calendar Days prior to 
initial synchronization date. 
9. 
Deliver to Transmission Owner and Transmission 
Provider “as-built” drawings, information and 
documents regarding Interconnection Customer’s 
Interconnection Facilities (ZGIA 5.10.3). 
Within 120 Calendar Days 
of Commercial Operation 
Date. 
10. 
Provide Transmission Owner final cost invoices to 
construct Stand Alone Network Upgrades for which the 
Interconnection Customer has exercised its Option to 
Build if the Transmission Owner has elected to Self 
Fund (ZGIA 5.2.13). 
Within six (6) months of 
completion. 
10a. 
Transfer ownership of the Transmission Owner’s 
Interconnection Facilities and Stand Alone Network 
Upgrades to Transmission Owner if Interconnection 
Customer has exercised the Option to Build (ZGIA 
5.2.9). 
As agreed to by the Parties 
but in no event later than the 
earlier of energization or 
three days prior to the Initial 
Synchronization Date. 
10b. 
Refund overpayment, if any, of estimated costs to 
Within 30 Calendar Days

MISO 
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construct any Stand Alone Network Upgrades for 
which the Interconnection Customer has exercised its 
Option to Build if the Transmission Owner has elected 
to Self Fund (ZGIA 5.2.13). 
after submitting invoice for 
final costs under Milestone 
10. 
11. 
Notify Transmission Provider and Transmission Owner 
in writing of Local Balancing Authority where 
Generating Facility is located (ZGIA 9.2). 
Three months prior to Initial 
Synchronization Date. 
12. 
Pre-energization meeting. 
As may be agreed to by the 
Parties. 
13. 
Initial Synchronization Date. 
As agreed to by the Parties. 
14. 
Commercial Operation Date. 
As agreed to by the Parties. 
15. 
Interconnection Customer shall provide the Parties with 
notice on the status of the Generating Facility, 
including COD, under Article 15 of this ZGIA and 
shall also send such notice by email to 
ResourceIntegration@misoenergy.org.  Notification 
shall include Interconnection Customer’s name, and as 
applicable Market Participant(s) name(s), and project 
number.   
6 months prior to Initial 
Synchronization Date. 
16. 
Interconnection Customer shall provide notice to the 
Parties of a test plan in advance of conducting tests for 
the Generating Facility.  The notice shall be in the form 
below and should be provided under Article 15 of this 
ZGIA, and a copy of such notice should be emailed to 
ResourceIntegration@misoenergy.org. 
5 Business Days prior to 
testing.

MISO 
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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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17. 
In the event the Interconnection Customer makes any 
modifications to the design of the site layouts or 
interconnection facility routes after execution of this 
ZGIA, Interconnection Customer shall notify the 
Parties of such changes immediately upon identifying 
the need for such changes.  After providing such 
notification, the Interconnection Customer shall 
provide to Transmission Provider evidence of 
continued Site Control for land sufficient to 
accommodate the changes in site layouts and/or 
interconnection facility routes (GIP 7.2.2). 
90 Calendar Days after 
Interconnection Customer 
provides notice to Parties. 
18. 
For ZGIAs that grant ZG Interconnection Service 
greater than 5 MW, take all steps required by the MISO 
Tariff and applicable Business Practices Manual to 
complete registration as a Generation Resource, Energy 
Storage Resource, or Dispatchable Intermittent 
Resource based on its applicable operating 
characteristics.  (GIA 7.1.1) 
Prior to Commercial 
Operation Date. 
 
B. 
Transmission Owner Milestones 
 
 
 
 
 
 
No. 
Description 
Date 
0. 
Transmission Owner to enter Network Upgrade 
information into Transmission Provider’s MTEP 
database and model on demand. 
10 Business Days after 
Effective Date. 
1. 
Provide Certificate of Insurance (ZGIA 18.4.9). 
The earlier of the

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construction work 
commencement date or the 
milestone date; within 90 
Calendar Days of end of 
fiscal year or insurance 
renewal date. 
2. 
•   Commence design of Interconnection Facilities 
(ZGIA 5.5 et seq.). 
 
•   Commence equipment procurement. 
As agreed to by the Parties 
(after completion of 
Interconnection Facilities 
Study, receipt of written 
authorization from 
Interconnection Customer 
and Interconnection 
Customer’s deposit of 
security. 
3. 
Commence construction of Interconnection Facilities 
(ZGIA 5.6 et seq.). 
As agreed to by the Parties 
(after receiving approval of 
Governmental Authority, 
receipt of written 
authorization and security 
from Interconnection 
Customer). 
4. 
Comment on Interconnection Customer’s final design 
and specifications.  
Within 30 Calendar Days of 
Interconnection Customer’s 
submission of final design 
and specifications. 
5. 
Deliver to Interconnection Customer and Transmission 
Provider “as-built” drawings, information and 
documents regarding Transmission Owner’s 
Interconnection Facilities (ZGIA 5.11). 
Within 120 Calendar Days of 
Commercial Operation Date. 
6. 
Provide payment for invoiced estimated costs to 
Within 30 Calendar Days of

MISO 
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FERC Electric Tariff 
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ATTACHMENTS 
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construct for which the Interconnection Customer has 
exercised its Option to Build if the Transmission 
Owner has elected to Self Fund (ZGIA 5.2.13). 
receipt of Interconnection 
Customer’s invoice for 
estimated costs. 
6a. 
Provide payment for invoiced final cost to construct 
Stand Alone Network Upgrades for which the 
Interconnection Customer has exercised its Option to 
Build if the Transmission Owner has elected to Self 
Fund (ZGIA 5.2.13). 
Within 30 Calendar Days of 
receipt of Interconnection 
Customer’s invoice for final 
costs. 
7. 
Provide Interconnection Customer final cost invoices 
(ZGIA 12.2 et seq.). 
Within (6) six months of 
completion.  
8. 
Refund overpayment of estimated costs (ZGIA 12.2). 
 
90 Calendar Days prior to 
initial synchronization date.  
Refunds within 30 Calendar 
Days. 
9. 
In-Service Date/Backfeed Date. 
As agreed to by the Parties. 
 
C. 
Affected System Owner Milestones 
 
Task 
Date Due

MISO 
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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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Appendix B-1 to ZGIA 
Pre-Certification Generation Test Notification Form 
 
The following form would need to be submitted to MISO Real Time Operations at least five (5) 
Business Days prior to the first date of testing. 
 
Project Number:  
 
Project Name:  
 
Point of Interconnection: 
 
Dispatcher Contact Information: 
 
 
Date 
Start Time 
(in EST) 
End Time 
(in EST) 
Expected MW 
Output 
Expected MVAR 
Output (Only needed if 
beyond normal power 
factor)

MISO 
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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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Appendix C to ZGIA 
Interconnection Details 
 
This Appendix C is a part of this ZGIA among Interconnection Customer, Transmission Owner 
and Transmission Provider. 
1. 
Transmission Owner shall provide the following “as-built” drawings, information and 
documents regarding the Transmission Owner’s Interconnection Facilities pursuant to 
Article 5.11 of this ZGIA. 
2. 
The unique requirements of each generation interconnection will dictate the 
establishment of mutually agreeable Interconnection and/or Operating Guidelines that 
further define the requirements of this ZGIA.  The Interconnection and/or Operating 
Guidelines applicable to this ZGIA consist of the following information.  Additional 
detail may be provided through attachment to this Appendix C or through electronic 
means via the web address specified. 
(a) 
System Protection Facilities; 
(b) 
Communication requirements; 
(c) 
Metering requirements; 
(d) 
Grounding requirements; 
(e) 
Transmission Line and Substation Connection configurations; 
(f) 
Unit Stability requirements; 
(g) 
Equipment ratings; 
(h) 
Short Circuit requirements; 
(i) 
Synchronizing requirements; 
(j) 
Generation and Operation Control requirements; 
(k) 
Data provisions; 
(l) 
Energization inspection and testing requirements; and 
(m) 
Control equipment, if any. 
3. 
Information required pursuant to Section 8.4 for Variable Energy Resource Generating 
Facilities:  ___________________________________________________.

MISO 
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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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Appendix D to ZGIA 
Security Arrangements Details 
 
Infrastructure security of Transmission or Distribution System equipment and operations, as 
applicable, and control hardware and software is essential to ensure day-to-day Transmission and 
Distribution System reliability and operational security.  The Commission will expect all 
Transmission Providers, market participants, and Interconnection Customers interconnected to 
the Transmission or Distribution System, as applicable, to comply with the recommendations 
provided by Governmental Authorities regarding Critical Energy Infrastructure Information 
(“CEII”) as that term is defined in 18 C.F.R. Section 388.113(c) and best practice 
recommendations from the electric reliability authority.  All public utilities will be expected to 
meet basic standards for system infrastructure and operational security, including physical, 
operational, and cyber-security practices.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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Appendix E to ZGIA 
Commercial Operation Date 
 
This Appendix E is a part of this ZGIA between Transmission Provider, Transmission 
Owner and Interconnection Customer. 
 
[Date] 
 
Midcontinent Independent System Operator, Inc. 
Attn:  Director, Transmission Access Planning 
720 City Center Drive 
Carmel, IN  46032 
 
Re: 
_____________ Generating Facility 
 
Dear _______________: 
 
On [Date] [Interconnection Customer] has completed Trial Operation of Unit No. ___.  
This letter confirms that [Interconnection Customer] commenced commercial operation of Unit 
No. ___ at the Generating Facility, effective as of [Date plus one Calendar Day]. 
Thank you. 
 [Signature] 
 
[Interconnection Customer Representative] 
cc: 
Transmission Owner

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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Appendix F to ZGIA 
Addresses for Delivery of Notices and Billings 
 
Notices: 
 
Transmission Provider: 
 
MISO 
Attn:  Director, Transmission Access Planning 
720 City Center Drive 
Carmel, IN  46032 
 
Transmission Owner: 
 
[To be supplied.] 
 
Interconnection Customer: 
 
[To be supplied.] 
 
 
Billings and Payments: 
 
Transmission Provider: 
 
MISO 
Attn:  Director, Transmission Access Planning 
720 City Center Drive 
Carmel, IN  46032 
 
Transmission Owner:

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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[To be supplied.] 
 
Interconnection Customer: 
 
[To be supplied.] 
 
 
Alternative Forms of Delivery of Notices (telephone, facsimile or email): 
 
Transmission Provider: 
 
Phone: (317) 249-5700  
Email: misotap@misoenergy.org or 
MISOTransmissionAccessPlanning@misoenergy.org 
 
Transmission Owner: 
 
[To be supplied.] 
 
Interconnection Customer: 
 
[To be supplied.]

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
Appendix G to ZGIA 
Interconnection Requirements for Inverter-Based Resource Plants 
 
 
Appendix G sets forth requirements and provisions specific to inverter-based resource 
(IBR) plants.  Transmission Owner Local Planning Criteria for IBR performance may differ from 
Appendix G requirements.  In such cases, Transmission Owner Local Planning Criteria shall 
supersede the Appendix G requirements and be documented in Appendix C of this ZGIA1.  All 
other requirements of this ZGIA also apply to IBR plant interconnections.  IBR plants shall meet 
both Applicable Reliability Standards and Appendix G requirements.  Battery energy storage 
systems required to furnish grid-forming controls shall be exempt from specific IEEE 2800 
requirements as outlined in the BPM for Generator Interconnection.  Italicized terms indicate 
IEEE 2800-2022 defined terms2.  IEEE 2800-2022's definitions will govern these italicized terms 
unless otherwise defined herein.  
 
A. 
General   
The IBR plant shall adhere to IEEE 2800-2022 Clause 4 requirements, except for 
subclauses 4.1 (introduction), 4.5 (operational measurement and communication capability), 4.6 
(control capability requirements), 4.8 (isolation devices), 4.9 (inadvertent energization of TS), 
4.11 (interconnection integrity), and 4.12 (integration with TS grounding).  
Within the adopted IEEE 2800-2022 Subclauses, the following requirements shall be 
incorporated as Transmission Provider and Transmission Owner3 specification options noted in 
IEEE 2800-2022. 
• 
Subclause 4.2.1: The reference point of applicability (RPA) shall be at the point 
of measurement (POM) bus with the exception of requirements specified in 
Clauses 7.2.2.3.4 and 7.2.2.3.5 of the standard to have the RPA at the point of 
 
1  IEEE 2800-2022 points to "weak grid” issues requiring exceptions to default values and ranges of available 
settings for various types of performance. IEEE 2800-2022 Annex C.2 contains discussion on characterizing weak 
grid areas.  
2  “IEEE Standard for Interconnection and Interoperability of Inverter-Based Resources (IBRs) Interconnecting with 
Associated Transmission Electric Power Systems," in IEEE Std 2800-2022 , vol., no., pp.1-180, 22 April 2022, doi: 
10.1109/IEEESTD.2022.9762253. 
3  For the purpose of this ZGIA, the IEEE 2800 term of TS operator is synonymous with Transmission Owner and 
the IEEE 2800 term of TS owner is synonymous with Transmission Planner or Transmission Owner, as applicable.

MISO 
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connection (POC).   
• 
Subclause 4.3: The Transmission Owner shall specify the nominal voltage and 
frequency at the RPA in Appendix C of this ZGIA.  
• 
Subclause 4.10.2: The enter service criteria shall use the default values for 
applicable voltages and applicable frequency specified in the table below unless 
otherwise specified in Appendix C of this ZGIA4.  
 
Enter service criteria 
Default setting 
Applicable voltage, minimum value 
0.9 p.u. 
Applicable voltage, maximum value 
1.05 p.u. 
Applicable frequency, minimum value 
58.8 Hz 
Applicable frequency, maximum value 
60.12 Hz.  
 
• 
Subclause 4.10.3: The performance during enter service shall use the default 
values specified below unless otherwise specified in Appendix C of this ZGIA. 
o The minimum intentional delay performance, as defined in Subclause 4.10.3, 
b), shall be 0 seconds.  
o The duration of the enter service period, as defined in Subclause 4.10.3, c), 
shall be 300 seconds.  
 
B.  
Response to Abnormal Conditions 
The IBR plant shall adhere to IEEE 2800-2022 Clause 7 requirements, except for 
subclauses 7.2.1 (voltage protection) and 7.3.1 (mandatory frequency tripping).  Where 
Applicable Reliability Standards require more stringent ride-through requirements compared to 
IEEE 2800-2022 Clause 7 requirements, those standards shall take precedence5.  
 
4  MISO default values may be modified within the IEEE 2800 range of allowable settings by Transmission Owner 
Local Planning Criteria. 
5  More stringent ride-through requirements include, but are not limited to, expanded voltage and frequency 
conditions or extended cumulative times under which IBR plants must ride-through.

MISO 
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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
Within the adopted IEEE 2800-2022 Subclauses, the following requirements shall be 
incorporated as the Transmission Provider and Transmission Owner decision points6 noted in 
IEEE 2800-2022.  
• 
Subclause 7.2.2.1: The Transmission Owner shall specify the nominal voltage for 
use by this clause. Nominal voltages may include nominal transmission system 
voltages that are different from standard ANSI C84.1-2016 voltages. 
• 
Subclause 7.2.2.2: If the IBR plant cannot deliver both active and reactive power 
due to its current limit (or apparent power limit), when the applicable voltage is 
below 95%, then preference shall be given to reactive power while minimizing 
any reductions in active power. 
• 
Subclause 7.2.2.3: The IBR plant shall give preference to reactive power unless 
otherwise specified in Appendix C of this ZGIA. In addition, the IBR plant shall 
minimize reductions in active power while carrying out the reactive current 
priority mode response.  
• 
Subclause 7.2.2.3.4: The Interconnection Customer shall submit the IBR plant 
controls default relationship between the magnitude of incremental positive and 
negative sequence reactive currents. The Transmission Provider and Transmission 
Owner, through this agreement, may specify a required IBR plant response 
relationship between the incremental positive and negative sequence reactive 
currents. 
 
C. 
Reactive Power 
The IBR plant shall adhere to IEEE 2800-2022 Clause 5 requirements. 
Within the adopted IEEE 2800-2022 Subclauses, the following requirements shall be 
incorporated as the Transmission Provider and Transmission Owner decision points noted in 
IEEE 2800-2022.  
• 
Subclause 5.1: The IBR plant shall have the reactive power capabilities outlined 
in this clause. Consistent with section 9.6.1 of this ZGIA, an IBR plant shall 
 
6  Decision points refer to language in the IEEE 2800-2022 standard that leaves default values, application of 
requirements, and other details open for the TS Owner or TS Operator to define.

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maintain a power factor within the range of 0.95 leading to 0.95 lagging, unless 
Transmission Provider has established different requirements that apply to all 
Generating Facilities in the Local Balancing Authority on a comparable basis, 
measured at the high side of the generator substation.   
• 
Subclause 5.2.2: The voltage control dynamic performance requirements in Table 
5 shall apply when the system short-circuit strength at the RPA is equal to or 
above the minimum short-circuit strength identified by the Transmission Provider 
or Transmission Owner. 
• 
Subclause 5.2.2: The reaction time, as defined in Subclause 5.2.2 Table 5, shall be 
250 milliseconds or less. 
• 
Subclause 5.2.2: The maximum step response time, as defined in Subclause 5.2.2 
Table 5, shall be 30 seconds. 
• 
Subclause 5.2.3: The power factor control mode shall appropriately operate at all 
active power levels from the Inverter Based Resource Continuous Rating (“ICR”) 
down to, but not including, zero. 
 
D. 
Primary Frequency Response 
The IBR plant shall adhere to IEEE 2800-2022 Clause 6 requirements, except for 
Subclause 6.2 (fast frequency response).   
Within the adopted IEEE 2800-2022 Subclauses, the following requirements shall be 
incorporated as the Transmission Provider and Transmission Owner decision points noted in IEEE 
2800-2022.  
• 
Subclause 6.1.1: The use of primary frequency response capabilities shall be 
required for all IBR plants. 
• 
Subclause 6.1.1: Frequency droop shall be based on the difference between 
nameplate capacity and zero output such that the slopes of the droop curves are 
always constant. 
• 
Subclause 6.1.2: The settling band default value in Table 8 shall be based on the 
maximum of 2.5% of change or 0.5% of nameplate capacity.

MISO 
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FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
The exceptions to primary frequency response requirements provided to electric storage 
resources in Article 9.6.4.4 of this ZGIA shall still apply.   
 
TABLE 1. SUMMARY OF ADOPTION TREATMENT OF IEEE 2800-2022 SUBCLAUSES 
IEEE 2800-2022 Subclause 
Required by 
Appendix G 
for DPP-2022 
and later 
Required by 
Appendix G 
for DPP-2023 
and later 
Exception 
4.1 Introduction 
 
 
X 
4.2 Reference Point of Applicability 
X 
 
4.3 Applicable Voltages and Frequencies 
X 
 
4.4 Measurement Accuracy 
X 
 
4.5 Operational Measurement and 
Communication Capability 
 
X 
4.6 Control Capability 
 
X 
4.7 Prioritization of IBR Responses 
X 
 
4.8 Isolation Devices 
 
 
X 
4.9 Inadvertent Energization of TS 
 
X 
4.10 Enter Service 
X 
 
4.11 Interconnection Integrity 
 
X 
4.12 Integration with TS grounding 
 
X 
5.1 Reactive Power Capability 
 
X 
 
5.2 Voltage and Reactive Power Modes 
 
X 
 
6.1 Primary Frequency Response 
 
X 
 
6.2 Fast Frequency Response 
 
 
X 
7.1 Introduction 
X 
 
 
7.2.1 Voltage protection  
 
 
X 
7.2.2.1 Voltage disturbance ride-through: 
General 
X 
 
 
7.2.2.2 Voltage disturbances within continuous 
X

MISO 
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operation 
7.2.2.3 Low- and high-voltage ride-through 
X 
 
 
7.2.2.4 Consecutive voltage deviations ride-
through 
 
X 
7.2.2.5 Dynamic voltage support 
X 
 
 
7.2.2.6 Restore output after voltage ride-through X 
 
 
7.2.3 Transient overvoltage  
X 
 
 
7.3.1 Mandatory frequency tripping  
 
 
X 
7.3.2 Frequency disturbance ride-through 
X 
 
 
7.4 Return to service 
X 
 
 
 
E. 
Supervisory Control and Data Acquisition (SCADA) Capability    
The IBR plant shall provide SCADA capability to transmit data and receive instructions 
from Transmission Provider to protect system reliability.  Transmission Provider and 
Interconnection Customer shall determine what SCADA information is essential for the 
proposed IBR plant, taking into account the size of the plant and its characteristics, location, and 
importance in maintaining generation resource adequacy and transmission system reliability in 
its area. 
 
F. 
Disturbance Monitoring and Reporting Requirements  
IBR plants with generating capacities of more than 20 MW must monitor and record data 
for all frequency ride-through events, transient low-voltage disturbances that initiated reactive 
current injection, reactive current injection or momentary cessation for transient high-voltage 
disturbances, and inverter trips.  Dynamic Disturbance Recording (“DDR”) data must be 
recorded continuously.  The data may be recorded and stored in a central plant control system. 
The following data must be recorded:  
Plant Level 
(1)  Plant three-phase voltage, current and power factor 
(2)  Status of ancillary reactive devices 
(3)  Status of all plant circuit breakers

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
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(4)  Status of plant controller 
(5)  Plant control set points 
(6)  Status of main plant transformer no load taps 
(7)  Status of main plant transformer tap changer (if applicable) 
(8)  Protective relay trips (relay target data) 
Inverter Level Data 
(1)  Frequency, current, and voltage during frequency ride-through events 
(2)  Voltage and current during momentary cessation for transient high-voltage events 
(when used) 
(3)  Voltage and current during reactive current injection for transient low or high-
voltage events 
(4)  Inverter alarm and fault codes 
(5)  DC current 
(6)  DC voltage 
DDR Data – Plant Level 
(1) One phase-to-neutral or positive sequence voltage on high-side of the main power 
transformer(s) 
(2) Positive sequence current or phase current for the same phase as (1)  
(3) Real and reactive power flows expressed on a three-phase basis corresponding to each 
main power transformer(s) where current measurements are required 
(4) Frequency of any one of the voltages in (1)  
 
The data must be time synchronized to a one millisecond level of resolution.  All data 
except DDR data must be sampled at least every 10 milliseconds.  DDR data must have an input 
sampling rate of at least 960 samples per second and an output recording rate of electrical 
quantities of at least 60 times per second. 
The IBR plant shall store this data for a minimum of 60 calendar days.  The IBR plant, 
upon request from MISO or the transmission owner, shall make this data available within 10 
calendar days of the request. 
Phasor measurement unit (“PMU”) capabilities shall be used to facilitate the DDR data.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
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G. 
Applicability   
IBR plants that are, or have been, interconnected to the network at the effective date of 
the Appendix G abnormal voltage ride-through standard are exempt from meeting the Appendix 
G abnormal voltage ride-through standard for the remaining life of the existing generation 
equipment.  Except for IBR plants actively undergoing a Generating Facility Replacement at the 
effective date of this ZGIA  that have equipment on order where the OEM has documented 
performance that differs from what is required in this ZGIA, all individual IBR units that are 
replaced are required to meet the Appendix G performance requirements.   
The IEEE 2800-2022 requirements cited in Section A (IEEE 2800-2022 Clause 4) and 
Section B (IEEE 2800-2022 Clause 7, except Subclause 7.2.2.4) of Appendix G shall apply to 
IBR plants in the DPP-2022-Cycle and beyond.  For the DPP-2022-Cycle, Interconnection 
Customers may request exceptions confined to these sections only if specific limitations or 
uncertainties of equipment or plant capabilities prevent implementation of these requirements.  
ZGIAs signed or amended with inverter changes on or after January 1, 2025, are not eligible for 
requirement exceptions. Further, the process for establishing exceptions for these requirements 
shall not apply beyond the DPP-2022-Cycle.  
The IEEE 2800-2022 requirements cited in Section B (IEEE 2800-2022 Subclause 
7.2.2.4), Section C (IEEE 2800-2022 Clause 5), and Section D (IEEE 2800.2022 Clause 6) of 
Appendix G shall apply to IBR plants in the DPP-2023-Cycle and beyond.  For the DPP-2023-
Cycle, Generating Facilities Replacements, and Surplus Interconnections, Interconnection 
Customers may request exceptions confined to these sections only if specific limitations or 
uncertainties of equipment or plant capabilities prevent implementation of these requirements.  
ZGIAs signed or amended with inverter changes on or after January 1, 2026, are not eligible for 
requirement exceptions.  Further, the process for establishing exceptions for these requirements 
shall not apply beyond the DPP-2023-Cycle.  
Interconnection Customers requesting exceptions shall submit documentation to the 
Transmission Provider outlining the specific IEEE 2800-2022 subclauses pertinent to the request 
along with information from the manufacturer regarding the nature of the issue conforming to or 
assessing conformance with requirements herein.  The Transmission Provider will, in good faith, 
accept Original Equipment Manufacturer (OEM)-documented requirement exceptions and 
document these exceptions in Appendix C of this ZGIA.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
If the performance or capability exception can be mitigated through equipment firmware 
upgrades still under development, the Interconnection Customer shall use commercially 
reasonable efforts to implement the firmware upgrade within sixty (60) calendar days of 
commercial availability of such firmware.  
The DDR and PMU requirements in the Section F, Disturbance Monitoring and 
Reporting Requirements of Appendix G shall apply to IBR plants in the DPP-2023-Cycle and 
beyond.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
Appendix H to ZGIA 
Interconnection Requirements for Provisional ZGIA 
 
Provisional Agreement 
 
This ZGIA is being provided in accordance with Section 11.5 of the Transmission Provider’s 
GIP, which provides among other things, that an Interconnection Customer may request that 
Transmission Provider provide Interconnection Customer with a Provisional Generator 
Interconnection Agreement that limits the transfer of energy by Interconnection Customer 
commensurate with that allowed for Energy Resource Interconnection Service.  Interconnection 
Customer requested Transmission Provider to provide a Provisional Generator Interconnection 
Agreement for limited operation at the discretion of Transmission Provider based upon the 
results of available studies (by Interconnection Customer and by Transmission Provider). 
 
A Provisional Interconnection Study, the results of which are posted on the confidential portion 
of the Transmission Provider’s internet website, was performed by Transmission Provider in 
order to confirm the facilities that are required for provisional Interconnection Service and to 
require them to be in place prior to commencement of service under the ZGIA.   
 
Interconnection Customer represents that the Interconnection Customer facilities (including 
Network Upgrades, Interconnection Facilities, Distribution Upgrades, System Protection 
Upgrades and/or Generator Upgrades) that are necessary to commence provisional 
Interconnection Service and meet the requirements of Electric Reliability Organization, or any 
applicable regional entity for the interconnection of a new generator are in place prior to the 
commencement of generation from the Generating Facility and will remain in place during the 
term of the service.  The requisite Interconnection Studies were performed for the Generating 
Facility.  Interconnection Customer shall meet any additional requirements (including reactive 
power requirements) pursuant to the results of applicable future Interconnection System Impact 
Studies.  Until such time as the applicable Interconnection Studies and any identified facilities 
are completed, the output of the Generating Facility will operate within the output limit 
prescribed in a future, if applicable, operating guide.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
 
The maximum permissible output of the Generating Facility under Appendix A will be updated 
by Transmission Provider on a quarterly basis, determined in accordance with Section 11.5 of the 
GIP, by finding the transfer limit of energy commensurate with the analysis for Energy Resource 
Interconnection Service (“ERIS”).  This study shall be performed assuming the system topology 
represented by the base cases used to calculate Available Flowgate Capability, as described in 
Attachment C of the Tariff, with dispatch and optimization algorithms posted on the MISO 
internet site and operation above those limits will be deemed as unauthorized use of the 
Transmission System and subject to provisions in the Tariff surrounding that use.   
 
Use of interim operating guide 
 
Implementation of interim operating guide, if applicable, will constitute an interim solution that 
will permit Interconnection Customer to operate the Generating Facility under conditional 
Interconnection Service until planned Network Upgrades are constructed.  Any interim operating 
guide will be subject to the approval of Transmission Owner and Transmission Provider.  
Minimum requirements for an interim operating guide are as indicated below. 
 
 *   Transmission Operator will have control of breaker(s) dedicated to the Generating Facility 
and will be able to trip the Interconnection Customer’s Generating Facility 
 *   Protection schemes must be tested and operative 
 *   Interconnection Customer will provide continuous communication capability with the 
Generator Operator 
 *   Interconnection Customer and the owner of the Existing Generating Facility will enter into 
an operating agreement or similar agreement which designates, among other things, the 
responsibilities and authorities of each of the parties and shall be subject to the acceptance of 
Transmission Provider and Transmission Owner. 
 *   A termination date consistent with completion of construction of Network Upgrades will be 
included as part of all operating guides accepted by Transmission Owner and Transmission 
Provider.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
Interconnection Customer assumes all risks and liabilities with respect to changes, which may 
impact the Generator Interconnection Agreement including, but not limited to, change in output 
limits and responsibilities for future Network Upgrade and cost responsibilities that have not yet 
been identified on the direct connect Transmission System as well as all affected Transmission, 
Distribution or Generation System(s) including non-Transmission Provider Systems.  Such 
upgrades will be determined pursuant to the Tariff and Policies in effect at the time of the 
Interconnection Studies.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
Appendix I to ZGIA 
Requirements Applicable to Surplus Interconnection Service 
 
Where this ZGIA provides for Surplus Interconnection Service, Interconnection Customer 
acknowledges, agrees to, and will be required to operate under the following conditions: 
 
1) The combined Real-Time Offers, including Energy and Operating Reserves, of the 
Generating Facility and the Existing Generating Facility with which Interconnection 
Customer has an executed Energy Displacement Agreement must be less than or equal to 
Interconnection Service limit (MW, MVAR, MVA output) provided in Exhibit I-1 
(Monitoring and Consent Agreement) (hereinafter, “Interconnection Service limit”).  
In the event that the sum of the simultaneous energy output of the Surplus 
Interconnection Service Generating Facility and the Existing Generating Facility exceeds 
such Interconnection Service limit, MISO reserves the right to curtail and/or disconnect 
the Generating Facility immediately. 
 
In the event that the sum of the emergency and/or economic maximum offer limits of the 
Generating Facility and the Existing Generating Facility exceeds the Interconnection 
Service limit, MISO reserves the right to curtail and/or disconnect the Generating Facility 
immediately. 
2) The total MW, MVAR, MVA output at the Point of Interconnection resulting from the 
combined output of the Generating Facility with Surplus Interconnection Service and the 
Existing Generating Facility with which Interconnection Customer has an executed 
Energy Displacement Agreement shall not at any time exceed the Interconnection Service 
limit. 
 
3) The Existing Generating Facility with which Interconnection Customer has an executed 
Energy Displacement Agreement is not relieved of any applicable requirements under the 
RAR of the Tariff.

MISO 
Attachment X: Appendix 19
FERC Electric Tariff 
ZG Interconnection Agreement (ZGIA)
ATTACHMENTS 
31.0.0
Effective On: October 18, 2026
4) The Interconnection Customer shall submit to the Transmission Provider a report by the 
seventh Calendar Day of each month showing the prior month’s output, by 15 minute 
increment, the combined real-time offers and cleared energy injection.  The Existing 
Generating Facility and the Interconnection Customer shall cooperate consistent with 
other provisions in the Tariff to the extent necessary to ensure accuracy of the report.  
Transmission Provider shall provide a template for this report. 
 
 
Exhibit I-1 (Completed Monitoring and Consent Agreement - Appendix 11 of the GIP) 
 
Exhibit I-2 (Completed Energy Displacement Agreement - Appendix 12 of the GIP)

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
ATTACHMENT FF
TRANSMISSION EXPANSION PLANNING PROTOCOL
I.
Transmission Expansion Plan - Purpose and Scope, Definition and Role of OMS 
Committee:  This Attachment FF describes the process to be used by the Transmission Provider 
to develop the MISO Transmission Expansion Plan (“MTEP”), subject to review and approval 
by the Transmission Provider Board.  The provisions of this Attachment FF are consistent with 
the applicable provisions of Appendix B of the ISO Agreement and this Tariff.  For purposes of 
this Attachment FF, all references to Transmission Owner(s) will include ITC(s).  The costs 
incurred by the Transmission Provider in the performance of data collection, analyses and 
review, and in the development of the MTEP report, costs incurred under Section I.C of this 
Attachment FF, and costs incurred under Section I.D of this Attachment FF shall be recovered 
from all Transmission Customers under Schedule 10 of the Tariff.
A.
Enrollment Process:  The MTEP is developed to facilitate the timely and orderly 
expansion of and/or modification to the Transmission System to maintain reliability, promote 
efficiency in bulk power markets and facilitate compliance with applicable Federal and state 
laws, regulatory mandates and regulatory obligations.  Any transmission provider that wishes to 
enroll in the Transmission Provider planning process for purposes of Order No. 1000 compliance 
must become a Transmission Owner, by signing the ISO Agreement, and by, within a reasonable 
period of time: (1) turning over functional control of its transmission facilities to the 
Transmission Provider; and (2) taking service under this Tariff for all its load that is physically 
located within the geographic area comprising the Transmission System.  All Transmission 
Owners enrolled in the Transmission Provider’s transmission planning region are listed in either

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
(1) Attachment FF-4 of this Tariff, for Transmission Owners without a separately filed local 
planning process or (2) Attachment FF-5 of this Tariff, for Transmission Owners with a 
separately filed local planning process.
B.
OMS Committee Input to MTEP Process:  To the extent not otherwise 
specifically addressed in other portions of this Attachment FF, with respect to the MTEP process, 
the OMS Committee may provide input to the Transmission Provider planning staff and the 
System Planning Committee of the Transmission Provider Board, as appropriate, regarding the 
following:
1.
At the start of a planning cycle, the OMS Committee may suggest to the 
Transmission Provider Board modifications to the Transmission Provider’s 
planning principles and planning objectives for that planning cycle;
2.
At the start of a planning cycle, the OMS Committee may suggest additional 
scope elements in the MTEP;
3.
Modeling inputs or assumptions used in the development of the MTEP and related 
appropriate cost/benefit analyses with respect to certain projects that are not 
proposed strictly for reliability; and 
4.
Concerns about general or specific issues with the MTEP process as they arise 
during the planning year.
Furthermore, at the end of the MTEP development process, but before the MTEP is submitted to 
the Transmission Provider Board for its review, the OMS Committee may submit a 
reconsideration request to the Transmission Provider planning staff, which shall respond prior to 
submitting the final MTEP report to the Transmission Provider Board.  This reconsideration

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
request can be made only with respect to Network Upgrades eligible to receive regional cost 
allocation under Attachment FF if such projects: (1) will be recommended to the Transmission 
Provider Board for MTEP Appendix A approval, but have not been considered through the 
complete MTEP process or (2) will have a change in project cost of twenty-five percent (25%) or 
greater between the final Subregional Planning Meeting in the current planning year and the 
project being submitted to the Transmission Provider Board for approval.  The Transmission 
Provider shall consider such a reconsideration request only if it is endorsed by the OMS acting 
by a vote of sixty-six percent (66%) or more of the OMS members.
At the end of each MTEP cycle, the OMS Committee may submit its assessment of the 
MTEP process to the Planning Advisory Committee, Transmission Provider, and the System 
Planning Committee of the Transmission Provider Board.  Upon receipt of any such assessment 
from the OMS Committee, the Transmission Provider planning staff shall provide an appropriate 
response in a reasonably timely manner.
The manner in which the OMS Committee shall provide its assessment shall be set forth 
in the Transmission Planning Business Practices Manual procedures.  The general procedures 
adopted with respect to the OMS Committee input into the MTEP shall remain unchanged until 
June 1, 2015, unless otherwise mutually agreed to by the Transmission Provider and the OMS 
Committee.  Changes to the Transmission Planning Business Practices Manual procedures which 
describe OMS Committee input into the MTEP process may not be adopted with less than sixty 
(60) days’ notice to the OMS Committee unless the OMS Committee consents to such earlier 
adoption.  At the end of the two year period the Transmission Provider, the OMS, and other 
stakeholders will assess the success of the input procedures and provide suggestions for

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
improvement.
C.
Development of the MTEP:  The Transmission Provider, working in 
collaboration with representatives of the Transmission Owners, OMS, and the Planning Advisory 
Committee, shall develop the MTEP, consistent with Good Utility Practice and taking into 
consideration long-range planning horizons, as appropriate.  The Transmission Provider shall 
develop the MTEP for expected use patterns and analyze the performance of the Transmission 
System in meeting both reliability needs and the needs of the competitive bulk power market, 
under a wide variety of contingency conditions.  The MTEP will give full consideration to the 
needs of all Market Participants, will include consideration of demand-side options, and will 
identify expansions or enhancements needed to i) support competition and efficiency in bulk 
power markets; ii) comply with Applicable Laws and Regulations; and iii) maintain reliability. 
Transmission expansions or enhancements may include any facilities that are eligible to be 
included in the Transmission System as provided for under this Tariff, including SATOA. Any 
SATOA may only participate in the Transmission Provider’s markets to the extent necessary to 
receive Energy from the Transmission System and to inject Energy into the Transmission System 
to provide the services for which the SATOA was included in the MTEP.  SATOA may not 
otherwise participate in the Energy and Operating Reserve Markets and/or the Planning Resource 
Auction unless and until the Tariff includes provisions for storage facilities recovering cost-
based revenues as transmission assets to also participate in these or other Market Activities.  This 
analysis and planning process shall integrate into the development of the MTEP among other 
things:  
(i) the Transmission Issues identified from Facilities Studies carried out in connection

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
with specific transmission service requests; (ii) Transmission Issues associated with 
generator interconnection service; (iii) the Transmission Issues, including proposed 
transmission projects, identified by the Transmission Owners in connection with their 
planning analyses in accordance with local planning process described in Section I.D.1.a 
to this Attachment FF and the coordination processes of Section I.D.1.b., or developed by 
Transmission Owners utilizing their own FERC-approved local transmission planning 
process described in Section I.D.2, as applicable, to provide reliable power supply to their 
connected load customers and to expand trading opportunities, better integrate the grid 
and alleviate congestion; (iv) the transmission planning obligations of a Transmission 
Owner, imposed by federal or state law(s) or regulatory authorities, which can no longer 
be performed solely by the Transmission Owner following transfer of functional control 
of its transmission facilities to the Transmission Provider; (v) plans and analyses 
developed by the Transmission Provider to provide for a reliable Transmission System 
and to expand trading opportunities, better integrate the grid and alleviate congestion; (vi) 
the identification, evaluation, and analysis of expansions to enable the Transmission 
System to fully support the simultaneous feasibility of all Stage 1A ARRs; (vii) the inputs 
provided by the Planning Advisory Committee; (viii) the inputs, if any, provided by the 
state and local regulatory authorities having jurisdiction over any of the Transmission 
Owners; (ix) the inputs of the OMS Committee; and (x) the transmission needs driven by 
public policy requirements selected to be included as Transmission Issues pursuant to 
Section I.C.1.b.ii in accordance with Applicable Laws and Regulations.
1.
Planning Cycle and Milestones:  The ISO Agreement requires that a regional

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
transmission plan be developed biennially or more frequently.  An MTEP planning cycle 
is established for each calendar year.  The development of the MTEP for a planning cycle 
with a given calendar year designation begins on June 1 of the year prior to the MTEP 
calendar year designation and ends with the approval of the final MTEP report by the 
Transmission Provider Board.  This approval typically occurs at the Transmission 
Provider Board Meeting in December of the MTEP designated year.  For example, the 
development of the MTEP14 transmission plan will commence on June 1 of 2013 and 
typically end with approval in December 2014.  The development of the MTEP will 
follow specified process steps that are detailed, including process diagrams, in the 
Transmission Provider’s Transmission Planning Business Practices Manual (“TPBPM”).  
The TPBPM shall be posted on the website of the Transmission Provider.
a.
Planning Functions:  The planning process includes the following functions 
which are described in detail in the TPBPM:
i. 
Model Development;
ii. 
Generator Interconnection Planning;
iii. 
Transmission Service Planning;
iv. 
Cyclical Regional Expansion Planning activities;
v. 
Interregional coordination with neighboring transmission planning 
regions;
vi. 
System Support Resource (“SSR”) Studies for unit de-
commissioning;
vii. 
Transmission-to-Transmission Interconnections;

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
viii.
Load Interconnections; and
ix.
Focus Studies.  These are studies initiated during the cyclical 
baseline planning process that cannot be delayed until the next 
planning cycle (for example, NERC/FERC directives, or near-term 
critical operational issues).
Each of these planning functions may develop system expansions that are taken into 
consideration in developing the entirety of the MTEP.
b.
Planning Cycle: The regional planning process is performed through a 
continuous series of planning cycles, with each cycle typically addressing 
Transmission Issues through a rolling planning horizon.  Each cycle 
commences with regional model development, identification of potential 
expansions from the local planning processes of the Transmission Owners, 
identification and selection of transmission needs driven by public policy 
requirements pursuant to Section I.C.1.b.ii to be included as Transmission 
Issues, and identification by stakeholders or the Transmission Provider of 
potential expansions that address the Transmission Issues.  Each cycle 
concludes with recommendations to the Transmission Provider Board of 
recommended solutions to the Transmission Issues evaluated.  Transmission 
Owner plans developed through local planning processes described in Section 
I.D.1.a are included in the beginning of each regional planning cycle as 
potential alternatives to local Transmission Issues identified by the 
Transmission Owners.

