ER26-3515-002 · 2026-11-09 · PJM

Thirty-Day Compliance Filing on PJM’s Large Load Definition and Large Load Registry

PJM Interconnection, L.L.C. 
2750 Monroe Blvd 
Audubon, PA 19403 
   Mark J. Stanisz 
Associate General Counsel 
T: (610) 666-4707 | (F) (610) 666-8211 
Mark.Stanisz@pjm.com 
November 9, 2026 
The Honorable Debbie-Anne A. 
Reese Secretary 
Federal Energy Regulatory 
Commission 888 First Street, N.E. 
Room 1A Washington, D.C. 20426 
Re: 
 
PJM Interconnection L.L.C., Docket No. ER26-3515-002;
Thirty-Day Compliance Filing to the Commission’s October 9, 2026 Order on PJM’s 
Large Load Definition and Large Load Registry  
Dear Secretary Reese: 
Pursuant to the October 9, 2026 Order of the Federal Energy Regulatory 
Commission (“Commission”) in Docket No. ER26-3515-000,1 PJM Interconnection, 
L.L.C. (“PJM”) submits this compliance filing to comply with the directives set forth in
the October 9 Order on PJM’s Proposed Revisions to its Open Access Transmission Tariff 
(“OATT”) and Reliability Assurance Agreement (“RAA”).2
1 PJM Interconnection, L.L.C., 197 FERC ¶ 61,019 (2026) (“October 9 Order”). 
2 The compliance directives are set forth in the following paragraphs of the October 9 Order:  13, 14, 27, 32, 48 & n. 
101 (“we find that PJM’s proposed Large Load Registry as described in proposed OATT, Attachment DD-4, § II(a), 
III(b), and proposed RAA Schedule 11 revisions in sections (B)(1), B(2)(a), and B(2)(b)”), 49, 50 & n. 102.

Debbie Anne-A. Reese, Secretary 
November 9, 2026 
Page 2 of 3 
 
 
Consistent with the October 9 Order, PJM submits on compliance the 
Commission-accepted definition of “Large Load” and OATT, Attachment DD-4, § 
II(a), III(b), and RAA Schedule 11 revisions in sections (B)(1), B(2)(a), and B(2)(b).3  
PJM’s submission also reflects clarifications that the Commission accepted regarding 
the meaning of the term “Party” as used in the language relating to the Large Load 
Registry in the RAA.4  PJM has also updated the information that must be provided for 
inclusion in the Large Load Registry to remove previously identified items that are part 
of the IRAS package (specifically, the amount of BYONC brought by a particular Large 
Load and the allocated RBP UCAP MW quantity).  Because the Commission found 
RAA, Schedule 11, section (B)(1) just and reasonable, PJM has filed on compliance 
the obligation to update the information required by this section (B)(1).  This obligation 
was previously filed in an unnumbered provision of Schedule 11, section (B)(2).     
In accordance with the Commission’s directives in the October 9 Order, PJM 
submits the proposed revisions to be effective as of October 12, 2026. 
 
I. 
DESCRIPTION OF SUBMITTAL 
 
This filing consists of the following: 
 
1. This transmittal letter; 
 
2. Attachment A – Revisions to the OATT and RAA in redline (marked) 
format; and 
 
3. Attachment B – Revisions to the OATT and RAA in clean format. 
 
 
 
3 RAA Schedule 11, section B(2)(b) has been revised given the order’s discussion of “New Large Load.”   
4 October 9 Order at P 50 & n. 102.

Debbie Anne-A. Reese, Secretary 
November 9, 2026 
Page 3 of 3 
 
 
II. 
SERVICE 
PJM has served a copy of this filing on all PJM Members and on all state 
utility regulatory commissions in the PJM Region by posting this filing 
electronically. In accordance with the Commission’s regulations,10  PJM will post 
a copy of this filing to the FERC filings section of its internet site, located at the 
following link: https://www.pjm.com/library/filing-order with a specific link to the 
newly-filed document, and will send an e-mail on the same date as this filing to all 
PJM Members and all state utility regulatory commissions in the PJM Region5 
alerting them that this filing has been made by PJM and is available by following 
such link. If the document is not immediately available by using the referenced link, 
the document will be available through the referenced link within 24 hours of the 
filing.  Also, a copy of this filing will be available on the FERC’s eLibrary website 
located at the following link: http://www.ferc.gov/docsfiling/elibrary.asp in 
accordance with the Commission’s regulations and Order No. 714. 
 
 
 
 
 
5 PJM already maintains, updates and regularly uses e-mail lists for all PJM Members and affected state 
commissions.

Debbie Anne-A. Reese, Secretary 
November 9, 2026 
Page 4 of 3 
 
 
III. 
CONCLUSION 
 
In accordance with the foregoing, PJM respectfully requests that the 
Commission accept this compliance filing, as discussed here. 
Respectfully submitted, 
 
/s/ Mark J. Stanisz 
 
          Craig Glazer 
          Vice President – Federal    
           Government Policy  
          PJM Interconnection, L.L.C. 
          1200 G Street,    
             N.W. Suite 600 
          Washington, D.C. 20005 
          (202) 423-4743 
          Craig.Glazer@pjm.com 
Mark J. Stanisz 
Associate General Counsel  
PJM Interconnection, L.L.C.  
2750 Monroe Boulevard 
Audubon, PA 19403 
(610) 666-4707 
Mark.Stanisz@pjm.com 
 
 
On behalf of PJM Interconnection, L.L.C.

CERTIFICATE OF SERVICE 
 
I hereby certify that I have this 9th day of November, 2026 caused a copy of the 
foregoing document to be served upon each person designated on the official service list 
compiled by the Secretary in this proceeding. 
/s/ Mark J. Stanisz 
Mark J. Stanisz 
Associate General Counsel 
PJM Interconnection, L.L.C.

Attachment A 
Revisions to the  
PJM Open Access Transmission Tariff and 
Reliability Assurance Agreement 
(Marked Format) 
(Identified by Additional Cover Pages) 
Page 1

Revisions to the 
PJM Open Access Transmission Tariff  
(Marked Format) 
Page 2

Definitions – L – M – N 
Large Load: 
“Large Load” shall have the meaning provided in the Reliability Assurance Agreement. 
Legacy Policy: 
“Legacy Policy” shall mean any legislative, executive, or regulatory action that specifically 
directs a payment outside of PJM Markets to a designated or prospective Generation Capacity 
Resource and the enactment of such action predates October 1, 2021, regardless of when any 
implementing governmental action to effectuate the action to direct payment outside of PJM 
Markets occurs. 
Limited Demand Resource: 
“Limited Demand Resource” shall have the meaning specified in the Reliability Assurance 
Agreement. 
Limited Demand Resource Reliability Target: 
“Limited Demand Resource Reliability Target” for the PJM Region or an LDA, shall mean the 
maximum amount of Limited Demand Resources determined by PJM to be consistent with the 
maintenance of reliability, stated in Unforced Capacity that shall be used to calculate the 
Minimum Extended Summer Demand Resource Requirement for Delivery Years through May 
31, 2017 and the Limited Resource Constraint for the 2017/2018 and 2018/2019 Delivery Years 
for the PJM Region or such LDA.  As more fully set forth in the PJM Manuals, PJM calculates 
the Limited Demand Resource Reliability Target by first:  i) testing the effects of the ten-
interruption requirement by comparing possible loads on peak days under a range of weather 
conditions (from the daily load forecast distributions for the Delivery Year in question) against 
possible generation capacity on such days under a range of conditions (using the cumulative 
capacity distributions employed in the Installed Reserve Margin study for the PJM Region and in 
the Capacity Emergency Transfer Objective study for the relevant LDAs for such Delivery Year) 
and, by varying the assumed amounts of DR that is committed and displaces committed 
generation, determines the DR penetration level at which there is a ninety percent probability 
that DR will not be called (based on the applicable operating reserve margin for the PJM Region 
and for the relevant LDAs) more than ten times over those peak days;  ii) testing the six-hour 
duration requirement by calculating the MW difference between the highest hourly unrestricted 
peak load and seventh highest hourly unrestricted peak load on certain high peak load days (e.g., 
the annual peak, loads above the weather normalized peak, or days where load management was 
called) in recent years, then dividing those loads by the forecast peak for those years and 
averaging the result; and (iii) (for the 2016/2017 and 2017/2018 Delivery Years) testing the 
effects of the six-hour duration requirement by comparing possible hourly loads on peak days 
under a range of weather conditions (from the daily load forecast distributions for the Delivery 
Year in question) against possible generation capacity on such days under a range of conditions 
(using a Monte Carlo model of hourly capacity levels that is consistent with the capacity model 
Page 3

employed in the Installed Reserve Margin study for the PJM Region and in the Capacity 
Emergency Transfer Objective study for the relevant LDAs for such Delivery Year) and, by 
varying the assumed amounts of DR that is committed and displaces committed generation, 
determines the DR penetration level at which there is a ninety percent probability that DR will 
not be called (based on the applicable operating reserve margin for the PJM Region and for the 
relevant LDAs) for more than six hours over any one or more of the tested peak days.  Second, 
PJM adopts the lowest result from these three tests as the Limited Demand Resource Reliability 
Target.  The Limited Demand Resource Reliability Target shall be expressed as a percentage of 
the forecasted peak load of the PJM Region or such LDA and is converted to Unforced Capacity 
by multiplying [the reliability target percentage] times [the Forecast Pool Requirement] times 
[the DR Factor] times [the forecasted peak load of the PJM Region or such LDA, reduced by the 
amount of load served under the FRR Alternative]. 
Limited Resource Constraint: 
“Limited Resource Constraint” shall mean, for the 2017/2018 Delivery Year and for FRR 
Capacity Plans the 2017/2018 and Delivery Years, for the PJM Region or each LDA for which 
the Office of the Interconnection is required under Tariff, Attachment DD, section 5.10(a) to 
establish a separate VRR Curve for a Delivery Year, a limit on the total amount of Unforced 
Capacity that can be committed as Limited Demand Resources for the 2017/2018 Delivery Year 
in the PJM Region or in such LDA, calculated as the Limited Demand Resource Reliability 
Target for the PJM Region or such LDA, respectively, minus the Short Term Resource 
Procurement Target for the PJM Region or such LDA, respectively. 
Limited Resource Price Decrement: 
“Limited Resource Price Decrement” shall mean, for the 2017/2018 Delivery Year, a difference 
between the clearing price for Limited Demand Resources and the clearing price for Extended 
Summer Demand Resources and Annual Resources, representing the cost to procure additional 
Extended Summer Demand Resources or Annual Resources out of merit order when the Limited 
Resource Constraint is binding. 
List of Approved Contractors: 
“List of Approved Contractors” shall mean a list developed by each Transmission Owner and 
published in a PJM Manual of (a) contractors that the Transmission Owner considers to be 
qualified to install or construct new facilities and/or upgrades or modifications to existing 
facilities on the Transmission Owner’s system, provided that such contractors may include, but 
need not be limited to, contractors that, in addition to providing construction services, also 
provide design and/or other construction-related services, and (b) manufacturers or vendors of 
major transmission-related equipment (e.g., high-voltage transformers, transmission line, circuit 
breakers) whose products the Transmission Owner considers acceptable for installation and use 
on its system. 
Load Interest: 
Page 4

“Load Interest” shall mean, for the purposes of the minimum offer price rule, responsibility for 
serving load within the PJM Region, whether by the Capacity Market Seller, an affiliate of the 
Capacity Market Seller, or by an entity with which the Capacity Market Seller is in contractual 
privity with respect to the subject Generation Capacity Resource. 
Load Management: 
“Load Management” shall mean a Demand Resource (“DR”) as defined in the Reliability 
Assurance Agreement. 
Load Management Event: 
“Load Management Event” shall mean a) a single temporally contiguous dispatch of Demand 
Resources in a Compliance Aggregation Area during an Operating Day, or b) multiple dispatches 
of Demand Resources in a Compliance Aggregation Area during an Operating Day that are 
temporally contiguous.  
Load Ratio Share: 
“Load Ratio Share” shall mean the ratio of a Transmission Customer’s Network Load to the 
Transmission Provider’s total load. 
Load Reduction Event: 
“Load Reduction Event” shall mean a reduction in demand by a Member or Special Member for 
the purpose of participating in the PJM Interchange Energy Market. 
Load Serving Charging Energy: 
“Load Serving Charging Energy” shall mean energy that is purchased from the PJM Interchange 
Energy Market and stored in an Energy Storage Resource or Open-Loop Hybrid Resource for 
later resale to end-use load. 
Load Serving Entity (LSE): 
“Load Serving Entity” or “LSE” shall have the meaning specified in the Reliability Assurance 
Agreement. 
Load Shedding: 
“Load Shedding” shall mean the systematic reduction of system demand by temporarily 
decreasing load in response to transmission system or area capacity shortages, system instability, 
or voltage control considerations under Tariff, Part II or Part III. 
Local Upgrades: 
Page 5

“Local Upgrades” shall mean modifications or additions of facilities to abate any local thermal 
loading, voltage, short circuit, stability or similar engineering problem caused by the 
interconnection and delivery of generation to the Transmission System.  Local Upgrades shall 
include: 
 
 
(i) Direct Connection Local Upgrades which are Local Upgrades that only serve the 
Customer Interconnection Facility and have no impact or potential impact on the Transmission 
System until the final tie-in is complete; and  
 
 
(ii) Non-Direct Connection Local Upgrades which are parallel flow Local Upgrades that 
are not Direct Connection Local Upgrades. 
 
Location: 
 
“Location” as used in the Economic Load Response rules shall mean an end-use customer site as 
defined by the relevant electric distribution company account number. 
 
LOC Deviation:   
 
“LOC Deviation,” shall mean, for units other than wind units, the LOC Deviation shall equal the 
desired megawatt amount for the resource determined according to the point on the Final Offer 
curve corresponding to the Real-time Settlement Interval real-time Locational Marginal Price at 
the resource’s bus and adjusted for any reduction in megawatts due to Regulation, Synchronized 
Reserve, or Secondary Reserve assignments and limited to the lesser of the unit’s Economic 
Maximum or the unit’s Generation Resource Maximum Output, minus the actual output of the 
unit.  For wind units, the LOC Deviation shall mean the deviation of the generating unit’s output 
equal to the lesser of the PJM forecasted output for the unit or the desired megawatt amount for 
the resource determined according to the point on the Final Offer curve corresponding to the 
Real-time Settlement Interval integrated real-time Locational Marginal Price at the resource’s 
bus, and shall be limited to the lesser of the unit’s Economic Maximum or the unit’s Generation 
Resource Maximum Output, minus the actual output of the unit. 
 
Locational Deliverability Area (LDA): 
 
“Locational Deliverability Area” or “LDA” shall mean a geographic area within the PJM Region 
that has limited transmission capability to import capacity to satisfy such area’s reliability 
requirement, as determined by the Office of the Interconnection in connection with preparation 
of the Regional Transmission Expansion Plan, and as specified in Reliability Assurance 
Agreement, Schedule 10.1. 
 
Locational Deliverability Area Reliability Requirement: 
 
“Locational Deliverability Area Reliability Requirement” shall mean the projected internal 
capacity in the Locational Deliverability Area plus the Capacity Emergency Transfer Objective 
for the Delivery Year, as determined by the Office of the Interconnection in connection with 
Page 6

preparation of the Regional Transmission Expansion Plan, less the minimum internal resources 
required for all FRR Entities in such Locational Deliverability Area. 
 
Locational Price Adder: 
 
“Locational Price Adder” shall mean an addition to the marginal value of Unforced Capacity 
within an LDA as necessary to reflect the price of Capacity Resources required to relieve 
applicable binding locational constraints.  
 
Locational Reliability Charge: 
 
“Locational Reliability Charge” shall have the meaning specified in the Reliability Assurance 
Agreement.  
 
Locational UCAP: 
 
“Locational UCAP” shall mean unforced capacity that a Member with available uncommitted 
capacity sells in a bilateral transaction to a Member that previously committed capacity through 
an RPM Auction but now requires replacement capacity to fulfill its RPM Auction commitment.  
The Locational UCAP Seller retains responsibility for performance of the resource providing 
such replacement capacity.   
 
Locational UCAP Seller: 
 
“Locational UCAP Seller” shall mean a Member that sells Locational UCAP. 
 
Long-lead Project: 
 
“Long-lead Project” shall have the same meaning provided in the Operating Agreement. 
 
Long-Term Firm Point-To-Point Transmission Service: 
 
“Long-Term Firm Point-To-Point Transmission Service” shall mean firm Point-To-Point 
Transmission Service under Tariff, Part II with a term of one year or more. 
 
Loss Price: 
 
“Loss Price” shall mean the loss component of the Locational Marginal Price, which is the effect 
on transmission loss costs (whether positive or negative) associated with increasing the output of 
a generation resource or decreasing the consumption by a Demand Resource based on the effect 
of increased generation from or consumption by the resource on transmission losses, calculated 
as specified in Operating Agreement, Schedule 1, section 2, and the parallel provisions of Tariff, 
Attachment K-Appendix, section 2. 
 
M2M Flowgate: 
 
Page 7

“M2M Flowgate” shall have the meaning provided in the Joint Operating Agreement between 
the Midcontinent Independent Transmission System Operator, Inc. and PJM Interconnection, 
L.L.C. 
 