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
i.
Key Planning Cycle Milestones:  The regional planning process evaluates, with 
stakeholder input throughout the cycle, the local plans of the Transmission 
Owners, as one input to the development of the regional plan.  Key milestones in 
the typical MTEP development process are listed below and requirements and 
timelines for data submittal, review, and comment at each of these milestone 
points are described in the TPBPM:
(a)
Model development;
(b)
Identification and selection of transmission needs driven by public 
policy requirements pursuant to Section I.C.1.b.ii to be included as 
Transmission Issues;
(c)
Testing models against applicable planning criteria;
(d)
Development of possible solutions to identified Transmission Issues;
(e)
Selection of preferred solution;
(f)
Determination of funding and cost responsibility; and 
(g)
Monitoring progress on solution implementation.  
ii.
Transmission needs driven by public policy requirements:  The process for 
selecting transmission needs driven by public policy requirements, out of the 
larger set of transmission needs driven by public policy requirements that 
stakeholders may propose, to be included in the Transmission Issue(s) for which 
transmission solutions will be evaluated shall be as follows:
a.
At the beginning of the MTEP cycle, stakeholders submit to the 
Transmission Provider, proposals to consider transmission needs

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
driven by public policy requirements, as part of the Transmission 
Issues they may raise, in accordance with Section I.C.2.b, through 
Sub-Regional Planning Meetings, the Planning Subcommittee 
and/or the Planning Advisory Committee.  The Transmission 
Provider may also identify transmission needs driven by public 
policy requirements to be evaluated. 
b.
The Transmission Provider will then consolidate all such identified 
transmission needs driven by public policy requirements that it 
receives into a list that will be distributed to stakeholders through 
the Planning Subcommittee and/or the Planning Advisory 
Committee and to other stakeholder forums as the Transmission 
Provider deems necessary.
c.
Transmission needs driven by public policy requirements will be 
discussed in the Sub-Regional Planning Meetings, Planning 
Subcommittee and/or the Planning Advisory Committee in 
accordance with Section I.C.2.b.
d.
The Transmission Provider will assess such identified transmission 
needs driven by public policy requirements that it receives, 
considering the feedback received from stakeholders and the Sub-
Regional Planning Meetings, Planning Subcommittee and/or the 
Planning Advisory Committee, and select the public policy 
requirements that will be further studied in the MTEP process.

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
This selection will be based on:  
1.
the effective dates, nature and magnitude of the public 
policy requirements in the Applicable Laws and 
Regulations; 
2.
 the immediacy or other estimated timing, and extent, of the 
potential impact on the identified transmission needs; 
3.
the availability of the resources, and any limitations thereto, 
that would be required by consideration of such 
transmission needs driven by public policy requirements; 
4.
the relative significance of other Transmission Issues that 
have been raised for consideration; and 
5.
other appropriate factors that can aid the prioritization of 
Transmission Issues to be considered by the regional 
transmission planning process.
iii.
The Transmission Provider shall address each of these milestones throughout the 
planning cycle through Sub-regional Planning Meetings, Planning Subcommittee 
and Planning Advisory Committee meetings.
2.
Stakeholders Input in Planning Process:  The Transmission Provider shall 
facilitate discussions with its Transmission Customers, Transmission Owners, OMS 
Committee, and other stakeholders about the Transmission Issues and solutions involving 
both transferred and non-transferred facilities, as described in Section I.D.1 of this 
Attachment FF.

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
These discussions will take place at Sub-regional Planning Meetings and at 
regularly scheduled meetings of the Transmission Provider’s Planning Subcommittee, at 
locations provided by the Transmission Provider and with communication capabilities for 
those participants unable to have in person representation at these meetings.  Once the 
MTEP report for a specific planning cycle has been completed but prior to 
recommendation to the Transmission Provider Board for approval, the Transmission 
Provider shall seek feedback on the proposed MTEP, including Network Upgrades 
recommended for approval, from the Transmission Provider’s stakeholders and the OMS 
Committee.
a.
Planning Advisory Committee (“PAC”):  The Planning Advisory 
Committee is a standing committee reporting to the Transmission Provider’s 
Advisory Committee, and functions subject to the Stakeholder Governance Guide 
developed by the Stakeholder Governance Working Group, as approved by the 
Advisory Committee.  The PAC is responsible for addressing planning policy 
issues of importance to stakeholders and within the responsibilities of the 
Transmission Provider.  The PAC charter is maintained on the Transmission 
Provider’s website.
b.
Planning Subcommittee (“PS”):  The Planning Subcommittee is a standing 
stakeholder-chaired subcommittee of the Planning Advisory Committee, and 
functions subject to the Stakeholder Governance Guide developed by the 
Stakeholder Governance Working Group, as approved by the Advisory 
Committee.  Planning Subcommittee membership is open to interested parties,

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
including, but not limited to:  transmission delivery service and interconnection 
service customers, marketers, developers, Transmission Owners, state and local 
regulatory authorities, federal regulatory staff, other Market Participants, and all 
interested parties.  The charter for the committee is developed by stakeholders and 
is maintained on the Transmission Provider’s website.  The Transmission 
Provider will seek guidance from Transmission Owners, state and local regulatory 
authorities, and other stakeholders through the Planning Subcommittee and/or the 
Planning Advisory Committee prior to the beginning of each new planning cycle.  
Guidance will include the scope of planning studies to be undertaken, the 
development of future scenarios to be modeled and analyzed in long-term 
planning studies, and the development of suitable models and assumptions to 
support such studies.  The Transmission Provider will also seek guidance from 
Transmission Owners, state and local regulatory authorities, and other 
stakeholders through the Planning Subcommittee and/or the Planning Advisory 
Committee prior to implementing changes or revisions to the scope, models, and 
assumptions during the planning cycle.  The Planning Subcommittee and/or the 
Planning Advisory Committee may form working groups at the discretion of 
stakeholders to perform specific tasks supporting the planning processes, such as 
model development and detail review of study results and draft plan reports.
c.
Sub-regional Planning Meetings (“SPMs”):  The Transmission Provider 
shall utilize SPMs to provide opportunity for Transmission Owners, state and 
local regulatory authorities, and other stakeholders to provide input to the

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
planning process, and to carry out the tasks of coordinating transmission plans 
among the Transmission Owners and proposals to address the Transmission 
Issues identified in the scope of transmission planning studies.  Input and planned 
coordination may occur through the use of existing sub-regional planning groups 
(“SPGs”) where they exist, or through the establishment of new sub-regional 
meeting forums.  One or more SPMs will be used or established for each of the 
four regional Planning Sub-regions of the Transmission Provider.  Planning Sub-
regions shall be defined based upon the Transmission Provider Planning Sub-
regions:  West, Central, South, and East as defined in Attachment FF-3.  
i)
SPM Participants:  Participants at an SPM will consist of 
representatives of the Transmission Owners operating within the 
associated Planning Sub-region that integrate their local planning 
processes with the regional process, representatives from state and local 
regulatory authorities, and any other parties interested in or impacted by 
the planning process.  For those Transmission Owners engaged in local 
planning under their own FERC approved local planning processes, such 
Transmission Owners shall participate in the SPM in order to coordinate 
their planning activities.  
Neighboring transmission-owning utilities and regulatory participants are 
eligible and encouraged to participate in the SPM to promote joint 
planning between the Transmission Provider and neighboring transmission 
systems.

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
ii)
SPM Guidelines.  The Sub-regional Planning Meeting participants 
shall: 
(a)
Make recommendations for a coordinated sub-regional 
Plan, after considering sub-regional and regional needs and 
alternatives, for the ensuing ten years, for all transmission facilities 
in the sub-region; 
(b)
Review and comment on proposed Transmission Owners 
plans identified in local planning processes described in Section 
I.D.1.a. of this Attachment FF, for additions and modifications to 
the sub-regional transmission system, as potential solutions to 
identify Transmission Issues and review the transmission plans 
developed by those Transmission Owners that have their own 
FERC-approved local planning process (described in Section 
I.D.2) to ensure coordination of the projects set forth in such plans 
with the potential regional planning solutions developed in the 
SPM process consistent with the requirements of Appendix B of 
the Transmission Owners’ Agreement; 
(c)
Form technical study task forces as required to carry out the 
sub-regional planning responsibilities; 
(d)
Encourage non-Transmission Provider member 
participation to improve understanding by the SPM participants, 
the Planning Subcommittee, and the Transmission Provider staff of

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
facility changes outside the Transmission Provider Region to 
ensure the impact of such changes are considered in the planning 
studies; 
(e)
Promote other stakeholder (i.e., environmental agencies, 
and load and generation developers) involvement in development 
of the sub-regional plans. 
(f)
Recommend to the Planning Subcommittee proposed sub-
regional plans to be included in the MTEP.  In addition, the 
transmission projects developed by any Transmission Owner or 
Owners utilizing the provisions of their own FERC-approved local 
planning process shall be submitted for inclusion in the regional 
MTEP after being evaluated by the Transmission Provider in the 
regional evaluation of SPMs in accordance with Appendix B of the 
Transmission Owners’ Agreement in determining the Transmission 
Provider’s recommendation for inclusion in the MTEP.
(g)
Reflect, as desired, minority opinions to the Transmission 
Provider or the Planning Subcommittee.  
(h)
SPM Frequency, Location and Agenda:  SPMs should meet 
at least two times per year or as otherwise provided for in the 
TPBPM, to provide input in the planning process, review plans and 
recommend changes, if any, needed to address stakeholder needs 
and to coordinate proposed plans.

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
Meetings involving CEII or confidential materials shall be handled 
under Section I.C.12 of this Attachment FF.    
3.
Meeting Notifications:  Notice shall be provided by way of email distribution lists 
by the Transmission Provider of all SPMs, Planning Subcommittee, and Planning 
Advisory Committee meetings.  These email distribution lists are established and 
maintained by the Transmission Provider and it is the responsibility of stakeholders to 
have registered as described on the Transmission Provider website.  Meeting dates, times, 
locations, and materials will also be posted on the meeting calendar page of the 
Transmission Provider’s website.  Meeting notification guidelines are set forth in the 
stakeholder developed Stakeholder Governance Guidelines. 
4.
Other Meeting Schedules:  Planning Subcommittee meetings are regularly 
scheduled meetings that occur no less than bimonthly.  Annual meeting schedules and 
objectives are developed at the December meeting each year for the subsequent year.  
Planning Advisory Committee meetings are scheduled as per the PAC Charter. 
5.
Planning Criteria:  The Transmission Provider shall evaluate the system to 
address Transmission Issues in a manner consistent with the ISO Agreement and this 
Attachment FF.  Projects included in the MTEP may be based upon any applicable 
planning criteria, including accepted NERC reliability standards and reliability standards 
adopted by Regional Entities, local planning reliability or economic planning criteria of 
the Transmission Owner, or required by State or local authorities, any economic or other 
planning criteria or metrics defined in this Attachment FF, and any Applicable Laws and 
Regulations.  Transmission Owners are required to annually provide updated copies of

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Transmission Expansion Planning Protocol
ATTACHMENTS
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local planning criteria for posting on the Transmission Provider’s website.
The Transmission Provider will post on its website an explanation of which transmission 
needs driven by public policy requirements will be evaluated for potential solutions in the 
local or regional transmission planning process, as well as an explanation of why other 
suggested potential transmission needs will not be evaluated.
6.
Planning Analysis Methods:  Planning analyses performed by the Transmission 
Provider will test the Transmission System under a wide variety of conditions as 
described in Section II and using standard industry applications to model steady state 
power flow, angular and voltage stability, short-circuit, and economic parameters, as 
determined appropriate by the Transmission Provider to be compliant with applicable 
criteria and this Tariff. 
7.
Planning Models:  The Transmission Provider shall collaborate with Transmission 
Owners, other transmission providers, Transmission Customers, and other stakeholders to 
develop appropriate planning models that reflect expected system conditions for the 
planning horizon.  The planning models shall reflect the projected Load growth of 
existing Network Customers and other transmission service and interconnection 
commitments.  The models shall include:  (1) any transmission projects identified in 
Service Agreements or Interconnection Agreements that are entered into in association 
with requests for transmission delivery service or interconnection service, as determined 
in Facilities Studies associated with such requests, and (2) MHVDC Transmission Lines 
with executed Transmission Connection Agreements.  Load forecasts applied to models 
will consider the forecast Load of Network Customers reported to the Transmission

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ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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Provider in accordance with the requirements of Module B and RAR of this Tariff, and 
the Business Practices Manuals of the Transmission Provider.  Models will be posted on 
a secure application maintained by the Transmission Provider and accessible to 
stakeholders with security measures as provided for in the TPBPM.  The Transmission 
Provider will provide an opportunity for stakeholders to review and comment on the 
posted models before commencing planning studies.  
The schedules for such reviews are maintained in the TPBPM.  Stakeholders shall be 
afforded opportunities to provide input on Load projections from Tariff reporting 
requirements or from Transmission Owner forecasts.  After the base line forecast and 
model are established, the Transmission Provider and/or Transmission Owners may 
adjust the forecast as necessary on an ad hoc basis throughout the planning year to 
address customer requests for new Load interconnections arising from on-going dialogue 
with existing and prospective customers.
8.
Planning Assumptions:  Each MTEP report shall list in detail the planning 
assumptions upon which the analyses are based.  In general, planning analyses will be 
based on the following:
a.
Planning Horizons:  The MTEP will identify Transmission Issues for a 
minimum planning horizon of five years and a maximum planning horizon of 
twenty years.
b.
Load:  Load demand will generally be modeled by the Transmission 
Provider as the most probable (“50/50”) coincident Load projection for each 
Transmission Owner’s service territory, for the season under study.  Specific

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ATTACHMENT FF
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Transmission Expansion Planning Protocol
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studies may model alternative Load probabilities or peak Load for areas within a 
Transmission Owner’s service territory as dictated by operational and planning 
experience and/or local planning criteria, but in any case shall be treated 
consistently in the planning for native Load and transmission access requests.  
c.
Generation:  Planning models of five years or longer will model 
generation, taking into consideration applicable planning reserve requirements, 
that are: (i) existing and expected to be in existence in the planning horizon; (ii) 
not existing but with executed interconnection agreements;  (iii) associated with 
MHVDC Transmission Lines with executed Transmission Connection 
Agreements, and (iv) additional generation as determined with stakeholder input, 
as necessary to adequately and efficiently meet demand forecasted through the 
planning horizon and to facilitate compliance with statutory or regulatory 
mandates.  The Transmission Provider shall apply a scenario analysis to 
determine alternative future generation portfolio possibilities.  
Generation portfolio development for planning model purposes will be developed 
with input from the Planning Advisory Committee and its subcommittees, 
working groups, and task forces.  Point-To-Point Transmission Service and 
Network Integration Transmission Service customers will have an opportunity to 
guide new generation portfolio development that is reflective of customer future 
resource plans.  
d.
Demand Response Resources:  Planning solutions will be based upon the 
best available information regarding the expected amount and location of Load

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Transmission Expansion Planning Protocol
ATTACHMENTS
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that can be effectively and efficiently reduced by demand response or energy 
efficiency programs, as well as the amount of behind-the-meter generation that 
can reliably be expected to produce Energy that could impact planning solutions.  
The Transmission Provider shall perform and report on sensitivity analyses that 
indicate the effectiveness of potential demand response as alternative planning 
solutions, to the extent that appropriate methodology for such analyses is 
developed with stakeholders and documented in the TPBPM.
e.
Topology:  Each planning study will use the best known topology based 
upon the most recently approved MTEP.  Planning studies will include all 
projects approved by the Transmission Provider Board, and shall identify, as 
appropriate, and as detailed in the TPBPM, any system needs already identified in 
the most recent approved MTEP.  
9.
Evaluation of Alternatives:  When the planning analyses, based on the foregoing 
principles, identifies Transmission Issues, the Transmission Provider will consider the 
inputs from stakeholders derived from the SPM processes, the inputs from the Planning 
Subcommittee and the Planning Advisory Committee, the plans of any Transmission 
Owner with its own FERC-approved local planning process, and the MTEP aggregate 
system analyses against applicable planning criteria, in determining the solutions to be 
included in the MTEP and recommended to the Transmission Provider Board for 
implementation.  
10.
Facility Design:  Facility design and system configuration (such as conductor 
sizes, transformer design, bus configuration, protection schemes) are selected by the

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ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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Transmission Owner, and must be consistently applied by the Transmission Owner for 
comparable system service conditions.  Comparable application of system design does 
not preclude the consideration or selection of advanced or alternative transmission 
technology.  For Competitive Transmission Facilities associated with Competitive 
Transmission Projects, the Transmission Provider may provide limitations or 
requirements regarding facility design when necessary due to a planning driver or to 
ensure compatibility with existing transmission facilities to which the Competitive 
Transmission Facilities will interconnect as further described in Section VIII.C.2.c of this 
Attachment FF.
11.
Status of Recommended Facilities:  The status of all project facilities 
recommended for implementation in the MTEP shall be reported to the Transmission 
Provider on a quarterly basis and upon solicitation from the Transmission Provider.  Each 
Selected Developer and Transmission Owner is required to provide such status updates 
regarding the facilities for which it is responsible to construct to the Transmission 
Provider as further specified in this Section I.C.11 of Attachment FF of the Tariff and the 
Business Practices Manuals. 
The Transmission Provider shall report on such status to the Transmission 
Provider Board on a quarterly basis, or as otherwise directed by the Transmission 
Provider Board.  The Transmission Provider shall also publicly post such status in a form 
consistent with the Business Practices Manuals to the Transmission Provider’s website on 
a quarterly basis, redacting any CEII and/or confidential information as necessary.  
(a)
Status of Eligible Project facilities approved after December 1, 2015:

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Transmission Expansion Planning Protocol
ATTACHMENTS
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Each Selected Developer and incumbent Transmission Owner shall provide 
quarterly status reports to the Transmission Provider regarding the facilities included in 
an Eligible Project approved after December 1st, 2015 for which it is responsible to 
construct until the quarter after all such facilities have been placed into service and 
transferred to the Transmission Provider’s functional control, or the facilities and/or
Eligible Project are otherwise reassigned, canceled, or terminated.
Quarterly status reports shall conform to the format set forth in the Business 
Practices Manuals and include, at a minimum, the following: (i) project schedule, 
including each facility’s estimated in-service date and any material changes therein; (ii) 
estimated project costs, including the estimated cost to complete each facility, any 
material changes therein as compared to the applicable Baseline Cost Estimate as set 
forth in Section IX.C.1.1, the total project expenditures to date, and the total project 
expenditures to date expressed as a percentage of the Baseline Cost Estimate, as set forth 
in Section IX.C.1.1; (iii) facility development status (i.e. under construction, in service, 
completed, or withdrawn); (iv) status of obtaining necessary regulatory and or 
environmental permits, certificates, or approvals, including meeting necessary licensing 
requirements; (v) status of land and right-of-way acquisition; (vi) status of design and 
engineering; (vii) status of any necessary interconnection agreements; (viii) an 
explanation of the causes of, or reasons for, any material changes to or deviations from 
the MTEP in-service date, Baseline Cost-Estimate as set forth in Section IX.C.1.1, and 
information provided in the last quarterly status report; and (ix) an assessment of the 
impact of any material changes on the project, including the continued ability to meet the

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Transmission Expansion Planning Protocol
ATTACHMENTS
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MTEP in-service date. 
Within one hundred eighty (180) Calendar Days after the date the Selected 
Developer or Transmission Owner have placed all of the facilities included in a Eligible 
Project for which it is responsible to construct into service, including the transfer of 
functional control to the Transmission Provider, unless the Transmission Provider and 
Selected Developer or Transmission Owner agree on a different date, shall provide the 
Transmission Provider with the following:
1. the final costs to construct the facilities;
2. copies of the final “as-built” drawings and specifications of the facilities;
3. copies of any inspection reports performed on the facilities; and
4. geo-spatial information specific to the facilities (i.e. GIS compatible maps,
GPS coordinates, etc.)  
(b) 
Additional status requirements for Competitive Transmission Facilities:
In addition to the requirements specified above in Section I.C.11.a of Attachment 
FF, each Selected Developer shall also include in its status reports the following:  
(i) status of any necessary project financing; (ii) the percentage (%) of the total project
expenditures to date as compared to the total projected project cost schedule provided in 
the Selected Proposal; (iii) whether any rate filings associated with the Competitive 
Transmission Facilities were made during the previous quarter or expected to be made in 
the upcoming quarter; (iv) any changes in the continuing ability to meet the obligations of 
the Selected Developer Agreement according to the schedules and milestones agreed to 
therein, including any binding cost-containment measures that were included in the

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Transmission Expansion Planning Protocol
ATTACHMENTS
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Selected Proposal; (v) an explanation of the causes of, or reasons for, any changes from 
the specifications included in the Selected Proposal; and (vi) an assessment of the impact 
of any such changes on the Competitive Transmission Facilities included in the 
Competitive Transmission Project.
(c) 
Status of all other facilities recommended for implementation in the MTEP:
The requirements and obligations set forth in this section I.C.11.c of Attachment
FF, shall be applicable to all facilities recommended for implementation in the MTEP 
except for those facilities that are included in an Eligible Project approved by the 
Transmission Provider Board after December 1, 2015.
Each incumbent Transmission Owner shall provide status reports to the 
Transmission Provider regarding the facilities that are included in projects other than 
those specified in Attachment FF §I.C.11.a for which it is responsible to construct, until 
the quarter after such facilities have been placed into service and transferred to the 
Transmission Provider’s functional control. Status reports shall conform to the format set 
forth in the Business Practices Manuals and at a minimum, include the following: (i) 
material changes to the schedule and to the estimated project cost; (ii) an explanation of 
the causes of, or reasons for, any such changes; and (iii) changes in project status (i.e., 
under construction, in service, completed, or withdrawn).  The Transmission Provider 
shall report such progress to the Transmission Provider Board on a quarterly basis, or as 
otherwise directed by the Transmission Provider Board.  
12.
Treatment of Critical Energy Infrastructure Information (“CEII”) and Confidential 
Data:  The Transmission Provider shall utilize appropriate Non-Disclosure and

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Transmission Expansion Planning Protocol
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Confidentiality Agreements (“NDA”) to address sharing of Confidential Information and 
CEII transmission planning information.  The secured sites containing such information 
will require such agreements to be executed in order to obtain access to those 
applications.  Stakeholder meetings at which CEII may be available shall be noticed to 
email distribution lists and shall require execution of NDAs prior to participation in such 
meetings.  In the alternative, such meetings will be structured to have separate discussion 
of issues involving CEII data only with participants that agree to execute the NDA.  
Confidential information related to economic (e.g., congestion) studies, as well as CEII, 
is clearly sensitive information which must remain confidential.  The Transmission 
Provider shall use generic, publicly available, cost information from industry sources in 
the economic studies to prevent the accidental release of confidential information.  This 
approach will promote an open planning process because the results of economic studies 
are available to all interested parties.
Entities that are members of any stakeholder sector of the Advisory Committee 
shall, upon request and subject to execution of the appropriate NDA(s), be provided with 
access to the data used by the Transmission Provider to develop the MISO Transmission 
Expansion Plan designated as Confidential Information and/or CEII.  Access, which shall 
be described in the Transmission Planning Business Practices Manual, shall be subject to: 
(1) the prior execution of all appropriate NDAs required by the Transmission Provider to 
protect Confidential Information as well as CEII by persons authorized by the sector 
member to receive transmission planning information on the sector member’s behalf and 
(2) any provisions of this Tariff or the applicable Business Practice Manuals that govern

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FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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access to or use of the type of information for which access is sought.  The provisions of 
this Section I.C.12 are not exclusive and do not diminish the right of any stakeholder to 
access Confidential Information or CEII under any other authorizing provision of the 
Tariff, Business Practices Manuals, or FERC order.
13.
Resolution of Stakeholder Input:  The Transmission Provider shall solicit input 
and comments from all stakeholders, including Transmission Owners, during and after 
stakeholder planning meetings, and will use reasonable efforts to reply to comments that 
the Transmission Provider does not elect to implement, together with reasons for such 
actions.  The Transmission Provider shall develop a process for the documentation and 
resolution of stakeholder issues raised in the planning process, including but not limited 
to issues related to planning criteria.
14.
Dispute resolution:  Consistent with Attachment HH of this Tariff, the 
Transmission Provider shall resolve disputes concerning MTEP issues.  The first step will 
be for designated representatives of the affected parties to work together to resolve the 
relevant issues in a manner that is acceptable to all parties.  If that step is unsuccessful, 
each affected party shall designate an officer who shall review disputes involving them 
that their designated representatives are unable to resolve.  The applicable officers of the 
parties involved in such dispute shall work together to resolve the disputes so referred in 
a manner that meets the interests of such parties, either until such agreement is reached, 
or until an impasse is declared by any party to such dispute.  If such officers are unable to 
satisfactorily resolve the issues, the matter shall be referred to mediation.  Parties that are 
not satisfied with the dispute resolution procedures may only file a complaint with the

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Transmission Expansion Planning Protocol
ATTACHMENTS
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Commission during the negotiation or mediation steps.  
If a matter remains unresolved, the affected parties may pursue arbitration.
D.
Project Coordination:  In the course of the MTEP process, the Transmission 
Provider shall seek out opportunities to coordinate or consolidate, where possible, individually 
defined transmission projects into more comprehensive cost-effective developments subject to 
the limitations imposed by prior commitments and lead-time constraints.  The Transmission 
Provider shall coordinate with Transmission Owners, and shall consider the input from the 
SPMs, Planning Subcommittee, and Planning Advisory Committee to develop expansion plans 
to meet the needs of the system.  This multi-party collaborative process will allow for all projects 
with regional and inter-regional impact to be analyzed for their combined effects on the 
Transmission System.  Moreover, this collaborative process is designed to ensure that the MTEP 
address Transmission Issues within the applicable planning horizon in the most efficient and cost 
effective manner, while giving consideration to the inputs from all stakeholders.  In addition to 
the requirements of this Attachment FF, there may be state or local procedural requirements 
applicable to the planning or siting of transmission facilities by the Transmission Owners.  A 
current list of those requirements can be found on the Transmission Provider’s website.
1.
Transmission Owners Electing to Integrate their Local Planning Processes into the 
Transmission Provider’s Processes:  Some Transmission Owners have agreed to integrate 
internal planning process with the Transmission Provider’s open and coordinated 
planning processes for all of their transmission facilities to comply with Order 890 
Planning Principles instead of filing a  separate Attachment K.  Through this election, the 
local planning for all transmission facilities of these Transmission Owners, regardless of

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ATTACHMENT FF
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Transmission Expansion Planning Protocol
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whether the facilities are ultimately transferred to the functional control of the 
Transmission Provider, shall be integrated with and included in the regional planning 
processes of the Transmission Provider.  These regional planning processes, as provided 
for in this Attachment FF and in additional detail in the TPBPM, ensure that the planning 
decisions for all such facilities are made in an open and transparent environment.
This planning environment provides opportunity for input from, and review by, 
stakeholders of the Open Access Transmission Tariff services throughout the planning 
process, and is in accordance with the Planning Principles of the Order 890 Final Rule.  
The open and transparent planning provisions of this Attachment FF shall not preclude 
interaction between stakeholders and Transmission Owners prior to the submittal of 
proposed projects to the regional planning process.
Transmission Owners integrating local planning processes into the regional 
planning processes are listed in Attachment FF-4.  Such Transmission Owners shall be 
responsible for providing the Transmission Provider with sufficient information 
regarding all planning activities to enable the Transmission Provider to adequately review 
and incorporate all of the Transmission Owner’s transmission facilities into the regional 
planning process of the Transmission Provider, as described in Sections I.D.1.a. and 
I.D.1.b. of this Attachment FF.  
The foregoing Transmission Owners will utilize the planning stakeholder forums 
of the Transmission Provider to demonstrate the need for, identify the alternatives to, and 
report the status of non-transferred transmission facilities using the same open, 
transparent and coordinated planning process provided by the Transmission Provider for

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Transmission Expansion Planning Protocol
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transferred facilities as described in this Attachment FF. 
a.
Local Planning Processes of Transmission Owners:  In accordance with 
the ISO Agreement, each Transmission Owner engages in local system planning in order 
to carry out its responsibility for meeting its respective transmission needs in 
collaboration with the Transmission Provider subject to the requirements of applicable 
state law or regulatory authority.  In meeting its responsibilities under the ISO 
Agreement, the Transmission Owners may, as appropriate, develop and propose plans 
involving modifications to any of the Transmission Owner’s transmission facilities which 
are part of the Transmission System.  The Transmission Owners shall include the 
following specific local planning steps in order to develop plans for potential inclusion in 
the regional plan, in accordance with the annual regional planning process as described in 
Section I.D.1.b. of this Attachment FF, and in accordance with the regional planning 
principles of Section I.C of this Attachment.  In addition to the local planning steps 
below, Transmission Owners shall adhere to any applicable state or local regulatory 
planning processes.   
i.
Define local study area and study horizon; 
ii.
Develop appropriate power system models;
a)
Utilize existing NERC or Transmission Provider cases to model 
external systems;
b)
Insert detailed model of Transmission Owner system if required;
c)
Insert updated detailed models of neighboring system models if 
required; and

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Transmission Expansion Planning Protocol
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d)
Verify model topology and generation.
iii.
Update loads (spatial and magnitude) in study area;
a)
Review historical MW and MVAR data to develop growth trends;
b)
Obtain Load forecasts from customers in study area; and
c)
Obtain input from local distribution planners in the study area.
iv.
Perform contingency analysis using applicable Transmission Owner 
planning criteria;
v.
Identify any violations to planning criteria for each of study period;
vi.
Develop alternative solutions to the criteria violations and test against the 
planning criteria;
a)
Obtain cost estimates for each alternative and perform economic 
analyses; and 
b)
Determine non-cost attributes of each alternative such as operating 
flexibility, robustness, among others.
vii.
Select alternative based on cost and non-cost attributes;
viii.
Submit proposed solution and list of alternatives and assumptions to the 
Transmission Provider;
ix.
Participate in stakeholder evaluations and discussions as a part of annual 
regional plan development process;
x.
Perform additional analysis as required based on feedback from 
stakeholder groups (SPM/PS) in the regional planning process;
xi.
Submit results of additional analysis (if performed) to the Transmission

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Transmission Expansion Planning Protocol
ATTACHMENTS
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Provider for further discussion with stakeholders (SPM/PS); 
xii.
Consider regional planning process results, including stakeholder feedback 
on needs, proposed solutions, and alternatives, in determining whether or not to 
proceed with implementation of Transmission Owner proposed expansions; and
xiii.
Post the planning criteria and assumptions, and power flow models used in 
development of each Transmission Owner’s current local planning proposal in 
accordance with Section I.D.1.b below.  To the extent that the Transmission 
Owner uses the MISO MTEP models in developing its list of newly proposed 
projects, the Transmission Owner shall indicate as per Section I.D.1.b. below, the 
associated MTEP model used.  
The Transmission Provider will maintain a link to applicable MTEP 
models on its website together with instructions for accessing such models 
consistent with CEII criteria and suitable non-disclosure agreements.  In the event 
that the Transmission Owner applies its own power flow models in developing its 
proposed local plans, the Transmission Owner shall provide such models to the 
Transmission Provider for posting, or shall provide to the Transmission Provider a 
link to the location of such Transmission Owner model(s) and to instructions for 
accessing such models consistent with the Transmission Owner’s CEII and non-
disclosure requirements.  Transmission Provider shall post on its website links to 
such postings on Transmission Owner’s website.
b.
Integration of Local Planning Processes of Transmission Owners:  
Transmission Owners listed on Attachment FF-4 as integrating local planning processes

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Transmission Expansion Planning Protocol
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with those of the Transmission Provider, shall integrate proposals for transmission 
expansions into the regional planning process as follows.  Each Transmission Owner 
shall submit its proposals for transmission plans to the Transmission Provider prior to the 
start of each regional planning cycle.  Each Transmission Owner’s local plan, which 
consists of a list of proposed projects, shall be made available on the Transmission 
Provider’s website for review by the PAC, the PS, and the SPM participants, subject to 
CEII and the confidentiality provisions in this Attachment FF.  Such local plans shall be 
posted by September 15 each year in order to provide time for written comments by 
stakeholders.  In addition to the list of proposed projects, each Transmission Owner 
submitting newly proposed projects by September 15 in any MTEP annual cycle shall 
provide to the Transmission Provider by June 1 of the same year identification of any 
MISO base power flow model used by the Transmission Owner in support of the 
identification of the list of proposed projects to be subsequently posted in September, or 
in the event that the Transmission Owner uses a non-MISO base power flow model in 
support of the identification of the list of proposed projects the Transmission Owner shall 
provide to the Transmission Provider such base power flow model or a link to the power 
flow model and assumptions used.
Each Transmission Owner’s local planning model and associated assumptions 
shall be accessible on or through a link on the Transmission Provider’s website for 
review, subject to CEII and the confidentiality provisions in this Attachment FF and 
consistent with section I.D.1.a.  In the event that the Transmission Owner uses a non-
MISO base power flow model, the Transmission Owner shall provide for posting updates

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Transmission Expansion Planning Protocol
ATTACHMENTS
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if there are significant changes in the model by July 15, August 15, and September 15 of 
each year.  Comments by stakeholders on the local planning models and assumptions that 
are provided to the Transmission Provider SPM Planning Contact by July 1, or August 1 
or September 1 with respect to updates, shall be forwarded to the applicable Transmission 
Owner by July 8, August 8, or September 8, respectively.  The Transmission Provider 
shall address any unresolved stakeholder issues through the SPM process.
Each Transmission Owner shall also provide to the Transmission Provider by June 1 of 
each year any updates to the posted transmission planning criteria, or a notification that 
the posted documents have not changed.  In the event a Transmission Owner has 
additional significant updates to the posted transmission planning criteria, the 
Transmission Owner shall provide such updates for posting by July 15, August 15, and 
September 15 of each year.  
The Transmission Provider shall post on its website the lists of newly proposed 
projects, criteria and assumptions, and supporting base power flow models or links to 
supporting base power flow models, as provided by the Transmission Owners.  Initial 
comments by stakeholders to the proposed projects should be provided to the 
Transmission Provider SPM Planning Contact 45 days after the posting of local plans 
otherwise comments may be made pursuant to Section I.C.2.c.ii.  The Transmission 
Provider SPM Planning Contact shall be identified on the Transmission Provider’s web 
site page devoted to Expansion Planning.  The Transmission Provider shall provide to the 
applicable Transmission Owner within five working days of receipt, a copy of all 
stakeholder comments received within 45 days of the posted information regarding

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ATTACHMENT FF
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Transmission Expansion Planning Protocol
ATTACHMENTS
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Transmission Owner planning criteria and assumptions, models applied, and list of 
proposed projects.  The Transmission Provider shall address any unresolved stakeholder 
issues through the SPM process.  Each Transmission Owner must participate in SPMs in 
the respective Planning sub-region as indicated in the Transmission Providers meeting 
schedule.  Such SPMs shall provide input to and review of the results of the needs 
assessments and adequacy of plans proposed by the Transmission Owners, or by 
stakeholders to the planning process, or by the Transmission Provider, to best meet the 
needs of the sub-region. 
Transmission Owners identified in Attachment FF-4, must submit to the 
Transmission Provider, on an annual basis and at a time to be determined by the 
Transmission Provider, which shall be prior to the beginning of each regional planning 
cycle, all proposed transmission plans for both transferred and non-transferred 
transmission facilities.  The submitted projects of such Transmission Owners shall be 
considered potential alternatives to system needs identified, and as such must be 
submitted when initially identified as a potential system solution, in order to permit the 
evaluation of such projects along with other potential alternatives that may be proposed 
by stakeholders or the Transmission Provider, in the SPM processes.  Such alternatives 
may include transmission, generation, and demand-side resources.  The Transmission 
Provider will review and evaluate such alternatives on a comparable basis and select the 
most appropriate solution. Comparability includes the ability of the Transmission 
Provider to obtain contractual assurances that the selected solution will be implemented 
by the required in-service dates.  Contractual commitments associated with the

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Transmission Expansion Planning Protocol
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construction of an MTEP Appendix A approved project by MISO Transmission Owner(s) 
and/or Selected Developer(s) are provided for by the ISO Agreement, this Tariff, and the 
Selected Developer Agreement.  
Contractual commitments associated with generation solutions require that a 
generator interconnection agreement be filed with the Commission pursuant to 
Attachment X of this Tariff by the time the alternative transmission solution would need 
to be committed to in order to ensure installation on the required need date.  Contractual 
commitments associated with ZG Associated Load require demonstration to the 
Transmission Provider of both: (1)  an executed agreement between the entity with the 
ZG Associated Load and the Generating Facility with the associated ZG Interconnection 
Service as described in Section 3.11 of Attachment X to the Tariff is in place and must 
span at least the five year planning horizon to ensure the ability to provide adequate lead 
time for an alternative transmission solution should the contracts terminate; and (2) that 
the Generating Facility associated with the ZG Associated Load has achieved 
Commercial Operation by the time that the transmission solution would otherwise need to 
be in service.  In the event that the Generating Facility associated with the ZG Associated 
Load fails to achieve Commercial Operation by the date that the transmission solution 
would otherwise need to be in service or the contract between the ZG Associated Load 
and the associated Generating Facility terminates, then the Transmission Provider may 
require the applicable Load Serving Entity to delay the in-service date of ZG Associated 
Load until such time as an alternative solution can be placed in service.
Contractual commitments associated with demand-side resource solutions require

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demonstration to the Transmission Provider of an executed contract between LSE and 
End-Use Customers.  Such demand-side contracts must be in place by the time that the 
transmission solution would otherwise need to be committed to in order to ensure a 
timely solution to the identified planning need, and must span the five year planning 
horizon to ensure the ability to provide adequate lead time for an alternative transmission 
solution should the demand contracts terminate.  Notwithstanding the provisions of 
Section VII of the ISO Agreement regarding the Transmission Provider review of 
Transmission Owner plans, no proposed project of a Transmission Owner that has elected 
to integrate their local planning processes into the Transmission Provider’s processes, as 
indicated on Attachment FF-4, shall be recommended in the MTEP for implementation 
until completion of the annual needs analysis carried out in the annual MTEP cycle, as 
described in Section I.C. of this Attachment FF, except as provided for in Section I.D.1.c. 
of this Attachment FF.  
c.
Out-of-Cycle Review of Transmission Owner Plans:  In the event that a 
Transmission Owner determines that system conditions warrant the urgent development 
of system enhancements that would be jeopardized unless the Transmission Provider 
performs an expedited review of the impacts of the project,  Transmission Provider shall 
use a streamlined approval process for reviewing and approving projects proposed by the 
Transmission Owners so that decisions will be provided to the Owner within thirty (30) 
days of the projects submittal to the MISO unless a longer review period is mutually 
agreed upon.
2.
Transmission Owners Filing Separate Attachment K:  Some Transmission Owners as

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listed on the last page of Attachment FF-5 have developed individual open, local planning 
processes for their facilities, that comply with the Planning Principles of the Order 890 Final 
Rule.  These Transmission Owners have an Attachment K that describes how the Transmission 
Owner will comply with the Order No. 890 Planning Principles for all transmission facilities that 
they plan for, regardless of whether those facilities are ultimately transferred to the functional 
control of the Transmission Provider.  With the exception of Sections I.D.1.a and I.D.1.b., the 
provisions of this Attachment FF remain applicable to all Transmission Owners notwithstanding 
the filing by any Transmission Owner of an Attachment K pursuant to the Order 890 Final Rule.
E.
Interregional  Coordination and Cost Allocation:  The MTEP shall be 
developed in accordance with the principles of interregional coordination through collaboration 
with representatives from adjacent transmission providers, their designated regional planning 
organizations, or regional transmission organizations, as provided for in this Attachment FF, or 
as otherwise provided for in existing joint agreements between the Transmission Provider and 
other regional entities that engage in planning activities.  The Transmission Provider has 
developed region-specific interregional coordination and cost allocation provisions with regard 
to the following neighboring transmission planning regions: 
•
PJM Interconnection, L.L.C. (“PJM”), as provided for under Article IX and other applicable 
provisions of the Joint Operating Agreement between the Transmission Provider and PJM; 
•
Southeastern Regional Transmission Planning (“SERTP”), as provided for under Section X 
of this Attachment FF; and 
•
Southwest Power Pool (“SPP”), as provided for under Article IX and other applicable 
provisions of the Joint Operating Agreement between the Transmission Provider and SPP.

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Transmission Expansion Planning Protocol
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The Transmission Provider also has planning coordination provisions as part of its 
coordination agreement with Manitoba Hydro. 
II.
Development Process for MTEP Projects:  The Transmission Provider will develop the 
MTEP biennially or more frequently.  The MTEP will identify expansion projects for inclusion 
in the MTEP according to the factors set forth in Appendix B of the ISO Agreement and Section 
I.C of this Attachment FF.  For purposes of assigning cost responsibility, expansion projects in 
the MTEP shall be categorized pursuant to the following criteria.
A.
Reliability Needs:  Reliability projects are identified either in the periodically performed 
Baseline Reliability Study, or in Facilities Studies associated with the request processes for new 
transmission access.  Transmission access includes requests for both new transmission delivery 
service and new generation interconnection service.
1.
Baseline Reliability Projects:  Baseline Reliability Projects are 
Network Upgrades identified in the base case as required to ensure that the 
Transmission System is in compliance with applicable national Electric 
Reliability Organization (“ERO”) reliability standards and reliability standards 
adopted by Regional Reliability Organizations and applicable within the 
Transmission Provider Region.  Baseline Reliability Projects include projects that 
are needed to maintain reliability while accommodating the ongoing needs of 
existing Market Participants and Transmission Customers.  Baseline Reliability 
Projects may consist of a number of individual facilities that in the judgment of 
the Transmission Provider constitute a single project for cost allocation purposes.  
The Transmission Provider shall collaborate with Transmission Owning

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ATTACHMENT FF
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Transmission Expansion Planning Protocol
ATTACHMENTS
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members, other transmission providers, Transmission Customers, and other 
stakeholders to develop appropriate planning models that reflect expected system 
conditions for the planning horizon.  The planning models shall reflect the 
projected load growth of existing network customers and other transmission 
service and interconnection commitments, and shall include any transmission 
projects identified in Service Agreements or interconnection agreements that are 
entered into in association with requests for transmission delivery service or 
transmission interconnection service, as determined in Facilities Studies 
associated with such requests, and MHVDC Transmission Lines with executed 
Transmission Connection Agreements.  The Transmission Provider shall test the 
MTEP for adequacy and security based on commonly applicable national Electric 
Reliability Organization (“ERO”) standards, and under likely and possible 
dispatch patterns of actual and projected Generation Resources within the 
Transmission System and of external resources, including dispatch reflective of 
Long-Term Transmission Rights of Transmission Customers, and shall produce 
an efficient expansion plan that includes all Baseline Reliability Projects 
determined by the Transmission Provider to be necessary through the planning 
horizon of the MTEP.  The Transmission Provider shall obtain the approval of the 
Transmission Provider Board, as set forth in Section VI, for each MTEP 
published.
2.
New Transmission Access Projects:  New Transmission Access 
Projects are defined for the purposes of Attachment FF as Network Upgrades

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Transmission Expansion Planning Protocol
ATTACHMENTS
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identified in Facilities Studies and agreements pursuant to requests for 
transmission delivery service or transmission interconnection service under the 
Tariff and also include JTIQ Upgrades.  New Transmission Access Projects 
include projects that are needed to maintain reliability while accommodating the 
incremental needs associated with requests for new transmission or 
interconnection service, as determined in Facilities Studies associated with such 
requests and/or were identified as JTIQ Upgrades.  New Transmission Access 
Projects may consist of a number of individual facilities, which in the judgment of 
the Transmission Provider constitute a single project for cost allocation purposes.  
New Transmission Access Projects are either Generation Interconnection Projects 
or Transmission Delivery Service Projects as defined in Sections II.A.2.a. and 
II.A.2.b.  The Transmission Provider shall consider the Baseline Reliability 
Projects already determined to be needed in the most current MTEP, as well as 
any other base-case needs not associated with the request for new service that 
may be identified during the impact study process when determining the need for 
New Transmission Access Projects.  Any identified base-case needs determined 
in the impact study process that are not a part of the Baseline Reliability Projects 
already identified in the most current MTEP shall become new Baseline 
Reliability Projects and shall be included in the next MTEP.  New Transmission 
Access Projects identified in Facilities Studies and agreements pursuant to 
requests for transmission delivery service or transmission interconnection service 
under this Tariff shall be included in the next MTEP.

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Transmission Expansion Planning Protocol
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a.
Generation Interconnection Projects:  Generation Interconnection 
Projects are New Transmission Access Projects that are associated with 
interconnection of new, or increase in generating capacity of existing, 
generation under Attachment X to this Tariff and include JTIQ Upgrades.
b.
Transmission Delivery Service Projects:  Transmission Delivery 
Service Projects are New Transmission Access Projects that are needed to 
provide for requests for new Point-To-Point Transmission Service, or 
requests under Module B of the Tariff for Network Service or a new 
designation of a Network Resource(s).
B.
Market Efficiency Projects:  Market Efficiency Projects are Network Upgrades:  (i) that 
are proposed by the Transmission Provider, Transmission Owner(s), ITC(s), Market 
Participant(s), or regulatory authorities; (ii) that are found to be eligible for inclusion in the 
MTEP or are approved pursuant to Appendix B, Section VII of the ISO Agreement after June 16, 
2005, applying the factors set forth in Section I.C. of this Attachment FF; (iii) that, except if 
qualifying as an Interregional Market Efficiency Project under Section IX of the MISO-PJM 
Joint Operating Agreement, have a Project Cost of $5 million or more; (iv) that, except if 
qualifying as an Interregional Market Efficiency Project under Section IX of the MISO-PJM 
Joint Operating Agreement, involve facilities with voltages of 230 kV or higher1; and that may 
include any lower voltage facilities of 100kV or above that collectively constitute less than fifty 
percent (50%) of the combined project cost, and without which the 230 kV or higher facilities 
could not deliver sufficient benefit to meet the required benefit-to-cost ratio threshold for the 
1 
Transformer voltage is defined by the voltage of the low-side of the transformer for these purposes.

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FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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project as established in Section II.B.1.c, or that otherwise are needed to relieve applicable 
reliability criteria violations that are projected to occur as a direct result of the development of 
the 230 kV or higher facilities of the project; (v) that are not determined to be Multi-Value 
Projects; (vi) that are found to have regional benefits under the criteria set forth in Section II.B.1 
of this Attachment FF.  In the event that a Network Upgrade qualifies as an Interregional Market 
Efficiency Project under Section IX of the MISO-PJM Joint Operating Agreement, the cost 
threshold of Section II.B(iii) does not apply, and the voltage threshold of Section II.B.(iv) shall 
be 100 kV or higher.2 
1.
Criteria to Determine Whether a Project Should be Included as a Market 
Efficiency Project:  The Transmission Provider shall employ multiple future scenarios 
and multi-year analyses including sensitivity analyses guided by input from the Planning 
Advisory Committee to evaluate the anticipated benefits of a proposed Market Efficiency 
Project in order to determine if such a project meets the criteria for inclusion in the 
regional plan as a Market Efficiency Project eligible for regional cost sharing.  Sensitivity 
analyses shall include, among other factors, consideration of:  (i) variations in amount, 
type, and location of future generation supplies as dictated by future scenarios developed 
with stakeholder input and guidance; (ii) alternative transmission proposals; (iii) impacts 
of variations in load growth; and (iv) effects of demand response resources on 
transmission benefits.
a. 
Benefits Analysis. For purposes of qualification as a Market Efficiency 
Project, the Transmission Provider will evaluate multiple types of economic value. The 
2 
A transformer is considered to operate above 100 kV when at least two sets of transformer terminals 
operate at voltages above 100 kV.

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Transmission Expansion Planning Protocol
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Transmission Provider shall apply the benefits metrics outlined in Attachment FF-7 and 
sum the results of each of the benefit metrics together to determine the economic benefits 
of a Market Efficiency Project to the Transmission Provider region.
b.
The costs applied in the benefit to cost ratio shall be the present value, 
over the same period for which the project benefits are determined, of the annual 
Network Upgrade Charges for the project as determined in accordance with the formula 
in Attachment GG.
i.
The present value calculation for both the annual benefits and 
annual costs will apply a discount rate representing the after-tax weighted average 
cost of capital of the Transmission Owners that make up the Transmission 
Provider Transmission System.  
c.
The Transmission Provider shall employ a benefit to cost ratio test to 
evaluate a proposed Market Efficiency Project.  Only projects that meet a benefit to cost 
ratio of 1.25 or greater shall be included in the MTEP as a Market Efficiency Project and 
be eligible for regional cost sharing.  
i.
The benefits of the project used to determine the associated cost 
allocations as a percentage of project cost shall be determined one time at the time 
that the project is presented to the Transmission Provider Board for approval.  
Estimated Project Cost will be used to estimate the benefit to cost ratio and the 
eligibility for cost sharing at the time of project approval.  To the extent that the 
Commission approves the collection of costs in rates for Construction Work in 
Progress (“CWIP”) for a constructing Transmission Owner, costs will be

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Transmission Expansion Planning Protocol
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allocated and collected prior to completion of the project.    
d.
The aforementioned Market Efficiency Project inclusion criteria 
shall be used for the exclusive purpose of determining whether projects are eligible for 
regional cost sharing in accordance with Section III.A.2.f below.  These criteria shall not 
affect the existing criteria set forth in Appendix B of the ISO Agreement for determining 
whether projects are eligible for inclusion in the MTEP.  Moreover, the costs of projects 
included in the MTEP, but not eligible for regional cost sharing, shall continue to be 
eligible for inclusion in the calculation of Transmission Owner revenue requirements under 
Attachment O of this Tariff. 
C. 
Multi-Value Projects:  A Multi-Value Project is one or more Network Upgrades 
that address a common set of Transmission Issues and satisfy the conditions listed in 
Sections II.C.1, II.C.2, and II.C.3 of Attachment FF.  All Network Upgrades associated 
with a Multi-Value Project including any network upgrades on an external system and  
lower voltage facilities that may be needed to relieve applicable reliability criteria 
violations that are projected to occur as a direct result of the development of the Multi-
Value Project including any lower voltage facilities that are needed on an external system; 
may be cost shared per Section III.A.2.g of Attachment FF except for (i) any Network 
Upgrade cost associated with constructing an underground or underwater transmission line 
above and beyond the cost of a feasible alternative overhead transmission line that provides 
comparable regional benefits, and (ii) any DC transmission line and associated terminal 
equipment when scheduling and dispatch of the DC transmission line is not turned over to 
the Transmission Provider's markets, real-time control of the DC transmission line is not

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FERC Electric Tariff
Transmission Expansion Planning Protocol
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turned over to the Transmission Provider's automatic generation control system and/or the 
DC transmission line is operated in a manner that requires specific users to subscribe for 
DC transmission service. 
1.
A Multi-Value Project must be evaluated as part of a Portfolio of projects, as 
designated in the transmission expansion planning process, whose benefits are: (i) 
spread broadly across the MISO system-wide footprint; or (ii) if the benefits of the 
Portfolio are not spread broadly across the MISO system-wide footprint, the 
benefits are spread broadly across: (a) the MISO Midwest MVP Cost Allocation 
Subregion; or (b) the MISO South MVP Cost Allocation Subregion.
2.
A Multi-Value Project must meet one of the three criteria outlined below:
a.
Criterion 1.  A Multi-Value Project must be developed through the 
transmission expansion planning process for the purpose of enabling the 
Transmission System to reliably and economically deliver energy in support 
of documented energy policy mandates or laws that have been enacted or 
adopted through state or federal legislation or regulatory requirement that 
directly or indirectly govern the minimum or maximum amount of energy 
that can be generated by specific types of generation.  The MVP must be 
shown to enable the transmission system to deliver such energy in a manner 
that is more reliable and/or more economic than it otherwise would be 
without the transmission upgrade.
b.
Criterion 2.  A Multi-Value Project must provide multiple types of 
economic value across multiple pricing zones with a Total MVP Benefit-to-

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Transmission Expansion Planning Protocol
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Cost ratio of 1.0 or higher where the Total MVP Benefit -to-Cost ratio is 
described in Section II.C.7 of this Attachment FF.  The reduction of 
production costs and the associated reduction of LMPs resulting from a 
transmission congestion relief project are not additive and are considered a 
single type of economic value.
c.
Criterion 3.  A Multi-Value Project must address at least one Transmission 
Issue associated with a projected violation of a NERC or Regional Entity 
standard and at least one economic-based Transmission Issue that provides 
economic value across multiple pricing zones.  The project must generate 
total financially quantifiable benefits, including quantifiable reliability 
benefits, in excess of the total project costs based on the definition of 
financial benefits and Project Costs provided in Section II.C.7 of 
Attachment FF.
3.
All of the following conditions must be satisfied in order for a project to be 
classified as a Multi-Value Project:
a.
Facilities associated with the transmission project must not be in service, 
under construction, or approved for construction by the Transmission 
Provider Board prior to July 16, 2010 or the date a Transmission Owner 
becomes a signatory member of the ISO Agreement, whichever is later.  
This Section II.C.3.a shall not preclude the Multi-Value Project 
classification of a Competitive Transmission Project that makes a Selected 
Developer(s) eligible to become a Transmission Owner.

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b.
The transmission project must be evaluated through the Transmission 
Provider's transmission planning process and approved for construction by 
the Transmission Provider Board prior to the start of construction, where 
construction does not include preliminary site and route selection activities.
c.
The transmission project must not contain any transmission facilities listed 
in Attachment FF-1 of this Tariff. 
d.
The total capital cost of the transmission project must be greater than or 
equal to $20,000,000.00.
e.
The transmission project must include, but not necessarily be limited to, the 
construction or improvement of transmission facilities operating at voltages 
above 100 kV. A transformer is considered to operate above 100 kV when 
at least two sets of transformer terminals operate at voltages above 100 kV.
f.
Network Upgrades driven solely by an Interconnection Request, as defined 
in Attachment X of the Tariff, or a Transmission Service request will not be 
considered Multi-Value Projects.
4.
Any transmission project that qualifies as a Multi-Value Project shall be 
classified as an MVP irrespective of whether such project is also a Baseline 
Reliability Project and/or Market Efficiency Project.
5.
The specific types of economic value provided by a Multi-Value Project 
include the following:
a.
Production cost savings where production costs include generator 
startup, hourly generator no-load, generator energy and generator

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FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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Operating Reserve costs. Production cost savings can be realized 
through reductions in both transmission congestion and transmission 
energy losses.  Productions cost savings can also be realized through 
reductions in Operating Reserve requirements within Reserve Zones 
and, in some cases, reductions in overall Operating Reserve 
requirements for the Transmission Provider.
b.
Capacity losses savings where capacity losses represent the amount 
of capacity required to serve transmission losses during the system 
peak hour including associated planning reserve.
c.
Capacity savings due to reductions in the overall Planning Reserve 
Margins resulting from transmission expansion.
d.
Long-term cost savings realized by Transmission Customers by 
accelerating a long-term project start date in lieu of implementing a 
short-term project in the interim and/or long-term cost savings 
realized by Transmission Customers by deferring or eliminating the 
need to perform one or more projects in the future.
e.
Any other financially quantifiable benefit to Transmission 
Customers resulting from an enhancement to the Transmission 
System and related to the provisions of Transmission Service.
6.
Any project to facilitate like-for-like capital replacements of plant originally 
installed as part of a Multi-Value Project where replacement is due to aging, failure, 
damage or relocation requirements where such replacement is not the result of

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FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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negligence by the constructing Transmission Owner will be treated as a Multi-
Value Project.  The minimum project cost limitation for Multi-Value Projects 
described in Section II.C.3.d of Attachment FF will not apply to the like for- like 
capital replacement projects described in this Section.
7.
The following Total MVP Benefit-to-Cost Ratio will be applied to any 
Multi-Value Project justified solely on the basis of Sections II.C.2.b or II.C.2.c of 
this Attachment FF to ensure such project qualifies as a Multi-Value Project: 
Total MVP Benefit-to-Cost Ratio = financial benefits / Project Costs.
For the purpose of this calculation, Financial Benefits will be set equal to the 
present value of all financially quantifiable benefits provided by the project 
projected for the first 20 years of the project's life and Project Costs will be set 
equal to the present value of the annual revenue requirements projected for the first 
20 years of the project's life.
8.
The aforementioned Multi-Value Project inclusion criteria shall be used for 
the exclusive purpose of determining whether projects are eligible for regional cost 
sharing in accordance with Section III.A.2.g below.  These criteria shall not affect 
the existing criteria set forth in Appendix B of the ISO Agreement for determining 
whether projects are eligible for inclusion in the MTEP.  Moreover, the costs of 
projects included in the MTEP, but not eligible for regional cost sharing, shall 
continue to be eligible for inclusion in the calculation of Transmission Owner 
revenue requirements under Attachment O of this Tariff.
D.
Market Participant Funded Projects: Market Participant funded projects (MPFPs) are

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defined as Network Upgrades fully funded by one or more market participants but owned and 
operated by an incumbent Transmission Owner.  These projects apply to those Network 
Upgrades that are neither currently included in the MTEP Appendix A nor targeted for approval 
within the current planning cycle.
The development of the MPFPs will follow specified process steps that are detailed in the 
Transmission Provider’s Transmission Planning Business Practices Manual (“TPBPM”).  These 
process steps shall include, at a minimum, the following:
1.
Consistent with the MTEP process the submittal deadline for a proposed 
MPFP project shall be September 15 of the current planning cycle and the 
proposed MPFP shall be submitted to the Transmission Provider planning contact, 
indicated on the MPFP submittal form posted on the Planning page of the 
Transmission Provider web site.
2.
An MPFP proposed by a Market Participant shall follow the same analysis 
and approval timeline as an MTEP Target Appendix A project for the current 
planning cycle.
3.
In the event that multiple Market Participants submit project proposals that 
are electrically similar, Transmission Provider shall make a determination in 
collaboration with the affected Transmission Owner(s) as to whether the projects 
are effectively the same project.  Such consideration shall include whether the 
proposals have the same terminal stations, substantially address the same market 
congestion issues or otherwise serve similar system purposes, and can each be  
physically accommodated together with the other similar proposals.  If the

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Transmission Expansion Planning Protocol
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projects are determined to be effectively the same project, the priority for the 
project shall be determined by the time-stamp date of receipt of the MPFP 
Proposal Form, unless otherwise agreed to by the impacted Market Participants.  
E.
Identification of Potential Impacts of a Market Efficiency Project or Multi-Value 
Project on Neighboring Transmission Planning Region(s)
As part of the evaluation of any proposed Market Efficiency Project or Multi-Value 
Project, the Transmission Provider will determine whether the proposed Market Efficiency Project 
or Multi-Value Project causes any violations of NERC reliability standards on the transmission 
system(s) of the adjacent neighboring transmission planning region(s).  If the Transmission 
Provider’s evaluation identifies any such violations of NERC reliability standards, the 
Transmission Provider will contact and coordinate with the other potentially affected adjacent 
neighboring transmission planning region(s) on any further evaluation.  
F.
Targeted Market Efficiency Projects:  
A Targeted Market Efficiency Project is an upgrade that is identified in a Targeted Market 
Efficiency Project Study initiated by the Joint RTO Planning Committee as provided for under 
Article IX of the Joint Operating Agreement between the Transmission Provider and PJM and that 
satisfies the criteria for a Targeted Market Efficiency Project as set forth in Article IX of the Joint 
Operating Agreement between the Transmission Provider and PJM.  Any Targeted Market 
Efficiency Project that is recommended by the Joint RTO Planning Committee under Article IX of 
the Joint Operating Agreement between the Transmission Provider and PJM shall be presented to 
the Transmission Provider Board for approval in the MTEP.

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G.
Treatment of Storage as a Transmission-Only Asset (SATOA)  
1.  SATOA May Be Included in MTEP as a Solution to a Transmission Issue
A storage facility proposed as a Storage as Transmission Only Asset (“SATOA”) may be 
considered in the transmission planning process as a solution to a Transmission Issue.   A 
SATOA may be any one of the transmission project types described in Sections II.A through 
II.D and II.F of this Attachment FF that meet the definitions, criteria, or factors applicable to 
those project types.  A SATOA is eligible for cost recovery consistent with the cost recovery for 
its project type under Attachment FF, including cost recovery under Attachment FF, Section 
III.A.2.k. 
a.
Comparative Evaluations of Proposed SATOA.   
The Transmission Provider will evaluate the appropriateness of proposed SATOAs as solutions 
to Transmission Issues identified in the development of the MTEP comparably to any other 
transmission asset.  Considerations will include:
i.
Ability of the proposed SATOA to address the Transmission Issue (e.g., loading, 
voltage, stability) in all hours that the Transmission Issue is determined to exist, 
with a life-cycle cost that is comparable to other proposed solutions or as 
otherwise needed to address the Transmission Issue, and after consideration of 
the comparability in system performance to other proposed solutions, including 
any non-transmission alternatives consistent with the provisions of Section 
I.D.1.b.
ii.
The minimum and maximum Capacity required to address the Transmission Issue

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to ensure that excess storage Capacity is not treated as a transmission asset.  Cost 
recovery under transmission rates is limited to the cost of the maximum Capacity 
determined to be needed to address the Transmission Issue and will be pro-rated 
on that basis if a SATOA of higher Capacity is proposed, selected for inclusion in 
Appendix A of MTEP, and installed.
iii.
Assurance of sufficient Energy and/or reactive capability (MWh/MVAr) to charge 
or discharge Energy for any period identified as necessary in the planning study. 
iv.
Assessment of system reliability impacts applicable to inverter-based facilities on 
the same basis and in a manner comparable to such analysis in the Generator 
Interconnection Procedures applicable to storage Resources as inverter-based 
facilities.  
v.
Life-cycle cost comparisons, including consideration of the period that is required 
to address the Transmission Issue, which may be less than the life cycle of 
alternatives, and including the factors described in Section II.G.1.b.  
vi.
Additional considerations that may support comparative evaluation to other 
solutions to the Transmission Issue, such as lead-time to develop, right of way or 
substation impacts, expandability, operational flexibility, or others.
b. Life Cycle, Degradation, and Cost Assumptions 
Selection of the proposed SATOA as the preferred solution will consider similar cost and 
effectiveness considerations as applied to any other proposed transmission solution.  The entity 
proposing the SATOA shall provide the planning estimate of the SATOA’s:

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i.
Direct capital cost; 
ii.
Expected useful life; 
iii.
Equipment replacement schedules and associated life-cycle costs and other 
ongoing costs to maintain the SATOA at its required Capacity and Energy 
capability necessary to address the Transmission Issue identified, or otherwise 
comparable to a traditional wires solution; and 
iv.
Other cost and performance information as the Transmission Provider may 
determine is necessary to compare cost and performance with other proposed 
solutions to the Transmission Issue identified.
c.
Selection of proposed SATOA as a Preferred Solution in MTEP
To be selected for inclusion in the MTEP, in addition to the requirements of Section II.G.1.a., the 
proposed SATOA must:
i.
Demonstrate a basis to be recommended for inclusion in Appendix A of the 
MTEP as a transmission asset by:
a. Unique characteristics or circumstances of the proposed SATOA 
necessary to meet the identified Transmission System performance 
requirements and not otherwise available at comparable costs from other 
proposed solutions, including speed of operation, lead-time to implement, 
right-of-way or other property considerations.   
b. A need to resolve the Transmission Issue(s) through the storage facility’s

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ATTACHMENTS
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Effective On: October 18, 2026
functioning as a SATOA instead of as a Resource that participates in the 
Transmission Provider’s markets. A storage facility will not be evaluated 
as a potential SATOA to resolve a routine (i.e. N-0 or N-1) Transmission 
Issue that can be addressed by a market solution.  
ii.
Meet the criteria to be designated in the MTEP as one of the transmission project 
types consistent with the provisions of Sections II.A through II.D and II.F of this 
Attachment FF, or as eligible for cost recovery pursuant to Section III.A.2.k.  
d. Consideration of Impacts on Resources in the Interconnection Queue
If the Transmission Provider or stakeholder identifies a potential impact to Generating Facilities 
in the Definitive Planning Phase pursuant to Attachment X, the Transmission Provider will 
assess whether the proposed SATOA will impact Generating Facilities in the Definitive Planning 
Phase and such assessment may include targeted contingency analyses applying Applicable 
Reliability Standards and applicable regional and local planning criteria to evaluate the 
incremental impact of the proposed SATOA on Generating Facilities in the Definitive Planning 
Phase that are in proximity to the SATOA in the MTEP model to compare loading and other 
system performance impacts attributable to the addition of the SATOA.  The Transmission 
Provider will test the expansion model with and without the SATOA operating in the manner 
required for the SATOA to address the Transmission Issue identified for the SATOA to resolve.  
If such assessment demonstrates that the necessary operating mode of the proposed SATOA 
would cause the need for additional system mitigation, the cost of such mitigation will be 
included in the evaluation of the proposed SATOA against other potential transmission solutions 
and will be included as part of the SATOA project itself and the total project costs will be

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ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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Effective On: October 18, 2026
eligible for recovery through the appropriate Attachment and Schedule of the Tariff.
2. Development of Operating Guides Associated with SATOA Selected for MTEP  
Operation of SATOA in real time will be under the functional control of the Transmission 
Provider as provided for in Rate Schedule 1 (Transmission Owners Agreement), Article Three, 
Section I.A.  For each SATOA included in the MTEP, the Transmission Provider will develop an 
Operating Guide specifying the operating practices applicable to the SATOA and consistent with 
the system performance requirements determined through the planning study supporting the 
selection of the SATOA for inclusion in the MTEP. The Operating Guide will include limitations 
on the operation of the SATOA above the maximum Capacity determined to be needed to 
address the Transmission Issue, consistent with Section II.G.1.a.ii.
3. Storage as Non-Transmission Alternatives
As provided for under Section I.D.1.b, storage facilities that are not proposed as SATOA may be 
considered as alternatives to transmission assets to address system needs when participating as 
generation or demand-side resources.    
4. SATOA Participation in Markets
SATOA may only participate in the Transmission Provider’s markets to the extent necessary to 
receive Energy from the Transmission System and to inject Energy into the Transmission System 
to provide the services for which the SATOA was included in the MTEP.  SATOA may not 
otherwise participate in the Energy and Operating Reserve Markets and/or the Planning Resource 
Auction.  
5. Transmission Service Associated with SATOA Operation
No Transmission Service charges are applicable to the operation of a SATOA.

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
6. Responsibility for Market-Derived Costs and Revenues Associated with SATOA 
a. Accounting for Costs Incurred in the Market
Costs resulting from Market Activities of a SATOA directed under the Transmission 
Provider’s functional control shall be collected through transmission rates in a manner 
consistent with the treatment of costs associated with the transmission project type that 
the SATOA is included as in Appendix A of the MTEP pursuant to Section II.G.1.c.ii.  
As an example, costs for charging a SATOA battery storage device may be included in 
transmission rates in a manner consistent with the inclusion in transmission rates as a 
Baseline Reliability Project if the battery storage device operates to serve as a Baseline 
Reliability Project.
b. Credit Back of Market Revenues
Revenues collected from Market Activities of a SATOA directed under the Transmission 
Provider’s functional control shall be credited back through transmission rates in a 
manner consistent with the treatment of costs associated with the project category in 
transmission rates. 
7. Removal
No SATOA may be removed from service permanently unless the removal is submitted into the 
annual MTEP planning process as a proposed project removal, reviewed by the Transmission 
Provider for its impact on Transmission System performance, and accepted by the Transmission 
Provider based on such review.
III.
Designation of Cost Responsibility for MTEP Projects:  Based on the planning 
analysis performed by the Transmission Provider, which shall take into consideration all

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
appropriate input from Market Participants or external entities, including, but not limited to, any 
indications of a willingness to bear cost responsibility for an enhancement or expansion, the 
recommended MTEP shall, for any enhancement or expansion that is included in the plan, 
designate:  (i) the Market Participant(s) in one or more pricing zones that will bear cost 
responsibility for such enhancement or expansion, as and to the extent provided by any 
applicable provision of the Tariff, including Attachments N, X, or any applicable cost allocation 
method ordered by the Commission; or, (ii) in the event and to the extent that no provision of the 
Tariff so assigns cost responsibility, the Market Participant(s) or Transmission Customer(s) in 
one or more pricing zones from which the cost of such enhancements or expansions shall be 
recovered through charges established pursuant to Attachment GG of this Tariff, or as otherwise 
provided for under this Attachment FF. 
Any designation under clause (ii) of the preceding sentence shall be determined as provided for 
in Section III.A of this Attachment FF with the cost responsibility at least roughly commensurate 
with the benefits.  For all such designations, the Transmission Provider shall calculate the cost 
allocation impacts to each pricing zone.  The results will be reviewed for unintended 
consequences by the Transmission Provider and the Tariff Working Group and any such 
identified consequences shall be reported to the Planning Advisory Committee, and the OMS.
A.
Allocation of Costs Within the Transmission Provider Region 
1.
Default Cost Allocation:  Except as otherwise provided for in this Attachment FF, or by 
any other applicable provision of this Tariff and consistent with the ISO Agreement, the 
responsibility for Network Upgrades included in the approved MTEP will be addressed in 
accordance with the provisions of the ISO Agreement.