Maintenance Adder:   
 
“Maintenance Adder” shall mean an adder that may be included to account for variable operation 
and maintenance expenses in a Market Seller’s Fuel Cost Policy.  The Maintenance Adder is 
calculated in accordance with the applicable provisions of PJM Manual 15, and may only include 
expenses incurred as a result of electric production. 
 
Manual Load Dump Action: 
 
“Manual Load Dump Action” shall mean an Operating Instruction, as defined by NERC, from 
PJM to shed firm load when the PJM Region cannot provide adequate capacity to meet the PJM 
Region’s load and tie schedules, or to alleviate critically overloaded transmission lines or other 
equipment. 
 
Manual Load Dump Warning: 
 
“Manual Load Dump Warning” shall mean a notification from PJM to warn Members of an 
increasingly critical condition of present operations that may require manually shedding load. 
 
Marginal Value:  
 
“Marginal Value” shall mean the incremental change in system dispatch costs, measured as a 
$/MW value incurred by providing one additional MW of relief to the transmission constraint. 
 
Market Monitor: 
 
“Market Monitor” means the head of the Market Monitoring Unit. 
 
Market Monitoring Unit or MMU: 
 
“Market Monitoring Unit” or “MMU” means the independent Market Monitoring Unit defined in 
18 CFR § 35.28(a)(7) and established under the PJM Market Monitoring Plan (Attachment M) to 
the PJM Tariff that is responsible for implementing the Market Monitoring Plan, including the 
Market Monitor.  The Market Monitoring Unit may also be referred to as the IMM or 
Independent Market Monitor for PJM 
 
Market Monitoring Unit Advisory Committee or MMU Advisory Committee: 
 
“Market Monitoring Unit Advisory Committee” or “MMU Advisory Committee” shall mean the 
committee established under Tariff, Attachment M, section III.H. 
 
Market Operations Center: 
Page 8

“Market Operations Center” shall mean the equipment, facilities and personnel used by or on 
behalf of a Market Participant to communicate and coordinate with the Office of the 
Interconnection in connection with transactions in the PJM Interchange Energy Market or the 
operation of the PJM Region. 
 
Market Participant: 
 
“Market Participant” shall mean a Market Buyer, a Market Seller, an Economic Load Response 
Participant, or all three, except when such term is used in Tariff, Attachment M, in which case 
Market Participant shall mean an entity that generates, transmits, distributes, purchases, or sells 
electricity, ancillary services, or any other product or service provided under the PJM Tariff or 
Operating Agreement within, into, out of, or through the PJM Region, but it shall not include an 
Authorized Government Agency that consumes energy for its own use but does not purchase or 
sell energy at wholesale. 
 
Market Participant Energy Injection: 
 
“Market Participant Energy Injection” shall mean transactions in the Day-ahead Energy Market 
and Real-time Energy Market, including but not limited to Day-ahead generation schedules, real-
time generation output, Increment Offers, internal bilateral transactions and import transactions, 
as further described in the PJM Manuals.  
 
Market Participant Energy Withdrawal: 
 
“Market Participant Energy Withdrawal” shall mean transactions in the Day-ahead Energy 
Market and Real-time Energy Market, including but not limited to Demand Bids, Decrement 
Bids, real-time load (net of Behind The Meter Generation expected to be operating, but not to be 
less than zero), internal bilateral transactions and Export Transactions, as further described in the 
PJM Manuals.  
 
Market Revenue Neutrality Offset:  
 
“Market Revenue Neutrality Offset” shall mean the revenue in excess of the cost for a resource 
from the energy, Synchronized Reserve, Non-Synchronized Reserve, and Secondary Reserve 
markets realized from an increase in real-time market megawatt assignment from a day-ahead 
market megawatt assignment in any of these markets due to the decrease in the real-time reserve 
market megawatt assignment from a day-ahead reserve market megawatt assignment in any of 
the reserve markets. 
 
Market Seller Offer Cap: 
 
“Market Seller Offer Cap” shall mean a maximum offer price applicable to certain Market 
Sellers under certain conditions, as determined in accordance with Tariff, Attachment DD. 
section 6 and Tariff, Attachment M-Appendix, section II.E.    
 
Page 9

Market Violation: 
 
“Market Violation” shall mean a tariff violation, violation of a Commission-approved order, rule 
or regulation, market manipulation, or inappropriate dispatch that creates substantial concerns 
regarding unnecessary market inefficiencies, as defined in 18 C.F.R. § 35.28(b)(8). 
 
Material Modification: 
 
“Material Modification” shall mean any modification to an Interconnection Request that has a 
material adverse effect on the cost or timing of Interconnection Studies related to, or any 
Network Upgrades or Local Upgrades needed to accommodate, any Interconnection Request 
with a later Queue Position. 
 
Maximum Daily Starts: 
 
“Maximum Daily Starts” shall mean the maximum number of times that a generating unit can be 
started in an Operating Day under normal operating conditions. 
 
Maximum Emergency: 
 
“Maximum Emergency” shall mean the designation of all or part of the output of a generating 
unit for which the designated output levels may require extraordinary procedures and therefore 
are available to the Office of the Interconnection only when the Office of the Interconnection 
declares a Maximum Generation Emergency and requests generation designated as Maximum 
Emergency to run.  The Office of the Interconnection shall post on the PJM website the 
aggregate amount of megawatts that are classified as Maximum Emergency. 
 
Maximum Facility Output: 
 
“Maximum Facility Output” shall mean the maximum (not nominal) net electrical power output 
in megawatts, specified in the Interconnection Service Agreement, after supply of any parasitic 
or host facility loads, that a Generation Interconnection Customer’s Customer Facility is 
expected to produce, provided that the specified Maximum Facility Output shall not exceed the 
output of the proposed Customer Facility that Transmission Provider utilized in the System 
Impact Study. 
 
Maximum Generation Emergency: 
 
“Maximum Generation Emergency” shall mean an Emergency declared by the Office of the 
Interconnection to address either a generation or transmission emergency in which the Office of 
the Interconnection anticipates requesting one or more Generation Capacity Resources, or Non-
Retail Behind The Meter Generation resources to operate at its maximum net or gross electrical 
power output, subject to the equipment stress limits for such Generation Capacity Resource or 
Non-Retail Behind The Meter resource in order to manage, alleviate, or end the Emergency. 
 
Maximum Generation Emergency Alert:  
Page 10

“Maximum Generation Emergency Alert” shall mean an alert issued by the Office of the 
Interconnection to notify PJM Members, Transmission Owners, resource owners and operators, 
customers, and regulators that a Maximum Generation Emergency may be declared, for any 
Operating Day in either, as applicable, the Day-ahead Energy Market or the Real-time Energy 
Market, for all or any part of such Operating Day. 
 
Maximum Run Time: 
 
“Maximum Run Time” shall mean the maximum number of hours a generating unit can run over 
the course of an Operating Day, as measured by PJM’s State Estimator. 
 
Maximum State of Charge: 
 
“Maximum State of Charge” shall mean the maximum State of Charge that should not be 
exceeded, measured in units of megawatt-hours. 
 
Maximum Weekly Starts: 
 
“Maximum Weekly Starts” shall mean the maximum number of times that a generating unit can 
be started in one week, defined as the 168 hour period starting Monday 0001 hour, under normal 
operating conditions. 
 
Member: 
  
“Member” shall have the meaning provided in the Operating Agreement. 
 
Merchant A.C. Transmission Facilities: 
 
“Merchant A.C. Transmission Facility” shall mean Merchant Transmission Facilities that are 
alternating current (A.C.) transmission facilities, other than those that are Controllable A.C. 
Merchant Transmission Facilities.  
 
Merchant D.C. Transmission Facilities: 
 
“Merchant D.C. Transmission Facilities” shall mean direct current (D.C.) transmission facilities 
that are interconnected with the Transmission System pursuant to Tariff, Part IV and Part VI.  
 
Merchant Network Upgrades: 
 
“Merchant Network Upgrades” shall mean additions to, or modifications or replacements of, 
physical facilities of the Interconnected Transmission Owner that, on the date of the pertinent 
Transmission Interconnection Customer’s Upgrade Request, are part of the Transmission System 
or are included in the Regional Transmission Expansion Plan. 
 
Merchant Transmission Facilities: 
Page 11

“Merchant Transmission Facilities” shall mean A.C. or D.C. transmission facilities that are 
interconnected with or added to the Transmission System pursuant to Tariff, Part IV and Part VI 
and that are so identified in Tariff, Attachment T, provided, however, that Merchant 
Transmission Facilities shall not include (i) any Customer Interconnection Facilities, (ii) any 
physical facilities of the Transmission System that were in existence on or before March 20, 
2003 ; (iii) any expansions or enhancements of the Transmission System that are not identified as 
Merchant Transmission Facilities in the Regional Transmission Expansion Plan and Attachment 
T to the Tariff, or (iv) any transmission facilities that are included in the rate base of a public 
utility and on which a regulated return is earned. 
 
Merchant Transmission Provider: 
 
“Merchant Transmission Provider” shall mean an Interconnection Customer that (1) owns,  
controls, or controls the rights to use the transmission capability of, Merchant D.C. Transmission 
Facilities and/or Controllable A.C. Merchant Transmission Facilities that connect the 
Transmission System with another control area, (2) has elected to receive Transmission Injection 
Rights and Transmission Withdrawal Rights associated with such facility pursuant to Tariff, Part 
IV, section 36, and (3) makes (or will make) the transmission capability of such facilities 
available for use by third parties under terms and conditions approved by the Commission and 
stated in the Tariff, consistent with Tariff, section 38. 
 
Metering Equipment: 
 
“Metering Equipment” shall mean all metering equipment installed at the metering points 
designated in the appropriate appendix to an Interconnection Service Agreement. 
 
Minimum Annual Resource Requirement: 
 
“Minimum Annual Resource Requirement” shall mean, for Delivery Years through May 31, 
2017,   the minimum amount of capacity that PJM will seek to procure from Annual Resources 
for the PJM Region and for each Locational Deliverability Area for which the Office of the 
Interconnection is required under Tariff, Attachment DD, section 5.10(a) to establish a separate 
VRR Curve for such Delivery Year.  For the PJM Region, the Minimum Annual Resource 
Requirement shall be equal to the RTO Reliability Requirement minus [the Sub-Annual 
Resource Reliability Target for the RTO in Unforced Capacity].  For an LDA, the Minimum 
Annual Resource Requirement shall be equal to the LDA Reliability Requirement minus [the 
LDA CETL] minus [the Sub-Annual Resource Reliability Target for such LDA in Unforced 
Capacity]. The LDA CETL may be adjusted pro rata for the amount of load served under the 
FRR Alternative. 
 
Minimum Down Time: 
 
For all generating units that are not combined cycle units, “Minimum Down Time” shall mean 
the minimum number of hours under normal operating conditions between unit shutdown and 
unit startup, calculated as the shortest time difference between the unit’s generator breaker 
Page 12

opening and after the unit’s generator breaker closure, which is typically indicated by 
telemetered or aggregated State Estimator megawatts greater than zero. For combined cycle 
units, “Minimum Down Time” shall mean the minimum number of hours between the last 
generator breaker opening and after first combustion turbine generator breaker closure, which is 
typically indicated by telemetered or aggregated State Estimator megawatts greater than zero. 
 
Minimum Extended Summer Resource Requirement: 
 
“Minimum Extended Summer Resource Requirement” shall mean, for Delivery Years through 
May 31, 2017, the minimum amount of capacity that PJM will seek to procure from Extended 
Summer Demand Resources and Annual Resources for the PJM Region and for each Locational 
Deliverability Area for which the Office of the Interconnection is required under Tariff, 
Attachment DD, section 5.10(a) to establish a separate VRR Curve for such Delivery Year.  For 
the PJM Region, the Minimum Extended Summer Resource Requirement shall be equal to the 
RTO Reliability Requirement minus [the Limited Demand Resource Reliability Target for the 
PJM Region in Unforced Capacity].  For an LDA, the Minimum Extended Summer Resource 
Requirement shall be equal to the LDA Reliability Requirement minus [the LDA CETL] minus 
[the Limited Demand Resource Reliability Target for such LDA in Unforced Capacity].  The 
LDA CETL may be adjusted pro rata for the amount of load served under the FRR Alternative. 
 
Minimum Generation Emergency: 
 
“Minimum Generation Emergency” shall mean an Emergency declared by the Office of the 
Interconnection in which the Office of the Interconnection anticipates requesting one or more 
generating resources to operate at or below Normal Minimum Generation, in order to manage, 
alleviate, or end the Emergency. 
 
Minimum Participation Requirements: 
 
“Minimum Participation Requirements” shall mean a set of minimum training, risk management, 
communication and capital or collateral requirements required for Participants in the PJM 
Markets, as set forth herein and in the Form of Annual Certification set forth as Tariff, 
Attachment Q, Appendix 1.  Participants transacting in FTRs in certain circumstances will be 
required to demonstrate additional risk management procedures and controls as further set forth 
in the Annual Certification found in Tariff, Attachment Q, Appendix 1. 
 
Minimum Run Time: 
 
For all generating units that are not combined cycle units, “Minimum Run Time” shall mean the 
minimum number of hours a unit must run, in real-time operations, from the time after generator 
breaker closure, which is typically indicated by telemetered or aggregated State Estimator 
megawatts greater than zero, to the time of generator breaker opening, as measured by PJM's 
State Estimator. For combined cycle units, “Minimum Run Time” shall mean the time period 
after the first combustion turbine generator breaker closure, which is typically indicated by 
telemetered or aggregated State Estimator megawatts greater than zero, and the last generator 
breaker opening as measured by PJM’s State Estimator. 
Page 13

Minimum State of Charge: 
 
“Minimum State of Charge” shall mean the minimum State of Charge that should be maintained 
in units of megawatt-hours. 
 
MISO: 
 
“MISO” shall mean the Midcontinent Independent System Operator, Inc. or any successor 
thereto. 
 
Mixed Technology Facility: 
 
“Mixed Technology Facility” shall mean a facility composed of distinct generation and/or 
electric storage technology types behind the same Point of Interconnection.  Co-Located 
Resources and Hybrid Resources form all or part of Mixed Technology Facilities. 
 
MOPR Floor Offer Price: 
 
“MOPR Floor Offer Price” shall mean a minimum offer price applicable to certain Market 
Seller’s Capacity Resources under certain conditions, as determined in accordance with Tariff, 
Attachment DD, sections 5.14(h), 5.14(h-1), and 5.14(h-2). 
 
Multi-Driver Project: 
 
“Multi-Driver Project” shall have the same meaning provided in the Operating Agreement. 
 
Native Load Customers: 
 
“Native Load Customers” shall mean the wholesale and retail power customers of a 
Transmission Owner on whose behalf the Transmission Owner, by statute, franchise, regulatory 
requirement, or contract, has undertaken an obligation to construct and operate the Transmission 
Owner’s system to meet the reliable electric needs of such customers. 
 
Near-Term Transmission Service: 
 
“Near-Term Transmission Service” shall mean Transmission Service which ends not more than 
10 days after the Transmission Service request date.  When the description of obligations below 
refers to either a request for information about the availability of potential Transmission Service 
(including, but not limited to, a request for ATC), or to the posting of ATC or other information 
related to potential service, the date that the information is requested or posted will serve as the 
Transmission Service request date.  “Near-Term Transmission Service” includes any Point-To-
Point Transmission Service and Network Integration Transmission Service where the start and 
end date of the designation or request is within the next 10 days. 
 
NERC: 
Page 14

“NERC” shall mean the North American Electric Reliability Corporation or any successor 
thereto. 
 
NERC Interchange Distribution Calculator: 
 
“NERC Interchange Distribution Calculator” shall mean the NERC mechanism that is in effect 
and being used to calculate the distribution of energy, over specific transmission interfaces, from 
energy transactions. 
 
Net Benefits Test:  
 
“Net Benefits Test” shall mean a calculation to determine whether the benefits of a reduction in 
price resulting from the dispatch of Economic Load Response exceeds the cost to other loads 
resulting from the billing unit effects of the load reduction, as specified in Operating Agreement, 
Schedule 1, section 3.3A.4 and the parallel provisions of Tariff, Attachment K-Appendix, section 
3.3A.4. 
 
Net Cost of New Entry:   
 
“Net Cost of New Entry” shall mean the Cost of New Entry minus the Net Energy and Ancillary 
Service Revenue Offset. 
 
Net Obligation: 
  
“Net Obligation” shall mean the amount owed to PJMSettlement and PJM for purchases from the 
PJM Markets, Transmission Service, (under Tariff, Parts II and III , and other services pursuant 
to the Agreements, after applying a deduction for amounts owed to a Participant by 
PJMSettlement as it pertains to monthly market activity and services.  Should other markets be 
formed such that Participants may incur future Obligations in those markets, then the aggregate 
amount of those Obligations will also be added to the Net Obligation. 
 
Net Sell Position: 
  
“Net Sell Position” shall mean the amount of Net Obligation when Net Obligation is negative. 
 
Network Customer: 
 
“Network Customer” shall mean an entity receiving transmission service pursuant to the terms of 
the Transmission Provider’s Network Integration Transmission Service under Tariff, Part III. 
 
Network External Designated Transmission Service: 
 
“Network External Designated Transmission Service” shall have the meaning set forth in 
Reliability Assurance Agreement, Article I. 
 
Page 15

Network Integration Transmission Service: 
 
“Network Integration Transmission Service” shall mean the transmission service provided under 
Tariff, Part III. 
 