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
2.
Cost Allocation:  The Transmission Provider will designate and assign cost 
responsibility on a regional, and sub-regional basis for Network Upgrades identified 
in the MTEP subject to the grand-fathered project provisions of Section III.A.2.b.  
a.
Market Participant’s Option to Fund:  Notwithstanding the Transmission 
Provider’s assignment of cost responsibility for a project included in the 
MTEP, one or more Market Participants may elect to assume cost 
responsibility for any or all costs of a Network Upgrade that is included in 
the MTEP.  Provided however, in the event the Market Participant is also 
a Transmission Owner such election of the option to fund must be made 
on a consistent, non-discriminatory basis.
b.
Grandfathered Projects:  The cost allocation provisions of this 
Attachment FF shall not be applicable to transmission projects identified 
in Attachment FF-1, which is based on the list of projects designated as 
Planned Projects in the MTEP approved by the Transmission Provider 
Board on June 16, 2005 (MTEP 05) and some additions of proposed 
projects that the Transmission Provider has determined to be in the 
advanced stages of planning.
c.
Baseline Reliability Projects:  Costs of Baseline Reliability Projects shall 
be recovered pursuant to Attachment O of this Tariff by the Transmission 
Owner(s) and/or ITC(s) developing such projects, such that the 
Transmission Owner(s) and/or ITC(s) developing a Baseline Reliability 
Project shall be responsible for all of the costs of the portion of the

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
Baseline Reliability Project that is physically located in the Transmission 
Owner’s and/or ITC’s pricing zone, subject to the requirements of the ISO 
Agreement.
d.
Generation Interconnection Projects:  Costs of Generation Interconnection 
Projects that are not JTIQ Upgrades and that are not determined by the 
Transmission Provider to be Baseline Reliability Projects, Market 
Efficiency Projects, or Multi-Value Projects and the Network Upgrade 
costs associated with advancing a Baseline Reliability Project, Market 
Efficiency Project, or Multi-Value Project associated with a generator 
interconnection will be paid for by the Interconnection Customer(s) in 
accordance with Attachment X.
For Generation Interconnection Projects interconnecting to the American 
Transmission Company LLC transmission system and that are not JTIQ 
Upgrades, such costs will be subject to the provision of Attachment FF – 
ATCLLC.  In the event that a Generation Interconnection Project that is 
not a JTIQ Upgrade defers or displaces a Baseline Reliability Project, the 
costs of the Generation Interconnection Project up to the costs of the 
deferred or displaced Baseline Reliability Project shall be allocated 
consistent with the cost allocation for the Baseline Reliability Project.
1)
For Network Upgrades to facilities in voltage classes at or above 
345 kV and that are not a JTIQ Upgrade, the Interconnection 
Customer shall be repaid 10 percent of the costs of the Generation

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
Interconnection Project funded by the Interconnection Customer 
once Commercial Operation is achieved.  The Transmission 
Owner(s) constructing the Generation Interconnection Project will 
repay 10% of the Generation Interconnection Project costs 
associated with Network Upgrade facilities in a voltage class of 
345 kV or greater to the Interconnection Customer under 
repayment terms consistent with the schedules and other terms of 
Attachment X.  
The 10% of the Project Cost associated with Network Upgrade 
facilities of voltage class 345 kV or above and that are not a JTIQ 
Upgrade, and repaid to the Interconnection Customer pursuant to 
this section, shall be allocated on a system-wide basis and 
recovered pursuant to Attachment GG of this Tariff.
Costs of Generation Interconnection Projects that are JTIQ 
Upgrades included in a JTIQ Portfolio, and where a JTIQ Upgrade 
included in the JTIQ Portfolio has been selected to receive funding 
through the United States Department of Energy Grid Resilience 
and Innovation Partnerships (GRIP) Program by December 31, 
2023, shall be allocated to Interconnection Customers included in 
the JTIQ Commitment Groups consistent with Section 9.4 and 
related subsections of Rate Schedule 6.  If none of the JTIQ 
Upgrades have been selected to receive funds through the GRIP

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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Effective On: October 18, 2026
program, the Transmission Provider will propose an appropriate 
cost allocation method pursuant to the terms of Section 9.4 of Rate 
Schedule 6. 
In the event that the JTIQ Portfolio in Section 9.4 of Rate Schedule 
6 is not fully subscribed as set forth in Rate Schedule 6, the costs 
of JTIQ Upgrades constructed by a Transmission Owner and not 
recovered from the JTIQ Commitment Groups shall be recovered 
on a system-wide basis pursuant to Attachment JJJ. 
A JTIQ Upgrade identified pursuant to Section 9.4 of Rate 
Schedule 6 shall be presented to the Transmission Provider Board 
for approval for inclusion in the MTEP.
2)
An Interconnection Customer may be required to contribute to the 
cost of Shared Network Upgrades, as defined in Attachment X to 
the Tariff, that are funded by another Interconnection Customer,  
including when the Transmission Owner elects to fund the capital 
cost of a Shared Network Upgrade under Section 11.3 of the 
Generator Interconnection Agreement, as a Generation 
Interconnection Project pursuant to Attachment X in accordance 
with the following provisions:  
(a)
Each Interconnection Customer with one or more Shared 
Network Upgrade(s) identified in Appendix A of its 
Generator Interconnection Agreement for which the

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
Transmission Owner(s) has not elected to fund the capital 
cost of a Shared Network Upgrade(s) under Section 11.3 of 
the Generator Interconnection Agreement shall make a one-
time payment under Schedule 26-B to the Transmission 
Provider in accordance with the terms in the Generator 
Interconnection Agreement. The one-time payment will 
reflect the cost of the Shared Network Upgrade assigned to 
the Interconnection Customer as determined by the 
Transmission Provider.
All revenue collected by the Transmission Provider through 
Schedule 26-B shall be distributed to the appropriate 
Interconnection Customer(s).
(b)
If the Transmission Owner(s) has elected to fund the capital 
cost of a Shared Network Upgrade(s) under Section 11.3 of 
the Generator Interconnection Agreement, each 
Interconnection Customer with that Shared Network 
Upgrade(s) identified in Appendix A of its Generator 
Interconnection Agreement shall enter into a Facilities 
Service Agreement(s) with the Transmission Owner(s).
3)
The Interconnection Customer shall be entitled, pursuant to 
Section 46 of this Tariff, to any Financial Transmission Rights or 
other rights to the extent provided for under this Tariff, for any

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
Network Upgrade costs funded by or charged to the 
Interconnection Customer and not subject to repayment under the 
provisions of this Section III.A.2.d and that are not costs for JTIQ 
Upgrades.  For costs funded by or charged to the Interconnection 
Customer for Generation Interconnection Projects that are JTIQ 
Upgrades, the Interconnection Customer shall be eligible for 
Financial Transmission Rights pursuant to Section 47 of this 
Tariff.  
4)
International Transmission/Michigan Electric Transmission 
Company: 
(a)
For those Generation Interconnection Projects that 
are not JTIQ Upgrades for which International 
Transmission Company or Michigan Electric Transmission 
Company, LLC, (“International” or “METC”) as 
Transmission Owners will be a signatory to the 
interconnection agreement under the terms of Attachment 
X of this Tariff or any successor provision of the Tariff 
executed by the parties after the effective date of this 
Attachment FF Section III.A.2.d.4, this Attachment FF 
Section III.A.2.d.4 shall apply.
(b)
Generation Interconnection Projects:  The cost of 
Network Upgrades for Generation Interconnection Projects

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
that are not determined by the Transmission Provider to be 
Baseline Reliability Projects shall be reimbursed by the 
Transmission Owner as provided in this Section III.A.2.d.4.  
All costs of Network Upgrades for Generation 
Interconnection Projects will initially be paid by the 
Interconnection Customer in accordance with the terms of 
the Interconnection Agreement entered into pursuant to 
Attachment X of this Tariff.  To the extent the 
Interconnection Customer demonstrates at the time of 
Commercial Operation of the Generating Facility one of the 
following:  
i.
Generating Facility has been designated as a 
Network Resource in accordance with the 
Tariff, or
ii.
Contractual commitment has been entered into 
with a Network Customer for capacity, or in the 
case of an Intermittent Resource, for energy, 
from the Generating Facility for a period of one 
(1) year or longer.
The Interconnection Customer will receive up to one 
hundred percent (100%) reimbursement of reimbursable 
costs within ninety (90) days of the Commercial Operation

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
Date, such reimbursement prorated by the percentage of the 
Generating Facility capacity or annual available energy 
output contracted for and as demonstrated to the 
satisfaction of the Transmission Provider.
If the Interconnection Customer is unable to 
demonstrate to the satisfaction of the Transmission 
Provider at the time of Commercial Operation of the 
Generating Facility that the Generating Facility has met the 
repayment obligations set forth in Attachment FF Sections 
III.A.2.d.4.b.i. or III.A.2.d.4.b.ii. the Interconnection 
Customer shall be directly assigned 100% of the costs of 
the Generation Interconnection Project.  The Transmission 
Owner may effect this direct assignment of costs by either 
foregoing any repayment of costs funded by the 
Interconnection Customer, or by electing to repay 100% of 
the costs under repayment terms consistent with the 
schedules and other terms of Attachment X.
The Interconnection Customer shall be entitled, pursuant to 
Section 46 of this Tariff, to any Financial Transmission 
Rights or other rights to the extent provided for under this 
Tariff, for any Network Upgrade costs funded by or 
charged to the Interconnection Customer and not subject to

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
repayment under the provisions of this Attachment FF 
Section III.A.2.d.4.  In the event that a Generation 
Interconnection Project defers or displaces a Baseline 
Reliability Project, the costs of the Generation 
Interconnection Project up to the costs of the deferred or 
displaced Baseline Reliability Project shall be allocated 
consistent with the cost allocation for the Baseline 
Reliability Project.
(c)
For all amounts to be reimbursed by a Transmission 
Owner to an Interconnection Customer in accordance with 
this Attachment FF Section III.A.2.d.4, the Transmission 
Owner will reimburse the sums received from the 
Interconnection Customer in cash together with any 
applicable interest, in accordance with the terms of the 
Interconnection Agreement.
(d)
Allocation of Generation Interconnection 
Reimbursement.  For all amounts reimbursed by a 
Transmission Owner to an Interconnection Customer under 
this Attachment FF Section III.A.2.d.4, the reimbursement 
will be allocated as follows:  
i.
Projects of Voltage Below 345 kV:  50% of 
the applicable Project Cost for Generation

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
Interconnection Projects with a voltage class 
below 345 kV shall be allocated on a sub-
regional basis to all Transmission Customers 
in designated pricing zones.  The designated 
pricing zones and the sub-regional allocation 
of the Project Cost shall be determined on a 
case-by-case basis in accordance with a Line 
Outage Distribution Factor Table (“LODF 
Table”) developed by the Transmission 
Provider which is similar in form to that 
attached hereto as Attachment FF-2.  The 
LODF Table is based on Transmission 
System topology and Line-Outage 
Distribution Factors associated with the 
project under consideration and is used to 
determine the pricing zones to be included 
in the sub-regional allocation of the Project 
Cost.  The percentage of the sub-regional 
allocation assigned to each designated 
pricing zone shall be determined based on 
the relative share between pricing zones of 
the sum of the absolute value of the product

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
of the Line-Outage Distribution Factor on 
each Branch Facility in a pricing zone and 
the length in miles of the Branch Facility.
The remaining fifty percent (50%) of the 
reimbursement will not be subject to any 
regional or sub-regional cost allocation, but 
will be recovered by that Transmission 
Owner under its Attachment O transmission 
rate formula under this Tariff.
ii.
Projects of Voltage 345 kV and Higher:  
10% of the applicable Project Cost for 
Generation Interconnection Projects with a 
voltage class of 345 kV or higher shall be 
allocated on a system-wide basis to all 
Transmission Customers and recovered 
through a system-wide rate.  40% of the 
applicable Project Cost for Generation 
Interconnection Projects with a voltage class 
of 345 kV or higher shall be allocated on a 
sub-regional basis to all Transmission 
Customers in designated pricing zones.  The 
designated pricing zones and the sub-

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
regional allocation of the Project Cost shall 
be determined on a case-by-case basis in 
accordance with a Line Outage Distribution 
Factor Table (“LODF Table”) developed by 
the Transmission Provider similar in form to 
that attached hereto as Attachment FF-2. 
The LODF Table is based on Transmission 
System topology and Line-Outage 
Distribution Factors associated with the 
project under consideration and is used to 
determine the pricing zones to be included 
in the sub-regional allocation of the Project 
Cost.  The percentage of the sub-regional 
allocation assigned to each designated 
pricing zone shall be determined based on 
the relative share between pricing zones of 
the sum of the absolute value of the product 
of the Line-Outage Distribution Factor on 
each Branch Facility in a pricing zone and 
the length in miles of the Branch Facility.
The remaining fifty percent (50%) of the 
reimbursement will not be subject to any

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
regional or sub-regional cost allocation, but 
will be recovered by that Transmission 
Owner under its Attachment O transmission 
rate formula under this Tariff.
e.
Transmission Delivery Service Projects:  Costs of Transmission Delivery 
Service Projects shall be assigned and recovered in accordance with 
Attachment N of this Tariff.
f.
Market Efficiency Projects:  Costs of Market Efficiency Projects shall be 
allocated as follows:
i)
One Hundred  percent (100%) of the costs of the Market 
Efficiency Projects with a voltage at or above 230 kV that do 
not qualify as Interregional Market Efficiency Projects under 
Section IX of the MISO-PJM JOA shall be allocated to all 
Transmission Customers in each of the of the Transmission 
Pricing Zones that has a net positive present value of the 
annual benefits over the evaluation period applying the 
benefit metrics in Attachment FF-7. For Market Efficiency 
Projects that are also Interregional Market Efficiency 
Projects under Section IX of the MISO-PJM Joint Operating 
Agreement with a voltage at or above 345 kV,one hundred 
percent (100%) of the Transmission Provider’s share of the 
costs shall be allocated to all Transmission Customers in

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
each of the Transmission Pricing Zones that has a net 
positive present value of the annual benefits over the 
evaluation period applying the benefit metrics in Attachment 
FF-7. 
ii)
For Market Efficiency Projects that are also Interregional 
Market Efficiency Projects under Section IX of the MISO-
PJM Joint Operating Agreement with a voltage at or above 
100 kV but below 345 kV, one hundred percent (100%) of 
the Transmission Provider’s share of the costs shall be 
allocated to all Transmission Customers in each of the 
Cost Allocation Zones, as defined in Attachment WW.  
The cost allocated to each Cost Allocation Zone shall be 
based on the relative benefit determined for each Cost 
Allocation Zone that has a positive present value of annual 
benefits over the evaluation period using the methodology 
for project benefit determination of Attachment FF-7, 
Section I.A. 
iii) 
Excessive Funding or Requirements:  The Transmission 
Provider shall seek to identify and manage the development 
of, as a part of the planning process for Market Efficiency 
Projects, portfolios of projects that tend to provide net 
benefits  over the planning horizon, as determined according

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
to the applicable section(s) of Attachment FF-7, throughout 
each Transmission Pricing Zone for each Market Efficiency 
Project with a voltage at or above 230 kV that does not 
qualify as Interregional Market Efficiency Projects under 
Section IX of the MISO-PJM JOA, for each Market 
Efficiency Project that is also an Interregional Market 
Efficiency Project under Section IX of the MISO-PJM Joint 
Operating Agreement with a voltage at or above 345 kV, and 
for each Cost Allocation Zone, as defined in Attachment 
WW, for each Market Efficiency Project that is also an 
Interregional Market Efficiency Projects under Section IX of 
the MISO-PJM Joint Operating Agreement with a voltage at 
or above 100 kV but below 345 kV.  The Transmission 
Provider shall analyze on an annual basis whether the project 
portfolios developed in accordance with this goal and the 
criteria in Section III.A.2.f unintentionally result in unjust or 
unreasonable annual capital funding requirements for any 
Transmission Owner or rate increases for Transmission 
Customers in designated pricing zones; or otherwise result in 
undue discrimination between the Transmission Customers, 
Transmission Owners, or any Market Participants; any such 
identified consequences shall be reported to the Planning

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
Advisory Committee and to the Organization of MISO 
States.  After discussing such assessments with the 
aforementioned stakeholder bodies, and taking into 
consideration the cumulative experience in applying this 
Attachment FF, the Transmission Provider will make a 
determination as to whether Tariff modifications are 
required, and if so file such modifications.
g.
Multi-Value Projects: Costs of Multi-Value Projects will be allocated as 
follows: 
i)
For a Portfolio of Multi-Value Projects with benefits spread 
broadly across the MISO system-wide footprint, one-
hundred percent (100%) of the annual revenue 
requirements of the Multi-Value Projects shall be allocated 
on a system-wide basis to Transmission Customers that 
withdraw energy, including external transactions sinking 
outside the Transmission Provider's region, and recovered 
through an MVP Usage Charge pursuant to Attachment 
MM.
ii)
For a Portfolio including only Multi-Value Projects with 
benefits spread broadly across the MISO Midwest MVP 
Cost Allocation Subregion identified in Attachment XX but 
not broadly spread across the MISO system-wide footprint,

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
one-hundred percent (100%) of the annual revenue 
requirements of such Multi-Value Projects shall be: (1) 
allocated on a pro-rata basis to Transmission Customers 
that withdrew energy in the MISO Midwest MVP Cost 
Allocation Subregion identified in Attachment XX, 
including applicable external transactions associated with 
the MISO Midwest MVP Cost Allocation Subregion 
sinking outside the Transmission Provider’s region; and (2) 
recovered through an MVP Usage Charge pursuant to 
Attachment MM.
iii)
For a Portfolio including only Multi-Value Projects with 
benefits spread broadly across the MISO South MVP Cost 
Allocation Subregion identified in Attachment XX but not 
broadly spread across the MISO system-wide footprint, 
one-hundred percent (100%) of the annual revenue 
requirements of such Multi-Value Projects shall be: (1) 
allocated on a pro-rata basis to Transmission Customers 
that withdraw energy in the MISO South MVP Cost 
Allocation Subregion as identified in Attachment XX, 
including applicable external transactions associated with 
the MISO South MVP Cost Allocation Subregion and 
sinking outside the Transmission Provider's region; and (2)

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
recovered through an MVP Usage Charge pursuant to 
Attachment MM.
h.
Targeted Market Efficiency Projects:  The cost of a Targeted Market 
Efficiency Project shall be allocated as follows:
i)
Targeted Market Efficiency Projects are interregionally 
cost allocated between the Transmission Provider and PJM 
per Section 9.4.4.2.5 of the Joint Operating Agreement 
between the Transmission Provider and PJM.
ii)
One hundred percent (100%) of the Transmission Provider’s 
share of the cost of a Targeted Market Efficiency Project 
shall be allocated to all Transmission Pricing Zones that 
receive a positive congestion contribution benefit from the 
Targeted Market Efficiency Project.  The share of such cost 
allocated to each Transmission Pricing Zone shall be in 
proportion to the relative positive congestion contribution 
benefit accruing from the Targeted Market Efficiency Project 
to the Transmission Pricing Zone over the evaluation period 
of Section 9.4.4.1.5(iv)(d) of the Joint Operating Agreement 
between the Transmission Provider and PJM.  To determine 
the relative positive contribution benefit accruing to each 
Transmission Pricing Zone, the Transmission Provider will 
use the data resulting from the Targeted Market Efficiency

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
Project study conducted pursuant to Section 9.3.7.2(c) of the 
Joint Operating Agreement and apply a congestion 
contribution formula to each load node and generator node in 
the Commercial Model equal to the multiplication of the 
Shadow Price of the flowgate, shift factor of the load node or 
generator node to the flowgate, and the amount of load or 
generation at the node.  This formula will be applied for all 
hours in the Day Ahead market where the Reciprocal 
Coordinated Flowgate experienced congestion.  The 
congestion contribution of each load node or generator node 
on the Reciprocal Coordinated Flowgate will be calculated 
for each congested interval during the evaluation period of 
Section 9.4.4.1.5(iv)(d) of the Joint Operating Agreement 
between the Transmission Provider and PJM.  Summing all 
of the congestion contributions will yield the relative benefits 
of the upgrade to each load node or generator node.  
Aggregating the load node or generator node congestion 
contributions for each Transmission Pricing Zone gives the 
net benefits of the upgrade to each Transmission Pricing 
Zone, providing the basis for cost allocation of the 
Transmission Provider’s share of the cost of the Targeted 
Market Efficiency Project.

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iii)
Provided, however, that no cost for the Targeted Market 
Efficiency Project shall be allocated to a Transmission 
Pricing Zone if the positive congestion contribution benefit 
from the Targeted Market Efficiency Project to that 
Transmission Pricing Zone is calculated to be less than a 
threshold of either: (1) $5,000 total or (2) less than one 
percent (1%) of the Transmission Provider’s cost of the 
Targeted Market Efficiency Project.  Any costs that are not 
allocated to a Transmission Pricing Zone because they fall 
within this threshold will be collected by a reallocation to the 
remaining Transmission Pricing Zones that receive positive 
congestion contribution benefits from the Targeted Market 
Efficiency Project in proportion to the share of positive 
congestion contribution benefits each Transmission Pricing 
Zone is calculated to receive from the Targeted Market 
Efficiency Project.
iv)
Provided, further, that no cost for a Targeted Market 
Efficiency Project that is approved in any MTEP by the 
Transmission Provider Board during the Second Planning 
Area’s Transition Period shall be allocated to a Transmission 
Pricing Zone located in the Second Planning Area if the 
Targeted Market Efficiency Project terminates wholly

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outside of MISO or terminates exclusively in the First 
Planning Area.  Any costs that are not allocated to a 
Transmission Pricing Zone in the Second Planning Area as a 
result of this subsection shall be collected by a reallocation to 
the remaining Transmission Pricing Zones that receive 
positive congestion contribution benefits from the Targeted 
Market Efficiency Project in proportion to the share of 
positive congestion contribution benefits each Transmission 
Pricing Zone is calculated to receive from the Targeted 
Market Efficiency Project.     
i.
Market Participant Funded Projects (MPFPs):  Costs of MPFPs 
will be allocated as follows: One-hundred percent (100%) of the cost of a 
Market Participant Funded Project (MPFP) shall be assigned to the Market 
Participant that proposed the project, subject to the provisions of this 
Attachment FF Section II.D.3, unless other cost sharing arrangement is 
agreed to between the Market Participant and the incumbent Transmission 
Owner.
j.
Treatment of Projects that meet both Baseline Reliability Project Criteria 
and/or New Transmission Access Project Criteria, and the Market 
Efficiency Project Criteria:  If the Transmission Provider determines that a 
project designated as a Market Efficiency Project also meets the criteria to 
be designated as a Baseline Reliability Project and/or a New Transmission

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Access Project, the cost of such project shall be allocated in accordance 
with the Market Efficiency Project allocation procedures.
k.
Other Projects:  Unless otherwise agreed upon pursuant to 
Section III.A.2.a. of this Attachment FF, the costs of Network Upgrades 
that are included in the MTEP, but do not qualify as Baseline Reliability 
Projects, New Transmission Access Projects, Targeted Market Efficiency 
Projects, Market Efficiency Projects, or Multi-Value Projects shall be 
eligible for recovery pursuant to Attachment O of this Tariff by the 
Transmission Owner(s) and/or ITC(s) paying the costs of such project, 
subject to the requirements of the ISO Agreement. 
l.
Withdrawal from MISO:  A Transmission Owner that withdraws from the 
MISO as a Transmission Owner shall remain responsible for all financial 
obligations incurred pursuant to this Attachment FF while a Member of 
the MISO and payments applicable to time periods prior to the effective 
date of such withdrawal shall be honored by the MISO and the 
withdrawing Member. 
m.
New Transmission Owners: A new Transmission Owner joining the MISO 
will be responsible for the following financial obligations:
a.
New Transmission Owners will not be responsible for any 
portion of Baseline Reliability Projects, Generation 
Interconnection Projects, Transmission Delivery Service 
Projects, Targeted Market Efficiency Projects, or Market

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Efficiency Projects that were approved prior to their entry 
date.
b.
For Multi-Value Projects approved prior to the new 
Transmission Owner’s entry date, the load interconnected 
to the Transmission Owner’s Transmission System will be 
responsible for one-hundred percent (100%) of the MVP 
usage charge described in Attachment MM for the years 
following the Transmission Owner’s entry date applied to 
the Monthly Net Actual Energy Withdrawals for Load 
interconnected to the Transmission Owner’s Transmission 
System.
n.
Only a Transmission Owner shall be authorized to construct and/or own 
transmission facilities associated with a Baseline Reliability Project.  For 
projects jointly developed between Transmission Owners and other 
parties the portion constructed and owned by a Transmission Owner may 
qualify as a Baseline Reliability Project, Market Efficiency Project, 
and/or Multi Value Project.
IV.
Merchant Transmission Project Data Requirements: A proposed merchant 
transmission developer assumes all financial risk and funding requirements for developing its 
transmission project(s) and constructing the proposed transmission facility(ies).  In order for a 
proposed merchant transmission developer’s facility to be interconnected to the Transmission

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System, it is first necessary for the impacted Transmission Owner and the Transmission Provider 
to analyze the reliability and operational impact of the proposed new merchant transmission 
facility(ies) on the Transmission System to determine if the new merchant transmission facilities 
can be reliably supported by the Transmission System, and if not, what Network Upgrades 
funded by the merchant transmission developer would be required to reliably support the 
proposed merchant transmission facility(ies).  In order to perform the required reliability and 
operational analyses, the merchant transmission developer must provide the following data to the 
Transmission Provider:  
(1)
Each transmission circuit and substation, including new facilities, associated with 
the merchant transmission proposal;
(2)
Nominal operating voltage level in kV and voltage characteristics (i.e., AC or DC) 
for each transmission circuit associated with the merchant transmission proposal;
(3)
Typical and maximum MW power flow schedules, in each direction, for all 
proposed DC transmission circuits associated with the merchant transmission proposal;
(4)
Normal and emergency summer and winter load ratings for each transmission 
circuit associated with the merchant transmission proposal;
(5)
Maximum allowable positive sequence impedance for each AC transmission circuit 
associated with the merchant transmission proposal, when applicable;
(6)
List of all transmission buses associated with the merchant transmission proposal, 
including nominal operating voltage level in kV, voltage characteristics, and terminating 
transmission branches and shunts;
(7)
Proposed substation one-line diagrams for all new substations associated with the

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merchant transmission proposal, including circuit breaker and bus configuration details;
(8)
Load ratings, winding connections, impedances, tap data, and any other relevant 
information for load carrying equipment and facilities associated with the merchant 
transmission proposal, as applicable;
(9)
Modeling files to model proposed facilities and relevant new contingencies in 
power flow, stability, short-circuit and other relevant study models; and
(10)
Any other data determined pertinent to the study by the Transmission Provider 
and/or interconnecting Transmission Owners for the specific merchant transmission facility 
proposal.
V.
Designation of Entities to Construct, Implement, Own, Operate, Maintain, Repair, 
Restore, and/or Finance MTEP Projects:  With the exception of Competitive Transmission 
Projects, for each project included in the recommended MTEP Appendix A and prior to approval 
by the Transmission Provider Board, the plan shall designate one or more Transmission Owners to 
construct, own, operate, maintain, repair, restore, and finance the recommended project, based on 
the planning analysis performed by the Transmission Provider and based on other input from 
participants, including, but not limited to, any indications of a willingness to bear cost 
responsibility for the project; and applicable provisions of the ISO Agreement.  Regarding 
Competitive Transmission Projects, upon the determination of the Selected Developer(s) for such 
projects, as set forth in Section VIII of this Attachment FF, the Transmission Provider shall update 
the approved MTEP Appendix A by identifying the Selected Developer(s) for each Competitive 
Transmission Project.  Should the facilities from such Competitive Transmission Projects not be

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approved by state regulatory authorities as Competitive Transmission Facilities, but instead as 
upgrades to existing transmission facilities, as defined in Section VIII.A.2 of this Attachment FF, 
the Transmission Provider shall update MTEP Appendix A by designating the appropriate 
Transmission Owner(s) to construct, own, operate, maintain, repair, restore, and finance such 
facilities in accordance with the ISO Agreement.
VI.
Implementation of the MTEP: 
A.
If the Transmission Provider and any Transmission Owner’s planning 
representatives, or other designated entity(ies), cannot reach agreement on any element of the 
MTEP, the dispute may be resolved through the dispute resolution procedures provided in the 
Tariff, or in any applicable joint operating agreement, or by the Commission or state regulatory 
authorities, where appropriate.  The MTEP shall have as one of its goals the satisfaction of all 
regulatory requirements as specified in Appendix B or Article IV, Section I, Paragraph C of the 
ISO Agreement.
B.
The Transmission Provider shall present the MTEP, along with a summary of 
relevant alternative projects that were not selected, to the Transmission Provider Board for 
approval on a biennial basis, or more frequently if needed.  The proposed MTEP shall include 
specific projects already approved as a result of the Transmission Provider entering into Service 
Agreements with Transmission Customers where such agreements provide for identification of 
needed transmission construction, timetable, cost, and Transmission Owner or other parties’ 
construction responsibilities.  
C.
Approval of the MTEP by the Transmission Provider Board certifies it as the

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Transmission Provider plan for meeting the transmission needs of all stakeholders subject to any 
required approvals by federal or state regulatory authorities.  The Transmission Provider shall 
provide a copy of the MTEP to all applicable federal and state regulatory authorities.  The 
affected Transmission Owner(s), Selected Developer(s), or other designated entity(ies), shall 
make a good faith effort to design, certify, and build the designated facilities to fulfill the 
approved MTEP.  However, in the event that an MTEP Appendix A project approved by the 
Transmission Provider Board is being challenged through the dispute resolution procedures 
under this Tariff or in court proceedings, the obligation of the Transmission Owners, or other 
designated entity(ies), to build that specific project (subject to required approvals) is waived until 
the approved project emerges from the dispute resolution procedures.  In the event that selection 
of the Selected Developer(s) to construct a project is being challenged through the Dispute 
Resolution Process under Attachment HH of the Tariff, the obligation of the Selected 
Developer(s) to construct the project pursuant to the Selected Developer Agreement is not 
waived.  The Transmission Provider Board shall allow the Transmission Owners, or other 
designated entity(ies), to optimize the final design of specific facilities and their in-service dates 
if necessary to accommodate changing conditions, provided that such changes comport with the 
approved MTEP and provided that any such changes are accepted by the Transmission Provider 
through the Variance Analysis process described in Section IX of this Attachment FF, as 
necessary.  Any disagreements concerning such matters shall be subject to the dispute resolution 
procedures of this Tariff. 
D.
The Transmission Provider shall assist the affected Owner(s), Selected 
Developer(s), or other designated entity(ies), in justifying the need for, and obtaining

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certification of, any facilities required by the approved MTEP by preparing and presenting 
testimony in any proceedings before state or federal courts, regulatory authorities, or other 
agencies as may be required.  The Transmission Provider shall publish annually, and distribute to 
all Members and all appropriate state regulatory authorities, a five-to-ten-year planning report of 
forecasted transmission requirements.  Annual reports and planning reports shall be available to 
the general public upon request.
VII.
Multi-Value Project Costs and Benefits Review and Reporting
A.
Frequency and Reporting of Multi-Value Project Review:  For two (2) three 
(3) year cycles, as provided below and in the Business Practices Manual for Transmission 
Planning, the Transmission Provider shall conduct a review of the cumulative costs and 
benefits associated with any MVP(s) first included in an approved MTEP in the 
preceding six (6) years, and shall disseminate the results of such reviews to its 
stakeholders.  The Transmission Provider shall use the review process and results to 
identify potential modifications to the MVP methodology and its implementation for 
projects to be approved at a future date.
1.
Triennial MVP Review:  Beginning with the third MTEP following approval of an 
MVP , and the third MTEP thereafter, the Transmission Provider shall conduct a 
MVP review, as provided in Section VII.B of this Attachment FF. 
2.
Calculation of Costs and Benefits:  The Triennial MVP Reviews MVP Reviews 
shall calculate costs and benefits on a forward-looking basis over both twenty 
(20)-year and forty (40)-year periods.  The costs calculation shall use updated

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project costs and in-service dates provided in the latest MTEP quarterly status 
report, and the benefits calculation shall use updated future scenarios from the 
latest MTEP planning cycle.  The results of the costs and benefits calculation shall 
be provided for each Cost Allocation Zone as defined in Attachment WW.
3.
Dissemination of the Results of the Triennial MVP Reviews:  Within a reasonable 
time after completion of each MVP review, the Transmission Provider shall 
disseminate the results of and supporting analysis for the MVP review through:  
(a) publication in the MTEP; (b) posting on the appropriate section of the 
Transmission Provider’s public website; and (c) presentation to the appropriate 
stakeholder committees.
B.
Scope of Triennial Multi-Value Project Review:  Each Triennial MVP Review 
shall at a minimum include the following: 
1.
Quantitative Benefits:  Analysis of the quantifiable economic benefits resulting 
from the addition of MVPs first included in an approved MTEP within the 
preceding six years, including, but not limited to:  
a.
Congestion and Fuel Savings:  Savings from increased access to lower 
cost Resources; 
b.
Decreased Operating Reserves:  Savings associated with lower Operating 
Reserve requirements; 
c.
Decreased System Planning Reserve Margin:  Savings associated with 
deferred generation investment due to a reduction in the system-wide 
Planning Reserve Margin; and

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d.
Decreased Transmission Line Losses:  Savings associated with deferred 
generation investment due to a reduction in the Capacity required to serve 
transmission losses during peak hours, to the extent that MVPs reduce 
such losses.
2.
Public Policy and Other Qualitative Benefits:  Analysis of the public policy and 
other qualitative benefits accruing from MVPs, such as newly interconnected 
wind units; and an increase in the percentage of the Transmission Provider’s 
Energy needs being supplied by wind and/or other renewable resources, and wind 
curtailments. 
3.
Historical Data:  Based on the historical data available to the Transmission 
Provider for the five (5) prior years, of information on certain additional market 
trend metrics including, but not limited to: 
a.
Congestion costs; 
b.
Energy prices; 
c.
Fuel costs; 
d.
Planning Reserve Margin requirements; 
e.
Number of newly interconnected Resources, by Resource type; and 
f.
The share of the Transmission Provider’s Energy supplied, by Resource 
type.  
VIII.
COMPETITIVE TRANSMISSION PROCESS
This section of Attachment FF of the Tariff describes the processes and requirements

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associated with identifying Competitive Transmission Facilities contained within a Market 
Efficiency Project or Multi-Value Project approved by the Transmission Provider Board in 
MTEP Appendix A; certifying entities as Qualified Transmission Developers, whether they are 
existing Transmission Owners or non-incumbent transmission developers; solicitation of 
Proposals from Qualified Transmission Developers to construct, implement, own, operate, 
maintain, repair, and restore the Competitive Transmission Facilities; evaluation of Proposals; 
and designation of a Selected Proposal and Selected Developer(s) pursuant to Section VIII of 
Attachment FF of the Tariff.
VIII.A.
APPLICABILITY 
Except as otherwise provided in Sections VIII.A.1, VIII.A.2 and VIII.A.3 of this 
Attachment FF, the Competitive Developer Selection Process shall be applicable to all 
transmission facilities and substation facilities located on the Transmission System and included 
in an Eligible Project.
VIII.A.1.
State or Local Rights of First Refusal:
The Transmission Provider shall comply with any Applicable Laws and 
Regulations granting a right of first refusal to a Transmission Owner.  The Transmission 
Owner will be assigned any transmission project within the scope, and in accordance with 
the terms, of any Applicable Laws and Regulations granting such a right of first refusal.  
These Applicable Laws and Regulations include, but are not limited to, those granting a 
right of first refusal to the incumbent Transmission Owner(s) or governing the use of 
existing developed and undeveloped right of way held by an incumbent utility. 
VIII.A.2.
Upgrades to Existing Transmission Facilities:

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A Transmission Owner shall have the right to develop, own, and operate any 
upgrade to a transmission facility owned by the Transmission Owner, in accordance with 
this Tariff and the ISO Agreement.
For an Eligible Project that contains both upgrades to existing transmission 
facilities as defined in Sections VIII.A.2.1 through VIII.A.2.2.1 and new transmission 
facilities that are not upgrades, the Transmission Provider shall apply the following rules 
to assign the facilities included in the Eligible Project to applicable incumbent 
Transmission Owners or Selected Developer.
a.
If 80% or more of the total cost of the transmission facilities included in 
the Eligible Project are upgrades as defined in Sections VIII.A.2.1 through 
VIII.A.2.2.1 of this Attachment FF, the Transmission Provider shall 
designate the applicable incumbent Transmission Owner(s) to develop, 
own, and operate all transmission facilities comprising the Eligible Project 
in accordance with the ISO Agreement.
b. If less than 80% of the total cost of the transmission facilities included in 
the Eligible Project are upgrades as defined in Sections VIII.A.2.1 through 
VIII.A.2.2.1 of this Attachment FF, the Transmission Provider shall divide 
the Eligible Project into two or more facilities or segments of facilities 
based upon the rules set forth in Sections VIII.A.2.1 through VIII.A.2.2.1 
of this Attachment FF.  For those facilities or segments of facilities that 
are upgrades as defined in Sections VIII.A.2.1 through VIII.A.2.2.1, the 
Transmission Provider shall designate the applicable incumbent

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Transmission Owner(s) to develop, own, and operate all transmission 
facilities comprising the Eligible Project in accordance with the ISO 
Agreement.  Those facilities or segments that are not exempt from the 
Competitive Developer Selections Process pursuant to Section VIII.A.1 
through VIII.A.3 shall be subject to the Competitive Developer Selection 
Process.
For purposes of this Section VIII.A.2, the Transmission Provider shall use 
the cost estimates prepared by the Transmission Provider for presentation to the 
Transmission Provider Board at the time such facilities are approved for inclusion 
in Appendix A to calculate the total cost of the transmission facilities contained 
within an Eligible Project.
VIII.A.2.1.
Upgrades to Existing Transmission Lines:  Upgrades to 
existing transmission line facilities include any expansion, replacement, or 
modification, for any purpose, made to existing transmission line facilities 
classified as transmission plant and owned by one or more Transmission Owners, 
for reasons including, but not limited to:
(a)
Increasing the load capability of the transmission line or an 
associated circuit;
(b)
Increasing the nominal operating voltage of the transmission line 
or an associated circuit;
(c)
Installing additional plant on an existing overhead or underground 
transmission line facility, such as, but not limited to:

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i.
plant associated with an additional circuit installed on spare 
structure positions;
ii.
additional structures to increase a sag limit or for other 
purposes;
iii.
a sectionalizing switch installed on an existing transmission 
line circuit regardless of whether or not it is installed on an existing 
structure; and
iv.
any other plant additions to existing transmission line 
facilities.
(d)
Installing additional plant on a replaced overhead or underground 
transmission line facility, where the new additional circuit will be co-
located with an existing transmission line, such as, but not limited to:
i.
plant associated with an additional circuit installed on a 
replaced structure; 
ii.
additional structures to increase a sag limit or for other 
purposes;
iii.
a sectionalizing switch installed on an existing transmission 
line circuit regardless of whether or not it is installed on an existing 
structure; and
iv.
any other plant additions to replacement transmission line 
facilities.
(e)
Any requirement or request to relocate transmission line facilities

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owned by an incumbent Transmission Owner where the purpose of the 
relocation is not part of the core scope of a Competitive Transmission 
Project, including, but not limited to, relocations driven by aesthetics, 
highway expansion projects, other infrastructure expansion projects, 
projects to improve the reliability or performance of the Transmission 
System, projects to reduce the cost to operate and maintain the 
Transmission System, projects to interconnect new generation and load, 
and projects to accommodate the relocation of an existing substation;
(f)
Any requirement or request to relocate existing transmission line 
facilities owned by an incumbent Transmission Owner to accommodate 
Competitive Transmission Line Facilities associated with a Competitive 
Transmission Project, where such construction of the Competitive 
Transmission Line Facilities requires or requests use of the incumbent 
Transmission Owner’s right-of-way and, as a result, also requires or 
requests transfer of the existing transmission facilities to alternative right-
of-way or an alternative position on the same right-of-way based on either 
mutual consent of the incumbent Transmission Owner and Selected 
Developer(s) and/or the outcome of a state regulatory proceeding or court 
action;  
(g)
Functionally equivalent capital replacement of any portion of an 
existing transmission line facility due to aging, deterioration, damage, 
poor performance, aesthetics, high operating and maintenance costs, or

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other similar reasons; 
(h)
Replacing one or more existing components of any existing 
transmission line facility, such as, but not limited to:
i.
replacing existing conductors with higher capacity 
conductors or better performing conductors;
ii.
replacing existing structures;
iii.
replacing insulators rated at a specific voltage with 
insulators rated at a higher voltage;
iv.
replacing aging or defective components associated with 
the existing transmission line;
(i)
Improving the performance or characteristics of the existing 
transmission line for any reason;
(j)
Converting an existing overhead transmission line to an 
underground transmission line on the same right-of-way and/or converting 
an existing underground transmission line to an overhead transmission on 
the same right-of-way;
(k)
Improving land and land rights booked under the Commission’s 
Uniform System of Accounts, Account Nos. 105, 350, and/or 380; or
(l)
Any other modifications to existing transmission facilities.
VIII.A.2.1.1. Installation of additional transmission circuits on 
existing transmission lines:
If a Competitive Transmission Project includes developing a new

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transmission circuit and in a subsequent state or local regulatory 
proceedings determine that all or a portion of the circuit must be installed 
on an existing transmission line that is part of the Transmission System 
(i.e., co-located with existing transmission circuits on the same structures), 
the following rules will be used to determine what constitutes an upgrade:   
(a)
If the structures associated with the existing transmission line are 
multi-circuit structures and have spare positions to accommodate 
installation of one or more additional transmission circuit(s), 
installation of the new transmission circuit(s) on these spare 
structure positions will be considered an upgrade.
(b)
If the structures associated with the existing transmission line can 
be expanded to accommodate installation of one or more additional 
transmission circuit(s), expansion of the structure and installation 
of the new transmission circuit(s) will be considered an upgrade.
(c)
If the structures associated with the existing transmission line are 
not multi-circuit structures and cannot be expanded to accept 
additional circuits, do not have sufficient spare structure positions 
available to accommodate the new transmission circuit(s), or have 
spare structure positions that are reserved for future use by the 
incumbent Transmission Owner and not available for the new 
transmission circuit(s) in question, it will be necessary to rebuild 
the existing transmission line to accommodate one or more

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additional transmission circuits.  Under this scenario, all of the 
necessary and applicable actions (e.g., acquisition of additional 
right-of-way; removal of the existing transmission line plant; 
construction of new transmission line structures; transfer or 
replacement of the existing transmission line conductors, 
insulators, and shield wire(s); and installation of new conductors, 
insulators, and shield wire(s) associated with the new transmission 
circuit(s) co-located with existing transmission circuit(s) on the 
same structures; etc.) will be considered an upgrade.  
VIII.A.2.2.
Upgrades to Existing Substations:  
Upgrades to existing substations include any expansions, 
replacements or modifications made, in part or in whole, to any existing 
substation or portion thereof that is owned by one or more Transmission 
Owners, and where some or all of the plant within the existing substation 
is classified as transmission plant.  These upgrades include, but are not 
limited to:
(a)
Replacing facilities and/or equipment within an existing substation 
footprint;
(b)
Installing additional plant within an existing substation footprint;  
(c)
Modifying facilities and/or equipment within an existing substation 
footprint;
(d)
Expanding an existing substation footprint within the existing

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substation site boundaries and installing additional plant within the 
expanded area; 
(e)
Acquiring additional land adjacent to the existing substation in 
conjunction with installation of additional plant within the 
boundaries of this additional land, including facilities to 
interconnect such plant to the existing substation plant; and
(f)
Developing an additional footprint near the existing substation to 
facilitate effective expansion of the existing substation as further 
described below in Section VIII.A.2.2.1.
VIII.A.2.2.1. Expansion of an existing substation by developing an 
additional footprint near the existing substation:
Construction of a new substation footprint near an existing substation to 
facilitate expansion of the existing substation is considered an upgrade and 
is necessary when the transmission project calls for expansion of the 
existing substation and there is not sufficient space for such expansion.  
Upgrades through development of a second substation footprint can be 
accomplished in one of two ways.  First, a second substation footprint can 
be developed near the existing substation footprint, and the two substation 
footprints will function electrically as a single substation and will be 
interconnected by bus extensions or connectors.  An example would be 
expanding an existing substation that is landlocked by public roadways by 
developing a second substation footprint on the other side of one of the

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roads and then installing an overhead single span connector which would 
function as a substation bus to interconnect the two substation footprints.  
Second, an existing substation could be retired for many reasons such as 
but not limited to: lack of room for future expansions, physical conditions 
such as soil subsidence, earthquake reinforcement requirements, to prevent 
flood damage, regulatory/public necessity/economic reasons, and other 
similar factors.  A new substation could be developed nearby on a 
different site and all transmission circuits into the existing substation could 
be rerouted to the new site, which is essentially the relocation of an 
existing substation.  These scenarios represent upgrades to an existing 
substation when the intent of the transmission project produced by the 
transmission planning process is to expand the existing substation rather 
than develop a new substation or to relocate an existing substation for 
reasons not related to implementation of a regionally cost shared 
transmission project.   
VIII.A.3. Immediate Need Reliability Projects
Immediate Need Reliability Projects are projects that: (a) are identified in a Baseline 
Reliability Study needed to address a reliability need and needed within thirty-six (36) 
months from first Calendar Day of the month in which the Transmission Provider Board 
approves the project for inclusion in Appendix A of an MTEP; and (b) meet the criteria 
for designation as a Baseline Reliability Project pursuant to Section II.A.1 of this 
Attachment FF, notwithstanding the fact that such project also meets the criteria set forth

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in Section II.B of this Attachment FF for classification as a Market Efficiency Project. 
The Transmission Provider shall designate the applicable Transmission Owner to 
develop, own, and operate all transmission facilities comprising such Immediate Need 
Reliability Project in accordance with the ISO Agreement.
VIII.A.3.1 Procedure for Review of Immediate Need Reliability Projects:
(a) 
Within thirty (30) Calendars Days after the Transmission Provider Board 
approves the respective MTEP, the Transmission Provider shall post a report on its 
website that separately identifies each Immediate Need Reliability Project that the 
Transmission Provider has determined to assign to the applicable Transmission Owner. 
The posted report shall include:
i. An identification of the transmission facilities contained within the Immediate
Need Reliability Project;
ii. The need by date of each Immediate Need Reliability Project;
iii. A brief explanation of the reliability need(s), that each Immediate Need
Reliability Project is required to address, including the reason(s) for the need
by date, in sufficient detail to allow stakeholders to understand the need and why
it is time sensitive;
iv. The date(s) and manner in which the reliability need was first identified
during the planning process along with an explanation of why the need was
not identified earlier;
v. An explanation of other transmission or, consistent with the provisions of
Section I.D.1.b, any non-transmission alternatives the Transmission Provider

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considered but concluded would not sufficiently address the immediate
reliability need.
(b) 
If the Transmission Provider identifies any Immediate Need Reliability Projects
pursuant to Section VIII.A.3.1(a), the Transmission Provider shall provide
stakeholders with thirty (30) Calendar Days to submit comments in response to
the report required by Section VIII.A.3.1(a) starting with the date that such report
is posted on the Transmission Provider’s website. Within sixty (60) Calendar
Days after posting the report required by Section VIII.A.3.1(a), the Transmission
Provider shall post the comments received together with any responses by the
Transmission Provider.
(c) 
The Transmission Provider shall post and update at least annually a list of prior 
years’ designations of Market Efficiency Projects that met the criteria in Section
VIII.A.3, for designation as an Immediate Need Reliability Project which list shall
contain both the need-by date and the date that the Transmission Owner placed the
facility in service.
VIII.A.3.2 Immediate Need Reliability Project Dispute Resolution.
Any disputes regarding determinations to classify or not classify a transmission project as
an Immediate Need Reliability Project and/or assign transmission facilities associated
with such Immediate Need Reliability Project to the Transmission Owner will be referred
to the Dispute Resolution Process under Attachment HH of this Tariff. In the event that
such classification and/or assignment is being challenged through the Dispute Resolution
Process under Attachment HH of the Tariff, the obligation of the designated

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Transmission Owner to construct such facilities is not waived.
VIII.B.
COMPETITIVE DEVELOPER QUALIFICATION PROCESS
This section of Attachment FF of the Tariff describes the processes and requirements 
associated with certifying entities as Qualified Transmission Developers, whether they are 
existing Members or non-incumbent transmission developers.
VIII.B.1.
Qualified Transmission Developers:
Only Qualified Transmission Developers may submit Proposals in response to a 
Request for Proposals posted by the Transmission Provider for a Competitive 
Transmission Project.  The Transmission Provider will maintain a list of Qualified 
Transmission Developers on its website that will be updated within thirty (30) Calendar 
Days of the conclusion of the Competitive Developer Qualification Process.
VIII.B.2.
Prequalification Process:
The Transmission Provider will open a prequalification window each quarter of 
the calendar year for entities that are not currently listed as Qualified Transmission 
Developers, including existing Members, Non-incumbent Developers, and Non-owner 
Members, by posting on its website a Transmission Developer Application template and 
invitation to submit a Transmission Developer Application.  To become a Qualified 
Transmission Developer, each Transmission Developer Applicant must submit a 
Transmission Developer Application using the template(s) posted with the invitation and 
further described in the applicable Business Practices Manuals, by the deadline specified 
in the invitation, but no less than thirty (30) Calendar Days from the date the invitation

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was posted.  The Transmission Developer Applicant shall submit its completed 
Transmission Developer Application by the day specified as the deadline in accordance 
with the requirements in the applicable Business Practices Manual.  The Transmission 
Developer Applicant shall also submit a non-refundable transmission developer 
application fee, as further described in the applicable Business Practices Manuals, in the 
amount of $20,000.00 by 5:00 PM EPT on the day specified as the Transmission 
Developer Application deadline to cover the cost of processing, reviewing, and 
determining whether the Transmission Developer Applicant does or does not satisfy all 
the qualification requirements  required by Sections VIII.B.4(a) – (g) and VIII.B.4.1 – 
VIII.B4.4 of this Attachment FF to be certified as a Qualified Transmission Developer.  
A Transmission Developer Applicant may rely on the resources, capabilities, or 
competencies of an Affiliate to satisfy the qualification requirements contained in 
Sections VIII.B.4.1 – VIII.B.4.4 provided that the Transmission Developer Applicant: (a) 
clearly identifies in the Transmission Developer Application which prequalification 
requirements the Transmission Developer Applicant will rely on its Affiliate to satisfy; 
(b) clearly identifies the resources, capabilities, and/or competencies of the Affiliate the 
Transmission Developer Applicant intends to rely on to satisfy each prequalification 
requirement; and (c) includes with its Transmission Developer Application submission a 
Statement of Support executed by the Affiliate on which the Transmission Developer 
Applicant will rely for such support.   
VIII.B.2.1.
Completed Transmission Developer Applications:
To the extent the Transmission Provider finds the Transmission

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Developer Application deficient of information or data required by the 
Transmission Developer Application template(s), the Transmission 
Provider will notify the Transmission Developer Applicant of the 
deficiencies electronically within thirty (30) Calendar Days of the 
Transmission Provider’s receipt of the respective Transmission 
Developer Application.  The Transmission Developer Applicant shall 
have thirty (30) Calendar Days from the date the Transmission Provider’s 
deficiency notification was sent to submit the additional data required to 
the Transmission Provider.  No additional Transmission Developer 
Application cure period will be allowed for the purposes of gaining 
Qualified Transmission Developer status. 
VIII.B.2.2.
Transmission Developer Application Review:
The Transmission Provider will review each Transmission 
Developer Application that has been cured of any identified deficiencies 
and will notify each Transmission Developer Applicant of the 
Transmission Provider’s decision to certify or not certify the 
Transmission Developer Applicant as a Qualified Transmission 
Developer within one-hundred eighty (180) Calendar Days of the 
Transmission Provider’s receipt of the respective Transmission 
Developer Application.  
The Transmission Provider will certify those Transmission 
Developer Applicants that meet the qualification requirements specified

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in Sections VIII.B.2 and VIII.B.4 of this Attachment FF and the 
applicable Business Practices Manuals.  If the Transmission Provider 
does not certify a Transmission Developer Applicant, it will provide the 
Transmission Developer Applicant with a written explanation detailing 
its determination within thirty (30) Calendar Days after notification.  
The Competitive Transmission Executive Committee shall have 
the exclusive and final authority to approve or reject Transmission 
Developer Applications and certify Transmission Developer Applicants 
as Qualified Transmission Developers.
VIII.B.3.
Biennial Recertification Process:
Each Qualified Transmission Developer that intends to remain qualified must 
recertify its Qualified Transmission Developer status every second calendar year as 
determined by the recertification cycle posted by the Transmission Provider.  The 
Transmission Provider will assign each Qualified Transmission Developer to a 
recertification cycle after the Qualified Transmission Developer’s initial application is 
approved.  Before July 15 of the year immediately preceding the year in which a QTD is 
due for recertification, the Transmission Provider will send a notification to each 
Qualified Transmission Developer that is required to recertify its status in accordance 
with Section VIII.B.3.1 of this Attachment FF.
VIII.B.3.1.
Recertification Submission Requirements:
 Each Qualified Transmission Developer that is sent a recertification 
notification shall submit, within thirty (30) Calendar Days after the recertification

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notification is sent, a recertification statement in a form to be provided by the 
Transmission Provider, executed by an authorized representative of the Qualified 
Transmission Developer.  There will be no fee for the first recertification, but for 
each recertification thereafter, the Qualified Transmission Developer shall also 
submit a non-refundable transmission developer recertification fee in the amount 
of $2,000 as further described in the applicable Business Practices Manuals, by 
5:00 PM EPT on the day specified as the Qualified Transmission Developer 
recertification deadline.  The recertification statement shall confirm, to the best of 
the Qualified Transmission Developer’s knowledge, that the Qualified 
Transmission Developer continues to meet the requirements for initial 
qualification as set forth in Sections VIII.B.4, VIII.B.4.1, VIII.B.4.2, VIII.B.4.3, 
and VIII.B.4.4 of this Attachment FF.  The recertification statement shall also 
contain a completed checklist indicating whether the Qualified Transmission 
Developer, or any parent or affiliate whose resources are relied upon for 
recertification, have experienced certain changes since the date the Qualified 
Transmission Developer last submitted a Transmission Developer Application or 
recertification statement.  The specific changes shall be identified in the 
recertification notice and may include, but are not limited to: (1) merger, 
reorganization, or a change in the identity of any parent or affiliate providing 
support; (2) changes to the Qualified Transmission Developer’s legal name, state 
of domicile, or MISO membership status; (3) bankruptcies, liquidations, 
receiverships or general assignments; (4) any new legal or regulatory violations

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that would be required to be reported in a Transmission Developer Application 
pursuant to Section VIII.B.4.3 of this Attachment FF; and (5) any specific 
changes that the Transmission Provider identifies as necessary to evaluate a 
Qualified Transmission Developer’s continued qualifications.
A properly completed and executed recertification statement stating that 
the Qualified Transmission Developer and, if applicable, its supporting parent or 
affiliate, has not experienced any of the changes listed by the Transmission 
Provider in the recertification statement form shall be deemed a completed 
recertification application.
If a Qualified Transmission Developer identifies in its recertification 
statement that any of the changes specified in the recertification statement form 
accompanying the recertification notice have occurred, initial disclosure shall not 
create any presumption of disqualification. Upon receipt of an executed  
recertification statement indicating that a listed change has occurred, the 
Transmission Provider shall provide the Qualified Transmission Developer with 
further instructions for submitting information and explanations to enable the 
Transmission Provider to evaluate the effect of the identified changes on the 
Qualified Transmission Developer’s continued qualifications. Such further 
instructions shall be tailored to the disclosed change and shall be due no later than 
thirty (30) Calendar Days after the date that the additional information request 
was sent to the Qualified Transmission Developer. 
Should a Qualified Transmission Developer fail to submit a properly

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completed recertification statement or any information in response to the 
Transmission Provider’s request for further information within the applicable 
submission periods specified in this Section VIII.B.3.1 of this Attachment FF, the 
Transmission Provider shall notify the Qualified Transmission Developer 
electronically within five (5) Business Days of the deadline specified in
the renewal notification or request for further information of any deficiencies that
the Transmission Provider has identified.  The Qualified Transmission
Developer will have five (5) Business Days from the date of notification of
deficiency to cure the identified deficiencies by submitting the required
information.  Should a Qualified Transmission Developer fail to cure the 
identified deficiency during this five (5) Business Day period, the Transmission 
Provider will deem that the Qualified Transmission Developer has requested to 
voluntarily terminate its certification as a Qualified Transmission Developer in 
accordance with Section VIII.B.5 of this Attachment FF.   
VIII.B.3.2.
Review of Recertification Submissions.
The Transmission Provider shall review each Qualified 
Transmission Developer’s recertification submission, any supporting 
information and explanations, and the annual financial information 
submitted pursuant to Section VIII.B.8 of this Attachment FF. The 
Transmission Provider shall determine whether the information included 
in the submission warrants recertification or termination of a Qualified 
Transmission Developer’s status under the standards established in

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Section VIII.B.1 through VIII.B.4.4 of this Attachment FF.  The 
Transmission Provider will notify each Qualified Transmission Developer 
as to whether or not such entity has been recertified, within one-hundred 
eighty (180) Calendar Days of the date the Transmission Provider sent the 
recertification notification.  
In the event that the Competitive Transmission Executive 
Committee terminates or determines not to recertify a Qualified 
Transmission Developer, the Transmission Provider shall provide that 
entity with a written explanation detailing its determination within thirty 
(30) Calendar Days of such notification.  If the Transmission Provider 
either terminates or does not recertify a Qualified Transmission 
Developer, such entity may seek re-qualification during any subsequent 
qualification process as described in Section VIII.B.2 of this Attachment 
FF.  The Competitive Transmission Executive Committee shall have the 
exclusive and final authority to recertify or terminate a Qualified 
Transmission Developer’s Qualified Transmission Developer status.  
VIII.B.4.
Requirements for Qualified Transmission Developer Status:  
To be certified as a Qualified Transmission Developer, the requirements set forth 
in Sections VIII.B.4, VIII.B.4.1, VIII.B.4.2, VIII.B.4.3, and VIII.B.4.4 of this Attachment 
FF must be satisfied. A Transmission Developer Applicant may elect to satisfy one or 
more of these requirements by referencing and/or utilizing the qualifications, capabilities, 
and/or competencies of one or more Affiliates instead of, or in addition to, those of the

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Transmission Developer Applicant. Should a Transmission Developer Applicant elect to 
reference and/or utilize the qualifications, capabilities, and/or competencies of one or 
more Affiliates, the Transmission Developer Applicant must: (a) clearly identify in the 
Transmission Developer Application each Tariff requirement that the Transmission 
Developer Applicant intends to rely on an Affiliate to satisfy; and (b) include in the 
Transmission Developer Application an executed Statement of Support for each such 
Affiliate that acknowledges that the Transmission Developer Applicant is relying on the 
specified qualifications, capabilities, and/or competencies of the Affiliate. A 
Transmission Developer Applicant may elect to satisfy one or more of the requirements 
of VIII.B.4.3(a) and VIII.B.4.3(b) of this Attachment FF by submitting documentation 
pertaining to an Affiliate provided that the Transmission Developer Applicant also 
submits such documentation pertaining to itself, included an executed Statement of 
Support in the Transmission Developer Application for each such Affiliate, and has 
clearly identified which information and documentation pertains to the Affiliate and 
which information and documentation pertains to itself. 
The general requirements applicable to Qualified Transmission Developers 
include the following: 
(a)
The Transmission Developer Applicant shall be a Transmission Owner or 
a Non-owner Member in good standing at the time the Transmission 
Developer Application is acted on by the Transmission Provider and shall 
maintain such status.

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(b)
The Transmission Developer Applicant shall either: (i) submit a written 
commitment, signed by an authorized representative of the Transmission 
Developer Applicant, to execute the ISO Agreement should it be 
designated as a Selected Developer and to list any Competitive 
Transmission Facilities for which it is designated a Selected Developer, 
pursuant to the Selected Proposal, in Appendix H of the ISO Agreement 
(i.e. the list of transmission facilities transferred to MISO’s functional 
control for the purposes of planning and operation); or (ii) state that it is 
already a signatory to the ISO Agreement and submit a written 
commitment, signed by an authorized representative of the Transmission 
Developer Applicant, that it will list any Competitive Transmission 
Facilities for which it is designated as a Selected Developer for, pursuant 
to the Selected Proposal, in Appendix H of the ISO Agreement.  The 
execution of the ISO Agreement must take place after the Competitive 
Transmission Facilities have been constructed but prior to their 
energization and the addition of the Competitive Transmission Facilities to 
Appendix H of the ISO Agreement must take place after the Competitive 
Transmission Facilities have been energized; 
(c)
The Transmission Developer Applicant shall submit a written 
commitment, signed by an authorized representative of the Transmission 
Developer Applicant, to comply with all Applicable Laws and 
Regulations, codes, and standards governing the engineering, design,

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construction, operation, and maintenance of transmission facilities 
including, but not limited to, federal laws; applicable state and local laws; 
applicable state and local building codes; federal regulatory requirements; 
applicable state and local regulatory requirements; applicable state and 
local licensing authorities; the National Electric Safety Code; the National 
Electric Code; Applicable Reliability Standards; and Good Utility Practice 
should the Transmission Developer Applicant be designated as a Selected 
Developer for one or more Competitive Transmission Facilities;  
(d)
The Transmission Developer Applicant shall either: (i) submit a written 
commitment, signed by an authorized representative of the  Transmission 
Developer Applicant, to register with NERC in accordance with NERC’s 
registration guidelines as the transmission owner (TO), transmission 
operator (TOP), and transmission planner (TP), as those terms are defined 
by NERC, for all Competitive Transmission Facilities that the 
Transmission Developer Applicant, if designated as the Selected 
Developer, will own; or (ii) demonstrate that the Transmission Developer 
Applicant is already registered with NERC, in accordance with NERC’s 
registration guidelines, as the transmission owner (TO), transmission 
operator (TOP), and transmission planner (TP), as those terms are defined 
by NERC; 
(e)
The Transmission Developer Applicant shall submit a written 
commitment, signed by an authorized representative of the Transmission

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Developer Applicant, that if designated as the Selected Developer, the 
Transmission Developer Applicant shall either: (i) contract with the 
interconnecting Local Balancing Authority(s) to include the Competitive 
Transmission Facilities within the boundaries of the interconnecting LBA 
and demonstrate to the satisfaction of the Transmission Provider and per 
agreement by the interconnecting LBA that applicable LBA-related tasks 
associated with the proposed Competitive Transmission Facilities that may 
be delegated to an LBA by the Balancing Authority Agreement will be 
carried out either by the LBA or the Transmission Developer Applicant if 
designated as a Selected Developer; or ii) execute the Balancing Authority 
Agreement, register with NERC as a Balancing Authority (BA), and be 
designated as the Local Balancing Authority for any proposed 
Competitive Transmission Facilities, unless the Transmission Developer 
Applicant is already registered with NERC as a BA and designated as an 
LBA for one or more of the existing transmission facilities that may 
interconnect directly with any Competitive Transmission Facilities 
associated with the Competitive Transmission Project(s) that the 
Transmission Developer may be awarded;
(f)
The Transmission Developer Applicant shall make a written commitment, 
signed by an authorized representative of the Transmission Developer 
Applicant, that, if designated as a Selected Developer, it shall comply with 
the FERC Form 715 Part 4 TRPC, Transmission Planning Criteria and

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Guidelines on file with FERC and established by each incumbent 
Transmission Owner whose existing transmission facilities will 
interconnect directly with the Competitive Transmission Facilities; and
(g)
The Transmission Developer Applicant must make a written commitment, 
signed by an authorized representative of the  Transmission Developer 
Applicant, that, if it is designated as a Selected Developer, it shall comply 
with current requirements and standards regarding the interconnection of 
transmission facilities published by each  Transmission Owner or non-
Member to which Competitive Transmission Facilities will interconnect 
including, but not limited to, those standards and requirements required for 
compliance with the applicable NERC Facilities Design, Connections, and 
Maintenance (“FAC”) Reliability Standards.  
VIII.B.4.1.
Project Implementation Requirements:  
Each Transmission Developer Applicant shall submit documentation to 
demonstrate to the Transmission Provider that the Transmission Developer 
Applicant has or can obtain sufficient capabilities and competencies to satisfy the 
following project implementation requirements for Competitive Transmission 
Projects:  
(a)
Project management; 
(b)
Routing and siting studies including public outreach;  
(c)
Preliminary and detailed engineering and surveying;
(d)
Material and equipment procurement;

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(e)
Construction; and
(f)
Commissioning.
There are two general methods that a Transmission Developer Applicant 
may use to demonstrate it will have sufficient capabilities and competencies to 
perform project implementation tasks if chosen as the Selected Developer for a 
Competitive Transmission Project.  First, the Transmission Developer Applicant 
may provide evidence that it currently develops transmission projects by listing 
data, pursuant to templates developed by the Transmission Provider, regarding the 
transmission facilities it owns and the infrastructure and resources it has in place 
to perform the project implementation activities to develop such transmission 
facilities, where infrastructure and resources may include, but not necessarily be 
limited to, employees, contractors, tools, equipment, buildings, vehicles, policies, 
processes, and procedures.  Second, a Transmission Developer Applicant can 
provide a detailed business implementation plan describing how it would acquire 
the capabilities and competencies to perform the specific project implementation 
tasks listed above, including plans for: (i) retaining personnel or contractors; (ii) 
utilizing infrastructure and resources owned and operated by an affiliate company; 
(iii) qualifying personnel and contractors utilized; (iv) acquiring required tools, 
equipment, and vehicles; (v) development of project management, engineering, 
material, and construction standards and practices to be followed for specific 
types of facilities; (vi) route and site studies (including public outreach); and (vii) 
procuring adequate capital to develop transmission projects.

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In the event that a Transmission Developer intends to demonstrate its 
project implementation qualifications by obtaining the requisite capabilities and 
competencies by contracting with third parties, the Transmission Developer 
Applicant shall submit either as part of its business implementation plan or in 
separate documentation an explanation of the capabilities and competencies that 
the Transmission Developer Applicant possesses at the time of application and 
those capabilities and competencies for which the Transmission Developer 
Applicant intends to contract in order to demonstrate its ability to satisfy the 
foregoing project implementation requirements for Competitive Transmission 
Projects.  For each capability or competency that the Transmission Developer 
Applicant does not possess but intends to procure through contracting with third 
parties, the Transmission Developer Applicant shall provide a detailed contracting 
plan that contains a detailed description of the steps the Transmission Developer 
Applicant intends to take to procure needed capabilities or competencies if it is 
chosen as the Selected Developer for a Competitive Transmission Project.
The Transmission Developer Applicant shall not be required to have 
executed contracts with third parties to obtain all required capabilities or 
competencies at the time of application in order to prequalify as a Transmission 
Developer.  However, the Transmission Developer Applicant bears the burden of 
identifying the capabilities or competencies it possesses and those for which it 
must contract with third parties and that the Transmission Developer Applicant 
has a realistic contracting plan for obtaining those capabilities.

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The Transmission Developer Applicant shall include a written certification 
signed by an authorized representative of the Transmission Developer Applicant 
stating that the information in the submission is true and accurate.
VIII.B.4.2 
Operations, maintenance, repair, and replacement requirements:
 
Each Transmission Developer Applicant shall submit documentation that 
demonstrates to the Transmission Provider that the  Transmission Developer 
Applicant possesses or can obtain sufficient capabilities and competencies to 
adequately perform the following operations, maintenance, testing, inspection, 
repair, and replacement tasks for any Competitive Transmission Facilities 
associated with a Competitive Transmission Project once such facilities are in 
service and part of the Transmission System: 
(a)
Forced outage response for transmission line circuits; 
(b)
Forced outage response for substations;  
(c)
Switching for transmission line circuits; 
(d)
Switching for substations; 
(e)
Transmission line emergency repair;
(f)
Substation emergency repair and testing; 
(g)
Transmission line preventative and/or predictive  maintenance, 
including vegetation management;  
(h)
Substation preventative and/or predictive maintenance including 
equipment testing;

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(i)
Maintenance and management of spare parts, spare structures, 
and/or spare equipment inventories for substations and/or 
transmission lines, as applicable, including description of any 
agreements to share spare equipment, spare parts, and/or spare 
structures with other transmission entities;
(j)
Real-time operations monitoring and control capabilities; 
(k)
Major facility replacements or rebuilds required as a result of 
catastrophic destruction or natural aging through normal wear and 
tear, including financial strategy to facilitate timely replacements 
and/or rebuilds; and
(l)
Once a Transmission Developer, the Transmission Provider may 
require additional demonstration of qualifications to operate, 
maintain, restore, test, inspect, and replace specific Competitive 
Transmission Facilities associated with specific Competitive 
Transmission Projects for a specific Request for Proposals.
There are two general methods that a Transmission Developer Applicant 
may use to demonstrate it will have sufficient capabilities and competencies to 
perform operations and maintenance services if chosen as the Selected Developer 
for a Competitive Transmission Project.  First, Transmission Developer Applicant 
may provide evidence that it currently owns and/or operates and maintains 
electric transmission facilities by listing data, pursuant to templates developed by 
the Transmission Provider, regarding the transmission facilities it owns and/or

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operates and maintains and the infrastructure and resources it has in place to 
perform the operations and maintenance activities for such transmission facilities, 
where infrastructure and resources may include, but not necessarily be limited to, 
employees, contractors, tools, equipment, buildings, spare materials and 
equipment, vehicles, policies, processes, and procedures.  Second, a Transmission 
Developer Applicant can provide a detailed business implementation plan 
describing how it would acquire the capabilities and competencies to perform the 
specific operations and maintenance tasks listed above, including plans for: (i) 
retaining personnel or contractors; (ii) utilizing infrastructure and resources 
owned and operated by an affiliate company; (iii) qualifying personnel and 
contractors utilized; (iv) acquiring required tools, equipment, and vehicles; (v) 
development of maintenance standards and practices to be followed for specific 
types of facilities; (vi) developing standards governing where personnel, 
equipment, and spare parts/equipment will be maintained with respect to potential 
future facilities (e.g., maximum distance between facility and local office, etc.); 
(vii) emergency response times; and (viii) maintaining adequate capital 
procurement capabilities to rebuild facilities following major catastrophic outages 
(including property insurance and risk mitigation strategies).  
In the event that a Transmission Developer Applicant intends to 
demonstrate its operations and maintenance, repair and replacement qualifications 
by obtaining the requisite capabilities and competencies by contracting with third 
parties, the Transmission Developer Applicant shall submit, either as part of its

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business implementation plan or in separate documentation, an explanation of the 
capabilities and competencies that the Transmission Developer Applicant 
possesses at the time of application and those capabilities and competencies for 
which the Transmission Developer Applicant intends to contract in order to 
demonstrate its ability to implement the foregoing project operation, maintenance, 
repair, and replacement requirements for Competitive Transmission Projects.  For 
each capability or competency that the Transmission Developer Applicant does 
not possess but intends to procure through contracting with third parties, the 
Transmission Developer Applicant shall provide a detailed contracting plan that 
contains a detailed description of the steps the Transmission Developer Applicant 
intends to take to procure needed capabilities or competencies if it is chosen as the 
Selected Developer for a Competitive Transmission Project.
The Transmission Developer Applicant shall not be required to have 
executed contracts with third parties to obtain all required capabilities or 
competencies at the time of application in order to prequalify as a Qualified 
Transmission Developer.  However, the Transmission Developer Applicant bears 
the burden of identifying the capabilities or competencies it possesses and those 
for which it must contract with third parties and that the Transmission Developer 
Applicant has a realistic contracting plan for obtaining those capabilities. 
The Transmission Developer Applicant shall include a written certification 
signed by an authorized representative of the Transmission Developer Applicant 
stating that the information in the submission is true and accurate.