Network Load: 
 
“Network Load” shall mean the load that a Network Customer designates for Network 
Integration Transmission Service under Tariff, Part III.  The Network Customer’s Network Load 
shall include all load (including losses, Non-Dispatched Charging Energy, and Load Serving 
Charging Energy) served by the output of any Network Resources designated by the Network 
Customer.  A Network Customer may elect to designate less than its total load as Network Load 
but may not designate only part of the load at a discrete Point of Delivery.  Where an Eligible 
Customer has elected not to designate a particular load at discrete points of delivery as Network 
Load, the Eligible Customer is responsible for making separate arrangements under Tariff, Part 
II for any Point-To-Point Transmission Service that may be necessary for such non-designated 
load.  Network Load shall not include Dispatched Charging Energy. 
 
Network Operating Agreement: 
 
“Network Operating Agreement” shall mean an executed agreement that contains the terms and 
conditions under which the Network Customer shall operate its facilities and the technical and 
operational matters associated with the implementation of Network Integration Transmission 
Service under Tariff, Part III. 
 
Network Operating Committee: 
 
“Network Operating Committee” shall mean a group made up of representatives from the 
Network Customer(s) and the Transmission Provider established to coordinate operating criteria 
and other technical considerations required for implementation of Network Integration 
Transmission Service under Tariff, Part III.  
 
Network Resource: 
 
“Network Resource” shall mean any designated generating resource owned, purchased, or leased 
by a Network Customer under the Network Integration Transmission Service 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, except for purposes of fulfilling obligations under a reserve sharing 
program. 
 
Network Service User: 
 
“Network Service User” shall mean an entity using Network Transmission Service. 
 
Network Transmission Service: 
Page 16

“Network Transmission Service” shall mean transmission service provided pursuant to the rates, 
terms and conditions set forth in Tariff, Part III, or transmission service comparable to such 
service that is provided to a Load Serving Entity that is also a Transmission Owner. 
 
Network Upgrades: 
 
“Network Upgrades” shall mean modifications or additions to transmission-related facilities that 
are integrated with and support the Transmission Provider’s overall Transmission System for the 
general benefit of all users of such Transmission System. Network Upgrades shall include: 
 
 
(i) Direct Connection Network Upgrades which are Network Upgrades that are not part 
of an Affected System; only serve the Customer Interconnection Facility; and have no impact or 
potential impact on the Transmission System until the final tie-in is complete.  Both 
Transmission Provider and Interconnection Customer must agree as to what constitutes Direct 
Connection Network Upgrades and identify them in the Interconnection Construction Service 
Agreement, Schedule D.  If the Transmission Provider and Interconnection Customer disagree 
about whether a particular Network Upgrade is a Direct Connection Network Upgrade, the 
Transmission Provider must provide the Interconnection Customer a written technical 
explanation outlining why the Transmission Provider does not consider the Network Upgrade to 
be a Direcct Connection Network Upgrade within 15 days of its determination. 
 
 
(ii) Non-Direct Connection Network Upgrades which are parallel flow Network 
Upgrades that are not Direct Connection Network Upgrades. 
 
Neutral Party: 
 
“Neutral Party” shall have the meaning provided in Tariff, Part I, section 9.3(v). 
 
New Entry Capacity Resource with State Subsidy: 
 
“New Entry Capacity Resource with State Subsidy” shall mean (1) starting with the 2022/2023 
Delivery Year, the MWs (in installed capacity) comprising a Capacity Resource with State 
Subsidy that have not cleared in an RPM Auction pursuant to its Sell Offer at or above its 
resource-specific MOPR Floor Offer Price or the applicable default New Entry MOPR Floor 
Offer Price or (2) starting with the Base Residual Auction for the 2022/2023 Delivery Year, any 
of those MWs (in installed capacity) comprising a Capacity Resource with State Subsidy that 
was not included in an FRR Capacity Plan at the time of the Base Residual Auction or the 
subject of a Sell Offer in a Base Residual Auction occurring for a Delivery Year after it last 
cleared an RPM Auction and since then has yet to clear an RPM Auction pursuant to its Sell 
Offer at or above its resource-specific MOPR Floor Offer Price or the applicable default New 
Entry MOPR Floor Offer Price.  Notwithstanding the foregoing, any Capacity Resource that 
previously cleared an RPM Auction before it became entitled to receive a State Subsidy shall not 
be deemed a New Entry Capacity Resource, unless, starting with the Base Residual Auction for 
the 2022/2023 Delivery Year, the Capacity Resource with State Subsidy was not the subject of a 
Page 17

Sell Offer in a Base Residual Auction or included in an FRR Capacity Plan at the time of the 
Base Residual Auction for a Delivery Year after it last cleared an RPM Auction. 
 
New PJM Zone(s): 
 
“New PJM Zone(s)” shall mean the Zone included in the Tariff, along with applicable Schedules 
and Attachments, for Commonwealth Edison Company, The Dayton Power and Light Company 
and the AEP East Operating Companies (Appalachian Power Company, Columbus Southern 
Power Company, Indiana Michigan Power Company, Kentucky Power Company, Kingsport 
Power Company, Ohio Power Company and Wheeling Power Company). 
 
New Service Customers: 
 
“New Service Customers” shall mean all customers that submit an Interconnection Request, a 
Completed Application, or an Upgrade Request that is pending in the New Services Queue. 
 
New Service Request: 
 
“New Service Request” shall mean an Interconnection Request, a Completed Application, or an 
Upgrade Request. 
 
New Services Queue: 
 
“New Services Queue” shall mean all Interconnection Requests, Completed Applications, and 
Upgrade Requests that are received within each six-month period ending on March 31 and 
September 30 of each year shall collectively comprise a New Services Queue. 
 
New York ISO or NYISO: 
 
“New York ISO” or “NYISO” shall mean the New York Independent System Operator, Inc. or 
any successor thereto. 
 
Nodal Reference Price: 
  
The “Nodal Reference Price” at each location shall mean the 97th percentile price differential 
between day-ahead and real-time prices experienced over the corresponding two-month 
reference period in the prior calendar year.   Reference periods will be Jan-Feb, Mar-Apr, May-
Jun, Jul-Aug, Sept-Oct, Nov-Dec.  For any given current-year month, the reference period 
months will be the set of two months in the prior calendar year that include the month 
corresponding to the current month.  For example, July and August 2003 would each use July-
August 2002 as their reference period. 
 
No-load Cost:  
 
“No-load Cost” shall mean the hourly cost required to theoretically operate a synchronized unit 
at zero MW. It consists primarily of the cost of fuel, as determined by the unit’s no load heat 
Page 18

(adjusted by the performance factor) times the fuel cost. It also includes operating costs, 
Maintenance Adders, and emissions allowances. 
 
Nominal Rated Capability: 
 
“Nominal Rated Capability” shall mean the nominal maximum rated capability in megawatts of 
a Transmission Interconnection Customer’s Customer Facility or the nominal increase in 
transmission capability in megawatts of the Transmission System resulting from the 
interconnection or addition of a Transmission Interconnection Customer’s Customer Facility, as 
determined in accordance with pertinent Applicable Standards and specified in the 
Interconnection Service Agreement. 
 
Nominated Demand Resource Value: 
 
“Nominated Demand Resource Value” shall mean the amount of load reduction that a Demand 
Resource commits to provide either through direct load control, firm service level or guaranteed 
load drop programs.  For existing Demand Resources, the maximum Nominated Demand 
Resource Value is limited, in accordance with the PJM Manuals, to the value appropriate for the 
method by which the load reduction would be accomplished, at the time the Base Residual 
Auction or Incremental Auction is being conducted. 
 
Nominated Energy Efficiency Value:  
 
“Nominated Energy Efficiency Value” shall mean the amount of load reduction that an Energy 
Efficiency Resource commits to provide through installation of more efficient devices or 
equipment or implementation of more efficient processes or systems. 
 
Non-Curtailment Charge: 
 
“Non-Curtailment Charge” shall mean the charge applicable to Demand Resources and Price 
Responsive Demand as defined in Tariff, Attachment DD, section 10B(b). 
 
Non-Dispatched Charging Energy:  
 
“Non-Dispatched Charging Energy” shall mean all Direct Charging Energy that an Energy 
Storage Resource Model Participant or Open-Loop Hybrid Resource receives from the electric 
grid that is not otherwise Dispatched Charging Energy. 
 
Non-Firm Point-To-Point Transmission Service: 
 
“Non-Firm Point-To-Point Transmission Service” shall mean Point-To-Point Transmission 
Service under the Tariff that is reserved and scheduled on an as-available basis and is subject to 
Curtailment or Interruption as set forth in Tariff, Part II, section 14.7.  Non-Firm Point-To-Point 
Transmission Service is available on a stand-alone basis for periods ranging from one hour to 
one month. 
 
Page 19

Non-Firm Sale: 
 
“Non-Firm Sale” shall mean an energy sale for which receipt or delivery may be interrupted for 
any reason or no reason, without liability on the part of either the buyer or seller. 
 
Non-Firm Transmission Withdrawal Rights: 
 
“No-Firm Transmission Withdrawal Rights” shall mean the rights to schedule energy 
withdrawals from a specified point on the Transmission System. Non-Firm Transmission 
Withdrawal Rights may be awarded only to a Merchant D.C. Transmission Facility that connects 
the Transmission System to another control area. Withdrawals scheduled using Non-Firm 
Transmission Withdrawal Rights have rights similar to those under Non-Firm Point-to-Point 
Transmission Service. 
 
Non-PAI Event: 
 
“Non-PAI Event” shall mean, effective for the 2028/2029 Delivery Year and subsequent 
Delivery Years, any intervals when a Demand Resource is dispatched or when Price Responsive 
Demand is required to respond and a Performance Assessment Interval is not in effect for such 
intervals for the same registration. 
 
Non-Performance Charge: 
 
“Non-Performance Charge” shall mean the charge applicable to Capacity Performance 
Resources as defined in Tariff, Attachment DD, section 10A(e). 
 
Nonincumbent Developer: 
 
“Nonincumbent Developer” shall have the same meaning provided in the Operating Agreement. 
 
Non-Regulatory Opportunity Cost: 
 “Non-Regulatory Opportunity Cost” shall mean the difference between (a) the forecasted cost to 
operate a specific generating unit when the unit only has a limited number of starts or available 
run hours resulting from (i) the physical equipment limitations of the unit, for up to one year, due 
to original equipment manufacturer recommendations or insurance carrier restrictions, (ii) a fuel 
supply limitation, for up to one year, resulting from an event of Catastrophic Force Majeure; and,  
(b) the forecasted future Locational Marginal Price at which the generating unit could run while 
not violating such limitations.  Non-Regulatory Opportunity Cost therefore is the value 
associated with a specific generating unit’s lost opportunity to produce energy during a higher 
valued period of time occurring within the same period of time in which the unit is bound by the 
referenced restrictions, and is reflected in the rules set forth in PJM Manual 15.  Non-Regulatory 
Opportunity Costs shall be limited to those resources which are specifically delineated in 
Operating Agreement, Schedule 2.  
 
Non-Retail Behind The Meter Generation: 
 
Page 20

“Non-Retail Behind The Meter Generation” shall mean Behind the Meter Generation that is used 
by municipal electric systems, electric cooperatives, or electric distribution companies to serve 
load. 
 
Non-Synchronized Reserve: 
 
“Non-Synchronized Reserve” shall mean the reserve capability of non-emergency generation 
resources that can be converted fully into energy within ten minutes of a request from the Office 
of the Interconnection dispatcher, and is provided by equipment that is not electrically 
synchronized to the Transmission System. 
 
Non-Synchronized Reserve Event: 
 
“Non-Synchronized Reserve Event” shall mean a request from the Office of the Interconnection 
to generation resources able and assigned to provide Non-Synchronized Reserve in one or more 
specified Reserve Zones or Reserve Sub-zones, within ten minutes to increase the energy output 
by the amount of assigned Non-Synchronized Reserve capability. 
 
Non-Variable Loads: 
“Non-Variable Loads” shall have the meaning specified in Operating Agreement, Schedule 1, 
section 1.5A.6, and the parallel provisions of Tariff, Attachment K-Appendix, section 1.5A.6. 
 
Non-Zone Network Load: 
 
“Non-Zone Network Load shall mean Network Load that is located outside of the PJM Region. 
 
Normal Maximum Generation: 
 
“Normal Maximum Generation” shall mean the highest output level of a generating resource 
under normal operating conditions. 
 
Normal Minimum Generation: 
 
“Normal Minimum Generation” shall mean the lowest output level of a generating resource 
under normal operating conditions. 
 
Page 21

ATTACHMENT DD-4 
LARGE LOAD REGISTRY 
Formatted: Font: Bold
Page 22

I. 
[RESERVED] 
 
 
Page 23

III. 
RESPONSBILITIES OF ELECTRIC DISTRIBUTORS 
 
Electric Distributors shall coordinate with the Office of the Interconnection in developing and 
maintaining the Large Load Registry by providing the Office of the Interconnection any 
information or data the Electric Distributor believes appropriate to facilitate an accurate Large 
Load Registry, including applicable state or RERRA retail tariff or contractual obligations. 
 
Page 24

II.
RESPONSBILITIES OF THE OFFICE OF THE INTERCONNECTION
The Office of the Interconnection shall maintain the Large Load Registry, pursuant to Reliability 
Assurance Agreement, Schedule 11. 
Page 25

Revisions to the 
PJM Reliability Assurance Agreement  
(Marked Format) 
Page 26

ARTICLE 1 – DEFINITIONS 
 
 
Unless the context otherwise specifies or requires, capitalized terms used herein shall 
have the respective meanings assigned herein or in the Schedules hereto, or in the PJM Tariff or 
PJM Operating Agreement if not otherwise defined in this Agreement, for all purposes of this 
Agreement (such definitions to be equally applicable to both the singular and the plural forms of 
the terms defined).  Unless otherwise specified, all references herein to Articles, Sections or 
Schedules, are to Articles, Sections or Schedules of this Agreement. As used in this Agreement: 
 
 
Accredited UCAP: 
 
“Accredited UCAP” shall mean the quantity of Unforced Capacity, as denominated in Effective 
UCAP, that an ELCC Resource is capable of providing in a given Delivery Year. 
 
Accredited UCAP Factor: 
 
“Accredited UCAP Factor” shall mean, through the 2024/2025 Delivery Year, one minus 
EFORd, and for 2025/2026 Delivery Year and subsequent Delivery Years, the ratio of the 
Capacity Resource’s Accredited UCAP to the Capacity Resource’s installed capacity. 
 
Agreement: 
 
 
“Agreement” shall mean this Reliability Assurance Agreement, together with all Schedules 
hereto, as amended from time to time. 
 
Annual Demand Resource: 
 
“Annual Demand Resource” shall mean a resource that is placed under the direction of the 
Office of the Interconnection  during the Delivery Year, and will be available for an unlimited 
number of interruptions during such Delivery Year by the Office of the Interconnection, and will 
be capable of maintaining each such interruption between the hours of 10:00AM to 10:00PM 
Eastern Prevailing Time for the months of June through October and the following May, and 
6:00AM through 9:00PM Eastern Prevailing Time for the months of November through April 
unless there is an Office of the Interconnection approved maintenance outage during October 
through April.  The Annual Demand Resource must be available in the corresponding Delivery 
year to be offered for sale or Self-Supplied in an RPM Auction, or included as an Annual 
Demand Resource in an FRR Capacity Plan for the corresponding Delivery Year. 
 
Annual Energy Efficiency Resource: 
 
“Annual Energy Efficiency Resource” shall mean a project, including installation of more 
efficient devices or equipment or implementation of more efficient processes or systems, 
meeting the requirements of  Reliability Assurance Agreement, Schedule 6 and exceeding then-
current building codes, appliance standards, or other relevant standards, designed to achieve a 
continuous (during the summer and winter periods described in such Schedule 6 and the PJM 
Manuals) reduction in electric energy consumption that is not reflected in the peak load forecast 
Page 27

prepared for the Delivery Year for which the Energy Efficiency Resource is proposed, and that is 
fully implemented at all times during such Delivery Year, without any requirement of notice, 
dispatch, or operator intervention. 
 
Applicable Regional Entity: 
 
 
“Applicable Regional Entity” shall have the same meaning as in the PJM Tariff.   
 
Base Capacity Demand Resource: 
 
“Base Capacity Demand Resource” shall mean, for the 2018/2019 and 2019/2020 Delivery 
Years, a resource that is placed under the direction of the Office of the Interconnection and that 
will be available June through September of a Delivery Year, and will be available to the Office 
of the Interconnection for an unlimited number of interruptions during such months, and will be 
capable of maintaining each such interruption for at least a 10-hour duration between the hours 
of 10:00AM to 10:00PM Eastern Prevailing Time.  The Base Capacity Demand Resource must 
be available June through September in the corresponding Delivery Year to be offered for sale or 
self-supplied in an RPM Auction, or included as a Base Capacity Demand Resource in an FRR 
Capacity Plan for the corresponding Delivery Year.   
 
Base Capacity Energy Efficiency Resource:  
 
“Base Capacity Energy Efficiency Resource” shall mean, for the 2018/2019 and 2019/2020 
Delivery Years, a project, including installation of more efficient devices or equipment or 
implementation of more efficient processes or systems, meeting the requirements of RAA, 
Schedule 6 and exceeding then-current building codes, appliance standards, or other relevant 
standards, designed to achieve a continuous (during the summer peak periods as described in 
Reliability Assurance Agreement, Schedule 6 and the PJM Manuals) reduction in electric energy 
consumption that is not reflected in the peak load forecast prepared for the Delivery Year for 
which the Base Capacity Energy Efficiency Resource is proposed, and that is fully implemented 
at all times during such Delivery Year, without any requirement of notice, dispatch, or operator 
intervention. 
 