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FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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VIII.B.4.3.
Legal Requirements:  
Each Transmission Developer Applicant shall submit the following 
information and demonstrate to the Transmission Provider that the information 
submitted represents an acceptable level of risk to rely on the Transmission 
Developer Applicant, if designated a Selected Developer, to successfully 
implement a Competitive Transmission Project and own and operate the 
associated transmission facilities once in service.  The information submitted 
must include written certification signed by an authorized representative of the 
Transmission Developer Applicant stating that the submitted information is 
accurate:  
(a)
A summary of legal and/or regulatory violations during the past 
five (5) years or, if the Transmission Developer Applicant has been 
in business for less than five years, the number of years for which 
the Transmission Developer Applicant has been in business, by the 
Transmission Developer Applicant found by federal or state courts, 
federal regulatory agencies, state public utility commissions, other 
regulatory agencies, or attorneys general. This includes, but is not 
limited to, the Federal Energy Regulatory Commission, North 
American Electric Reliability Corporation Reliability Standards, 
Securities Exchange Commission (“SEC”) regulations, U.S. 
Commodity Futures Trading Commission (“CFTC”) regulations, 
and other applicable requirements.  Notwithstanding the foregoing,

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FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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Effective On: October 18, 2026
the Transmission Developer Applicant does not need to provide 
any information regarding violations of the Applicable Reliability 
Standards that were resolved as a compliance exception as defined 
by the NERC rules of procedure.
(b)
A summary of any and all instances in which the Transmission 
Developer Applicant is currently under investigation or is a 
defendant in a proceeding involving an attorney general or any 
state or federal regulatory agency, for violation of any laws, 
including regulatory requirements, during the past five years or, if 
the Transmission Developer Applicant has been in business for 
less than five years, the number of years for which the 
Transmission Developer Applicant has been in business. The 
Transmission Developer Applicant shall include an affidavit 
signed by an authorized officer of the Transmission Developer 
Applicant’s company stating that the information in the submission 
is true and accurate and that the Transmission Developer Applicant 
will comply with all applicable requirements in this Tariff, the 
Business Practices Manuals, or other applicable Transmission 
Provider documents or agreements.
VIII.B.4.4
Financial Requirements:

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FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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Effective On: October 18, 2026
Each Transmission Developer Applicant shall submit the following 
information and demonstrate to the Transmission Provider that the information 
submitted represents an acceptable level of risk to rely on the Transmission 
Developer Applicant to successfully implement a Competitive Transmission 
Project and own and operate the associated transmission facilities once in service.  
The information submitted must include written certification signed by an 
authorized representative of the Transmission Developer Applicant stating that 
the submitted information is accurate:  
(a)
A proposed financial plan demonstrating adequate capital resources (e.g., 
current assets, revolving lines, commercial paper, letter of credit, stock or 
bond issuance or other sources of liquidity) are available to the  
Transmission Developer Applicant to allow for Competitive Transmission 
Projects to be implemented on schedule and associated Competitive 
Transmission Facilities to be operated and maintained appropriately after 
the facilities are in service.
(b)
The credit rating(s) for the Transmission Developer Applicant from 
Moody’s Investor Services, Inc., Standard and Poor’s Rating Group and/or 
other Nationally Recognized Statistical Rating Organization (“NRSRO”) 
as recognized by the Securities and Exchange Commission (“SEC”).  In 
the event the Transmission Developer Applicant is rated by more than one 
NRSRO, then the lowest rating will be the benchmark for consideration of 
demonstrating and maintaining an investment grade credit rating.  For

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FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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example, an investment grade rating is considered to be a rating of Baa3 or 
above from Moody’s Investor Services, Inc. or BBB- or above from 
Standard and Poor’s Rating Group (equivalent ratings will be used for 
other rating agencies).  The focus of the review will be on the entity’s 
unsecured, senior long-term debt ratings (not supported by third-party 
enhancements).  If unsecured, senior long-term debt ratings are not 
available, the Transmission Provider may consider Issuer Ratings. 
In the event the Transmission Developer Applicant does not have 
an investment grade rating, the Transmission Provider will consider the 
other information the Transmission Developer Applicant has submitted to 
evaluate its financial capability to construct the transmission facility in a 
timely manner, and to maintain and operate it reliably for the long term.  
(c)
General financial information, including two (2) years of audited financial 
statements with notes to the financials and a signed commitment by an 
authorized representative of the Transmission Developer Applicant that it 
is not aware of any material events or circumstances that would likely 
result in a material adverse weakness in financial strength throughout 
project implementation of future Competitive Transmission Projects that it 
might be awarded after it is certified as a Transmission Developer.   In the 
event the Transmission Developer Applicant does not have two (2) years 
of audited financial statements and has not submitted two (2) years of 
audited financial statements from an Affiliate providing an executed

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ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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Effective On: October 18, 2026
Statement of Support, the Transmission Developer Applicant must submit 
an audited balance sheet dated within the last ninety (90) days. It must also 
submit pro forma financials for the next fiscal year which include an 
income statement, balance sheet, and statement of cash flows.
(d)
A summary of any history of bankruptcy, dissolution, merger, or 
acquisition of the Transmission Developer Applicant, or any predecessors 
in interest for the current calendar year and the five (5) calendar years 
immediately preceding its submission of the Transmission Developer 
Application.  This information must also be submitted for any Affiliate 
providing a Statement of Support to satisfy any of the requirements in 
Section VIII.B.4.4 of this Attachment FF. 
VIII.B.5.
Voluntary Termination of Qualified Transmission Developer Status:
A Qualified Transmission Developer that desires to voluntarily terminate its’ 
status as a Qualified Transmission Developer, may do so at any time by notifying the 
Transmission Provider.  Upon such notification, the Transmission Provider will update 
the Qualified Transmission Developer list within thirty (30) Calendar Days of the 
notification.  Failure of a Qualified Transmission Developer to timely submit a 
recertification statement pursuant to Section VIII.B.3.1 of this Attachment FF of the 
Tariff shall be deemed a voluntary termination under this Section VIII.B.5 of this 
Attachment FF.  A terminated Qualified Transmission Developer may become a 
Qualified Transmission Developer again by following the process outlined in Section 
VIII.B.2 of this Attachment FF of the Tariff for Transmission Developer Applicants

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FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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seeking Qualified Transmission Developer status in a subsequent qualification process. 
VIII.B.6. Confidential Treatment of Competitive Developer Qualification 
Information:
All information submitted with Transmission Developer Applications and 
recertification submittals will be considered Confidential Information, except for the 
name of the organization to be posted on the Qualified Transmission Developer list, and 
will not be publicly posted or shared with any individual except for employees of the 
Transmission Provider and/or contractors of the Transmission Provider that have 
executed appropriate non-disclosure agreement(s). 
VIII.B.7.
Alternative Dispute Resolution:
Any Transmission Developer Applicant who is not approved as a Qualified 
Transmission Developer by the Transmission Provider may request alternative dispute 
resolution under Attachment HH of the Tariff within thirty (30) Calendar Days of 
receiving the Transmission Provider’s written explanation detailing its determination to 
deny the Transmission Developer Application.  Any entity that is not recertified as a 
Qualified Transmission Developer by MISO, or a Qualified Transmission Developer 
whose Qualified Transmission Developer status is terminated, may request alternative 
dispute resolution under Attachment HH of the Tariff within
thirty (30) Calendar Days 
of receiving the MISO’s written explanation detailing its determination to not recertify or 
to terminate the entity’s Qualified Transmission Developer status.
VIII.B.8. 
Ongoing Responsibilities of Qualified Transmission Developers: 
Each Qualified Transmission Developer has an ongoing duty to provide the

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ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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Effective On: October 18, 2026
Transmission Provider with notification as soon as reasonably practical should any of the 
changes specified in Section VIII.B.3.1 of this Attachment FF occur and a copy or link to 
their audited financial statements annually, within thirty (30) Calendar Days of such 
statements being prepared.  The Competitive Transmission Executive Committee shall 
have the exclusive and final authority to make determinations regarding the continued 
qualifications of Qualified Transmission Developers based upon the information received 
in accordance with this Section VIII.B.8.
VIII.C.
REQUEST FOR PROPOSALS
Should Appendix A of a Transmission Provider Board approved MTEP contain Eligible 
Projects, the Transmission Provider will review each such Eligible Project to determine whether 
or not it contains any Competitive Transmission Facilities.  The Transmission Provider will 
release a Request for Proposals (RFP) for each Competitive Transmission Project pursuant to 
Section VIII.C of this Attachment FF and the applicable Business Practices Manuals.  If 
Appendix A of a Transmission Provider Board approved MTEP contains only one (1) 
Competitive Transmission Project, the Transmission Provider will release an RFP within sixty 
(60) Calendar Days of the date the Transmission Provider Board approved the Competitive 
Transmission Facilities for inclusion in Appendix A of the MTEP.  If Appendix A of a 
Transmission Provider Board approved MTEP contains multiple Competitive Transmission 
Projects, the Transmission Provider shall have the option to stagger the release of each RFP 
associated with the multiple Competitive Transmission Projects.  
If the Transmission Provider elects to stagger the release of RFPs, the Transmission 
Provider shall take the following actions following the date that  the Transmission Provider

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ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
Board approved the Competitive Transmission Facilities for inclusion in Appendix A of the 
MTEP: (1) Within ten (10) Business Days publicly post on its website a statement indicating that 
the Transmission Provider will stagger the RFP release dates; (2) Within thirty (30) Calendar 
Days post a schedule listing the planned release dates for each RFP, with the first RFP being 
released within sixty (60) Calendar Days of the date the respective MTEP was approved by the 
Transmission Provider Board.  In determining the schedule of RFP releases when staggering is 
used, the Transmission Provider will consider the timing impacts of the Competitive Developer 
Selection Process with respect to the in-service dates of the Competitive Transmission Projects.  
In all events, the schedule of RFP releases developed by the Transmission Provider shall provide 
that all RFPs are released not later than three hundred and sixty five (365) Calendar Days after 
the date the Transmission Provider Board approved the Competitive Transmission Facilities for 
inclusion in Appendix A of the MTEP.  If the Transmission Provider elects not to stagger the 
release of RFPs, the Transmission Provider shall release each RFP within sixty (60) Calendar 
Days of the date the respective MTEP was approved by the Transmission Provider Board.
VIII.C.1.
Minimum Contents of a RFP:
Each RFP shall include, at a minimum, a listing of each Competitive Transmission 
Facility contained within the Competitive Transmission Project, the Proposal Submission 
Deadline, the applicable items specified in Sections VIII.C.1.1 and VIII.C.1.2 of this Attachment 
FF to the Tariff, any applicable items specified in the Transmission Provider’s Business Practices 
Manuals, and a list of the current transmission facility interconnection standards and 
requirements, established by the Transmission Owner(s) and established by any transmission 
owner(s) that are not a Member who have chosen to provide interconnection standards and

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ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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Effective On: October 18, 2026
requirements to the Transmission Provider, to which the Competitive Transmission Project will 
interconnect.  The Transmission Provider reserves the right to specify any additional information 
in a RFP including, but not limited to, any additional information for specific Competitive 
Transmission Line Facilities and/or Competitive Substation Facilities. The Transmission 
Provider shall include in each RFP a list of any aspects, or elements of the Competitive 
Transmission Project that the Transmission Provider anticipates at the time of posting to be 
particularly important for the success of the Competitive Transmission Project. This information 
shall be provided for informational purposes only and shall not alter the criteria and/or 
weightings applicable to evaluation of the Proposals pursuant to Sections VIII.E through 
VIII.E.3 of this Attachment FF.
If and to the extent a RFP contains any Critical Energy Infrastructure Information (CEII), 
the Transmission Provider will redact such CEII for public posting and create a non-public RFP 
containing the CEII which will be available to entities and individuals that have executed the 
appropriate CEII and non-disclosure agreements required by the Transmission Provider.  
Information on how to request the non-public RFP will be provided in the publicly posted RFP.  
Pursuant to Section VIII.A.1 of this Attachment FF, only Competitive Transmission Facilities 
eligible under state law will be included in the Competitive Transmission Project where (i) all 
other Competitive Transmission Facilities and (ii) upgrades as described in Section VIII.A.2 of 
this Attachment FF will be assigned to the applicable incumbent Transmission Owner in 
accordance with the ISO Agreement. 
VIII.C.1.1
RFP Requirements for Competitive Transmission Line Facilities:
Each RFP that includes one or more Competitive Transmission Line

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ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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Effective On: October 18, 2026
Facilities will specify, at a minimum, the following items for each Competitive 
Transmission Line Facility:
 (a)
Expected in-service date;
(b)
Nominal operating voltage level in kV and voltage characteristics 
(i.e., three-phase AC, bipolar DC, etc.) for each transmission 
circuit;
(c)
Terminating substations and buses for each transmission circuit;
(d)
Minimum required normal and emergency load ratings for both 
summer and winter seasons for each transmission circuit; and
(e)
Maximum allowable positive sequence impedance for each 
transmission circuit when determined applicable by planning 
studies performed by the Transmission Provider.
VIII.C.1.2
RFP Requirements for Competitive Substation Facilities:
Each RFP that includes one or more Competitive Substation Facilities will 
specify, at a minimum, the following information for each Competitive Substation 
Facility:
(a)
Expected in-service date;
(b)
List of all transmission buses within the Competitive Substation 
Facility, including nominal operating voltage level in kV and 
voltage characteristics;
(c)
List of all major equipment and facilities within the Competitive 
Substation Facility and associated terminating buses including

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
95.0.0, 97.0.0
Effective On: October 18, 2026
power transformers, voltage regulators, phase angle regulators, 
series reactors, series capacitors, shunt reactors, shunt capacitors, 
static VAR compensators, DC converters, transmission line circuit 
terminals, generator terminals, and loads;
(d)
Limitations on and/or requirements for bus configurations when 
determined applicable by planning studies performed by the 
Transmission Provider including required load ratings of circuit 
breakers, disconnects, bus sections and other load carrying 
equipment under alternative bus configurations;
(e)
Required load ratings for all load carrying equipment and facilities 
identified in item (c) above;
(f)
Winding connection and tap requirements for power transformers, 
voltage regulators, phase angle regulators and load tap changers 
when determined necessary by planning studies performed by the 
Transmission Provider;
(g)
Impedance requirements for power transformers, phase angle 
regulators, series reactors and series capacitors when determined 
necessary by planning studies performed by the Transmission 
Provider; and
(h)
Limitations on and/or requirements for protection systems when 
determined applicable by a planning driver or Applicable 
Reliability Standard or in order to ensure a compatible

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ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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Effective On: October 18, 2026
interconnection with existing protection systems associated with 
existing transmission facilities to which the Competitive 
Transmission Facilities will interconnect.
VIII.D.
PROPOSALS
Proposals may be submitted only in response to an RFP issued by the Transmission 
Provider and only by entities that are certified as a Qualified Transmission Developer at the time 
such Proposal is submitted.  Once submitted and unless withdrawn pursuant to Section VIII.D.8 
of this Attachment FF, Proposals shall be held open as offers capable of acceptance by the 
Transmission Provider until such time as the Transmission Provider announces the identity of the 
Selected Developer and designates an Alternate Selected Developer pursuant to Sections 
VIII.E.2 and VIII.H of this Attachment FF.   
VIII.D.1.
Proposal Submission Deadline:
Proposals shall be submitted to the Transmission Provider no later than 5:00 PM 
EPT on the Proposal Submission Deadline.  The Proposal Submission Deadline will be 
the date specified in the RFP, which shall not exceed one hundred and sixty-five (165) 
Calendar Days from the date the Transmission Provider issued the RFP, unless the one 
hundred and sixty-five (165) day maximum duration causes the Proposal Submission 
Deadline to fall on a Saturday, Sunday, or holiday in which case the Proposal Submission 
Deadline shall be the next Business Day that is not a holiday.
VIII.D.2. Proposal Deposit:
An RFP Respondent must submit an initial deposit, in an amount not to exceed 
$150,000.00 (in August 2023 dollars), to the Transmission Provider.  The Transmission

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FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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Effective On: October 18, 2026
Provider shall calculate the maximum amount of the deposit by determining the inflation 
adjustment in accordance with the inflation calculator located at the U.S. Bureau of Labor 
Statistics website.  The inflation adjustment shall be calculated from August 2023, to the 
most up-to-date data available at the time the notification takes place, where such amount 
will be rounded to the nearest $100.  The RFP shall state the amount of each deposit, the 
date(s) by which such deposit must be received, and any applicable submission 
requirements. In no event shall an RFP specify a deadline for submitting Proposal 
deposits that is more than thirty (30) Calendar Days prior to the Proposal Submission 
Deadline.  Only one (1) proposal deposit is required for each Proposal, regardless of the 
number of RFP Respondents and Proposal Participants involved with the Proposal. In the 
event that an RFP Responder submits an initial deposit for a Proposal before the Proposal 
Submission Deadline specified in an RFP but does not submit the corresponding Proposal 
for such RFP by the Proposal Submission Deadline, the Transmission Provider shall 
refund the full amount of such deposit within thirty (30) Calendar Days after the Proposal 
Submission Deadline. Each deposit submitted to the Transmission Provider will be held 
in an interest-bearing account.
VIII.D.3. RFP Administration and Proposal Evaluation Expenses:
RFP Respondents shall, on a pro rata basis, be responsible for paying the actual 
costs incurred by the Transmission Provider, including the costs of the expert 
consultant(s) engaged to assist the Transmission Provider, in administering the 
Competitive Developer Selection Process for the specific RFP that the RFP 
Respondent(s) responded to through its Proposal submission.  The Transmission Provider

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ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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Effective On: October 18, 2026
will track all costs, including the Transmission Provider’s time and the costs of the expert 
consultant(s), in administering the Competitive Developer Selection Process for each 
specific RFP.
The Transmission Provider shall evaluate all Proposals submitted in response to a 
specific RFP together and apply each of their respective proposal deposits equally to the 
cost of administering the Competitive Developer Selection Process for that specific RFP, 
except for Proposals that were found to be deficient by the Transmission Provider and 
were refunded 90% of the proposal deposit under Section VIII.D.10 of Attachment FF of 
the Tariff.  Any shortfall will be billed by the Transmission Provider on a pro rata basis 
to each Proposal submitted in response to the RFP.  Each respective RFP Respondent(s) 
is responsible for paying the pro rata share allocated to its Proposal(s) within thirty (30) 
Calendar Days of receiving notice of such shortfall.  If a RFP Respondent fails to pay the 
expenses allocated to any of the Proposals it submitted within sixty (60) Calendar Days 
of the monthly invoice remittance date, those Proposals shall be disqualified from further 
consideration and evaluation by the Transmission Provider.  Furthermore, the RFP 
Respondent may lose its Qualified Transmission Developer designation at the sole 
discretion of the Transmission Provider as they are no longer in good standing with the 
Transmission Provider pursuant to Section VIII.B.4.a of Attachment FF of the Tariff.
Any funds remaining after the Transmission Provider has completed the 
Competitive Developer Selection Process, including the issuance of refunds to Proposals 
that were withdrawn pursuant to Section VIII.D.8 of Attachment FF of the Tariff or 
deemed deficient pursuant to Section VIII.D.10 of Attachment FF of the Tariff, will be

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ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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Effective On: October 18, 2026
refunded by the Transmission Provider on a pro rata basis to each Proposal within 
seventy-five (75) Calendar Days following the designation of the Selected Proposal, 
including any interest actually earned on such deposits.
VIII.D.4.
Proposal Submission Format:
Proposals shall be submitted to the Transmission Provider prior to the Proposal 
Submission Deadline.  Proposals shall be submitted to the Transmission Provider in 
accordance with the requirements specified in the RFP and Business Practices Manuals 
(e.g. the location, format, number of copies, use of submission templates, etc.).  Proposals 
may be submitted in one of two different forms: (i) a Single-Developer Proposal; or (ii) a 
Joint-Developer Proposal.  The Transmission Provider may provide template(s) for 
Proposal submissions and, if provided, RFP Respondents shall utilize the template(s) in 
submitting their Proposals.  Any questions or inquiries regarding an issued RFP from the 
date the RFP was issued through the date that the selection report for the Competitive 
Transmission Project is publicly posted shall be solely directed to the Transmission 
Provider through the contacts listed in the RFP and not to the interconnecting incumbent 
Member(s).
VIII.D.4.1.
Single-Developer Proposal:
A Single-Developer Proposal is a Proposal submitted by a single RFP 
Respondent that would become the sole Selected Developer for the Competitive 
Transmission Project, should its Single-Developer Proposal be designated as the 
Selected Proposal by the Transmission Provider.
VIII.D.4.2.
Joint-Developer Proposal:

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ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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Effective On: October 18, 2026
A Joint-Developer Proposal is a Proposal submitted jointly by two or more 
RFP Respondents that would each be designated as Selected Developers for the 
Competitive Transmission Project, should the Joint-Developer Proposal be 
designated as the Selected Proposal by the Transmission Provider.  The Joint-
Developer Proposal shall only be submitted once to the Transmission Provider by 
one of the RFP Respondents.  Each RFP Respondent of a Joint-Developer 
Proposal shall either: (i) acknowledge and agree to be jointly and severally liable 
for all aspects of the submitted Joint-Developer Proposal; or (ii) clearly specify 
the aspects of the Competitive Transmission Project that each RFP Respondent 
will be solely liable, such that all aspects of the submitted Joint-Developer 
Proposal are accounted for.  If at least one of the RFP Respondents does not 
commit to being jointly and severally liable for all aspects of the submitted Joint-
Developer Proposal, the existence of any grounds that would trigger Variance 
Analysis, including default and termination of the Selected Developer Agreement, 
with respect to any one RFP Respondent shall trigger Variance Analysis of the 
entire Joint-Developer Proposal, pursuant to Attachment FF Section IX of the 
Tariff.
VIII.D.4.3.
Proposal Participants:
RFP Respondents may convey an interest of the Competitive 
Transmission Project to one or more Proposal Participant(s) at any time, provided 
however that (i) the RFP Respondent(s) identified and disclosed in its Proposal 
the Proposal Participants to which an interest will be conveyed; (ii) RFP

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ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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Effective On: October 18, 2026
Respondent(s) convey such an interest on substantially the same terms as 
disclosed in the Proposal; (iii) the Aggregate ATRR for the Competitive 
Transmission Project shall not exceed the Aggregate ATRR contained in the 
Proposal; (iv) each RFP Respondent and each Proposal Participant to which an 
interest will be conveyed has each provided a written agreement committing to 
any applicable cost-containment measures contained in the Proposal; (v) each 
RFP Respondent and each identified Proposal Participant has each executed the 
ISO Agreement, to the extent that the entity is not already a Member, but no later 
than the date the Competitive Transmission Facilities are energized; and (vi) each 
RFP Respondent and each identified Proposal Participant has listed the 
Competitive Transmission Facilities for which it owns or has been conveyed an 
ownership interest in Appendix H of the ISO Agreement (i.e. the list of 
transmission facilities transferred to MISO’s functional control for the purposes of 
planning and operation).  If a Proposal identifies one or more Proposal 
Participants, the RFP Respondent(s) that convey such an interest shall 
acknowledge and agree to be responsible for all aspects of the Competitive 
Transmission Project, notwithstanding any default of any Proposal Participant’s 
obligations, whether identified in the Proposal or under any contractual 
agreement(s) between the Proposal Participant and the respective RFP 
Respondent(s).  Except as provided in Section VIII.D.5 of Attachment FF of the 
Tariff, the Transmission Provider shall only evaluate the capabilities and 
resources of the RFP Respondent(s) when evaluating a Proposal.

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FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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VIII.D.5. Proposal Content Requirements:
Each Proposal shall include all data and information required by the RFP, 
applicable Business Practices Manuals, and Tariff including, but not limited to, the items 
specified below in Section VIII.D.5 of Attachment FF of the Tariff.  RFP Respondents 
may include additional data and information in the Proposal if they believe it is relevant 
and useful to the evaluation  of their Proposal.  If and to the extent RFP Respondents are 
utilizing any resources, capabilities, or competencies from an Affiliate, those resources, 
capabilities, or competencies shall be clearly identified in the Proposal and the RFP 
Respondent shall submit an “Acknowledgement of Support” signed by an authorized 
agent of the  Affiliate expected to provide such support and the RFP Respondent.  An 
“Acknowledgement of Support” may also be provided, but is not required, from any 
other entity on which RFP Respondent(s) intends to rely for such support.
VIII.D.5.1.
General Proposal Information:
VIII.D.5.1.1. Identification of RFP Respondents:
Each Proposal shall clearly identify each RFP Respondent involved in the 
Proposal and identify a primary and secondary point of contact for the Proposal 
that will represent the RFP Respondent(s) in any communications and actions 
with the Transmission Provider.
Each Joint-Developer Proposal shall clearly and specifically identify each 
RFP Respondent’s respective roles and responsibilities (including the respective 
percentage of responsibility) to finance, construct, implement, own, operate, 
maintain, repair, and restore the Competitive Transmission Project in such a

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ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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Effective On: October 18, 2026
manner that one hundred percent (100%) of the responsibilities are identified and 
disclosed in the Proposal.  Any agreements between or among the RFP 
Respondents governing the division of roles and responsibilities shall also be 
submitted with the Proposal
Furthermore, each RFP Respondent involved in a Joint-Developer 
Proposal shall include either: (i) an agreement to be jointly and severally liable for 
all aspects of the Joint-Developer Proposal; or (ii) clearly specify the aspects of 
the Competitive Transmission Project that each RFP Respondent will be solely 
liable, such that all aspects of the submitted Joint-Developer Proposal are 
accounted for.  If at least one of the RFP Respondents does not commit to being 
jointly and severally liable for all aspects of the Joint-Developer Proposal, the 
existence of any grounds that would trigger Variance Analysis, including default 
and termination of the Selected Developer Agreement, with respect to any one 
RFP Respondent shall trigger Variance Analysis of the entire Joint-Developer 
Proposal, pursuant to Attachment FF Section IX of the Tariff. 
VIII.D.5.1.2. Identification of Proposal Participants:
Each Proposal shall clearly identify whether the RFP Respondent(s) plan 
to convey an interest of the Competitive Transmission Project to one or more 
Proposal Participant(s).  If a RFP Respondent contemplates any conveyance of 
interest of the Competitive Transmission Project to one or more Proposal 
Participant(s), it shall clearly and specifically (i) identify each Proposal 
Participant in the Proposal;  (ii) identify the type and amount of any conveyed

MISO
ATTACHMENT FF
FERC Electric Tariff
Transmission Expansion Planning Protocol
ATTACHMENTS
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interest in the Proposal; (iii) provide any agreements between or among the RFP 
Respondent and the Proposal Participants regarding the conveyed interest in the 
Competitive Transmission Project; (iv) disclose the expected timing of any such 
transfer of ownership or interest; (v) provide a written agreement from the RFP 
Respondent and each Proposal Participant to execute the ISO Agreement, to the 
extent that the entity is not already a Member, but no later than the date the 
Competitive Transmission Facilities are energized, should the Transmission 
Provider designate the proposal as the Selected Proposal; and (vi) the RFP 
Respondent’s written agreement to be responsible for all aspects of the 
Competitive Transmission Project notwithstanding, any default of any Proposal 
Participant’s obligations, whether identified in the Proposal or under any 
contractual agreement(s) between the Proposal Participant and the respective RFP 
Respondent(s).
VIII.D.5.2.
Project Implementation Schedule:
Each Proposal shall contain a detailed project implementation schedule, driven by 
the required in-service date, for each Competitive Transmission Facility contained in the 
Competitive Transmission Project which shall include proposed schedules for route and 
site evaluation, regulatory permitting, land acquisition, engineering and design, land 
surveying, material procurement, construction, and commissioning/energization for all 
Competitive Transmission Facilities.
VIII.D.5.3.
Project Cost Estimate:
Each Proposal shall contain a detailed project cost-estimate, based upon the

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reasonably descriptive facility design submitted in the Proposal, for each Competitive 
Transmission Facility in the Competitive Transmission Project.  The cost-estimates 
developed by the Transmission Provider during the transmission planning process and 
utilized for project approval should be considered by RFP Respondents for informational 
purposes only and are not guaranteed to be accurate or complete in all respects.  RFP 
Respondents shall create and rely on their own cost calculations when submitting 
Proposals. To the extent that any RFP Respondent or Proposal Participant identified in a 
Proposal, or an Affiliate of either, has not committed to forego recovery of such costs, the 
project cost estimate shall include: 
(i) all costs to develop the Proposal, including any costs of participating in the 
planning process and Competitive Developer Selection Process for the Competitive 
Transmission Project for which recovery may be sought.  To the extent that a RFP 
Respondent submits more than one Proposal for a Competitive Transmission Project, 
such cost estimate shall state all costs for which recovery may be sought if any of the 
Proposals submitted by such RFP Respondent for the Competitive Transmission Project 
is selected as the Selected Proposal; and 
(ii) any other pre-commercial expense for which a RFP Respondent or Proposal 
Participant identified in a Proposal, or an Affiliate of either, may seek recovery if the 
Proposal is selected as the Selected Proposal.
VIII.D.5.4.
Estimated Annual Transmission Revenue Requirements:
Each Proposal shall contain separate estimated annual transmission revenue 
requirements for each RFP Respondent and Proposal Participant involved with the

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Proposal beginning in the year costs would first be recovered under Attachment O and 
either Attachment MM or Attachment GG (including any incentives, such as  to collect 
Construction Work In Progress (“CWIP”) in ratebase or pass-through pre-commercial 
expenses on a current basis), through the first forty (40) calendar years that the 
Competitive Transmission Facilities included in the Competitive Transmission Project 
will be in service, in accordance with Attachment MM of the Tariff for Multi-Value 
Projects and Attachment GG of the Tariff for Market Efficiency Projects, including the 
supporting detail on the annual allocation factors for operations and maintenance, general 
and common depreciation expense, taxes other than income taxes, income taxes, and 
return used to estimate the annual revenue requirements.  
If the Proposal involves more than one RFP Respondent or any Proposal 
Participants, the Proposal shall also include an estimated Aggregate ATRR beginning in 
the year costs would first be recovered under Attachment O and either Attachment MM 
or Attachment GG (including any incentives, such as to collect CWIP in ratebase or pass-
through pre-commercial expenses on a current basis), through for the first forty (40) years 
the Competitive Transmission Facilities included in the Competitive Transmission 
Project will be in service representing the combined effect of each RFP Respondents’ and 
Proposal Participants’ individual annual transmission revenue requirements.
VIII.D.5.5.
Binding Cost-Containment:
Each Proposal shall contain information and details regarding any binding cost-
containment measures, including any binding cost caps, that may be offered as part of the 
Proposal.  If any binding cost-containment measures are submitted as part of the

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Proposal, each RFP Respondent and Proposal Participant submitting such binding cost-
containment measures shall also provide a draft term sheet or agreement that clearly 
describes in detail the nature of the cost-containment measures being proposed, including 
all exclusions, exceptions, conditions, enforcement mechanisms, interaction with change 
orders, and such other information as is specified in the applicable Business Practices 
Manuals, as part of the Proposal submittal.
VIII.D.5.6.
Financial Information:
Each Proposal shall include a detailed financing plan for the Competitive 
Transmission Project.  The financing plan shall conform to the format(s) specified in an 
RFP and must contain information pertaining to the following elements, if applicable, as 
further explained in the applicable Business Practices Manuals:
1) 
A description of capital resources available to fund Competitive Transmission 
Project implementation costs, which demonstrate that the RFP Respondent(s) can 
procure capital to fund at least one hundred percent (100%) of expected project 
implementation costs, including any contingencies projected by the RFP 
Respondent(s) to show an ability to cover risks associated with foreseeable cost 
overruns.  
For each funding source the RFP Respondent(s) shall provide a description of 
how much capital is available, when the funds will be obtained, and what 
conditions must to be met to secure the funds.  At a minimum, the RFP 
Respondent(s) shall identify each funding source by type with a brief description 
and state the costs for each funding sources.  If the cost of funds information is

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not known at the time the RFP Response is submitted, the RFP Respondent(s) 
may submit a range or estimate and describe the limitations that prevent this 
information from being provided.  
2) 
An exhibit or a high-level narrative description of the expected cash flows 
between the RFP Respondent(s) and the funding sources sufficient to explain the 
timing, form and volume of cash flows expected between each RFP Respondent 
and the identified funding sources. 
3) 
An overview schedule of significant expenditures for project implementation 
sufficient to demonstrate that funds will be available when needed for significant 
expenditures. 
4) 
A description of immediately available funds, that the RFP Respondent(s) shall 
have access to in order to address unforeseen contingencies that arise during 
project implementation. 
5) 
Information describing the RFP Respondent’s plan to obtain Project Financial 
Security within the timeframe required by the Selected Developer Agreement in 
sufficient detail to demonstrate that the RFP Respondent(s) reasonably expect(s) 
to be able to satisfy this requirement if selected as the Selected Developer. 
6) 
In the event that a RFP Respondent intends to rely on personnel, material, 
technical, financial, and/or other resources from an Affiliate in its Proposal, the 
RFP Respondent shall provide an Acknowledgment of Support executed by such 
Affiliate, which lists the personnel, material, technical, financial, and/or other 
resources that the RFP Respondent(s) desire(s) the Transmission Provider to

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consider in evaluating the Proposal to demonstrate that such Affiliate is aware of 
the RFP Respondent’s reliance on such Affiliate’s resources and will make such 
resources available if the RFP Respondent’s Proposal is selected. 
7)  
The credit ratings, if applicable, of the RFP Respondent and any Affiliate 
providing financial support pursuant to an Acknowledgment of Support and 
general financial information including audited financial statements and notes for 
the RFP Respondent and any parent or Affiliate providing financial support 
pursuant to an Acknowledgment of Support, as well as pro forma financial 
statements for each calendar year until the RFP Respondent(s) expect(s) to place 
all project facilities into service.
8) 
The RFP Respondent’s financial strategy to facilitate timely replacements and 
rebuilds for the life of the project to demonstrate that it reasonably can be relied 
upon to address catastrophic destruction and normal wear and tear.
VIII.D.5.7.
Reasonably Descriptive Design:  
Each Proposal shall contain a reasonably descriptive facility design for each 
Competitive Transmission Facility included in the Competitive Transmission Project.  
Reasonably descriptive facility designs represent descriptions of the core attributes and 
features of a design, not the detailed engineering and design calculations and documents.   
VIII.D.5.7.1. Design for Competitive Transmission Line Facilities:  
For each Competitive Transmission Line Facility, reasonably descriptive 
facility design proposals must include, if applicable, and as further described by 
the applicable RFP, the following:

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(a)
The estimated length of the Competitive Transmission Line 
Facility in miles and the basis for the estimate;  
(b)
The proposed conductor type, size, and, if applicable, bundling 
configuration;  
(c)
The proposed default or typical structure design attribute(s) (e.g., 
steel vs. wood vs. aluminum vs. concrete, monopole vs. H-frame 
vs. lattice, single circuit vs. double circuit, self-supporting vs. 
guyed, structural calculation assumptions, etc.) to be used for 
tangent, running angle, in-line dead-end, and angle dead-end 
structures when feasible and/or for the majority of the Competitive 
Transmission Line Facilities;  
(d)
The estimated positive sequence line impedance and pi-equivalent 
shunt susceptance; 
(e)
The calculated normal and emergency seasonal thermal loading 
ratings, including the basis for such calculations; 
(f)
The proposed type of lightning protection system to be used when 
feasible and/or for the majority of the Competitive Transmission 
Line Facilities (e.g., shield wires vs. surge arresters, etc.) and key 
attributes (e.g., shielding angle, arrester location and type, etc.); 
(g)
The proposed grounding method to be used when feasible and/or 
for the majority of the Competitive Transmission Line Facilities

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(e.g., ground rods only, counterpoise, etc.) and key attributes (e.g., 
targeted structure footing grounding resistance, etc.);  
(h)
The proposed method to address or mitigate adverse impacts of 
galloping conductors and/or Aeolian vibration, if any (e.g., 
Stockbridge dampers, special conductors, etc.);
(i)
The continuous rating of any load carrying switchgear installed on 
the Competitive Transmission Line Facilities; and  
(j)
The assumed communications systems to be used for the 
Competitive Transmission Line Facilities to facilitate protective 
relaying (e.g., fiber optic, power line carrier, microwave, etc.).
VIII.D.5.7.2. Design for Competitive Substation Facilities:  
For each Competitive Substation Facility, reasonably descriptive facility 
design proposals shall include, if applicable, and as further described, by the 
applicable RFP, the following:  
(a)
A detailed one-line diagram; 
(b)
The proposed protection systems including protection schemes, 
any anticipated interaction with existing/other facilities and 
conceptual protection system design (including backup protection 
systems, if applicable).  Remote system monitoring capability shall 
be described with major features listed (redundancy, monitored 
parameters, etc.);  
(c)
The detailed specifications for proposed power transformers;

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(d)
A description of other substation equipment items, including load 
ratings, voltage ratings, fault interrupting ratings, tap data, and 
impedances as applicable, where other substation equipment 
includes, but is not limited to, bus sections, circuit breakers, circuit 
switchers, switches, disconnects, regulating transformers, station 
service transformers, series and shunt capacitors, series and shunt 
reactors, static VAR compensators, DC conversion equipment, 
instrument transformers (metering and relaying), wave traps, and 
surge arresters;  
(e)
The proposed line terminal ratings and basis for calculation, 
including limiting element;  
(f)
The basis for load rating calculations on any equipment where 
nameplate continuous ratings are not used; and 
(g)
A description of the communication system for remote monitoring, 
control and data acquisition facilities, including monitoring and 
control points.  
VIII.D.5.7.3.
Additional reasonably descriptive facility design data:
An RFP may require submission of additional facility design data when 
deemed necessary by the Transmission Provider.  Proposals may also include 
additional facility data when deemed necessary by RFP Respondents, including 
but not limited to, optional facility design data listed in the Business Practices 
Manuals, which may be considered by the Transmission Provider in the

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evaluation and selection of Proposals.   
VIII.D.5.8.
Project Implementation:
Each Proposal shall contain a description of existing and/or planned project 
implementation capabilities, relative to the applicable locations and jurisdictions where 
the Competitive Transmission Facilities will be located, to be used by the RFP 
Respondent(s) to perform the following tasks, as applicable and as further described in 
the applicable RFP:  
(a)
Project management; 
(b)
Routing/siting evaluation studies for Competitive Transmission Facilities; 
(c)
Regulatory permitting; 
(d)
Right-of-way and land acquisition for Competitive Transmission  
Facilities; 
(e)
Engineering and surveying required for Competitive Transmission 
Facilities; 
(f)
Material procurement for Competitive Transmission Facilities; 
(g)
Construction of Competitive Transmission Facilities;  
(h)
Commissioning/energization of Competitive Transmission Facilities; and 
(i)
Safety during construction of the Competitive Transmission Facilities. 
  VIII.D.5.8.1.Additional Project Implementation Capabilities Data:
A RFP may require the submission of additional data, when deemed 
necessary by the Transmission Provider, related to the policies, processes, 
methods, capabilities, experience, and past performance the RFP Respondent(s)

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Proposals may also include additional information regarding project 
implementation capabilities when deemed necessary by RFP Respondents, 
including but not limited to, existing capabilities and past experience regarding 
project implementation, which may be considered by the Transmission Provider 
in the evaluation and selection of Proposals. 
VIII.D.5.9.
Operations and Maintenance:
Each Proposal shall contain a description of existing and/or planned operations, 
maintenance, repair, and replacement capabilities, relative to the locations and applicable 
jurisdictions where the Competitive Transmission Facilities will be located, to be used by 
the RFP Respondent(s) to perform the following tasks, as applicable and as further 
described in the RFP: 
(a)
Forced outage response for transmission line circuits and substations;  
(b)
Switching for transmission line circuits and substations; 
(c)
Emergency repair and testing for transmission line circuits and 
substations; 
(d)
Preventative and/or predictive maintenance for transmission line circuits 
and substations, including vegetation management and equipment testing;
(e)
Maintenance and management of spare parts, spare structures, and/or 
spare equipment inventories for substations and/or transmission lines,  
including description of any agreements to share spare equipment, spare 
parts, and/or spare structures with other transmission entities;