Base Capacity Resource:  
 
“Base Capacity Resource” shall have the same meaning as in Tariff, Attachment DD. 
 
Base Residual Auction: 
 
 
“Base Residual Auction” shall have the same meaning as in Tariff, Attachment DD. 
 
 
Behind The Meter Generation: 
 
 
“Behind The Meter Generation” shall refer to a generating unit that delivers energy to load 
without using the Transmission System or any distribution facilities (unless the entity that owns 
or leases the distribution facilities consented to such use of the distribution facilities and such 
Page 28

consent has been demonstrated to the satisfaction of the Office of the Interconnection; provided, 
however, that Behind The Meter Generation does not include (i) at any time, any portion of such 
generating unit’s capacity that is designated as a Generation Capacity Resource or DER Capacity 
Aggregation Resource or (ii) in any hour, any portion of the output of such generating unit that is 
sold to another entity for consumption at another electrical location or into the PJM Interchange 
Energy Market. 
 
 
Black Start Capability: 
 
 
“Black Start Capability” shall mean the ability of a generating unit or station to go from a 
shutdown condition to an operating condition and start delivering power without assistance from 
the power system. 
 
 
Capacity Emergency Transfer Objective (CETO): 
 
 
“Capacity Emergency Transfer Objective” or “CETO” shall mean, through the 2024/2025 
Delivery Year, the amount of electric energy that a given area must be able to import in order to 
remain within a loss of load expectation of one event in 25 years when the area is experiencing a 
localized capacity emergency, as determined in accordance with the PJM Manuals.  Without 
limiting the foregoing, CETO shall be, for Delivery Years through 2024/2025, calculated based 
in part on EFORD determined in accordance with Reliability Assurance Agreement, Schedule 5, 
Paragraph C. Beginning with the 2025/2026 Delivery Year, CETO shall mean the amount of 
electric energy that a given area must be able to import in order to satisfy a normalized expected 
unserved energy for the area that is equal to forty percent of the normalized expected unserved 
energy for the RTO when at the annual reliability criteria, where normalized expected unserved 
energy is the expected unserved energy (for the area or RTO, as appropriate) divided by  the 
forecasted annual energy (for the area or RTO, as appropriate), when the area is experiencing a 
localized capacity emergency, as determined in accordance with the PJM Manuals. 
 
 
Capacity Emergency Transfer Limit (CETL): 
 
 
Capacity Emergency Transfer Limit” or “CETL” shall mean the capability of the transmission 
system to support deliveries of electric energy to a given area experiencing a localized capacity 
emergency as determined in accordance with the PJM Manuals. 
 
 
Capacity Import Limit: 
 
For any Delivery Year up to and including the 2019/2020 Delivery Year, “Capacity Import 
Limit” shall mean, (a) for the PJM Region, (1) the maximum megawatt quantity of external 
Generation Capacity Resources that PJM determines for each Delivery Year, through appropriate 
modeling and the application of engineering judgment, the transmission system can receive, in 
aggregate at the interface of the PJM Region with all external balancing authority areas and 
deliver to load in the PJM Region under capacity emergency conditions without violating 
applicable reliability criteria on any bulk electric system facility of 100kV or greater, internal or 
external to the PJM Region, that has an electrically significant response to transfers on such 
interface, minus (2) the then-applicable Capacity Benefit Margin; and (b) for certain source 
Page 29

zones identified in the PJM manuals as groupings of one or more balancing authority areas, (1) 
the maximum megawatt quantity of external Generation Capacity Resources that PJM 
determines the transmission system can receive at the interface of the PJM Region with each 
such source zone and deliver to load in the PJM Region under capacity emergency conditions 
without violating applicable reliability criteria on any bulk electric system facility of 100kV or 
greater, internal or external to the PJM Region, that has an electrically significant response to 
transfers on such interface, minus the then-applicable Capacity Benefit Margin times (2) the ratio 
of the maximum import quantity from each such source zone divided by the PJM total maximum 
import quantity.  As more fully set forth in the PJM Manuals, PJM shall make such 
determination based on the latest peak load forecast for the studied period, the same computer 
simulation model of loads, generation and transmission topography employed in the 
determination of Capacity Emergency Transfer Limit for such Delivery Year, including external 
facilities from an industry standard model of the loads, generation, and transmission topography 
of the Eastern Interconnection under peak conditions.  PJM shall specify in the PJM Manuals the 
areas and minimum distribution factors for identifying monitored bulk electric system facilities 
that have an electrically significant response to such transfers on the PJM interface.  Employing 
such tools, PJM shall model increased power transfers from external areas into PJM to determine 
the transfer level at which one or more reliability criteria is violated on any monitored bulk 
electric system facilities that have an electrically significant response to such transfers.  For the 
PJM Region Capacity Import Limit, PJM shall optimize transfers from other source areas not 
experiencing any reliability criteria violations as appropriate to increase the Capacity Import 
Limit.  The aggregate megawatt quantity of transfers into PJM at the point where any increase in 
transfers on the interface would violate reliability criteria will establish the Capacity Import 
Limit.  Notwithstanding the foregoing, a Capacity Resource located outside the PJM Region 
shall not be subject to the Capacity Import Limit if the Capacity Market Seller seeks an 
exception thereto by demonstrating to PJM, by no later than five (5) business days prior to the 
commencement of the offer period for the relevant RPM Auction, that such resource meets all of 
the following requirements: 
(i)  
it has, at the time such exception is requested, met all applicable requirements to 
be pseudo-tied into the PJM Region, or the Capacity Market Seller has committed in writing that 
it will meet such requirements, unless prevented from doing so by circumstances beyond the 
control of the Capacity Market Seller, prior to the relevant Delivery Year; 
 
(ii)  
at the time such exception is requested, it has long-term firm transmission service 
confirmed on the complete transmission path from such resource into PJM; and 
 
(iii) 
it is, by written commitment of the Capacity Market Seller, subject to the same 
obligations imposed on Generation Capacity Resources located in the PJM Region by Tariff, 
Attachment DD, section 6.6 to offer their capacity into RPM Auctions; provided, however, that 
(a) the total megawatt quantity of all exceptions granted hereunder for a Delivery Year, plus the 
Capacity Import Limit for the applicable interface determined for such Delivery Year, may not 
exceed the total megawatt quantity of Network External Designated Transmission Service on 
such interface that PJM has confirmed for such Delivery Year; and (b) if granting a qualified 
exception would result in a violation of the rule in clause (a), PJM shall grant the requested 
exception but reduce the Capacity Import Limit by the quantity necessary to ensure that the total 
quantity of Network External Designated Transmission Service is not exceeded. 
Page 30

Capacity Only Option: 
 
“Capacity Only Option” shall mean participation in Emergency Load Response Program or Pre-
Emergency Program which allows, pursuant to Tariff, Attachment DD and as applicable, a 
capacity payment for the ability to reduce load during a pre-emergency or emergency event. 
 
Capacity Performance Resource: 
 
“Capacity Performance Resource” shall have the same meaning as in Tariff, Attachment DD. 
 
Capacity Resources: 
 
 
“Capacity Resources” shall mean megawatts of (i) net capacity from Existing Generation 
Capacity Resources or Planned Generation Capacity Resources meeting the requirements of the 
Reliability Assurance Agreement, Schedules 9 and Reliability Assurance Agreement, Schedule 
10 that are or will be owned by or contracted to a Party and that are or will be committed to 
satisfy that Party's obligations under the Reliability Assurance Agreement, or to satisfy the 
reliability requirements of the PJM Region, for a Delivery Year; (ii) net capacity from Existing 
Generation Capacity Resources or Planned Generation Capacity Resources not owned or 
contracted for by a Party which are accredited to the PJM Region pursuant to the procedures set 
forth in such Schedules 9 and 10; or (iii)  load reduction capability provided by Demand 
Resources or Energy Efficiency Resources that are accredited to the PJM Region pursuant to the 
procedures set forth in the Reliability Assurance Agreement, Schedule 6; or (iv) generation and 
load reduction capability provided by a DER Capacity Aggregation Resource, pursuant to the 
procedures set forth in the Reliability Assurance Agreement, Schedule 6.2 and the PJM Manuals. 
 
 
Capacity Resource Provider: 
 
“Capacity Resource Provider” shall mean a Member that (1) owns, or has the contractual 
authority to control the output of, a Generation Capacity Resource, that has not transferred such 
authority to another entity; (2) or a DER Aggregator that has a contractual relationship to use a 
Component DER within a DER Aggregation Resource that is linked to a DER Capacity 
Aggregation Resource. 
 
Capacity Storage Resource Class: 
 
“Capacity Storage Resource Class” shall mean the ELCC Classes specified in Schedules 9.1 and 
9.2, section B of this Agreement, each of which is composed of (1) Capacity Storage Resources 
with the same specified characteristic duration of 4, 6, 8, and 10 hours or; (2) storage device 
Component DER. The characteristic duration of an Energy Storage Resource Class is the ratio of 
the modeled MWh energy storage capability of members of the class to the modeled MW power 
capability of members of the class. 
 
Capacity Transfer Right: 
 
 
Page 31

“Capacity Transfer Right” shall have the meaning specified in Tariff, Attachment DD. 
 
Coal Class: 
 
 
“Coal Class” shall mean an ELCC Class consisting of Unlimited Resources primarily 
fueled by coal. 
 
Combination Resource: 
 
“Combination Resource” shall mean a Generation Capacity Resource, or a generation 
Component DER within a DER Aggregation Resource that is linked to a DER Capacity 
Aggregation Resource, that has a component that has the characteristics of a Limited Duration 
Resource combined with (i) a component that has the characteristics of an Unlimited Resource or 
(ii) a component that has the characteristics of a Variable Resource. 
 
Compliance Aggregation Area (CAA): 
 
“Compliance Aggregation Area” or “CAA” shall have the same meaning as in the Tariff. 
 
Complex Hybrid Class: 
 
“Complex Hybrid Class” shall mean an ELCC Class composed of Combination Resources that 
combine three or more components, whereby one component is a class of Limited Duration 
Resource, and the other components are different Variable Resource classes, and such 
Combination Resources cannot be included in any other Combination Resource class. A resource 
that is a member of a Complex Hybrid Class has a single Point Of Interconnection, unless the 
resource is controlled in an integrated fashion, is at a single site, and is approved by PJM to be 
considered a single resource in accordance with the PJM Manuals. 
 
Consolidated Transmission Owners Agreement, PJM Transmission Owners Agreement or 
Transmission Owners Agreement: 
 
 
“Consolidated Transmission Owners Agreement,” “PJM Transmission Owners Agreement” or 
“Transmission Owners Agreement” shall mean that certain Consolidated Transmission Owners 
Agreement, dated as of December 15, 2005, by and among the Transmission Owners and by and 
between the Transmission Owners and PJM Interconnection, L.L.C. on file with the 
Commission, as amended from time to time. 
 
 
Control Area: 
 
“Control Area” shall mean an electric power system or combination of electric power systems 
bounded by interconnection metering and telemetry to which a common generation control 
scheme is applied in order to: 
 
 
Page 32

(a) 
match the power output of the generators within the electric power system(s) and 
energy purchased from entities outside the electric power system(s), with the load within the 
electric power system(s); 
 
 
 
(b) 
maintain scheduled interchange with other Control Areas, within the limits of 
Good Utility Practice; 
 
 
 
 (c) 
maintain the frequency of the electric power system(s) within reasonable limits in 
accordance with Good Utility Practice and the criteria of NERC and each Applicable Regional 
Entity; 
 
 
 
(d) 
maintain power flows on transmission facilities within appropriate limits to 
preserve reliability; and 
 
 
 
(e) 
provide sufficient generating capacity to maintain operating reserves in 
accordance with Good Utility Practice. 
 
 
Daily Unforced Capacity Obligation: 
 
 
“Daily Unforced Capacity Obligation” shall mean the capacity obligation of a Load Serving 
Entity during the Delivery Year, determined in accordance with the Reliability Assurance 
Agreement, Schedule 8 or, as to an FRR Entity, in the Reliability Assurance Agreement, 
Schedule 8.1. 
 
 
Delivery Year: 
 
 
“Delivery Year” shall mean a Planning Period for which a Capacity Resource is committed 
pursuant to the auction procedures specified in Tariff, Attachment DD or pursuant to an FRR 
Capacity Plan under RAA, Schedule 8.1. 
 
 
Demand Resource (DR): 
 
 
“Demand Resource” or “DR” shall mean a Limited Demand Resource, Extended Summer 
Demand Resource, Annual Demand Resource, Base Capacity Demand Resource or Summer-
Period Demand Resource with a demonstrated capability to provide a reduction in demand or 
otherwise control load in accordance with the requirements of RAA, Schedule 6 that offers and 
that clears load reduction capability in a Base Residual Auction or Incremental Auction or that is 
committed through an FRR Capacity Plan.   
 
Demand Resource Factor or DR Factor: 
 
 
“Demand Resource Factor” or “DR Factor” shall mean, for Delivery Years through May 31, 
2018, that factor approved from time to time by the PJM Board used to determine the unforced 
capacity value of a Demand Resource in accordance with Reliability Assurance Agreement, 
Schedule 6 
 
Page 33

Demand Resource Officer Certification Form: 
 
“Demand Resource Officer Certification Form” shall mean a certification as to an intended 
Demand Resource Sell Offer, in accordance with Reliability Assurance Agreement, Schedule 6 
and Reliability Assurance Agreement, Schedule 8.1 and the PJM Manuals. 
 
 
Demand Resource Registration: 
 
“Demand Resource Registration” shall mean a registration in the Full Program Option or 
Capacity Only Option of the Emergency or Pre-Emergency Load Resource Program in 
accordance with Tariff, Attachment K-Appendix, section 8. 
 
Demand Resource Sell Offer Plan: 
 
“Demand Resource Sell Offer Plan” shall mean the plan required by Reliability Assurance 
Agreement, Schedule 6 and Reliability Assurance Agreement, Schedule 8.1 in support of an 
intended offer of Demand Resources in an RPM Auction, or an intended inclusion of Demand 
Resources in an FRR Capacity Plan. 
 
Diesel Utility Class: 
 
"Diesel Utility Class" shall mean an ELCC Class consisting of Unlimited Resources of the diesel 
technology type that is not primarily fueled by landfill gas. 
 
DER Aggregator Officer Certification Form:  
 
“DER Aggregator Officer Certification Form” shall mean a DER Aggregator’s certification as to 
an intended DER Capacity Aggregation Resource Sell Offer, in accordance with Reliability 
Assurance Agreement, Schedule 6.2 and Reliability Assurance Agreement, Schedule 8.1 and the 
PJM Manuals. 
 
DER Capacity Aggregation Resource Sell Offer Plan:  
 
“DER Capacity Aggregation Resource Sell Offer Plan” shall mean the plan required by 
Reliability Assurance Agreement, Schedule 6.2 and Reliability Assurance Agreement, Schedule 
8.1 in support of an intended offer of a DER Capacity Aggregation Resource in an RPM 
Auction, or an intended inclusion of a DER Capacity Aggregation Resource in an FRR Capacity 
Plan. 
 
Effective Nameplate Capacity: 
 
“Effective Nameplate Capacity” shall mean (i) for each Variable Resource and Combination 
Resource that is a Generation Capacity Resource, the resource’s Maximum Facility Output (or, 
for a Co-Located Resource, the applicable share of the Mixed Technology Facility’s Maximum 
Facility Output); (ii) for each Variable Resource and Combination Resource, that is an individual 
Component DER within a DER Aggregation Resource that is linked to a DER Capacity 
Page 34

Aggregation Resource, the device’s maximum energy production capability, as defined by the 
resource’s state interconnection agreement; or (iii) for each Limited Duration Resource, the 
sustained level of output that the device can provide and maintain over a continuous period, 
whereby the duration of that continuous period matches the characteristic duration of the 
corresponding ELCC Class, with consideration given to ambient conditions expected to exist at 
the time of PJM system peak load, to the extent that such conditions impact such resource’s 
capability, not to exceed the Maximum Facility Output (or, for a Co-Located Resource, the 
applicable share of the Mixed Technology Facility’s Maximum Facility Output).  For the 
2025/2026 Delivery Year and subsequent Delivery Years, the Effective Nameplate Capacity of 
each Limited Duration Resource shall not exceed the greater of the Capacity Interconnection 
Rights of such Limited Duration Resource, or the transitional system capability as limited by the 
transitional resource MW ceiling as defined in the PJM Manuals, awarded for the applicable 
Delivery Year. 
 
Effective UCAP: 
 
“Effective UCAP” shall mean a unit of measure that represents the capacity product transacted in 
the Reliability Pricing Model and included in FRR Capacity Plans.  One megawatt of Effective 
UCAP has the same capacity value of one megawatt of Unforced Capacity. 
 
ELCC Class: 
 
“ELCC Class” shall mean a defined group of ELCC Resources that share a common set of 
operational characteristics and for which effective load carrying capability analysis, as set forth 
in RAA, Schedules 9.1 and 9.2, will establish a unique ELCC Class UCAP and corresponding 
ELCC Class Rating(s). ELCC Classes shall be defined in the Schedules 9.1 and 9.2, section B of 
this Agreement.  Members of an ELCC Class shall share a common method of calculating the 
ELCC Resource Performance Adjustment, provided that the individual ELCC Resource 
Performance Adjustment values will generally differ among ELCC Resources. 
 