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(f)
Real-time operations monitoring and control capabilities, if the 
Competitive Transmission Project contains one or more Competitive 
Substation Facilities; 
(g)
Major facility replacements or rebuilds required as a result of catastrophic 
destruction or natural aging through normal wear and tear, including 
financial strategy to facilitate timely replacements and/or rebuilds; and
(h)
Safety during operations and maintenance of the Competitive 
Transmission Facilities.
VIII.D.5.9.1. Local Balancing Authority:
Each Proposal shall contain a description regarding the RFP Respondent’s 
plan for incorporating the Competitive Transmission Facilities into a Local 
Balancing Authority Area.
VIII.D.5.9.2. Other Operations and Maintenance Capabilities Data:
A RFP may require the submission of additional data related to the 
policies, processes, methods, capabilities, experience, and past performance of the 
RFP Respondents regarding operations, maintenance, repair, and replacement 
when deemed necessary by the Transmission Provider.  
Proposals may also include additional information regarding operations, 
maintenance, repair, and replacement capabilities when deemed necessary by RFP 
Respondents, including but not limited to, existing capabilities and past 
experience regarding operations, maintenance, repair and replacement, which may

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be considered by the Transmission Provider in the evaluation and selection of 
Proposals.
VIII.D.5.10.
Participation in the Transmission Planning Process:
While not required, RFP Respondents and Proposal Participants who desire to 
have such participation considered in the evaluation of their Proposal shall state whether 
any RFP Respondent or Proposal Participant, or Affiliate of either, was identified by the 
Transmission Provider eligible to receive planning participation credit for such 
Competitive Transmission Project for which the Proposal is submitted.  Any Proposal 
stating that an Affiliate of a RFP Respondent or Proposal Participant earned the planning 
participation credit shall also identify and describe the relationship between the RFP 
Respondent or Proposal Participant to the Affiliate.
VIII.D.5.11.
Disclosure of Assignments or Potential Assignments:
Proposals shall include a declaration stating whether or not the RFP 
Respondent(s) will seek to assign the Competitive Transmission Facilities, Competitive 
Transmission Project, or Selected Developer Agreement pursuant to Article 14 of the pro 
forma Selected Developer Agreement.  For all proposed assignments except assignments 
to Project Finance Entities pursuant to Article 14.4 of the Selected Developer Agreement, 
such declaration shall include the identity of the proposed assignee(s) and the material 
terms, including timing, of such proposed assignment. If such assignment is conditioned 
on the occurrence of future events, then a statement of the conditions under which the 
assignment would occur and their anticipated timing shall be included.  If an assignment

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is contemplated to an Affiliate that does not yet exist, then a description of the 
relationship that the RFP Respondent and such future Affiliate will have at the time of 
assignment and any commitments that the RFP Respondent intends to make to support 
the Affiliate shall constitute a sufficient identification of the intended assignee.  
VIII.D.5.12.
Proposal Attestation:
Each RFP Respondent shall include an affidavit as part of the Proposal 
submission, signed by an officer of its organization, attesting that: (i) it understands that 
the Transmission Provider’s evaluation of Proposals and designation of a Selected 
Proposal is governed by the Tariff and the Business Practices Manuals; (ii) it agrees to be 
bound by the Tariff and to follow the applicable Business Practices Manuals; (iii) it has 
submitted the Proposal in good faith; (iv) the information submitted by the organization 
in the Proposal is true to the best of the RFP Respondent’s knowledge and belief; (v) it 
has complied with all Applicable Laws, and Regulations and Good Utility Practice in 
preparing the Proposal; and (vi) if selected, the Respondent agrees to be bound by its 
Proposal.  Furthermore, each Proposal Participant shall include an affidavit as part of the 
Proposal signed by an officer of its organization attesting that: (i) the Aggregate ATRR 
for the Competitive Transmission Project and any required financial information about 
the Proposal Participant and its inputs into the Aggregate ATRR that has been submitted 
by the organization is true to the best of the Proposal Participant’s knowledge and belief; 
(ii) that Proposal Participant agrees to be bound by any applicable cost containment 
measure and (iii) either (a) that it agrees to execute the ISO Agreement and identify the 
Competitive Transmission Facilities associated with the Competitive Transmission

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Project in Appendix H of the ISO Agreement prior to closing on its conveyed interest 
should the Transmission Provider designate the Proposal as the Selected Proposal; or (b) 
prior to such closing it will demonstrate that it has already executed the ISO Agreement 
and it agrees to identify the Competitive Transmission Facilities associated with the 
Competitive Transmission Project in Appendix H of the ISO Agreement.
VIII.D.6.
Additional Data Requests:
If, during the evaluation of Proposals, the Transmission Provider determines that 
additional information is required to evaluate the Proposals, the Transmission Provider 
will request, in writing, the additional data from all RFP Respondents, along with the 
timeframe that this data must be submitted.  If the additional data is not submitted within 
the specified timeframe, the Proposal be deemed invalid and will not be evaluated or 
considered further by the Transmission Provider.  This timeframe shall not be less than 
ten (10) Business Days from when the Transmission Provider issues the additional data 
request.  This data request will not extend the evaluation timeframe defined in Section 
VIII.E.2 of Attachment FF of the Tariff.
VIII.D.7.
Proposal Clarifications and Corrections:
The Transmission Provider will have the right, but not the obligation, during the 
Competitive Developer Selection Process described in Section VIII of Attachment FF of 
the Tariff, to request a RFP Respondent(s) to provide clarifications, corrections, or 
further supporting information to its submitted Proposal(s), along with the timeframe that 
a response must be submitted.  The RFP Respondent(s) shall be responsible for any 
clarifications, corrections, or further supporting information the Transmission Provider

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requires that relates to the Proposal Participants.  In the event the RFP Respondent agrees 
to provide said clarification(s), corrections, or further supporting information, the RFP 
Respondent shall provide these within the time set forth by the Transmission Provider 
which shall be no less than ten (10) Business Days of the Transmission Provider’s 
request.  If the Transmission Provider accepts the RFP Respondent’s clarification(s), 
corrections, or further supporting information. These shall immediately become a part of 
the submitted Proposal; or upon the Transmission Provider’s request, the RFP 
Respondent shall immediately update its Proposal to reflect the accepted clarification(s), 
corrections, or further supporting information.  In the event that the RFP Respondent 
declines to provide the requested clarification(s), corrections, or further supporting 
information, the Transmission Provider shall evaluate the Proposal as submitted.
VIII.D.8.
Withdrawing Submitted Proposals:
Prior to the Proposal Submission Deadline, a RFP Respondent may withdraw a 
Proposal that was submitted to the Transmission Provider by informing the Transmission 
Provider as soon as practical in writing.  Any deposits submitted to the Transmission 
Providers associated with the withdrawn Proposal will be returned in full and the 
withdrawn Proposal will not be considered or evaluated by the Transmission Provider.
A RFP Respondent may withdraw its submitted Proposal after the Proposal 
Submission Deadline by informing the Transmission Provider in writing, as soon as 
practical, but no later than such time that the Transmission Provider publicly announces 
the Selected Proposal for the RFP.  Upon receiving a withdrawal notification, the 
Transmission Provider will stop its evaluation and consideration of the Proposal.  A

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withdrawn Proposal will not relieve the RFP Respondent from its obligations for the pro 
rata costs associated with the full evaluation period nor will the RFP Respondent be 
afforded any refund other than those funds remaining once the Competitive Developer 
Selection Process has been completed for the RFP.
VIII.D.9.
Confidential Treatment of Proposals:
The Transmission Provider will treat information and documents, or portions of 
documents, received from RFP Respondents and/or Proposal Participants, whether 
received as Part of a Proposal, a response to a request for clarification or additional 
information pursuant to Sections VIII.D.6 and VIII.D.7 of this Attachment FF, or 
otherwise, as either Project confidential information pursuant to Section VIII.D.9.a, or 
non-confidential information pursuant to Section VIII.D.9.b, as set forth below.
VIII.D.9.a
Confidential Information:
Except as provided in Section VIII.D.9.d, the Transmission Provider will not, 
without the prior written consent of the respective RFP Respondent and/or the Proposal 
Participant, publicly disclose or share any of the following confidential information with 
any individual except for employees of the Transmission Provider or an independent 
contractor of the Transmission Provider who require access to such information to 
perform their duties and have executed the Transmission Provider’s non-disclosure 
and/or CEII agreement:
(i)
All detailed breakdowns of costs, including but not limited to, the itemized costs 
for labor and materials;

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(ii)
All details of an RFP Respondent and/or Proposal Participant’s financing 
arrangements;
(iii)
All detailed design, routing, siting, or specialty construction techniques; and
(iv)
Any other information or portions of documents that are clearly labeled and 
specifically designated as ”CONFIDENTIAL,” except for: (1) the items specified 
in Section VIII.D.9.b  of this Attachment FF; and (2) information and/or items 
which the Transmission Provider is otherwise required, or explicitly authorized by 
another provision of the Tariff, to make publicly available.
VIII.D.9.b
Non-Confidential Information:
The following categories of information shall not be considered confidential or 
maintained as Confidential Information:
(i)
The identity of RFP Respondents and Proposal Participants;
(ii)
The high-level design for Competitive Transmission Facilities;
(iii)
The total estimated cost of the Competitive Transmission Project;
(iv)
The estimated forty (40) year Annual Transmission Revenue Requirement 
(“ATRR”);
(v)
Information relating to any cost-containment measures, and rate-incentives;
(vi)
Information regarding the proposed in-service dates of the Competitive 
Transmission Facilities;
(vii)
The final evaluation score assigned to each Proposal, with the names of the RFP 
Respondents and Proposal Participants redacted or masked;

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(viii)
All timetables and milestones agreed to between a Selected Developer(s) and the 
Transmission Provider in the Selected Developer Agreement;
(ix)
All publicly available information; 
(x)
Any information for which a RFP Respondent or Proposal Participant has 
provided consent to release; and
(xi)
Any information the Transmission Provider is required to make publicly available 
pursuant to Section VIII.D.9.d of this Attachment FF.
VIII.D.9.c
Use of Non-Confidential Information–Post-Evaluation Report:
The Transmission Provider may use the non-confidential information of RFP 
Respondents and Proposal Participants to prepare the public post-evaluation selection 
report for a Competitive Transmission Project required by Section VIII.E.2 of this 
Attachment FF as is reasonably necessary to explain the basis for the Transmission 
Provider’s selection of a Selected Developer.  In all cases, the Confidential Information 
and non-confidential information that was not disclosed in the post-evaluation selection 
report or the publicly posted version of the Selected Developer Agreement shall not 
otherwise be disclosed by the Transmission Provider except as required by Section 
VIII.D.9.d of this Attachment FF. 
i.
Use of Selected Developer Non-Confidential Information
The Transmission Provider may use the non-confidential information of the RFP 
Respondent(s) and Proposal Participants whose Proposal is selected to prepare: (1) 
appendices for a Selected Developer Agreement memorializing the commitments and 
salient features of the Selected Proposal; and (2) a post-evaluation selection report that

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explains the basis for the Transmission Provider’s selection of the Selected Proposal 
pursuant to the comparative analysis required by Sections VIII.E, VIII.E.1, VIII.E.1.1, 
VIII.E.1.2, VIII.E.1.3, and VIII.E.1.4 of this Attachment FF to the Tariff.  The 
Transmission Provider may use such information to the extent reasonably necessary to 
explain why the selection of the Selected Proposal is proper based on the comparative 
analysis required by the Tariff, including discussions of features of the Selected Proposal 
that the Transmission Provider determined to be important in selecting the Selected 
Proposal. 
ii.
Use of Non-Confidential Information of RFP Respondents 
and Proposal Participants whose Proposals are Not Selected 
The Transmission Provider may disclose the non-confidential information of RFP 
Respondents and Proposal Participants whose Proposals were not selected as the Selected 
Proposal only to the extent reasonably necessary to explain why the selection of the 
Selected Proposal is proper based on the comparative analysis required by Sections 
VIII.E, VIII.E.1, VIII.E.1.1, VIII.E.1.2, VIII.E.1.3, and VIII.E.1.4 of this Attachment FF 
to the Tariff.  The Transmission Provider may disclose the non-confidential information 
contained in Section VIII.D.9.b(i) and VIII.D.9.b(ix)-(xi) without masking the 
identity(ies) of the entity(ies) to whom such non-confidential information pertains.  The 
Transmission Provider may disclose the non-confidential information contained in 
Section VIII.D.9.b(ii)-(viii) for RFP Respondents and Proposal Participants whose 
Proposals were not selected as the Selected Proposal but must mask the identities of such 
parties, either through aggregation or the redacting of names, as appropriate for

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comparative purposes. 
VIII.D.9.d
Other Disclosures of Proposal Information:
The Transmission Provider will disclose any information submitted in Proposals 
or in response to a request for clarifications and or additional information, whether 
confidential or non-confidential, that it is otherwise required by or subject to another 
Tariff provision, Commission rule or order, or court order, as ordered by state or federal 
agencies, as reasonably deemed by the Transmission Provider is required to be disclosed 
in connection with a dispute between the Transmission Provider and the entity or entities 
to which such confidential information pertains, or the defense of litigation or a dispute. 
In addition, the Transmission Provider may disclose confidential information contained 
in the Selected Proposal in filings before the Federal Energy Regulatory Commission to 
the extent necessary to explain or enforce commitments made in a Selected Developer 
Agreement provided that the Transmission Provider, consistent 18 C.F.R. Section 
388.112, requests that that the information be treated as confidential and non-public by 
the Commission and its staff and that the information be withheld from public disclosure.
The Transmission Provider may disclose confidential or non-confidential 
information submitted in Proposals or in response to a request for clarifications and/or 
additional information to Federal Energy Regulatory Commission staff to the extent 
necessary to discuss the Transmission Provider’s implementation of the Competitive 
Developer Selection Process without first obtaining an order provided that the 
Transmission Provider: (1) clearly communicates the confidential nature of the 
information shared; and (2) consistent with 18 C.F.R. Section 388.112, requests that the

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information be treated as confidential and non-public by the Commission and its staff and 
that the information be withheld from public disclosure.
VIII.D.10.
Proposal Validation – Review for Completeness:
The Transmission Provider will review each submitted Proposal for completeness and 
validate whether the RFP Respondent(s) is/are listed as a Qualified Transmission Developer.  
Within thirty (30) Calendar Days of the Proposal Submission Deadline, the Transmission 
Provider will notify each RFP Respondent if the Transmission Provider identifies that their 
Proposal is incomplete.  Except when any of the RFP Respondents involved in a Proposal were 
not listed as a Qualified Transmission Developer on the date the Proposal was submitted, the 
RFP Respondent(s) will have a single Proposal Cure Period set for by the Transmission Provider 
of not less than ten (10) Business Days from the date of such notification to submit the requested 
information to cure any deficiencies in their Proposal.  Proposals that are not complete at the end 
of the Proposal Cure Period will be deemed invalid and will not be evaluated or considered 
further by the Transmission Provider.  Such Proposals will be refunded ninety percent (90%) of 
the initial proposal deposit specified in Section V.III.D.2 of Attachment FF of the Tariff, if such 
initial proposal deposit was submitted to the Transmission Provider.  Proposals that include a 
RFP Respondent that was not listed as a Qualified Transmission Developer on the date the 
Proposal was submitted will also be deemed invalid and will not be evaluated or considered 
further by the Transmission Provider.   The Transmission Provider will provide a written 
explanation to RFP Respondents identifying why the Proposal has been disqualified.
VIII.D.11.
Posting List of RFP Respondents and Proposals Participants:
The Transmission Provider will post a list of the RFP Respondents and Proposal

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Participants that submitted completed Proposals in response to an issued RFP on its website after 
the end of the Proposal Cure Period.  
VIII.D.12.
RFP Respondent’s Qualified Transmission Developer status:
RFP Respondents are required to maintain their status as a Qualified Transmission 
Developer throughout the duration of the Competitive Developer Selection Process.   In the 
event that the Transmission Provider determines that a RFP Respondent has ceased to be a 
Qualified Transmission Developer, the Transmission Provider shall send a written notice of such 
fact to the RFP Respondent, which notice shall state the reason(s) for loss of Qualified 
Transmission Developer status.  The RFP Respondent shall have thirty (30) Calendar Days from 
the Transmission Provider’s notification of loss of Qualified Transmission Developer status to 
remove the grounds for such loss of status.  Any Proposal involving a RFP Respondent that 
ceases to be a Qualified Transmission Developer will be deemed invalid and will not be 
evaluated or considered further by the Transmission Provider if such failure remains uncured 
more than thirty (30) Calendar Days from the date of the notice to the RFP Respondent.  A 
Proposal shall not be deemed invalid if the RFP Respondent cures the loss of Qualified 
Transmission Developer status within the thirty (30) Calendar Day period.  If one or more RFP 
Respondents who have submitted a Joint-Developer Proposal pursuant to Section VIII.D.4.2 is 
disqualified after the cure period, the Joint-Developer Proposal shall be disqualified unless all of 
the RFP Respondents have acknowledged and agreed to be jointly and severally liable for all 
aspects of the submitted Joint-Developer Proposal. If all RFP Respondents submitting a Joint 
Developer Proposal have acknowledged and agreed to be jointly and severally liable for all 
aspects of the submitted Joint-Developer Proposal, then the remaining RFP Respondents shall

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assume the obligations of the RFP Respondent that has failed to cure a loss of Qualified 
Transmission Developer status and the Joint-Developer Proposal shall not be disqualified. The 
Transmission Provider will provide a written explanation to RFP Respondents identifying why 
the Proposal has been disqualified or, in the event that all RFP Respondents involved in a Joint-
Developer Proposal have acknowledged and agreed to be jointly and severally liable for all 
aspects of the submitted Joint-Developer Proposal, stating that the remaining RFP Respondents 
must assume the obligations of the RFP Respondent that has lost its Qualified Transmission 
Developer status.
VIII.E.
EVALUATION OF PROPOSALS
The Transmission Provider will have one hundred and sixty-five (165) Calendar Days 
from the Proposal Submission Deadline to evaluate all completed Proposals.  Only those 
Proposals that were submitted prior to the Proposal Submission Deadline and cured of any 
deficiencies pursuant to Section VIII.D.10 of Attachment FF of the Tariff and otherwise have not 
been withdrawn or deemed invalid will be evaluated by the Transmission Provider based on a 
comparative analysis using the evaluation criteria below and as further described in the Business 
Practices Manuals and applicable RFP.  Specific methods used to evaluate various aspects of a 
Proposal shall be described in the Business Practices Manuals.  This comparative analysis 
evaluation will be conducted by Transmission Provider and/or independent consultants 
competent in the areas of finance, transmission facility design, transmission project 
implementation, and transmission operations, maintenance, repair, and replacement.  In 
conducting the comparative analysis evaluation of Proposals, the Transmission Provider and any 
independent expert consultants will be overseen by the Competitive Transmission Executive

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Committee, which will have the exclusive and final authority to determine Selected Proposal.  
The Transmission Provider may decline to accept any or all Proposals that do not meet the 
Tariff’s requirements for the project classification in question or will not sufficiently address the 
Transmission Issue(s) the RFP was intended to address.  If no Proposals are received from 
Qualified Transmission Developers or selected by the Transmission Provider, the Competitive 
Transmission Project may be cancelled or assigned to the applicable Member(s), as defined 
below:
(a)
Ownership and the responsibility to construct facilities which are connected to a 
single Member’s system belong to that Member; 
(b)
Ownership and the responsibilities to construct facilities which are connected 
between two (2) or more Members’ facilities belong equally to each Member, 
unless such Members otherwise agree; and
(c)
Ownership and the responsibility to construct facilities which are connected 
between a Member(s)’ system and a system or systems that are not part of the 
Transmission Provider belong to such Members(s) unless the Member(s) and the 
non-Transmission Provider party or parties otherwise agree.
VIII.E.1.
Proposal Evaluation Criteria:  
In evaluating Proposals, the Transmission Provider will consider the following 
general aspects and weighting for each Competitive Transmission Project evaluated:  
(a)
Competitive Transmission Line Projects:
The following weights will be applied to Competitive Transmission

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Projects containing only Competitive Transmission Line Facilities:
(i)
Cost and reasonably descriptive facility design quality:  30%
(ii)
Project implementation capabilities:  35%
(iii)
Operations, maintenance, repair, and replacement capabilities:  
30%
(iv)
Transmission Provider planning process participations:  5%
(b)
Competitive Substation Projects:
The following weights will be applied to Competitive Transmission 
Projects containing only Competitive Substation Facilities:
(i)
Cost and reasonably descriptive facility design quality:  30%
(ii)
Project implementation capabilities:  30%
(iii)
Operations, maintenance, repair, and replacement capabilities:  
35%
(iv)
Transmission Provider planning process participations:  5%
(c)
Mixed Competitive Transmission Facility Projects:
The following weights will be applied to Competitive Transmission 
Projects containing both Competitive Transmission Line Facilities and 
Competitive Substation Facilities:
(i)
Cost and reasonably descriptive facility design quality:  35%
(ii)
Project implementation capabilities:  30%

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(iii)
Operations, maintenance, repair, and replacement capabilities:  
30%
(iv)
Transmission Provider planning process participations:  5%
VIII.E.1.1.
Cost and Reasonably Descriptive Facility Design:
When considering cost and reasonably descriptive facility design quality, 
the Transmission Provider shall evaluate, at a minimum and to the extent 
applicable, the following: 
(a)
Estimated project cost; 
(i)
Estimated project cost(s), as set forth in Section VIII.D.5.3 
of this Attachment FF; and 
(ii)
Cost estimate rigor, which shall include financial 
assumptions and supporting information to clearly 
demonstrate a thorough analysis in support of the cost 
estimate.   
(b)
Estimated annual transmission revenue requirement:
(i)
The estimated annual transmission revenue requirement(s), 
as described in Section VIII.D.5.4 of this Attachment FF; 
and
(ii)
Estimated annual transmission revenue requirement rigor, 
which shall include financial assumptions and supporting 
information to clearly demonstrate a thorough analysis in

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support of the estimated annual transmission revenue 
requirement.
(c) 
Cost Containment
(i) 
Binding cost containment measures as described in Section 
VIII.D.5.5 of this Attachment FF if a Proposal contains any 
such measures relating to the estimated project cost; and
(ii)
Binding cost containment measures as described in Section 
VIII.D.5.5 of this Attachment FF if a Proposal contains any 
such measures relating to the estimated annual transmission 
revenue requirement(s).
(d)
Electrical design:
(i)
Reasonably descriptive facility electrical design quality; 
and 
(ii)
Reasonably descriptive facility electrical design rigor, 
which shall include facility studies performed and other 
specific supporting data that clearly documents and 
supports consideration and attention given to the proposed 
reasonably descriptive facility electrical designs.  For 
reasonably descriptive facility electrical design, the 
Transmission Provider shall consider the items set forth in 
Sections VIII.D.5.7.1 through VII.D.5.7.3 of this 
Attachment FF, as each is applicable to the electrical design

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of Competitive Transmission Facilities discussed in the 
Proposal.
(e)
Structural design:
(i)
Reasonably descriptive facility structural design quality; 
and
(ii)
Reasonably descriptive facility structural design rigor, 
which shall include facility studies performed and other 
specific supporting data that clearly documents and 
supports consideration and attention given to the proposed 
reasonably descriptive facility structural designs.  For 
reasonably descriptive facility structural design, the 
Transmission Provider shall consider the items set forth in 
Sections VIII.D.5.7.1 through VII.D.5.7.3 of this 
Attachment FF, as each is applicable to the structural 
design of Competitive Transmission Facilities discussed in 
the Proposal.
VIII.E.1.2.
Project Implementation Capabilities:  
When considering project implementation capabilities, the Transmission 
Provider shall evaluate, at a minimum and to the extent applicable, the existing 
and/or planned capabilities, competencies, previous applicable experience and 
demonstrated ability, and processes regarding the following project 
implementation categories relative to the locations and jurisdictions where the

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Competitive Transmission Facilities associated with the Competitive 
Transmission Project are to be located, including: 
(a)
Project schedule and management:
(i)
Project implementation schedule, as required by Section 
VIII.D.5.2 of this Attachment FF; and
(ii)
Project management. 
(b)
Regulatory permitting, and route/site evaluation:
(i)
Regulatory permitting; 
(ii)
Route and site evaluation; and
(iii)
Right of way and land acquisition. 
(c)
Construction;
(i)
Engineering and surveying; 
(ii)
Material procurement; 
(iii)
Facility construction; and
(iv)
Final facility commissioning. 
(d)
Financing and capital resource plan;
(i)
The information and documentation from the detailed 
financing plan required by Sections VIII.D.5.6(1)-(7) of this 
Attachment FF; and
(e)
Safety, as described in Section VIII.D.5.9(h) of this Attachment 
FF.
VIII.E.1.3.
Operations, Maintenance, Repair, and Replacement 
Capabilities:

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When considering operations, maintenance, repair and replacement 
capabilities, the Transmission Provider shall evaluate, at a minimum and to the 
extent applicable, the existing and/or planned capabilities, competencies, and 
processes regarding the following operations and maintenance categories relative 
to the locations and jurisdictions where the Competitive Transmission Facilities 
associated with the Competitive Transmission Project are to be located:
(a)
Normal operations:
(i)
Real-time operations monitoring and control;   
(ii)
Switching; and 
(iii)
Plan for incorporating the Competitive Transmission 
Facilities into a Local Balancing Authority Area as required 
by Section VIII.D.5.9.1 of this Attachment FF.
(b)
Non-normal operations:
(i)
Forced outage response;
(ii)
Emergency repair; and
(iii)
Capabilities to perform major facility replacements or 
rebuilds required to restore the Competitive Transmission 
Facilities as a result of catastrophic destruction, as required 
by Section VIII.D.5.9(g) of this Attachment FF.
(c)
Maintenance activities: 
(i) 
Spare parts; 
(ii) 
Preventative and/or predictive maintenance and testing; and

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(iii) 
Capabilities to perform major facility replacements or 
rebuilds required as a result of natural aging through 
normal wear and tear, as required by Section VIII.D.5.9(g) 
of this Attachment FF.
(d) 
Financial capabilities and strategy 
(i)
Financial capabilities and strategy to facilitate major 
facility replacements or rebuilds required to restore the 
Competitive Transmission Facilities as a result of 
catastrophic destruction, as required by Section 
VIII.D.5.6(8) of this Attachment FF; and
(ii) 
Financial capabilities and strategy to facilitate major 
facility replacements or rebuilds required as a result of 
normal wear and tear, as required by Section VIII.D.5.6(8) 
of this Attachment FF.
(e) Safety, as described in Sections VIII.D.5.9(h) of this Attachment.
VIII.E.1.4.
Transmission Provider Planning Process Participation:  
Within thirty (30) Calendar Days after the date, the Transmission Provider 
Board approves an MTEP containing a Competitive Transmission Project, MISO 
will publicly post a list on its website identifying the entities that have meet the 
requirements to earn planning participation for such Competitive Transmission 
Project.   Such determination shall be based on relevant planning studies 
performed by such entities and the results supplied to the Transmission Provider

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during the planning process, as well as documentation of transmission project 
ideas submitted by such entities to the Transmission Provider to address the same 
Transmission Issues being addressed by the Competitive Transmission Project for 
which an RFP will be issued.  In evaluating Proposals, the Transmission Provider 
shall determine whether any RFP Respondent or Proposal Participant (including 
Affiliates) qualified to receive such credit.  Credit shall be awarded for a Proposal 
where any RFP Respondent or Proposal Participant named in such Proposal, or an 
affiliate of either, qualifies to receive such credit.  
VIII.E.2.
Proposal Selection and Posting Selection Report:
The Transmission Provider will post the name of the Selected Developer(s) on its 
website within one hundred and sixty-five (165) Calendar Days of the Proposal 
Submission Deadline.  Upon posting of the name of the Selected Developer(s), the 
obligation of RFP Respondents not named as the Selected Developer or notified that they 
have been designated as the Alternate Selected Developer(s) pursuant to Section VIII.H 
of this Attachment FF to hold their Proposals open shall cease.  Within thirty (30) 
Calendar Days after the designation of a Selected Proposal and the Selected  
Developer(s) for a Competitive Transmission Project, the Transmission Provider will 
post on its website a report in which it explains the basis for designating the Selected 
Proposal and Selected Developer(s) for each Competitive Transmission Project.  The 
report will set forth the results of the comparative analysis undertaken by the 
Transmission Provider, the basis for Transmission Provider’s decision(s), and the date(s) 
by which state approval(s) to construct must be achieved based upon when construction

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must begin to timely meet the Transmission Issue(s) to be addressed by the Competitive 
Transmission Project and taking into account the project implementation schedule(s) 
provided by the Selected Developer(s) in its Selected Proposal.  
VIII.E.3.
Proposal Selection Dispute Resolution:
Any disputes regarding the developer selection will be referred to the Dispute 
Resolution Process under Attachment HH of this Tariff.
VIII.F.
SELECTED DEVELOPER AGREEMENT
RFP Respondents identified in a Selected Proposal shall execute the pro forma Selected 
Developer Agreement, or request the submission of an unexecuted Selected Developer 
Agreement with the Commission, no later than sixty (60) Calendar Days after the Transmission 
Provider posted the name of the Selected Developer(s) on its website.  Any Proposal 
Participant(s) identified in the Selected Proposal shall execute the Proposal Participant 
acknowledgement of the pro forma Selected Developer Agreement by the same sixty (60) 
Calendar Day deadline.  The Selected Developer Agreement establishes the terms and conditions 
under which the Selected Developer will construct and implement the Competitive Transmission 
Facilities specified in its Selected Proposal.  The Selected Developer Agreement shall be 
executed by the Selected Developer and the Transmission Provider, by an authorized officer or 
equivalent official with the authority to bind their respective organizations.  The Selected 
Developer(s) for each Competitive Transmission Project, including where the Selected 
Developer is a Member, will be required to sign the Selected Developer Agreement or request it 
be submitted unexecuted with the Commission.  All executed Selected Developer Agreements 
that conform to the pro forma template in Appendix 1 of Attachment FF of the Tariff, will be

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reported to the Commission in the Transmission Provider’s next Electric Quarterly Report after 
the executed Selected Developer Agreement becomes effective on a non-provisional basis.  Any 
request to file the Selected Developer Agreement unexecuted shall be filed with the Commission, 
together with an explanation of any matters as to which the Selected Developer and the 
Transmission Provider disagree, as soon as practicable, but no later than fifteen (15) Calendar 
Days after receiving the request to file the Selected Developer Agreement unexecuted.  An 
unexecuted Selected Developer Agreement should contain terms and conditions deemed 
appropriate by the Transmission Provider for the Competitive Transmission Project.  If the 
Selected Developer and the Transmission Provider agree to proceed with design, procurement, 
and construction of the Competitive Transmission Project under the agreed-upon terms of the 
unexecuted Selected Developer Agreement, they may proceed pending Commission action.
If the Selected Developer Agreement contains information determined to be confidential 
pursuant to Section VIII.D.9 of Attachment FF of the Tariff, the Transmission Provider will post 
and/or file publicly only a redacted version of the Selected Developer Agreement.
VIII.G.
OBLIGATION TO CONSTRUCT COMPETITIVE TRANSMISSION 
PROJECT
The Selected Developer(s) will assume the responsibility and obligation to construct the 
Competitive Transmission Facilities it is selected to construct.  If the Selected Developer(s) is/are 
financially incapable of carrying out its construction responsibilities, alternate construction 
arrangements shall be identified.  Depending on the specific circumstances, such alternate 
arrangements shall include solicitation of Transmission Owners to take on financial and/or 
construction responsibilities.  If the delay in construction adversely affects the Transmission 
System reliability, the Transmission Provider shall coordinate with and support the affected

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Transmission Owner(s) regarding any mitigation measures that may be required by the 
Applicable Reliability Standards.  
However, in the event that a MTEP Appendix A Competitive Transmission Project 
approved by the Transmission Provider Board is being challenged through the Dispute 
Resolution process under Attachment HH of the Tariff or a court proceeding, the obligation of 
the Selected Developer(s) to build the specific Competitive Transmission Project (subject to 
required approvals) is waived until the Competitive Transmission Project emerges from the 
Dispute Resolution process or court proceedings as an approved Competitive Transmission 
Project.  In the event that selection of the Selected Developer to construct a project is being 
challenged through the Dispute Resolution Process under Attachment HH of the Tariff, the 
obligation of the Selected Developer to construct the project pursuant to the Selected Developer 
Agreement is not waived.  
VIII.H. 
ALTERNATE SELECTED DEVELOPER(S)
At the same time that the Transmission Provider posts the name of the Selected 
Developer(s) on its website, as specified in Attachment FF Section VIII.E.2, the Transmission 
Provider shall also notify the Alternate Selected Developer(s) that it has been selected as the 
Alternate Selected Developer(s). Upon this notification, each Alternate Selected Developer shall 
be required to hold their Proposal open for acceptance by the Transmission Provider for a period 
of one hundred (100) Calendar Days thereafter, unless released earlier by the Transmission 
Provider. The Transmission Provider shall release the Alternate Selected Developer(s) from its 
obligation to hold its Proposal open promptly upon the Selected Developer(s) satisfying all 
conditions necessary for the Selected Developer Agreement to become effective.