ELCC Class Rating: 
 
“ELCC Class Rating” shall mean the rating factor, based on effective load carrying capability 
analysis, that applies to ELCC Resources that are members of an ELCC Class as part of the 
calculation of their Accredited UCAP. 
 
ELCC Class UCAP: 
 
“ELCC Class UCAP” shall mean the aggregate Effective UCAP all modeled ELCC Resources in 
a given ELCC Class are capable of providing in a given Delivery Year.  
 
ELCC Portfolio UCAP: 
 
“ELCC Portfolio UCAP” shall mean the aggregate Effective UCAP that all modeled ELCC 
Resources are capable of providing in a given Delivery Year. 
 
Page 35

ELCC Resource: 
 
“ELCC Resource” shall mean a Component DER within a DER Aggregation Resource that is 
linked to a DER Capacity Aggregation Resource, a Generation Capacity Resource or a Demand 
Resource. 
 
ELCC Resource Performance Adjustment: 
 
“ELCC Resource Performance Adjustment” shall mean the performance of a specific ELCC 
Resource relative to the aggregate performance of the ELCC Class to which it belongs as further 
described in RAA, Schedule 9.1, section F and RAA, Schedule 9.2, section D. 
 
Electric Cooperative: 
 
 
“Electric Cooperative” shall mean an entity owned in cooperative form by its customers that is 
engaged in the generation, transmission, and/or distribution of electric energy. 
 
 
Electric Distributor: 
 
 
“Electric Distributor” shall mean a Member that 1) owns or leases with rights equivalent to 
ownership of electric distribution facilities that are used to provide electric distribution service to 
electric load within the PJM Region; or 2) is a generation and transmission cooperative or a joint 
municipal agency that has a member that owns electric distribution facilities used to provide 
electric distribution service to electric load within the PJM Region. 
 
 
Emergency: 
 
 
“Emergency” shall mean (i) an abnormal system condition requiring manual or automatic action 
to maintain system frequency, or to prevent loss of firm load, equipment damage, or tripping of 
system elements that could adversely affect the reliability of an electric system or the safety of 
persons or property; or (ii) a fuel shortage requiring departure from normal operating procedures 
in order to minimize the use of such scarce fuel; or (iii) a condition that requires implementation 
of emergency procedures as defined in the PJM Manuals. 
 
 
End-Use Customer: 
 
 
“End-Use Customer” shall mean a Member that is a retail end-user of electricity within the 
PJM Region.  For purposes of Members Committee sector classification, a Member that is a 
retail end-user that owns generation may qualify as an End-Use customer if:  (1) the average 
physical unforced capacity owned by the Member and its affiliates in the PJM region over the 
five Planning Periods immediately preceding the relevant Planning Period does not exceed the 
average PJM capacity obligation for the Member and its affiliates over the same time period; or 
(2) the average energy produced by the Member and its affiliates within the PJM region over the 
five Planning Periods immediately preceding the relevant Planning Period does not exceed the 
average energy consumed by that Member and its affiliates within the PJM region over the same 
Page 36

time period.  The foregoing notwithstanding, taking retail service may not be sufficient to qualify 
a Member as an End-Use Customer. 
 
 
 
Energy Efficiency Resource: 
 
 
“Energy Efficiency Resource” shall mean a project, including installation of more efficient 
devices or equipment or implementation of more efficient processes or systems, meeting the 
requirements of RAA, Schedule 6 and exceeding then-current building codes, appliance 
standards, or other relevant standards, designed to achieve a continuous (during the periods 
described in Reliability Assurance Agreement, Schedule 6 and the PJM Manuals) reduction in 
electric energy consumption that is not reflected in the peak load forecast prepared for the 
Delivery Year for which the Energy Efficiency Resource is proposed, and that is fully 
implemented at all times during such Delivery Year, without any requirement of notice, dispatch, 
or operator intervention.  Annual Energy Efficiency Resources, Base Capacity Energy Efficiency 
Resources and Summer-Period Energy Efficiency Resources are types of Energy Efficiency 
Resources. 
 
Exigent Water Storage: 
 
“Exigent Water Storage” shall mean water stored in the pondage or reservoir of a hydropower 
resource which is not typically available during normal operating conditions (as those conditions 
are described in the relevant FERC hydropower license), but which can be drawn upon during 
emergency conditions (as described in the FERC hydropower license), including in order to 
avoid a load shed.  In an effective load carrying capability analysis, exigent storage capability 
from an upstream hydro facility can be considered relative to a downstream hydro facility by 
assessing cascading storage and flows. 
 
Existing Demand Resource: 
 
“Existing Demand Resource” shall mean a Demand Resource for which the Demand Resource 
Provider has identified existing end-use customer sites that are registered for the current Delivery 
Year with PJM (even if not registered by such Demand Resource Provider) and that the Demand 
Resource Provider reasonably expects to have under a contract to reduce load based on PJM 
dispatch instructions by the start of the Delivery Year for which such resource is offered. 
 
Existing DER Capacity Aggregation Resource: 
 
“Existing DER Capacity Aggregation Resource” shall mean a DER Capacity Aggregation 
Resource for which the DER Aggregator has identified existing Component DER that are 
registered in a DER Capacity Aggregation Resource for the current Delivery Year with PJM 
(even if not registered by such DER Aggregator) and that the DER Aggregator reasonably 
expects to have under a contract to generate or reduce load based on PJM dispatch instructions 
by the start of the Delivery Year for which such DER Capacity Aggregation Resource is offered. 
 
Existing Generation Capacity Resource: 
Page 37

“Existing Generation Capacity Resource” shall mean, for purposes of the must-offer requirement 
and mitigation of offers for any RPM Auction for a Delivery Year, a Generation Capacity 
Resource that, as of the date on which bidding commences for such auction: (a) is in service; or 
(b) is not yet in service, but has cleared any RPM Auction for any prior Delivery Year.  A 
Generation Capacity Resource shall be deemed to be in service if interconnection service has 
ever commenced (for resources located in the PJM Region), or if it is physically and electrically 
interconnected to an external Control Area and is in full commercial operation (for resources not 
located in the PJM Region).  The additional megawatts of a Generation Capacity Resource that is 
being, or has been, modified to increase the number of megawatts of available installed capacity 
thereof shall not be deemed to be an Existing Generation Capacity Resource until such time as 
those megawatts (a) are in service; or (b) are not yet in service, but have cleared any RPM 
Auction for any prior Delivery Year. 
 
Extended Summer Demand Resource: 
 
“Extended Summer Demand Resource” shall mean, for Delivery Years through May 31, 2018, 
and for FRR Capacity Plans Delivery Years through May 31, 2019, a resource that is placed 
under the direction of the Office of the Interconnection and that will be available June through 
October and the following May, and will be available for an unlimited number of interruptions 
during such months by the Office of the Interconnection, and will be capable of maintaining each 
such interruption for at least a 10-hour duration between the hours of 10:00AM to 10:00PM 
Eastern Prevailing Time. The Extended Summer Demand Resource must be available June 
through October and the following May in the corresponding Delivery Year to be offered for sale 
or Self-Supplied in an RPM Auction, or included as an Extended Summer Demand Resource in 
an FRR Capacity Plan for the corresponding Delivery Year.   
 
 
Facilities Study Agreement: 
 
 
“Facilities Study Agreement” shall have the same meaning as in Tariff, Part VI, section 206. 
 
 
 
FERC or Commission: 
 
 
“FERC” or “Commission” shall mean the Federal Energy Regulatory Commission or any 
successor federal agency, commission or department exercising jurisdiction over the Tariff, 
Operating Agreement and Reliability Assurance Agreement. 
 
 
Firm Point-To-Point Transmission Service: 
 
 
“Firm Point-To-Point Transmission Service” shall have the meaning specified in the Tariff. 
 
 
Firm Service Level: 
 
“Firm Service Level” or “FSL” of Price Responsive Demand shall mean the level, determined at 
a PRD Substation level, to which Price Responsive Demand shall be reduced during the Delivery 
Year when the Locational Marginal Price exceeds the price associated with such Price 
Page 38

Responsive Demand identified by the PRD Provider in its PRD Plan. “Firm Service Level” or 
“FSL” of Demand Resource shall mean the pre-determined level to which an end-use customer’s 
load shall be reduced, upon notification from the Curtailment Service Provider’s market 
operations center or its agent. 
 
Firm Transmission Service: 
 
 
“Firm Transmission Service” shall mean transmission service that is intended to be available at 
all times to the maximum extent practicable, subject to an Emergency, an unanticipated failure of 
a facility, or other event beyond the control of the owner or operator of the facility or the Office 
of the Interconnection. 
 
 
Fixed Resource Requirement Alternative or FRR Alternative: 
 
 
“Fixed Resource Requirement Alternative” or “FRR Alternative” shall mean an alternative 
method for a Party to satisfy its obligation to provide Unforced Capacity hereunder, as set forth 
in the Reliability Assurance Agreement, Schedule 8.1. 
 
Fixed-Tilt Solar Class: 
 
“Fixed-Tilt Solar Class” shall mean an ELCC Class consisting of Variable Resources that 
produce electrical energy with solar panels that are primarily mounted in a fixed orientation. 
 
 
Forecast Pool Requirement: 
 
 
“Forecast Pool Requirement” or “FPR” shall mean the amount equal to one plus the unforced 
reserve margin (stated as a decimal number) for the PJM Region required pursuant to this 
Reliability Assurance Agreement, as approved by the PJM Board pursuant to Reliability 
Assurance Agreement, Schedule 4.1. 
 
 
FRR Capacity Plan or FRR Plan: 
 
 
“FRR Capacity Plan” or “FRR Plan” shall mean a long-term plan for the commitment of 
Capacity Resources and Price Responsive Demand to satisfy the capacity obligations of a Party 
that has elected the FRR Alternative, as more fully set forth in the Reliability Assurance 
Agreement, Schedule 8.1. 
 
 
FRR Entity: 
 
 
“FRR Entity” shall mean, for the duration of such election, a Party that has elected the FRR 
Alternative hereunder. 
 
 
FRR Service Area: 
 
 
“FRR Service Area” shall mean (a) the service territory of an IOU as recognized by state law, 
rule or order; (b) the service area of a Public Power Entity or Electric Cooperative as recognized 
Page 39

by franchise or other state law, rule, or order; or (c) a separately identifiable geographic area that 
is: (i) bounded by wholesale metering, or similar appropriate multi-site aggregate metering, that 
is visible to, and regularly reported to, the Office of the Interconnection, or that is visible to, and 
regularly reported to an Electric Distributor and such Electric Distributor agrees to aggregate the 
load data from such meters for such FRR Service Area and regularly report such aggregated 
information, by FRR Service Area, to the Office of the Interconnection; and (ii) for which the 
FRR Entity has or assumes the obligation to provide capacity for all load (including load growth) 
within such area.  In the event that the service obligations of an Electric Cooperative or Public 
Power Entity are not defined by geographic boundaries but by physical connections to a defined 
set of customers, the FRR Service Area in such circumstances shall be defined as all customers 
physically connected to transmission or distribution facilities of such Electric Cooperative or 
Public Power Entity within an area bounded by appropriate wholesale aggregate metering as 
described above.   
 
 
Full Program Option: 
 
“Full Program Option” shall mean participation in Emergency Load Response Program or Pre-
Emergency Program which allows, pursuant to Tariff, Attachment DD and as applicable, (i) an 
energy payment for load reductions during a pre-emergency or emergency event, and (ii) a 
capacity payment for the ability to reduce load during a pre-emergency or emergency event. 
 
Full Requirements Service: 
 
 
“Full Requirements Service” shall mean wholesale service to supply all of the power needs of a 
Load Serving Entity to serve end-users within the PJM Region that are not satisfied by its own 
generating facilities. 
 
Gas Combined Cycle Class: 
 
“Gas Combined Cycle Class” shall mean an ELCC Class consisting of Unlimited Resources of 
the combined cycle technology type that is primarily fueled by natural gas, but does not meet the 
requirements to be included in the Gas Combined Cycle Dual Fuel Class. 
 
Gas Combined Cycle Dual Fuel Class: 
 
“Gas Combined Cycle Dual Fuel Class” shall mean an ELCC Class consisting of Unlimited 
Resources of the combined cycle technology type that is primarily fueled by natural gas, and that 
attests that it has the capability to start independently using onsite sources and operate 
independently on alternate onsite fuel source(s) up to its maximum capacity level during the 
winter season of the applicable Delivery Year in which it is providing capacity, and capable of 
operating on the alternate fuel for two 16-hour periods over two consecutive days at its 
maximum capacity level.  
 
Gas Combustion Turbine Class: 
 
Page 40

“Gas Combustion Turbine Class” shall mean an ELCC Class consisting of Unlimited Resources 
of the combustion turbine technology type that is primarily fueled by natural gas, but does not 
meet the requirements to be included in the Gas Combustion Turbine Dual Fuel Class. 
 
Gas Combustion Turbine Dual Fuel Class: 
 
“Gas Combustion Turbine Dual Fuel Class” shall mean an ELCC Class consisting of Unlimited 
Resources of the combustion turbine technology type that is primarily fueled by natural gas, and 
attests that it has the capability to start independently using onsite sources and operate 
independently on alternate onsite fuel source(s) up to its maximum capacity level during the 
winter season of the applicable Delivery Year in which it is providing capacity, and capable of 
operating on the alternate fuel for two 16-hour periods over two consecutive days at its 
maximum capacity level. 
 
 
Generation Capacity Resource: 
 
 
“Generation Capacity Resource” shall mean a Generating Facility, or the contractual right to 
capacity from a specified Generating Facility, that meets the requirements of RAA, Schedule 9 
and RAA, Schedule 10, and, for Generating Facilities that are committed to an FRR Capacity 
Plan, that meets the requirements of RAA, Schedule 8.1.  A Generation Capacity Resource may 
be an Existing Generation Capacity Resource or a Planned Generation Capacity Resource.  
 
Generation Owner: 
 
 
“Generation Owner” shall mean a Member that owns or leases with rights equivalent to 
ownership, or otherwise controls and operates one or more operating generation resources 
located in the PJM Region.  The foregoing notwithstanding, for a planned generation resource to 
qualify a Member as a Generation Owner, such resource shall have cleared an RPM auction, and 
for Energy Resources, the resource shall have a FERC-jurisdictional interconnection agreement 
or wholesale market participation agreement within PJM.   Purchasing all or a portion of the 
output of a generation resource shall not be sufficient to qualify a Member as a Generation 
Owner.  For purposes of Members Committee sector classification, a Member that is primarily a 
retail end-user of electricity that owns generation may qualify as a Generation Owner if:  (1) the 
generation resource is the subject of a FERC-jurisdictional interconnection agreement or 
wholesale market participation agreement within PJM; (2) the average physical unforced 
capacity owned by the Member and its affiliates over the five Planning Periods immediately 
preceding the relevant Planning Period exceeds the average PJM capacity obligation of the 
Member and its affiliates over the same time period; and (3) the average energy produced by the 
Member and its affiliates within PJM over the five Planning Periods immediately preceding the 
relevant Planning Period exceeds the average energy consumed by the Member and its affiliates 
within PJM over the same time period. 
 
 
Generator Forced Outage: 
 
 
“Generator Forced Outage” shall mean an immediate reduction in output or capacity or removal 
from service, in whole or in part, of a generating unit by reason of an Emergency or threatened 
Page 41

Emergency, unanticipated failure, or other cause beyond the control of the owner or operator of 
the facility, as specified in the relevant portions of the PJM Manuals.  A reduction in output or 
removal from service of a generating unit in response to changes in market conditions shall not 
constitute a Generator Forced Outage. 
 
 
Generator Maintenance Outage: 
 
 
“Generator Maintenance Outage” shall mean the scheduled removal from service, in whole or in 
part, of a generating unit in order to perform repairs on specific components of the facility, if 
removal of the facility qualifies as a maintenance outage pursuant to the PJM Manuals. 
 
 
Generator Planned Outage: 
 
 
“Generator Planned Outage” shall mean the scheduled removal from service, in whole or in part, 
of a generating unit for inspection, maintenance or repair with the approval of the Office of the 
Interconnection in accordance with the PJM Manuals. 
 
 
Good Utility Practice: 
 
 
“Good Utility Practice” shall mean any of the practices, methods and acts engaged in or 
approved by a significant portion of the electric utility 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 is intended to include acceptable 
practices, methods, or acts generally accepted in the region; including those practices required by 
Federal Power Act Section 215(a)(4).  
 
 
Hybrid Resource Class: 
 
“Hybrid Resource Class” shall mean the ELCC Classes specified in RAA Schedules 9.1 and 9.2 
Section B.  Each Hybrid Resource Class has a specified combination of two components, 
whereby, absent being part of a Combination Resource, the individual components would be in a 
Capacity Storage Resource Class, a Variable Resource Class or would be an Unlimited 
Resource.  A resource that is a member of a Hybrid Resource Class has a single Point Of 
Interconnection, unless the resource is controlled in an integrated fashion, is at a single site, and 
is approved by PJM to be considered a single resource in accordance with the PJM Manuals. 
 
Hydropower With Non-Pumped Storage: 
 
“Hydropower With Non-Pumped Storage” shall mean a hydropower facility that can capture and 
store incoming stream flow, without use of pumps, in pondage or a reservoir, and the Generation 
Owner has the ability, within the constraints available in the applicable operating license, to exert 
material control over the quantity of stored water and output of the facility throughout an 
Operating Day. 
Page 42

Hydropower With Non-Pumped Storage Class: 
 
“Hydropower With Non-Pumped Storage Class” shall mean an ELCC Class consisting of 
Combination Resources that are Hydropower With Non-Pumped Storage resources. 
 
Incremental Auction: 
 
 
“Incremental Auction” shall mean any of several auctions conducted for a Delivery Year after 
the Base Residual Auction for such Delivery Year and before the first day of such Delivery Year, 
including the First Incremental Auction, Second Incremental Auction, Third Incremental 
Auction, or Conditional Incremental Auction.  Incremental Auctions (other than the Conditional 
Incremental Auction), shall be held for the purposes of: 
 
(i) 
allowing Market Sellers that committed Capacity Resources in the Base Residual 
Auction for a Delivery Year, which subsequently are determined to be unavailable 
to deliver the committed Unforced Capacity in such Delivery Year (due to 
resource retirement, resource cancellation or construction delay, resource 
derating, EFORd increase, Accredited UCAP Factor decrease, a decrease in the 
Nominated Demand Resource Value of a Planned Demand Resource, delay or 
cancellation of a Qualifying Transmission Upgrade, or similar occurrences) to 
submit Buy Bids for replacement Capacity Resources; and  
 
(ii) 
allowing the Office of the Interconnection to reduce or increase the amount of 
committed capacity secured in prior auctions for such Delivery Year if, as a result 
of changed circumstances or expectations since the prior auction(s), there is, 
respectively, a significant excess or significant deficit of committed capacity for 
such Delivery Year, for the PJM Region or for an LDA. 
 
 
Intermittent Hydropower Class: 
 
“Intermittent Hydropower Class” shall mean an ELCC Class consisting of Variable Resources 
that are run-of-river hydropower generators that must generally pass incoming water and 
therefore cannot appreciably store water to later increase the output of the facility. Resources in 
the Intermittent Hydropower Class are not Hydropower with Non-Pumped Storage resources. 
 
IOU: 
 
 
“IOU” shall mean an investor-owned utility with substantial business interest in owning and/or 
operating electric facilities in any two or more of the following three asset categories:  
generation, transmission, distribution. 
 
Intermittent Landfill Gas Class: 
 
Page 43

“Intermittent Landfill Gas Class” shall mean an ELCC Class consisting of Variable Resources 
fueled by landfill gas that, because of fuel availability patterns, cannot run consistently at 
installed capacity levels for 24 or more hours. 
 
Large Load: 
 
“Large Load” shall mean end-use customer(s) load that has a cumulative peak load of 50 
megawatts or greater at a single electrical site behind one or more points of interconnection, 
where for configurations involving multiple affiliated load facilities or multiple points of 
interconnection with affiliated load facilities behind them, all affiliated load facilities within a 
one-mile radius will be considered a single electrical site as further described in the PJM 
Manuals. 
 
Large Load Adjustment: 
 
“Large Load Adjustment” shall mean any MW quantity of adjustments to summer peak load at 
the “zone/area” level and summed by Zone as further detailed in PJM Manuals.  For purposes of 
this definition, a “zone/area” is an area within a Zone for which the relevant Electric Distributor 
specifies a separate Obligation Peak Load MW value.  A zone/area is a service area of an 
Electric Distributor that is a separately identifiable, geographic area bounded by wholesale 
metering (e.g., the service territory of an operating company of a Transmission Owner). 
 
Limited Demand Resource: 
 
 
“Limited Demand Resource” shall mean, for Delivery Years through May 31, 2018, and for FRR 
Capacity Plans Delivery Years through May 31, 2019, a resource that is placed under the 
direction of the Office of the Interconnection and that will, at a minimum, be available for 
interruption for at least 10 Load Management Events during the summer period of June through 
September in the Delivery Year, and will be capable of maintaining each such interruption for at 
least a 6-hour duration.  At a minimum, the Limited Demand Resource shall be available for 
such interruptions on weekdays, other than NERC holidays, from 12:00PM (noon) to 8:00PM 
Eastern Prevailing Time.  The Limited Demand Resource must be available during the summer 
period of June through September in the corresponding Delivery Year to be offered for sale or 
Self-Supplied in an RPM Auction, or included as a Limited Demand Resource in an FRR 
Capacity Plan for the corresponding Delivery Year. 
 
Limited Duration Resource: 
 
“Limited Duration Resource” shall mean a Generation Capacity Resource or a generation 
Component DER within a DER Aggregation Resource that is linked to a DER Capacity 
Aggregation Resource, that is not a Variable Resource, that is not a Combination Resource, and 
that is not capable of running continuously at Maximum Facility Output for 24 hours or longer.  
A Capacity Storage Resource is a Limited Duration Resource. 
 
 
Load Serving Entity or LSE: 
 
 
Page 44

“Load Serving Entity” or “LSE” shall mean any entity (or the duly designated agent of such an 
entity), including a load aggregator or power marketer, (i) serving end-users within the PJM 
Region, and (ii) that has been granted the authority or has an obligation pursuant to state or local 
law, regulation or franchise to sell electric energy to end-users located within the PJM Region.  
Load Serving Entity shall include any end-use customer that qualifies under state rules or a 
utility retail tariff to manage directly its own supply of electric power and energy and use of 
transmission and ancillary services. 
 
 
Locational Reliability Charge: 
 
 
“Locational Reliability Charge” shall mean the charge determined pursuant to RAA, Article 7, 
section 2. 
 
 
Markets and Reliability Committee: 
 
 
“Markets and Reliability Committee” shall mean the committee established pursuant to the 
Operating Agreement as a Standing Committee of the Members Committee.  
 
 
Maximum Emergency Service Level: 
 
“Maximum Emergency Service Level” or “MESL” of Price Responsive Demand for the 
2017/2018 through the 2021/2022 Delivery Years shall mean the level, determined at a PRD 
Substation level, to which Price Responsive Demand shall be reduced during the Delivery Year 
when a Maximum Generation Emergency is declared and the Locational Marginal Price exceeds 
the price associated with such Price Responsive Demand identified by the PRD Provider in its 
PRD Plan. 
 
Member: 
 
 
“Member” shall have the meaning provided in the Operating Agreement. 
 
 
Members Committee: 
 
 
“Members Committee” shall mean the committee specified in Operating Agreement, section 8 
composed of the representatives of all the Members. 
 
 
NERC: 
 
 
“NERC” shall mean the North American Electric Reliability Corporation or any successor 
thereto. 
 
Network External Designated Transmission Service: 
 
“Network External Designated Transmission Service” shall mean the quantity of network 
transmission service confirmed by PJM for use by a market participant to import power and 
energy from an identified Generation Capacity Resource located outside the PJM Region, upon 
Page 45

demonstration by such market participant that it owns such Generation Capacity Resource, has 
an executed contract to purchase power and energy from such Generation Capacity Resource, or 
has a contract to purchase power and energy from such Generation Capacity Resource contingent 
upon securing firm transmission service from such resource. 
 
Network Resources: 
 
 
“Network Resources” shall have the meaning set forth in the PJM Tariff. 
 
 
Network Transmission Service: 
 
 
“Network Transmission Service” shall mean transmission service provided pursuant to the rates, 
terms and conditions set forth in Tariff, Part III or transmission service comparable to such 
service that is provided to a Load Serving Entity that is also a Transmission Owner. 
 
Nominal PRD Value:  
 
“Nominal PRD Value” shall mean, as to any PRD Provider, an adjustment, determined in 
accordance with Reliability Assurance Agreement, Schedule 6.1, to the peak-load forecast used 
to determine the quantity of capacity sought through an RPM Auction, reflecting the aggregate 
effect of Price Responsive Demand on peak load resulting from the Price Responsive Demand to 
be provided by such PRD Provider.    
 
Nominated Demand Resource Value: 
 
 
“Nominated Demand Resource Value” shall have the meaning specified in Tariff, Attachment 
DD. 
 
 
Non-Retail Behind the Meter Generation: 
 
 
“Non-Retail Behind the Meter Generation” shall mean Behind the Meter Generation that is used 
by municipal electric systems, electric cooperatives, and electric distribution companies to serve 
load. 
 
 
Nuclear Class: 
 
“Nuclear Class” shall mean an ELCC Class consisting of Unlimited Resources primarily fueled 
by nuclear fuel. 
 
Obligation Peak Load: 
 
 
“Obligation Peak Load” shall have the meaning specified in Reliability Assurance Agreement, 
Schedule 8. 
 
 
Office of the Interconnection: 
 
 
Page 46

“Office of the Interconnection” shall mean the employees and agents of PJM Interconnection, 
L.L.C., subject to the supervision and oversight of the PJM Board, acting pursuant to the 
Operating Agreement. 
 
Offshore Wind Class: 
 
“Offshore Wind Class” shall mean an ELCC Class consisting of Variable Resources that produce 
electrical energy with offshore wind turbines located in the ocean. 
 
Onshore Wind Class: 
 
“Onshore Wind Class” shall mean an ELCC Class consisting of Variable Resources that produce 
electrical energy using wind turbines and that are not in the Offshore Wind Class. 
 
 
Operating Agreement of the PJM Interconnection, L.L.C., Operating Agreement or PJM 
Operating Agreement: 
 
 
“Operating Agreement of the PJM Interconnection, L.L.C.,”  “Operating Agreement” or “PJM 
Operating Agreement” shall mean that agreement, dated as of April 1, 1997 and as amended and 
restated as of June 2, 1997, including all Schedules, Exhibits, Appendices, addenda or 
supplements hereto, as amended from time to time thereafter, among the Members of the PJM 
Interconnection, L.L.C, on file with the Commission. 
 
 
Operating Day: 
 
“Operating Day” shall have the same meaning as provided in the Operating Agreement. 
 
 
Operating Reserve: 
 
 
“Operating Reserve” shall mean the amount of generating capacity scheduled to be available for 
a specified period of an Operating Day to ensure the reliable operation of the PJM Region, as 
specified in the PJM Manuals. 
 
Ordinary Water Storage: 
 
“Ordinary Water Storage” shall mean water stored in the pondage or reservoir of a hydropower 
resource which is typically available during normal operating conditions pursuant to the FERC 
license governing the operation of the hydropower resource. 
 
 
Other Limited Duration Class: 
 
“Other Limited Duration Class” shall mean the ELCC Classes specified in RAA Schedules 9.1 
and 9.2 section B of this Agreement, each of which has a specified characteristic duration and 
consists of Limited Duration Resources that are not Capacity Storage Resources. The 
characteristic duration of an Other Limited Duration Class is the maximum period of time 
represented in the ELCC model that the resources of the class can run at a stated capability. 
Page 47

Other Limited Duration Combination Class: 
 
“Other Limited Duration Combination Class” shall mean the ELCC Classes specified in RAA 
Schedules 9.1 and 9.2 section B. Each Other Limited Duration Class has a specified combination 
of two components, whereby, absent being part of a Combination Resource, one component 
would be in an Other Limited Duration Class, and the other component would be in a Variable 
Resource Class or would be an Unlimited Resource. A resource that is a member of an Other 
Limited Duration Combination Class has a single Point Of Interconnection, unless the resource is 
controlled in an integrated fashion, is at a single site, and is approved by PJM to be considered a 
single resource in accordance with the PJM Manuals. 
 
Other Supplier: 
 
 
“Other Supplier” shall mean a Member that: (i) is engaged in buying, selling or transmitting 
electric energy, capacity, ancillary services, Financial Transmission Rights or other services 
available under PJM’s governing documents in or through the Interconnection or has a good faith 
intent to do so, and (ii) is not a Generation Owner, Electric Distributor, Transmission Owner or 
End-Use Customer. 
 
 
Other Unlimited Resource Class: 
 
“Other Unlimited Resource Class” shall mean an ELCC Class consisting of Unlimited Resources 
that do not qualify for any other ELCC Class specified in RAA Schedule 9.2, section D. 
 
Other Variable Resource Class: 
 
“Other Variable Resource Class” shall mean an ELCC Class consisting of Variable Resources 
that are not in any other Variable Resource class, including Variable Resources that are 
composed of multiple components, each of which would be a Variable Resource. A resource 
composed of both fixed-tilt solar panels and tracking solar panels is not in this class. A resource 
that is a member of a Other Variable Resource Class has a single Point Of Interconnection, 
unless the resource is controlled in an integrated fashion, is at a single site, and is approved by 
PJM to be considered a single resource in accordance with the PJM Manuals. 
 
Partial Requirements Service: 
 
 
“Partial Requirements Service” shall mean wholesale service to supply a specified portion, but 
not all, of the power needs of a Load Serving Entity to serve end-users within the PJM Region 
that are not satisfied by its own generating facilities. 
 
Party: 
 
“Party” shall mean an entity bound by the terms of the Operating Agreement. 
 
Peak Shaving Adjustment:  
Page 48

“Peak Shaving Adjustment” shall mean a load forecast mechanism that allows load reductions by 
end-use customers to result in a downward adjustment of the summer load forecast for the 
associated Zone. Any End-Use Customer identified in an approved peak shaving plan shall not 
also participate in PJM Markets as Price Responsive Demand, Demand Resource, Base Capacity 
Demand Resource, Capacity Performance Demand Resource, or Economic Load Response 
Participant. 
 
Percentage Internal Resources Required: 
 
 
“Percentage Internal Resources Required” shall mean, for purposes of an FRR Capacity Plan, the 
percentage of the LDA Reliability Requirement for an LDA that must be satisfied with Capacity 
Resources located in such LDA. 
 
Performance Assessment Interval: 
 
“Performance Assessment Interval” shall have the meaning specified in Tariff, Attachment DD. 
 
 
PJM: 
 
 
“PJM” shall mean PJM Interconnection, L.L.C., including the Office of the Interconnection as 
referenced in the PJM Operating Agreement.  When such term is being used in the RAA it shall 
also include the PJM Board. 
 
 
PJM Board: 
 
 
“PJM Board” shall mean the Board of Managers of the  LLC, acting pursuant to the Operating 
Agreement, except when such term is being used in Tariff, Attachment M, in which case PJM 
Board shall mean the Board of Managers of PJM or its designated representative, exclusive of 
any members of PJM Management. 
 
PJM Manuals: 
 
 
“PJM Manuals” shall mean the instructions, rules, procedures and guidelines established by the 
Office of the Interconnection for the operation, planning and accounting requirements of the PJM 
Region. 
 
PJM Region: 
 
 
“PJM Region” shall have the same meaning as provided in the Operating Agreement. 
 
 
PJM Region Installed Reserve Margin: 
 
 
“PJM Region Installed Reserve Margin” shall mean the percent installed reserve margin for the 
PJM Region required pursuant to Reliability Assurance Agreement, Schedule 4.1, as approved 
by the PJM Board. 
Page 49

PJM Tariff, Tariff, O.A.T.T., OATT or PJM Open Access Transmission Tariff: 
 
 
“PJM Tariff,” “Tariff,” “O.A.T.T., “OATT” or “PJM Open Access Transmission Tariff” shall 
mean that certain PJM Open Access Transmission Tariff, including any schedules, appendices, 
or exhibits attached thereto, on file with FERC and as amended from time to time thereafter. 
 
 
Planned Demand Resource: 
 
 
“Planned Demand Resource” shall mean any Demand Resource that does not currently have the 
capability to provide a reduction in demand or to otherwise control load, but that is scheduled to 
be capable of providing such reduction or control on or before the start of the Delivery Year for 
which such resource is to be committed, as determined in accordance with the requirements of 
Reliability Assurance Agreement, Schedule 6.  As set forth in Reliability Assurance Agreement, 
Schedule 6 and Reliability Assurance Agreement, Schedule 8.1, a Demand Resource Provider 
submitting a DR Sell Offer Plan shall identify as Planned Demand Resources in such plan all 
Demand Resources in excess of those that qualify as Existing Demand Resources. 
 
 
Planned DER Capacity Aggregation Resource: 
 
A “Planned DER Capacity Aggregation Resource” shall mean any DER Capacity Aggregation 
Resource that does not currently have the capability to provide generation or reduction in 
demand, but that is scheduled to be capable of providing such generation or reduction in demand 
on or before the start of the Delivery Year for which such resource is to be committed, as 
determined in accordance with the requirements of Reliability Assurance Agreement, Schedule 
6.2.  As set forth in Reliability Assurance Agreement, Schedule 6.2 and Reliability Assurance 
Agreement, Schedule 8.1, a DER Aggregator submitting a DER Capacity Aggregation Resource 
Sell Offer Plan shall identify in such plan all DER Capacity Aggregation Resources in excess of 
those that qualify as Existing DER Capacity Aggregation Resources.  A Planned DER Capacity 
Aggregation Resource must comply with all provisions of the DER Aggregator Participation 
Model described in Tariff, Attachment K-Appendix, section 1.4B and Operating Agreement, 
Schedule 1, section 1.4B, prior to the applicable Delivery Year. 
 