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If a Selected Developer does not execute the Selected Developer Agreement or request
that the Selected Developer Agreement be filed unexecuted, and provide the required Project
Financial Security within ninety (90) Calendar Days after the Transmission Provider posted the
name of the Selected Developer(s) on its website, the Transmission Provider shall proceed to
designate the Alternate Selected Developer(s) as the Selected Developer(s) for the Competitive 
Transmission Project.  Should this be required, the Transmission Provider shall notify the
Alternate Selected Developer(s) and publicly announce the Alternate Selected Developer(s) as 
the Selected Developer(s).  The Alternate Selected Developer(s) shall then be required to assume
the obligations of the Selected Developer for the Competitive Transmission Project and shall
have the same period of time to execute or request the unexecuted filing of the Selected 
Developer Agreement and provide the required Project Financial Security as the originally 
designated Selected Developer(s).
VIII.I OBLIGATION TO NEGOTIATE INTERCONNECTION AGREEMENTS
The Selected Developer(s) and any Transmission Owner(s) whose facilities will 
interconnect to the Competitive Transmission Facilities that the Selected Developer is obligated to 
construct shall each take commercially reasonable efforts to finalize and execute any required 
Transmission-to-Transmission Interconnection Agreements at least one hundred and twenty 
(120) calendar days before the scheduled in service date of the Competitive Transmission 
Project. 
IX.
VARIANCE ANALYSIS  
After the Transmission Provider Board approves an Eligible Project for inclusion in
Appendix A of the MTEP, certain circumstances or events may significantly affect the cost,

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schedule, and or the ability of Selected Developers and Transmission Owners to complete and
place into service the facilities comprising an Eligible Project for which they are responsible as 
specified in the MTEP. Under these circumstances or events, the Transmission Provider may
need to perform a Variance Analysis in order to further understand the reasons for such 
circumstances or events and to evaluate any potential impacts that they may have on the 
successful completion of the Project or on the Transmission System.
IX.A. Applicability and Scope of Variance Analysis
The provisions set forth in this Section IX of Attachment FF are only applicable to 
Eligible Projects (and the facilities that comprise these projects) approved by the Transmission 
Provider Board for inclusion in Appendix A of the MTEP after December 1, 2015. These
provisions become applicable upon: (i) the date the Transmission Provider Board approves the
respective Eligible Project for facilities that are not Competitive Transmission Facilities; or (ii)
the date the Selected Developer Agreement has been executed or filed unexecuted with the 
Commission for Competitive Transmission Facilities. Facilities comprising Eligible Projects
shall remain subject to the provisions of Attachment FF Section IX until such facilities have been
placed into service and placed under the Transmission Provider’s functional control. 
IX.B. Variance Analysis Governance
The Competitive Transmission Executive Committee shall have the exclusive and final 
authority to oversee and implement Variance Analysis, including the decision to implement any 
of the appropriate Variance Analysis Outcomes pursuant to Section IX.E of this Attachment FF. 
Such exclusive and final authority shall: (1) be subject to the Dispute Resolution provisions of 
Section IX.G of this Attachment FF and to Attachment HH; and (2) shall not prejudice any rights

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or obligations the Transmission Provider, Selected Developer(s), and incumbent Transmission
Owner(s) have to make filings before the Commission.
IX.C.  Grounds for Variance Analysis
The following circumstances or events shall trigger the Transmission Provider’s Variance 
Analysis for facilities included in an Eligible Project.  
IX.C.1.
Cost Increase
If the Transmission Provider determines that the estimated cost to 
complete an entity’s portion of an approved Eligible Project (e.g. the 
competitively bid facilities of the Competitive Transmission Project or the 
facilities assigned to an incumbent Transmission Owner included in an Eligible 
Project(s) either has exceeded or is projected to exceed the Baseline Cost Estimate 
as set forth in Section IX.C.1.1 by twenty-five percent (25%)) or more, the 
Transmission Provider shall initiate a Variance Analysis.
The Transmission Provider will not consider any portion of cost increases 
under this section to the extent that the Selected Developer has agreed to 
internalize such costs through an accepted binding  containment mechanism(s). 
However in the event that the accepted binding cost-containment mechanism(s) 
are applied and the remaining estimated cost increase still has exceeded or is 
projected to exceed the threshold, the Transmission Provider shall initiate a 
Variance Analysis.
IX.C.1.1.
Baseline Cost Estimate
The Baseline Cost Estimate for an entity’s portion of an Eligible

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Project shall be set as follows: (i) for Competitive Transmission Facilities 
the Baseline Cost Estimate shall be the project cost estimate provided in 
the Selected Proposal as agreed to in the Selected Developer Agreement; 
and (ii) for the facilities assigned to an incumbent Transmission Owner 
included in the Eligible Project not eligible for the Competitive 
Transmission Process, as described in Attachment FF Section VIII.A of 
the Tariff, the Baseline Cost Estimate shall be the project cost estimate 
provided by the respective Transmission Owner through their status 
update provided upon achieving Milestone #2 pursuant to the Business 
Practices Manuals.  The Baseline Cost Estimate for facilities included in 
an Eligible Project shall be adjusted appropriately based upon any 
approved change orders or as necessary based on the outcome of any 
Variance Analysis conducted for such facilities.
In the event that an entity’s portion of an Eligible Project is 
reassigned pursuant to Section IX.E.3 of this Attachment FF, the 
Transmission Provider shall adjust the Baseline Cost Estimate to reflect 
the cost estimates and supporting information submitted to the 
Transmission Provider by the applicable Transmission Owner during 
Variance Analysis.  The Transmission Provider shall include such 
information in any filing made to the Commission pursuant to Section 
IX.D.4.E of this Attachment FF.  
IX.C.2.
Schedule Delays

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If the Transmission Provider determines that the in-service date of 
facilities included in an approved Eligible Project has been or is projected to be 
delayed beyond the in-service date as established in MTEP Appendix A, the 
Transmission Provider shall meet with the Selected Developer(s), incumbent
Transmission Owner(s), if applicable, interconnecting Transmission Owner(s), 
and any entities responsible for facilities to which the delayed facilities 
interconnect to discuss whether such delay creates a significant risk of one or 
more NERC reliability standards violations as well as any other material issues, 
including service obligations, economic or public policy needs that may be 
jeopardized as a result of the delay. If any such issues are identified, the 
Transmission Provider shall, in consultation with these entities, develop a plan, as 
necessary, to address potential NERC reliability standards violations as well as 
any other issues that may be of material concern arising from the delay of the 
transmission facilities.   
If the potential NERC reliability standards violations, or other issues of 
material concern, cannot be adequately addressed by the entity responsible for 
constructing the delayed facilities, the Transmission Provider will take 
appropriate action; including but not limited to, determining that Reassignment is 
necessary to complete the transmission solution as set forth in Section IX.E.3 of 
this Attachment FF.
IX.C.3. 
Default under the Selected Developer Agreement
If the Transmission Provider determines that a Selected Developer is in

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Transmission Expansion Planning Protocol
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Default under a Selected Developer Agreement for an Eligible Project pursuant to 
the terms thereof.  
IX.C.4 
Inability to Complete Facilities
If the Transmission Provider makes a determination that a Selected 
Developer or an incumbent Transmission Owner will be unable to complete 
facilities for which it has been designated to construct; where such determination 
may be based on, but is not limited to the following:
a.
A Selected Developer’s or an incumbent Transmission Owner’s inability 
to secure necessary approvals, permits, certificates, financing, resources, 
needed expertise and/or third party support identified in the Selected 
Proposal, property rights, rights of way, or is otherwise unable or unlikely 
to construct the facilities;
b.
A Selected Developer’s or an incumbent Transmission Owner’s 
notification to the Transmission Provider that it is unable or unwilling to 
proceed with construction of its facilities for which it has been designated 
to construct;
c.
A Selected Developer or an incumbent Transmission Owner’s 
abandonment of the facilities it has been designated to construct;
d.
A determination by the Transmission Provider that a Selected Developer is 
no longer a Qualified Transmission Developer; and
e.
A determination by the Transmission Provider that reassignment is 
necessary pursuant to Section IX.E.3 of this Attachment FF.

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In selecting the appropriate Variance Analysis Outcome to apply where 
the Transmission Provider has determined that a Selected Developer or an 
incumbent Transmission Owner will be unable to complete the facilities for which 
it has been designated to construct, the Transmission Provider will consider, but is 
not limited to considering the following, in addition to the general factors set forth 
in Section IX.D.2.1:
(i)
The reasons that the Selected Developer or the Transmission Owner was 
unable or was unlikely to construct the facilities;
(ii)
Whether the facilities are still needed;
(iii)
Whether a Mitigation Plan, as further described in Section IX.E.2 of this 
Attachment FF, is available that could remedy the ground(s) for Variance 
Analysis, including consideration of the extent to which it will cost; and
(iv)
Whether reassignment, as further described in Section IX.E.3 of this 
Attachment FF, is available, including the impacts of reassigning the 
facilities to another entity.
IX.C.5 
Undisclosed Assignments 
If the Transmission Provider determines that the Selected Developer has 
assigned the Competitive Transmission Facilities, Competitive Transmission 
Project, or Selected Developer Agreement to an entity not disclosed in its 
Proposal as required by Section VIII.D.5.12 or on terms materially different than 
those disclosed in the Proposal, except for assignments to a Project Finance Entity 
pursuant to Article 14.4 of the Selected Developer Agreement.

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Transmission Expansion Planning Protocol
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IX.D.
Variance Analysis Procedure
Variance Analysis shall commence when the Transmission Provider makes an 
initial determination that one or more of the grounds for Variance Analysis as described 
in Section IX.C of this Attachment FF exists.  The Transmission Provider will adhere to 
the following steps, as further detailed in the applicable Business Practices Manuals, in 
performing a Variance Analysis:
IX.D.1.
Initial Inquiry and Confirmation of Grounds for Variance 
Analysis
Upon making an initial determination that one or more of the grounds for 
Variance Analysis as described in Section IX.C of this Attachment FF exists, the 
Transmission Provider shall notify the applicable Selected Developer or 
Transmission Owner in writing that Variance Analysis has commenced, including 
the ground(s) for commencing Variance Analysis, and a brief description of the 
Transmission Provider’s concerns.  The applicable Selected Developer or 
incumbent Transmission Owner shall be provided an opportunity to be heard by 
the Transmission Provider and present to the Transmission Provider its position 
on whether the identified ground(s) for Variance Analysis exist and what outcome 
it believes is appropriate along with supporting facts and documentation.  If the 
Transmission Provider determines that the ground(s) for Variance Analysis do not 
exist after considering the Selected Developer or Transmission Owner’s response 
and any other relevant information, the Transmission Provider shall terminate the 
Variance Analysis.  If the Transmission Provider continues to believe that 
reasonable grounds for Variance Analysis exist after considering the Selected

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Transmission Expansion Planning Protocol
ATTACHMENTS
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Developer or Transmission Owner’s response and any other relevant information, 
the Transmission Provider shall continue to commence Variance Analysis and so 
notify the Selected Developer or Transmissions Owner.
IX.D.2.
Determination of Variance Analysis Outcome
If the Transmission Provider continues to believe that reasonable 
ground(s) for Variance Analysis exists pursuant to the process described in 
Section IX.D.1 of this Attachment FF, the Transmission Provider shall further 
investigate the circumstances or events and the relevant facts surrounding the 
facilities identified in Section IX.D.1 above.  Upon completing its investigation, 
the Transmission Provider shall make a determination of which Variance Analysis 
Outcome to apply, as described in Section IX.E of this Attachment FF.  In 
determining which Variance Analysis Outcome to apply, the Transmission 
Provider shall consider the general factors set forth in Section IX.D.2.1 and the 
appropriate factors of Sections IX.E of this Attachment FF.
IX.D.2.1.
General Factors in Variance Analysis Outcome 
Determination
Before deciding to impose any Variance Analysis Outcome 
authorized by the Tariff in Sections IX.E of this Attachment FF, the 
Transmission provider shall consider the following factors:
A.
The causes of, or reasons for, the circumstances or events 
triggering Variance Analysis, including the degree of fault of the 
applicable Selected Developer or incumbent Transmission Owner;
B.
The potential impacts to the Transmission System and the MTEP,

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including potential reliability, economic, or public policy impacts;
C.
The degree of completion of the Eligible Projects or facilities;
D.
A comparison of the estimated costs of each outcome;
E.
A comparison of the degree to which each outcome will likely 
result in the successful completion of or increase the ability to 
complete the facilities and/or Eligible Projects; and 
F.
A comparison of the degree to which each outcome will alleviate 
the ground(s) for Variance Analysis.
IX.D.3.
Implementation of Variance Analysis Outcome
Upon completing the procedures detailed in Section IX.D.2 of this 
Attachment FF, the Transmission Provider shall perform the following as further 
detailed in the Business Practices Manuals:
A.
Inform the applicable Selected Developer(s) or incumbent 
Transmission Owner and any other affected parties of the Variance 
Analysis Outcome in writing;
B.
Post a description of the Variance Analysis Outcome and the 
reason(s) it was selected on the Transmission Provider’s website, 
redacting any confidential information and or Critical Energy 
Infrastructure Information (CEII) as necessary.  The Transmission  
Provider shall be authorized to publicly disclose confidential 
information, limited in scope to the specific information needed to 
explain the reason(s) Variance Analysis was triggered and why the

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Transmission Expansion Planning Protocol
ATTACHMENTS
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Transmission Provider selected the Variance Analysis Outcome for 
implementation;
C.
Implement the Variance Analysis Outcome in coordination with 
the applicable Selected Developer(s), incumbent Transmission 
Owner(s), and any other affected parties;
D.
If implementation of the Variance Analysis Outcome results in a 
mitigation plan to be placed into effect that alters the schedule, 
cost, design, or scope of a Competitive Transmission Facility, the 
Transmission Provider and Selected Developer shall amend the 
Selected Developer Agreement to include the requirements of the 
mitigation plan or the Transmission Provider shall file such plan 
with the Commission unexecuted; and
E.
If implementation of the Variance Analysis Outcome results in 
Reassignment or Cancellation of Competitive Transmission 
Facilities, the Transmission Provider shall file a Notice of 
Termination with the Commission to terminate the Selected 
Developer Agreement pursuant to the provisions of the Selected 
Developer Agreement.  In the event that the Transmission Provider 
files a Notice of Termination pursuant to Section IX.E of this 
Attachment FF or otherwise discusses confidential information in 
the course of administrative or judicial proceedings, the 
Transmission Provider may request that the information be treated

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Transmission Expansion Planning Protocol
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as confidential and non-public pursuant to 18 C.F.R. §1b.20 and 
388.112.
IX.E. Variance Analysis Outcomes
In determining which Variance Analysis outcome to apply, the Transmission 
Provider shall apply the procedures specified in Section IX.D of this Attachment FF.
IX.E.1.
No Action
The Transmission Provider may determine to take no action when 
Variance Analysis is triggered.  In determining whether to take no action in 
Variance Analysis, the Transmission Provider will consider, but is not limited to, 
the following:
A.
The causes of, or reasons for, the circumstances or events 
triggering Variance Analysis, including the degree of fault of the 
applicable Selected Developer or incumbent Transmission Owner;
B.
The potential impacts to the Transmission System and the MTEP, 
including any potential reliability, economic, or public policy 
impacts;
C.
The degree of completion of the Eligible Projects or facilities; and
D.
The cost and impacts of implementing another Variance Analysis 
Outcome pursuant to Sections IX.E.2 through IX.E.4 of this 
Attachment FF as compared to taking no action.

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Transmission Expansion Planning Protocol
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IX.E.2.
Mitigation Plan(s)
The Transmission Provider may allow a Selected Developer or incumbent 
Transmission Owner to alleviate the ground(s) for the Variance Analysis through 
a mitigation plan.  If the Transmission Provider determines that a delay in the 
applicable facilities and/or Eligible Project’s in-service date may cause the 
Transmission Provider or one or more Transmission Owners, Selected 
Developers, or non-Members to violate any Applicable Reliability Standards, the 
Transmission Provider shall identify the potential violation(s) and direct the 
impacted entities to develop a mitigation plan in coordination with the 
Transmission Provider.  The Transmission Provider, the impacted Transmission 
Owners(s) and/or Selected Developers, as applicable, shall take any and all 
reasonable actions necessary to meet the requirements of the mitigation plan and 
Applicable Reliability Standards.
Mitigation plans may also be utilized to address ground(s) for Variance 
Analysis arising under Sections IX.C.1 through IX.C.5 that do not involve a delay 
of the in-service date that potentially causes violations of Applicable Reliability 
Standards, should the Transmission Provider determine it is appropriate.  In 
determining whether to require a mitigation plan, the Transmission Provider will 
consider the factors set forth in Sections IX.D.2.1 and IX.E.1 of this Attachment 
FF as well as, but not limited to:
A.
The extent to which the ground(s) for Variance Analysis can be 
remedied through a mitigation plan, if successfully implemented,

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including the extent to which cost can be restored to baseline and 
the required in-service date realized;
B.
The willingness of the Selected Developer(s) or incumbent 
Transmission Owner(s) to implement the mitigation plan, 
including their willingness to bear the costs thereof;
C.
The resources and ability of the Selected Developer(s) or 
incumbent Transmission Owner(s) to successfully implement the 
mitigation plan; and
D.
Whether the Transmission Owner(s) that would receive the 
reassigned facilities would be better able to alleviate the ground(s) 
for Variance Analysis than the Selected Developer.
The mitigation measures may include, without limitation, any one or 
combination of the following components: (i) an updated implementation plan; 
(ii) an operating procedure; or (iii) alternative facilities and or projects to mitigate 
reliability violations.  If a mitigation plan is used, the Transmission Provider and 
Selected Developer shall work together to amend the Selected Developer 
Agreement to reflect the mitigation plan. In the event that the Selected Developer 
or incumbent Transmission Owner refuses to execute the Transmission Provider’s 
proposed mitigation plan or offer a substitute plan reasonably acceptable to the 
Transmission Provider, the Transmission Provider may elect either to file its 
proposed mitigation plan with the Commission unexecuted, select an alternate

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Transmission Expansion Planning Protocol
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Variance Analysis Outcome or, in if the Selected Developer is a signatory to the 
ISO Agreement, proceed thereunder.
IX.E.3.
Reassignment
The Transmission Provider may determine to reassign Competitive Transmission 
Facilities in accordance with Section IX.E.3.1 of this Attachment FF.  Reassignment shall 
also be proper if a Selected Developer fails to maintain its Qualified Transmission 
Developer status after the expiration of any applicable cure period.  If a Selected 
Developer is the incumbent Transmission Owner whose service area is the service area 
for which the facilities triggering Variance Analysis are located, the Transmission 
Provider shall seek recourse through the ISO Agreement or FERC, as appropriate.  In all 
other cases, the Transmission Provider will consider the factors set forth in Sections 
IX.D.2.1, IX.E.1, and IX.E.2 of this Attachment FF as well as the following, in 
determining whether Reassignment is applied including but not limited to:  
A.
Whether a mitigation plan would be sufficient to alleviate the ground(s) 
for Variance Analysis;
B.
The actions that the incumbent Transmission Owner(s), to whom the 
facilities would be reassigned to if the Transmission Provider selects the 
Reassignment Variance Analysis Outcome, would reasonably be required 
to take to successfully complete the facilities;
C.
The incremental costs of the Reassignment Variance Analysis Outcome; 
and
D.
The extent of any potential delay that the Reassignment Variance Analysis

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Outcome may cause and any potential impacts on reliability.
If the Transmission Provider selects the Reassignment Variance Analysis 
Outcome, the Selected Developer(s) shall be obligated to work cooperatively and 
in good faith with the Transmission Provider, the incumbent Transmission 
Owner(s), and the affected Transmission Owner(s) and/or non-MISO 
transmission owners, to implement the transition.
IX.E.3.1.
Procedure for Reassignment
Prior to making any determination to reassign facilities or projects, 
the Transmission Provider shall consult with the entity or entities to which 
such facilities or projects would be assigned to ascertain: (1) the 
willingness of such entities to develop, own, operate, and maintain such 
facilities or project; (2) the estimated costs submitted by such entities and 
the certainty of such estimates; and (3) the proposed schedule submitted 
by such entity or entities for developing the reassigned facilities or 
projects and the degree of certainty of such schedule.  Reassigned facilities 
and or projects will be offered to the applicable Transmission Owner(s), as 
defined below:  
A.
Ownership and the responsibility to construct facilities which are 
connected to a single Transmission Owner’s system belong to that 
Transmission Owner; 
B. 
Ownership and the responsibilities to construct facilities which are 
connected between two (2) or more Owners’ facilities belong equally to

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each Transmission Owner, unless such Transmission Owners otherwise 
agree; and 
C.
Ownership and the responsibility to construct facilities which are 
connected between a Transmission Owner(s)’ system and a system or 
systems that are not part of the Transmission Provider belong to such 
Transmission Owner(s) unless the Transmission Owner(s) and the non-
Transmission Provider party or parties otherwise agree.  
If the applicable Transmission Owner(s) decline to construct the reassigned facilities and 
or Eligible Project, the Transmission Provider will reassign, as applicable, the facilities 
and/or Eligible Projects through the Competitive Transmission Developer Selection 
Process, as described in Section VIII of Attachment FF of the Tariff.
IX.E.4.
Cancellation of Facilities and or Projects
The Transmission Provider may determine to cancel Eligible Projects 
and/or facilities comprising such projects.  In determining whether to cancel 
Eligible Projects or facilities, the Transmission Provider will consider the factors 
set forth in Sections IX.D.2.1, IX.E.1, IX.E.2, and X.E.3 of this Attachment FF.
IX.F. Variance Analysis Confidentiality
The Transmission Provider shall not disclose to the public that a Variance 
Analysis has commenced until such time as it has confirmed its initial determination that 
a ground for Variance Analysis exists pursuant with Section IX.D.1 of this Attachment 
FF.  Notwithstanding the preceding sentence, the Transmission Provider shall be allowed 
to disclose that it is commencing a Variance Analysis to third parties, including

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Transmission Expansion Planning Protocol
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interconnecting Transmission Owners, Selected Developers, or non-Members from 
whom the Transmission Provider requires information to determine whether the 
ground(s) for Variance Analysis exist.  However, no confidential information will be 
disclosed when the Transmission Provider solicits information from third parties unless 
and to the extent such disclosure is needed to obtain information necessary to determine 
any potential NERC reliability standards violations, service obligation issues, and 
economic or public policy needs that may be jeopardized.
In the event that the Transmission Provider determines pursuant to Section IX.D.1 
of this Attachment FF that ground(s) for Variance Analysis do not exist, the Transmission 
provider shall treat any information collected pursuant to Section IX.D.1 as Project 
Confidential Information.  In the event that the Transmission Provider determines 
pursuant to IX.D.1 of this Attachment FF that ground(s) for Variance Analysis do exist, 
the Transmission provider shall be authorized to share Project Confidential Information 
with such third parties as the Transmission Provider determines are reasonably necessary 
in order to enable the Transmission Provider to obtain needed input and information to 
identify any potential system reliability impacts of Variance Analysis Outcomes, 
including impacts from any potential NERC reliability standards violations, service 
obligation issues, and economic or public policy needs that may be jeopardized.  The 
Transmission Provider shall consult with the Selected Developer and or the incumbent 
Transmission Owner prior to sharing any such confidential information for the purposes 
of discussing reasonable confidentiality safeguards.
IX.G. Variance Analysis Dispute Resolution

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All disputes by the affected Selected Developer or Transmission Owner shall be 
addressed in accordance with the provisions of Attachment HH, except that disputes 
involving the termination of a Selected Developer Agreement shall be addressed in 
accordance with the Dispute Resolution provisions of the Selected Developer Agreement. 
IX.H
Project Financial Security
The Transmission Provider may utilize Project Financial Security to cover the 
costs of Variance Analysis resulting from Default under the Selected Developer 
Agreement.  In such event, the Transmission Provider may draw upon such funds after 
confirming that a Default exists pursuant to Section IX.D.1 of this Attachment FF.  The 
Transmission Provider shall utilize such funds to offset any costs reasonably incurred by 
the Transmission Provider in performing a Variance Analysis, transitioning the 
Competitive Transmission Project to a new Selected Developer and/or incumbent 
Transmission Owner(s), and otherwise distribute such funds as determined by the 
Commission to cover Variance Analysis and transition costs.  Costs for which Project 
Financial Security funds may be used include reasonable consultant fees, attorneys’ fees, 
costs of litigation and or regulatory proceedings, and staffing costs directly attributable to 
taking actions under the Variance Analysis provisions of the Tariff.  The Transmission 
Provider shall track its use of Project Financial Security and provide an informational 
filing to the Commission within six (6) months after the Transmission Provider concludes 
implementation of the selected outcome.
X. Interregional Coordination and Cost Allocation with the Southeastern Regional 
Transmission Planning Region

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The public utility transmission providers in the Southeastern Regional Transmission Planning 
region (“SERTP”) and the Midcontinent Independent System Operator region (“MISO”) shall 
undertake the interregional transmission coordination and cost allocation procedures under 
Section X of this Attachment FF. 
Where the regional transmission planning process is referenced as part of this 
interregional transmission coordination process the applicable regional transmission planning 
process for the Transmission Provider is described in Attachment FF; and is described for the 
SERTP in attachment K of the applicable SERTP transmission provider.
A.
Interregional Transmission Coordination
1.
Annual Meeting: Representatives of the SERTP and staff of the 
Transmission Provider will meet no less than once per year to facilitate the 
interregional 
coordination 
procedures 
described 
below 
(as 
applicable).  
Representatives of the SERTP and staff of the Transmission Provider may meet 
more frequently during the evaluation of interregional transmission project(s) 
proposed for purposes of interregional cost allocation between the SERTP and the 
Transmission Provider transmission planning regions.
2.
Website Posting of Information on Interregional Coordination: The 
Transmission Provider shall utilize the regional planning website for 
communication of information related to these coordinated interregional 
transmission planning procedures. The Transmission Provider shall coordinate 
with the SERTP with respect to the posting of materials to the regional planning 
website related to the interregional coordination procedures between the SERTP

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and the Transmission Provider transmission planning regions. The Transmission 
Provider shall, at a minimum, provide the following on the regional planning 
website:
a.
Interregional coordination and cost allocation procedures between the 
SERTP and Transmission Provider;
b.
Links to where stakeholders can register (if applicable/available) for the 
stakeholder committees or distribution lists of the SERTP; 
c.
Documents related to joint evaluation of interregional transmission projects; 
and
d.
Status report on interregional transmission projects selected for purposes of 
interregional cost allocation between the SERTP and the Transmission 
Provider.
B.
Model and Data Exchange 
At least annually, the Transmission Provider and the SERTP shall exchange their then-
current regional transmission plans including power-flow models and associated data 
used in the regional transmission planning processes to develop such transmission 
plan(s).   This exchange will occur when such data is available in each of the regional 
transmission planning processes, typically during the first calendar quarter of each year. 
Additional transmission-based models and data may be exchanged between the SERTP 
and the Transmission Provider as necessary and if requested.  For purposes of their 
interregional coordination activities, the Transmission Provider and SERTP will 
exchange only data and models used in the development of their then-current regional

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transmission process and plans. This data will be posted on the pertinent regional 
transmission planning process’ websites, consistent with the posting requirements of the 
respective regional transmission planning processes, and subject to the applicable 
treatment of confidential data and Critical Energy Infrastructure Information (CEII).  The 
Transmission Provider shall notify SERTP of such posting.   
C.
Identification and Joint Evaluation of Proposed Interregional Transmission 
Projects
1.
Identification of Interregional Transmission Projects:  At least 
biennially, the Transmission Provider and the SERTP shall meet to review the 
respective regional transmission plans.  Such plans include each region’s 
transmission needs as prescribed by each region’s planning process.  This review 
shall occur on a mutually agreeable timetable, taking into account each region’s 
regional transmission planning process timeline.  If through this review, the 
Transmission Provider and the SERTP identify a potential interregional 
transmission project that may be more efficient or cost-effective than regional 
transmission projects, the Transmission Provider and the SERTP shall jointly 
evaluate the potential interregional transmission project pursuant to Section 
X.C.4. 
2.
Identification of Interregional Transmission Projects by Stakeholders:  
Stakeholders and transmission developers (pursuant to Section X.D.1) may also 
propose interregional transmission projects that may be more efficient or cost-

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effective than regional transmission projects pursuant to the procedures in each 
region’s regional transmission planning processes.   
3.
Identification of Interregional Transmission Projects by Developers:
Interregional transmission projects proposed for interregional cost allocation 
purposes (“Interregional CAP”) must be submitted in both the Transmission 
Provider and the SERTP regional transmission planning processes. The project 
submittal must satisfy the requirements of Section X.D.1 except for the benefit-to-
cost ratio requirements of Section X.D.1.a.ii3. The submittal must identify the 
potential transmission project as interregional in scope and identify the 
Transmission Provider and the SERTP as regions in which the project is proposed 
to interconnect. The Transmission Provider will verify whether the submittal for 
the potential interregional transmission project satisfies all applicable 
requirements.  Upon finding that the proposed interregional transmission project 
satisfies all such applicable requirements, the Transmission Provider will notify 
the SERTP.  Once the potential project has been proposed through the regional 
transmission planning processes in both regions, and upon both regions so 
notifying one another that the project is eligible for consideration pursuant to their 
respective regional transmission planning processes, the Transmission Provider 
and the SERTP will jointly evaluate the proposed interregional projects pursuant 
to Sections X.C and X.D. 
3 A transmission developer is not responsible for determining the benefit-to-cost ratio referenced in Section 
X.D.1.a.ii in a project submittal.  However, an interregional transmission project proposed for Interregional CAP 
must ultimately satisfy the benefit-to-cost ratio requirements in accordance with the provisions of Section X.D.1.a.ii 
and X.D.3.

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4.
Evaluation of Interregional Transmission Projects:  The Transmission 
Provider and the SERTP shall act through their respective regional transmission 
planning processes in the joint evaluation of potential interregional transmission 
projects identified pursuant to Sections X.C.1 and X.C.2 to determine whether the 
inclusion of any potential interregional transmission projects in each region’s 
regional transmission plan would be more efficient or cost-effective than regional 
projects.  Such analysis shall be consistent with accepted transmission planning 
practices of the respective regions and the methods utilized to produce each 
region’s respective regional transmission plan(s).  The Transmission Provider will 
evaluate potential interregional transmission projects consistent with Section I.C.6 
and Section II of Attachment FF. 
5.
Review of Proposed Interregional Transmission Projects:  Initial 
coordination activities regarding potential interregional transmission projects will 
typically begin during the third quarter of each calendar year.  The Transmission 
Provider and the SERTP will exchange status updates regarding interregional 
transmission projects that are newly proposed or that are currently under 
consideration as needed.  These status updates will generally include, if 
applicable: (i) an update of the region’s evaluation of the proposal(s); (ii) the 
latest calculation of benefits (as identified pursuant to  Section X.D.2); and (iii) 
the anticipated timeline for future assessments.

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6.
Coordination of Assumptions Used in Joint Evaluation:  The 
Transmission Provider and the SERTP will coordinate assumptions and data used 
in joint evaluations, as necessary, including items such as:
a.
Expected timelines and milestones associated with the joint 
evaluation;
b.
Study assumptions;
c.
Models; and
d.
Benefit calculations (as identified pursuant to Section X.D.2). 
 
D.
Interregional Cost Allocation:  If an interregional transmission project is 
proposed for Interregional CAP in the SERTP and the Transmission Provider 
transmission planning regions, then the following cost allocation and benefits 
calculations, as identified pursuant to Section X.D.2, shall apply to the project: 
1. Interregional Transmission Projects Proposed for Interregional Cost 
Allocation Purposes: 
a.
For a transmission project to be eligible for Interregional CAP 
within the SERTP and the Transmission Provider, the project must:  
i.
Interconnect to transmission facilities in both the SERTP and 
Transmission Provider regions. The facilities to which the project 
is proposed to interconnect may be either existing facilities or 
transmission projects included in the regional transmission plan 
that are currently under development4 
4 For the MISO region, “under development” refers to Appendix A projects under development approved by the

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ii.
Have a combined benefit-to-cost ratio of 1.25 or higher to the 
SERTP and Transmission Provider regions, as calculated in 
Section X.D.3; and 
iii.
Meet the threshold and qualification criteria for transmission 
projects potentially eligible to be included in the respective 
regional transmission plans for purposes of cost allocation in the 
Transmission Provider and the SERTP, pursuant to their respective 
regional transmission planning processes.
b.
On a case-by-case basis, the Transmission Provider and the SERTP 
may consider an interregional transmission project that does not satisfy all 
of the criteria specified in this Section X.D.1, but that: (i) meets the 
threshold criteria for a project proposed to be included in the regional 
transmission plan for purposes of cost allocation in only one of the two 
regions; and (ii) would be interconnected to transmission facilities in both 
the SERTP and Transmission Provider regions.  The facilities to which the 
project is proposed to interconnect may be either existing facilities or 
transmission projects included in the regional transmission plan that are 
currently under development. 
c.
The transmission project must be proposed for purposes of cost 
allocation in both the SERTP and the Transmission Provider. The project 
submittal must satisfy all criteria specified in the respective regional 
MISO Board of Directors.

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transmission processes, including the respective timeframes for submittals 
proposed for cost allocation purposes. If a project is proposed by a 
transmission developer, the transmission developer must also satisfy the 
qualification criteria specified by each region. 
2. Calculation of Benefits for Interregional Transmission Projects Proposed 
for Interregional Cost Allocation Purposes:
The benefits used to establish 
the allocation of costs of a transmission project proposed for Interregional 
CAP between the SERTP and the Transmission Provider shall be determined 
as follows: 
a.
Each transmission planning region, acting through its regional 
transmission planning process, will evaluate proposals to determine 
whether the proposed project(s) addresses transmission needs that are 
currently being addressed with projects in its regional transmission plan 
and, if so, which projects in the regional transmission plan could be 
displaced by the proposed project(s). 
b. Based upon its evaluation, each region will quantify its benefits based 
upon the transmission costs that each region is projected to avoid due to its 
transmission projects being displaced by the proposed interregional 
transmission project as follows: 
i.
for the SERTP, the total avoided costs of projects included 
in the then-current regional transmission plan that would be

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displaced if the proposed interregional transmission project 
was included; and 
ii.
for the Transmission Provider, the total avoided costs of 
projects included in the then-current regional transmission 
plan that would be displaced if the proposed interregional 
transmission project was included.  
The benefits calculated pursuant to this Section X.D.2 are not necessarily 
the same as the benefits used for purposes of regional cost allocation. 
3. Calculation of Benefit-to-Cost Ratio for an Interregional Transmission 
Project Proposed for Interregional CAP:  
Prior to any regional benefit-to-cost ratio calculation pursuant to either 
regional transmission planning process, the combined interregional benefit-to-
cost ratio, referenced in Section X.D.1.a, shall be calculated for an 
interregional transmission project proposed for Interregional CAP.  Such 
calculation shall be performed by dividing the sum of the present value of the 
avoided project cost determined in accordance with Section X.D.2.b.i for the 
SERTP region and the present value of avoided project cost determined in 
accordance with Section X.D.2.b.ii for the Transmission Provider region by 
the present value of the proposed interregional transmission project’s total 
project cost. The present values used in the cost calculation shall be based on 
a common date, comparable cost components, and the latest cost estimates 
used in the evaluation of the interregional transmission project.  The combined

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interregional benefit-to-cost ratio will be assessed in addition to, not in the 
place of, the SERTP’s and the Transmission Provider’s respective regional 
benefit-to-cost ratio assessment(s) (if applicable) as specified in the respective 
regional processes. 
4. Inclusion in Regional Transmission Plans:  An interregional transmission 
project proposed for Interregional CAP in the transmission planning regions 
of the SERTP and the Transmission Provider will be included in the 
respective regional transmission plans for purposes of cost allocation after: 
a.
Each region has performed all evaluations, as prescribed in its regional 
transmission planning process, necessary for a project to be included in its 
regional transmission plan for purposes of cost allocation including any 
regional benefit-to-cost ratio calculations.  Each region shall utilize the 
benefit calculation(s) as defined in such region’s regional transmission 
planning process (for purposes of clarity, these benefits are not necessarily 
the same as the benefits determined pursuant to Section X.D.2).  Each 
region shall utilize the cost calculation(s) as defined in such region’s 
regional transmission planning process.  The anticipated percentage 
allocation of costs of the interregional transmission project to each region 
shall be based upon the ratio of the region’s benefits to the sum of the 
benefits, both as determined pursuant to Section X.D.2, identified for both 
the SERTP and the Transmission Provider.

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b. Each region has obtained all approvals, as prescribed in its regional 
process, necessary for a project to be included in the regional transmission 
plan for purposes of regional cost allocation. 
5. Allocation of Costs Between the SERTP and the Transmission Provider 
Regions:  The cost of an interregional transmission project, selected for 
purposes of cost allocation in the regional transmission plans of both the 
SERTP and the Transmission Provider, will be allocated as follows: 
a.
Each region will be allocated a portion of the interregional transmission 
project’s costs in proportion to such region’s benefit as calculated pursuant 
to Section X.D.2 to the sum of the benefits identified for both the SERTP 
and the Transmission Provider calculated pursuant to Section X.D.2.
i.
The benefits used for this determination shall be based upon 
the benefit calculation most recently performed – pursuant to 
the method described in Section X.D.2 – before each region 
included the project in its regional transmission plan for 
purposes of cost allocation and as approved by each region. 
b. Costs allocated to each region shall be further allocated within each region 
pursuant to the cost allocation methodology contained in its regional 
transmission planning process.
6. Milestones of Required Steps Necessary to Maintain Status as Being 
Selected for Interregional Cost Allocation Purposes:  Once selected in the 
respective regional transmission plans for purposes of cost allocation, the

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transmission owners in the SERTP planning region that will be allocated costs 
of the transmission project,  the Transmission Provider, and the transmission 
developer(s) must mutually agree upon an acceptable development schedule 
including milestones by which the necessary steps to develop and construct 
the interregional transmission project must occur.  These milestones may 
include (to the extent not already accomplished) obtaining all necessary 
rights-of-way and requisite environmental, state, and other governmental 
approvals and executing a mutually-agreed upon contract(s) between the 
applicable transmission owners in the SERTP planning region, the 
Transmission Provider and the transmission developer.  If such critical steps 
are not met by the specified milestones and then afterwards maintained, then 
the Transmission Provider and the SERTP may remove the transmission 
project from the selected category in the regional transmission plans for 
purposes of cost allocation.
7. Interregional Transmission Project Contractual Arrangements:  The 
contracts referenced in Section X.D.6 will address terms and conditions 
associated with the development of the proposed interregional transmission 
project included in the regional transmission plans for purposes of cost 
allocation, including but not limited to:
a.
Engineering, procurement, construction, maintenance, and operation of the 
proposed transmission project, including coordination responsibilities of 
the parties;

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b. Emergency restoration and repair;
c.
The specific financial terms and specific total amounts to be charged by 
the transmission developer of the transmission project to each beneficiary, 
as agreed to by the parties;
d. Creditworthiness and project security requirements;
e.
Milestone reporting, including schedule of projected expenditures;
f.
Reevaluation of the transmission project; and
g. Non-performance or abandonment.
8. Removal from Regional Transmission Plans:  An interregional transmission 
project may be removed from the SERTP’s or the Transmission Provider’s 
regional transmission plan(s) for Interregional CAP: (i) if the transmission 
developer fails to meet developmental milestones; (ii) pursuant to the 
reevaluation procedures specified in the respective regional transmission 
planning processes; or (iii) if the project is removed from one of the region’s 
regional transmission plans pursuant to the requirements of its regional 
transmission planning process. 
a.
The Transmission Provider shall notify the SERTP if an interregional 
transmission project or a portion thereof is likely to be, and/or is actually 
removed from its regional transmission plan.
E. Transparency 
1. Stakeholders will have an opportunity to provide input and feedback 
within the respective regional transmission planning processes of the

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SERTP and the Transmission Provider related to interregional 
transmission 
projects 
identified, 
analysis 
performed, 
and 
any 
determination/results.  Stakeholders may participate in either or both 
regions’ regional transmission planning processes to provide their input 
and feedback regarding the interregional coordination between the SERTP 
and the Transmission Provider.
2.  The Transmission Provider shall use the existing planning stakeholder 
forums, such as the Planning Advisory Committee and Sub-regional 
Planning Meetings, to review with stakeholders the interregional activities 
associated with the SERTP.
3. The Transmission Provider will post a list, on the Regional Planning 
Website, of interregional transmission projects proposed for purposes of 
cost allocation in both the Transmission Provider and the SERTP regions 
that are not eligible for consideration because they do not satisfy the 
regional project threshold criteria of one or both of the regions as well as 
post an explanation of the thresholds the proposed interregional projects 
failed to satisfy.