Planned External Generation Capacity Resource: 
 
 
“Planned External Generation Capacity Resource” shall mean a proposed Generation Capacity 
Resource, or a proposed increase in the capability of a Generation Capacity Resource, that (a) is 
to be located outside the PJM Region, (b) participates in the generation interconnection process 
of a Control Area external to PJM, (c) is scheduled to be physically and electrically 
interconnected to the transmission facilities of such Control Area on or before the first day of the 
Delivery Year for which such resource is to be committed to satisfy the reliability requirements 
of the PJM Region, and (d) is in full commercial operation prior to the first day of such Delivery 
Year, such that it is sufficient to provide the Installed Capacity set forth in the Sell Offer forming 
the basis of such resource’s commitment to the PJM Region.  Prior to participation in any Base 
Residual Auction for such Delivery Year, the Capacity Market Seller must demonstrate that it 
has documentation which is functionally equivalent to an approved Decision Point I submission 
Page 50

under the PJM Tariff Part VII or VIII as applicable or, for resources which are greater than 
20MWs participating in a Base Residual Auction for the 2019/2020 Delivery Year and 
subsequent Delivery Years, an agreement or other documentation which is functionally 
equivalent to an approved Decision Point II submission under the PJM Tariff Part VII or VIII as 
applicable, with the transmission owner to whose transmission facilities or distribution facilities 
the resource is being directly connected, and, as applicable, the transmission provider.  Prior to 
participating in any Incremental Auction for such Delivery Year, the Capacity Market Seller 
must demonstrate it has entered into an interconnection agreement, or such other documentation 
that is functionally equivalent to a Generation Interconnection Agreement under the PJM Tariff, 
with the transmission owner to whose transmission facilities or distribution facilities the resource 
is being directly connected, and, as applicable, the transmission provider.  A Planned External 
Generation Capacity Resource must provide evidence to PJM that it has been studied as a 
Network Resource, or such other similar interconnection product in such external Control Area, 
must provide contractual evidence that it has applied for or purchased transmission service to be 
deliverable to the PJM border, and must provide contractual evidence that it has applied for 
transmission service to be deliverable to the bus at which energy is to delivered, the agreements 
for which must have been executed prior to participation in any Reliability Pricing Model 
Auction for such Delivery Year. Any such resource shall cease to be considered a Planned 
External Generation Capacity Resource as of the earlier of (i) the date that interconnection 
service commences as to such resource; or (ii) the resource has cleared an RPM Auction, in 
which case it shall become an Existing Generation Capacity Resource for purposes of the 
mitigation of offers for any RPM Auction for all subsequent Delivery Years.   
 
 
Planned Generation Capacity Resource: 
 
 
“Planned Generation Capacity Resource” shall mean a Generation Capacity Resource, or 
additional megawatts to increase the size of a Generation Capacity Resource that is being or has 
been modified to increase the number of megawatts of available installed capacity thereof,  
participating in the generation interconnection process under Tariff, Part IV, Subpart A, Part VII 
or Part VIII, as applicable, for which: (i) Interconnection Service is scheduled to commence on 
or before the first day of the Delivery Year for which such resource is to be committed to RPM 
or to an FRR Capacity Plan; (ii) for any such resource seeking to offer into a Base Residual 
Auction, or for any such resource of 20 MWs or less seeking to offer into a Base Residual 
Auction, all the requirements for an approved Decision Point I submission have been met under 
Tariff Part VII or VIII (or, for resources for which a Decision Point I submission is not required, 
has such other agreement or documentation that is functionally equivalent to a an approved 
Decision Point I submission) prior to the Base Residual Auction for such Delivery Year; (iii) for 
any such resource of more than 20 MWs seeking to offer into a Base Residual Auction for the 
2019/2020 Delivery Year and subsequent Delivery Years, all the requirements for an approved 
Decision Point II submission have been met under Tariff Part VII or VIII (or, for resources for 
which a Decision Point II submission is not required, has such other agreement or documentation 
that is functionally equivalent to an approved Decision Point II submission) has been executed 
prior to the Base Residual Auction for such Delivery Year; and (iv) a Generation Interconnection 
Agreement or Wholesale Market Participation Agreement has been executed prior to any 
Incremental Auction for such Delivery Year in which such resource plans to participate.  For 
purposes of the must-offer requirement and mitigation of offers for any RPM Auction for a 
Page 51

Delivery Year, a Generation Capacity Resource shall cease to be considered a Planned 
Generation Capacity Resource as of the earlier of (i) the date that Interconnection Service 
commences as to such resource; or (ii) the resource has cleared an RPM Auction for any 
Delivery Year, in which case it shall become an Existing Generation Capacity Resource for any 
RPM Auction for all subsequent Delivery Years.   
 
 
Planning Period: 
 
 
“Planning Period” shall mean the 12 months beginning June 1 and extending through May 31 of 
the following year, or such other period approved by the Members Committee. 
 
 
Portfolio Expected Unserved Energy: 
 
“Portfolio Expected Unserved Energy” shall mean the annual amount of expected unserved 
energy, in MWh, that is expected for the RTO when at the annual reliability criteria that provides 
an acceptable level of reliability consistent with the Reliability Principles and Standards. 
 
PRD Curve: 
 
“PRD Curve” shall mean a price-consumption curve at a PRD Substation level, if available, and 
otherwise at a Zonal (or sub-Zonal LDA, if applicable) level, that details the base consumption 
level of Price Responsive Demand and the decreasing consumption levels at increasing prices. 
 
PRD Provider:  
 
“PRD Provider” shall mean a PJM Member that has entered contractual arrangements with end-
use customers that satisfy the eligibility criteria for and provides Price Responsive Demand. 
 
PRD Provider’s Zonal Expected Peak Load Value of PRD:  
 
“PRD Provider’s Zonal Expected Peak Load Value of PRD” shall mean the expected 
contribution to Delivery Year peak load of a PRD Provider’s Price Responsive Demand, were 
such demand not to be reduced in response to price, based on the contribution of the end-use 
customers comprising such Price Responsive Demand to the most recent prior Delivery Year’s 
peak demand, escalated to the Delivery Year in question, as determined in a manner consistent 
with the Office of the Interconnection’s load forecasts used for purposes of the RPM Auctions. 
 
PRD Reservation Price: 
 
“PRD Reservation Price” shall mean an RPM Auction clearing price identified in a PRD Plan for 
Price Responsive Demand load below which the PRD Provider desires not to commit the 
identified load as Price Responsive Demand. 
  
PRD Substation: 
 
Page 52

“PRD Substation” shall mean an electrical substation that is located in the same Zone or in the 
same sub-Zonal LDA as the end-use customers identified in a PRD Plan or PRD registration and 
that, in terms of the electrical topography of the Transmission Facilities comprising the PJM 
Region, is as close as practicable to such loads. 
 
Price Responsive Demand: 
 
“Price Responsive Demand” or “PRD” shall mean end-use customer load registered by a PRD 
Provider pursuant to Reliability Assurance Agreement, Schedule 6.1 that have, as set forth in 
more detail in the PJM Manuals, the metering capability to record electricity consumption at an 
interval of one hour or less, Supervisory Control capable of curtailing such load (consistent with 
applicable RERRA requirements) at each PRD Substation identified in the relevant PRD Plan or 
PRD registration in response to a Performance Assessment Interval that triggers a PRD 
performance assessment or a Non-PAI Event, and a retail rate structure, or equivalent contractual 
arrangement, capable of changing retail rates as frequently as an hourly basis, that is linked to or 
based upon changes in real-time Locational Marginal Prices at a PRD Substation level and that 
results in a predictable automated response to varying wholesale electricity prices. 
 
Price Responsive Demand Credit: 
 
“Price Responsive Demand Credit” shall mean a credit, based on committed Price Responsive 
Demand, as determined under Reliability Assurance Agreement, Schedule 6.1. 
 
Price Responsive Demand Plan or PRD Plan: 
 
“Price Responsive Demand Plan” or “PRD Plan” shall mean a plan, submitted by a PRD 
Provider and received by the Office of the Interconnection in accordance with Reliability 
Assurance Agreement, Schedule 6.1 and procedures specified in the PJM Manuals, claiming a 
peak demand limitation due to Price Responsive Demand to support the determination of such 
PRD Provider’s Nominal PRD Value. 
 
Public Power Entity: 
 
 
“Public Power Entity” shall mean any agency, authority, or instrumentality of a state or of a 
political subdivision of a state, or any corporation wholly owned by any one or more of the 
foregoing, that is engaged in the generation, transmission, and/or distribution of electric energy. 
 
 
Qualifying Transmission Upgrades: 
 
 
“Qualifying Transmission Upgrades” shall have the meaning specified in Tariff, Attachment DD. 
 
 
Relevant Electric Retail Regulatory Authority: 
 
“Relevant Electric Retail Regulatory Authority” or “RERRA” shall have the meaning specified 
in the PJM Operating Agreement. 
 
Page 53

Reliability Principles and Standards: 
 
 
“Reliability Principles and Standards” shall mean the principles and standards established by  the 
Office of the Interconnection that define, among other things, an acceptable probabilistic of loss 
of load criteria due to inadequate generation or transmission capability, as amended from time to 
time. 
 
 
Required Approvals: 
 
 
“Required Approvals” shall mean all of the approvals required for the Operating Agreement to 
be modified or to be terminated, in whole or in part, including the acceptance for filing by FERC 
and every other regulatory authority with jurisdiction over all or any part of the Operating 
Agreement. 
 
 
Self-Supply: 
 
 
“Self-Supply” shall have the meaning provided in Tariff, Attachment DD. 
 
Small Commercial Customer: 
 
“Small Commercial Customer” shall have the same meaning as in the PJM Tariff. 
 
 
State Consumer Advocate: 
 
 
“State Consumer Advocate” shall mean a legislatively created office from any State, all or any 
part of the territory of which is within the PJM Region, and the District of Columbia established, 
inter alia, for the purpose of representing the interests of energy consumers before the utility 
regulatory commissions of such states and the District of Columbia and the FERC.  
 
 
State Regulatory Structural Change: 
 
 
“State Regulatory Structural Change” shall mean as to any Party, a state law, rule, or order that, 
after September 30, 2006, initiates a program that allows retail electric consumers served by such 
Party to choose from among alternative suppliers on a competitive basis, terminates such a 
program, expands such a program to include classes of customers or localities served by such 
Party that were not previously permitted to participate in such a program, or that modifies retail 
electric market structure or market design rules in a manner that materially increases the 
likelihood that a substantial proportion of the customers of such Party that are eligible for retail 
choice under such a program (a) that have not exercised such choice will exercise such choice; or 
(b) that have exercised such choice will no longer exercise such choice, including for example, 
without limitation, mandating divestiture of utility-owned generation or structural changes to 
such Party’s default service rules that materially affect whether retail choice is economically 
viable. 
 
Steam Class: 
 
Page 54

“Steam Class” shall mean an ELCC Class consisting of Unlimited Resources of the steam 
technology type and the primary fuel is not coal or nuclear. 
 
Summer-Period Demand Resource: 
 
Summer-Period Demand Resource shall mean, for the 2020/2021 Delivery Year and subsequent 
Delivery Years, a resource that is placed under the direction of the Office of the Interconnection, 
and will be available June through October and the following May of the Delivery Year, and will 
be available for an unlimited number of interruptions during such months by the Office of the 
Interconnection, and will be capable of maintaining each such interruption between the hours of 
10:00AM to 10:00PM Eastern Prevailing Time.  The Summer-Period Demand Resource must be 
available June through October and the following May in the corresponding Delivery Year to be 
offered for sale in an RPM Auction, or included as a Summer-Period Demand Resource in an 
FRR Capacity Plan for the corresponding Delivery Year. 
 
Summer-Period Energy Efficiency Resource:  
 
Summer-Period Energy Efficiency Resource shall mean, for the 2020/2021 Delivery Year and 
subsequent Delivery Years, a project, including installation of more efficient devices or 
equipment or implementation of more efficient processes or systems, meeting the requirements 
of Reliability Assurance Agreement, Schedule 6 and exceeding then-current building codes, 
appliance standards, or other relevant standards, designed to achieve a continuous (during the 
summer peak periods as described in Reliability Assurance Agreement, Schedule 6 and the PJM 
Manuals) reduction in electric energy consumption that is not reflected in the peak load forecast 
prepared for the Delivery Year for which the Summer-Period Energy Efficiency Resource is 
proposed, and that is fully implemented at all times during such Delivery Year, without any 
requirement of notice, dispatch, or operator intervention. 
 
Supervisory Control: 
 
“Supervisory Control” shall mean the capability to curtail, in accordance with applicable 
RERRA requirements, load registered as Price Responsive Demand at each PRD Substation 
identified in the relevant PRD Plan or PRD registration in response to a Maximum Generation 
Emergency declared by the Office of the Interconnection.  Except to the extent automation is not 
required by the provisions of the Operating Agreement, the curtailment shall be automated, 
meaning that load shall be reduced automatically in response to control signals sent by the PRD 
Provider or its designated agent directly to the control equipment where the load is located 
without the requirement for any action by the end-use customer. 
 
 
Threshold Quantity: 
 
 
“Threshold Quantity” shall mean, as to any FRR Entity for any Delivery Year, the sum of (a) the 
Unforced Capacity equivalent (determined using the Pool-Wide Average EFORD through the 
2024/2025 Delivery Year, or pool-wide average Accredited UCAP Factor effective with the 
2025/2026 Delivery Year) of the Installed Reserve Margin for such Delivery Year multiplied by 
the Preliminary Forecast Peak Load for which such FRR Entity is responsible under its FRR 
Page 55

Capacity Plan for such Delivery Year, plus (b) the lesser of (i) 3% of the Unforced Capacity 
amount determined in (a) above or (ii) 450 MW.  If the FRR Entity is not responsible for all load 
within a Zone, the Preliminary Forecast Peak Load for such entity shall be determined in 
accordance with Reliability Assurance Agreement, Schedule 8.1, section D.2. 
 
 
Tracking Solar Class: 
 
“Tracking Solar Class” shall mean an ELCC Class consisting of Variable Resources that produce 
electrical energy with solar panels that are primarily mounted on trackers that align the panels 
with incoming sunlight over the course of the day. 
 
Transmission Facilities: 
 
 
“Transmission Facilities” shall mean facilities that:  (i) are within the PJM Region; (ii) meet the 
definition of transmission facilities pursuant to FERC’s Uniform System of Accounts or have 
been classified as transmission facilities in a ruling by FERC addressing such facilities; and (iii) 
have been demonstrated to the satisfaction of the Office of the Interconnection to be integrated 
with the PJM Region transmission system and integrated into the planning and operation of the 
PJM Region to serve all of the power and transmission customers within the PJM Region. 
 
 
Transmission Owner: 
 
 
“Transmission Owner” shall mean a Member that owns or leases with rights equivalent to 
ownership Transmission Facilities and is a signatory to the PJM Transmission Owners 
Agreement.  Taking transmission service shall not be sufficient to qualify a Member as a 
Transmission Owner. 
 
 
Unforced Capacity: 
 
 
“Unforced Capacity” shall mean installed capacity rated at summer conditions that is not on 
average experiencing a forced outage or forced derating, calculated for each Capacity Resource 
on the 12-month period from October to September without regard to the ownership of or the 
contractual rights to the capacity of the unit. 
 
Unlimited Resource: 
 
“Unlimited Resource” shall mean a generating unit having the ability to maintain output at a 
stated capability continuously on a daily basis without interruption.  Through the 2024/2025 
Delivery Year, an Unlimited Resource is a Generation Capacity Resource that is not an ELCC 
Resource. 
 
Variable Resource: 
 
“Variable Resource” shall mean a Generation Capacity Resource or a generation Component 
DER within a DER Aggregation Resource that is linked to a DER Capacity Aggregation 
Resource, with output that can vary as a function of its energy source, such as wind, solar, run of 
Page 56

river hydroelectric power without storage, and landfill gas units without an alternate fuel source.  
All Intermittent Resources are Variable Resources, with the exception of Hydropower with Non-
Pumped Storage. 
 
 
Winter Peak Load (or WPL): 
 
“Winter Peak Load” or “WPL” shall mean the average of the Demand Resource customer’s 
specific peak hourly load between hours ending 7:00 EPT through 21:00 EPT on the PJM 
defined 5 coincident peak days from December through February two Delivery Years prior the 
Delivery Year for which the registration is submitted.  Notwithstanding, if the average use 
between hours ending 7:00 EPT through 21:00 EPT on a winter 5 coincident peak day is below 
35% of the average hours ending 7:00 EPT through 21:00 EPT over all five of such peak days, 
then up to two such days and corresponding peak demand values may be excluded from the 
calculation.  Upon approval by the Office of the Interconnection, a Curtailment Service Provider 
may provide alternative data to calculate Winter Peak Load, as outlined in the PJM Manuals, 
when there is insufficient hourly load data for the two Delivery Years prior to the relevant 
Delivery Year or if more than two days meet the exclusion criteria described above. 
 
Zonal Capacity Price: 
 
 
“Zonal Capacity Price” shall mean the clearing price required in each Zone to meet the demand 
for Unforced Capacity and satisfy Locational Deliverability Requirements for the LDA or LDAs 
associated with such Zone.  If the Zone contains multiple LDAs with different Capacity 
Resource Clearing Prices, the Zonal Capacity Price shall be a weighted average of the Capacity 
Resource Clearing Prices for such LDAs, weighted by the Unforced Capacity of Capacity 
Resources cleared in each such LDA.   
 
 
Zone or Zonal: 
 
 
“Zone” or “Zonal” shall refer to an area within the PJM Region, as set forth in Tariff, 
Attachment J and RAA, Schedule 15, or as such areas may be (i) combined as a result of mergers 
or acquisitions or (ii) added as a result of the expansion of the boundaries of the PJM Region.  A 
Zone shall include any Non-Zone Network Load located outside the PJM Region that is served 
from such Zone under Tariff, Attachment H-A. 
 
Zonal Winter Weather Adjustment Factor (ZWWAF): 
 
“Zonal Winter Weather Adjustment Factor” or “ZWWAF” shall mean the PJM zonal winter 
weather normalized  coincident peak  divided by PJM zonal average of 5 coincident peak loads in 
December through February. 
 
Page 57

SCHEDULE 11 
 
DATA SUBMITTALS 
 
A. 
To perform the studies required to determine the Forecast Pool Requirement and Daily 
Unforced Capacity Obligations under this Agreement and to determine compliance with the 
obligations imposed by this Agreement, each Party and other owner of a Capacity Resource shall 
submit data to the Office of the Interconnection in conformance with the following minimum 
requirements: 
 
1. 
All data submitted shall satisfy the requirements, as they may change from time to time, of 
any procedures adopted by the Members Committee. 
 
2. 
Data shall be submitted in an electronic format, or as otherwise specified by the Markets 
and Reliability Committee and approved by the PJM Board. 
 
3. 
Actual outage data for each month for Generator Forced Outages, Generator Maintenance 
Outages and Generator Planned Outages shall be submitted so that it is received by such 
date specified in the PJM Manuals. 
 
4. 
On or before the date specified in the PJM Manuals, planned and maintenance outage data 
for all Generation Resources shall be submitted. 
 
 
 
 
 
 
 
 
 
The Parties acknowledge that additional information required to determine the Forecast Pool 
Requirement is to be obtained by the Office of the Interconnection from Electric Distributors in 
accordance with the provisions of the Operating Agreement. 
 
B. 
1. 
(a) 
Each entity bound by the Operating Agreement shall submit, or cause to be 
submitted, to the Office of the Interconnection the following information, as may be further 
described in the PJM Manuals, related to each Large Load served by the entity bound by 
the Operating Agreement: 
 
• Eligible Customer/Network Customer for Large Load; 
• Description of Large Load; 
• Location(s) (Control Zone, Electric Distributor zone/area, where a 
zone/area is an area within a Zone for which the relevant Electric 
Distributor specifies a separate Obligation Peak Load MW value. A 
Page 58

zone/area is a service area of an Electric Distributor that is a separately 
identifiable, geographic area bounded by wholesale metering); 
• In-service date for each increment of load; 
• Peak shaving adjustment value pursuant to a state program codified in 
state law and whether and how it meets the requirements of Tariff, 
Attachment DD-2; 
• Delivery point / Point(s) of interconnection (include all if more than 
one); 
• Peak load quantity (MW) and ramp schedule, if applicable; 
• Telemetry specifications; 
• Backup generation (MW), including fuel type and relevant permitting 
limitations; 
• Contracts or service agreements between the Large Load and the LSE; 
• Points of contact at the applicable Transmission Owner, Electric 
Distributor, and Load Serving Entity; 
• EMS B1/B2/B3 name (for the applicable Transmission Owner, Electric 
Distributor); and  
• Additional details and contents as necessary, in accordance with the 
PJM Manuals. 
 
(b) 
The entities bound by the Operating Agreement acknowledge that 
information related to the development and maintenance of the Large Load Registry may 
be obtained by the Office of the Interconnection from Electric Distributors in accordance 
with the provisions of the Operating Agreement and the Tariff.   
 
(c) 
The Office of the Interconnection may review information and coordinate 
with the applicable Transmission Owner and Electric Distributor as needed, regarding the 
validity of the information provided, including through requesting additional information 
as the Office of the Interconnection deems necessary, as further set forth in the PJM 
Manuals.  The Office of the Interconnection also may consult with the Large Load. 
 
(d) 
Based on the information provided, or caused to be provided, by each entity 
bound by the Operating Agreement, as well as other information provided by, for example, 
Electric Distributors, the Office of the Interconnection shall maintain a registry of all Large 
Loads, and update it periodically.  To the extent such documents, data, or other information 
provided to the Office of the Interconnection has been designated as confidential by an 
entity bound by the Operating Agreement, Electric Distributor, or other entity supplying 
the information, the Office of the Interconnection shall maintain the confidentiality of the 
information provided under this RAA, Schedule 11, section B consistent with its 
obligations under Operating Agreement, section 18.17.  Information maintained in the 
Large Load registry may be available to Authorized Commissions, Transmission Owners, 
Electric Distributors, Load Serving Entities, the Market Monitoring Unit, and FERC 
subject to appropriate data protection safeguards required by Operating Agreement, section 
18.17. 
 
Page 59

(e) 
The Office of the Interconnection shall post aggregate data from the Large 
Load Registry on the PJM website, aggregated by Electric Distributor zone/area, where 
possible and in a manner consistent with existing confidentiality protections in the PJM 
Governing Agreements. 
 
2. 
(a) 
Each entity bound by the Operating Agreement serving or contracted to 
serve a Large Load that is or will be in service prior to June 1, 2027, shall provide the 
information required by RAA, Schedule 11.B.1 to the Office of the Interconnection by 
March 1, 2027.  
 
(b) 
Each entity bound by the Operating Agreement serving or contracted to 
serve a Large Load that will be in service on or after June 1, 2027, shall provide the 
information required by RAA, Schedule 11.B.1 to the Office of the Interconnection before 
the in-service date of the Large Load. 
 
Each entity bound by the Operating Agreement shall promptly inform the Office of the 
Interconnection of any change in the information required by RAA, Schedule 11.B.1 with 
respect to a Large Load served by such entity bound by the Operating Agreement, including 
whether the entity bound by the Operating Agreement no longer serves the Large Load or 
has acquired the contractual right to serve a registered Large Load. 
Page 60

Attachment B 
Revisions to the  
PJM Open Access Transmission Tariff and 
Reliability Assurance Agreement 
(Clean Format) 
(Identified by Additional Cover Pages) 
Page 1

Revisions to the 
PJM Open Access Transmission Tariff  
(Clean Format) 
Page 2

Definitions – L – M – N 
Large Load: 
“Large Load” shall have the meaning provided in the Reliability Assurance Agreement. 
Legacy Policy: 
“Legacy Policy” shall mean any legislative, executive, or regulatory action that specifically 
directs a payment outside of PJM Markets to a designated or prospective Generation Capacity 
Resource and the enactment of such action predates October 1, 2021, regardless of when any 
implementing governmental action to effectuate the action to direct payment outside of PJM 
Markets occurs. 
Limited Demand Resource: 
“Limited Demand Resource” shall have the meaning specified in the Reliability Assurance 
Agreement. 
Limited Demand Resource Reliability Target: 
“Limited Demand Resource Reliability Target” for the PJM Region or an LDA, shall mean the 
maximum amount of Limited Demand Resources determined by PJM to be consistent with the 
maintenance of reliability, stated in Unforced Capacity that shall be used to calculate the 
Minimum Extended Summer Demand Resource Requirement for Delivery Years through May 
31, 2017 and the Limited Resource Constraint for the 2017/2018 and 2018/2019 Delivery Years 
for the PJM Region or such LDA.  As more fully set forth in the PJM Manuals, PJM calculates 
the Limited Demand Resource Reliability Target by first:  i) testing the effects of the ten-
interruption requirement by comparing possible loads on peak days under a range of weather 
conditions (from the daily load forecast distributions for the Delivery Year in question) against 
possible generation capacity on such days under a range of conditions (using the cumulative 
capacity distributions employed in the Installed Reserve Margin study for the PJM Region and in 
the Capacity Emergency Transfer Objective study for the relevant LDAs for such Delivery Year) 
and, by varying the assumed amounts of DR that is committed and displaces committed 
generation, determines the DR penetration level at which there is a ninety percent probability 
that DR will not be called (based on the applicable operating reserve margin for the PJM Region 
and for the relevant LDAs) more than ten times over those peak days;  ii) testing the six-hour 
duration requirement by calculating the MW difference between the highest hourly unrestricted 
peak load and seventh highest hourly unrestricted peak load on certain high peak load days (e.g., 
the annual peak, loads above the weather normalized peak, or days where load management was 
called) in recent years, then dividing those loads by the forecast peak for those years and 
averaging the result; and (iii) (for the 2016/2017 and 2017/2018 Delivery Years) testing the 
effects of the six-hour duration requirement by comparing possible hourly loads on peak days 
under a range of weather conditions (from the daily load forecast distributions for the Delivery 
Year in question) against possible generation capacity on such days under a range of conditions 
(using a Monte Carlo model of hourly capacity levels that is consistent with the capacity model 
Page 3

employed in the Installed Reserve Margin study for the PJM Region and in the Capacity 
Emergency Transfer Objective study for the relevant LDAs for such Delivery Year) and, by 
varying the assumed amounts of DR that is committed and displaces committed generation, 
determines the DR penetration level at which there is a ninety percent probability that DR will 
not be called (based on the applicable operating reserve margin for the PJM Region and for the 
relevant LDAs) for more than six hours over any one or more of the tested peak days.  Second, 
PJM adopts the lowest result from these three tests as the Limited Demand Resource Reliability 
Target.  The Limited Demand Resource Reliability Target shall be expressed as a percentage of 
the forecasted peak load of the PJM Region or such LDA and is converted to Unforced Capacity 
by multiplying [the reliability target percentage] times [the Forecast Pool Requirement] times 
[the DR Factor] times [the forecasted peak load of the PJM Region or such LDA, reduced by the 
amount of load served under the FRR Alternative]. 
Limited Resource Constraint: 
“Limited Resource Constraint” shall mean, for the 2017/2018 Delivery Year and for FRR 
Capacity Plans the 2017/2018 and Delivery Years, for the PJM Region or each LDA for which 
the Office of the Interconnection is required under Tariff, Attachment DD, section 5.10(a) to 
establish a separate VRR Curve for a Delivery Year, a limit on the total amount of Unforced 
Capacity that can be committed as Limited Demand Resources for the 2017/2018 Delivery Year 
in the PJM Region or in such LDA, calculated as the Limited Demand Resource Reliability 
Target for the PJM Region or such LDA, respectively, minus the Short Term Resource 
Procurement Target for the PJM Region or such LDA, respectively. 
Limited Resource Price Decrement: 
“Limited Resource Price Decrement” shall mean, for the 2017/2018 Delivery Year, a difference 
between the clearing price for Limited Demand Resources and the clearing price for Extended 
Summer Demand Resources and Annual Resources, representing the cost to procure additional 
Extended Summer Demand Resources or Annual Resources out of merit order when the Limited 
Resource Constraint is binding. 
List of Approved Contractors: 
“List of Approved Contractors” shall mean a list developed by each Transmission Owner and 
published in a PJM Manual of (a) contractors that the Transmission Owner considers to be 
qualified to install or construct new facilities and/or upgrades or modifications to existing 
facilities on the Transmission Owner’s system, provided that such contractors may include, but 
need not be limited to, contractors that, in addition to providing construction services, also 
provide design and/or other construction-related services, and (b) manufacturers or vendors of 
major transmission-related equipment (e.g., high-voltage transformers, transmission line, circuit 
breakers) whose products the Transmission Owner considers acceptable for installation and use 
on its system. 
Load Interest: 
Page 4

“Load Interest” shall mean, for the purposes of the minimum offer price rule, responsibility for 
serving load within the PJM Region, whether by the Capacity Market Seller, an affiliate of the 
Capacity Market Seller, or by an entity with which the Capacity Market Seller is in contractual 
privity with respect to the subject Generation Capacity Resource. 
 
Load Management: 
 
“Load Management” shall mean a Demand Resource (“DR”) as defined in the Reliability 
Assurance Agreement. 
 
Load Management Event: 
 
“Load Management Event” shall mean a) a single temporally contiguous dispatch of Demand 
Resources in a Compliance Aggregation Area during an Operating Day, or b) multiple dispatches 
of Demand Resources in a Compliance Aggregation Area during an Operating Day that are 
temporally contiguous.  
 
Load Ratio Share: 
 
“Load Ratio Share” shall mean the ratio of a Transmission Customer’s Network Load to the 
Transmission Provider’s total load. 
 
Load Reduction Event: 
 
“Load Reduction Event” shall mean a reduction in demand by a Member or Special Member for 
the purpose of participating in the PJM Interchange Energy Market. 
 
Load Serving Charging Energy:  
 
“Load Serving Charging Energy” shall mean energy that is purchased from the PJM Interchange 
Energy Market and stored in an Energy Storage Resource or Open-Loop Hybrid Resource for 
later resale to end-use load. 
 
Load Serving Entity (LSE): 
 
“Load Serving Entity” or “LSE” shall have the meaning specified in the Reliability Assurance 
Agreement. 
 
Load Shedding: 
 
“Load Shedding” shall mean the systematic reduction of system demand by temporarily 
decreasing load in response to transmission system or area capacity shortages, system instability, 
or voltage control considerations under Tariff, Part II or Part III. 
 
Local Upgrades: 
 
Page 5

“Local Upgrades” shall mean modifications or additions of facilities to abate any local thermal 
loading, voltage, short circuit, stability or similar engineering problem caused by the 
interconnection and delivery of generation to the Transmission System.  Local Upgrades shall 
include: 
 
 
(i) Direct Connection Local Upgrades which are Local Upgrades that only serve the 
Customer Interconnection Facility and have no impact or potential impact on the Transmission 
System until the final tie-in is complete; and  
 
 
(ii) Non-Direct Connection Local Upgrades which are parallel flow Local Upgrades that 
are not Direct Connection Local Upgrades. 
 
Location: 
 
“Location” as used in the Economic Load Response rules shall mean an end-use customer site as 
defined by the relevant electric distribution company account number. 
 
LOC Deviation:   
 
“LOC Deviation,” shall mean, for units other than wind units, the LOC Deviation shall equal the 
desired megawatt amount for the resource determined according to the point on the Final Offer 
curve corresponding to the Real-time Settlement Interval real-time Locational Marginal Price at 
the resource’s bus and adjusted for any reduction in megawatts due to Regulation, Synchronized 
Reserve, or Secondary Reserve assignments and limited to the lesser of the unit’s Economic 
Maximum or the unit’s Generation Resource Maximum Output, minus the actual output of the 
unit.  For wind units, the LOC Deviation shall mean the deviation of the generating unit’s output 
equal to the lesser of the PJM forecasted output for the unit or the desired megawatt amount for 
the resource determined according to the point on the Final Offer curve corresponding to the 
Real-time Settlement Interval integrated real-time Locational Marginal Price at the resource’s 
bus, and shall be limited to the lesser of the unit’s Economic Maximum or the unit’s Generation 
Resource Maximum Output, minus the actual output of the unit. 
 
Locational Deliverability Area (LDA): 
 
“Locational Deliverability Area” or “LDA” shall mean a geographic area within the PJM Region 
that has limited transmission capability to import capacity to satisfy such area’s reliability 
requirement, as determined by the Office of the Interconnection in connection with preparation 
of the Regional Transmission Expansion Plan, and as specified in Reliability Assurance 
Agreement, Schedule 10.1. 
 
Locational Deliverability Area Reliability Requirement: 
 
“Locational Deliverability Area Reliability Requirement” shall mean the projected internal 
capacity in the Locational Deliverability Area plus the Capacity Emergency Transfer Objective 
for the Delivery Year, as determined by the Office of the Interconnection in connection with 
Page 6

preparation of the Regional Transmission Expansion Plan, less the minimum internal resources 
required for all FRR Entities in such Locational Deliverability Area. 
 
Locational Price Adder: 
 
“Locational Price Adder” shall mean an addition to the marginal value of Unforced Capacity 
within an LDA as necessary to reflect the price of Capacity Resources required to relieve 
applicable binding locational constraints.  
 
Locational Reliability Charge: 
 
“Locational Reliability Charge” shall have the meaning specified in the Reliability Assurance 
Agreement.  
 
Locational UCAP: 
 
“Locational UCAP” shall mean unforced capacity that a Member with available uncommitted 
capacity sells in a bilateral transaction to a Member that previously committed capacity through 
an RPM Auction but now requires replacement capacity to fulfill its RPM Auction commitment.  
The Locational UCAP Seller retains responsibility for performance of the resource providing 
such replacement capacity.   
 
Locational UCAP Seller: 
 
“Locational UCAP Seller” shall mean a Member that sells Locational UCAP. 
 
Long-lead Project: 
 
“Long-lead Project” shall have the same meaning provided in the Operating Agreement. 
 
Long-Term Firm Point-To-Point Transmission Service: 
 
“Long-Term Firm Point-To-Point Transmission Service” shall mean firm Point-To-Point 
Transmission Service under Tariff, Part II with a term of one year or more. 
 
Loss Price: 
 
“Loss Price” shall mean the loss component of the Locational Marginal Price, which is the effect 
on transmission loss costs (whether positive or negative) associated with increasing the output of 
a generation resource or decreasing the consumption by a Demand Resource based on the effect 
of increased generation from or consumption by the resource on transmission losses, calculated 
as specified in Operating Agreement, Schedule 1, section 2, and the parallel provisions of Tariff, 
Attachment K-Appendix, section 2. 
 
M2M Flowgate: 
 
Page 7

“M2M Flowgate” shall have the meaning provided in the Joint Operating Agreement between 
the Midcontinent Independent Transmission System Operator, Inc. and PJM Interconnection, 
L.L.C. 
 
Maintenance Adder:   
 
“Maintenance Adder” shall mean an adder that may be included to account for variable operation 
and maintenance expenses in a Market Seller’s Fuel Cost Policy.  The Maintenance Adder is 
calculated in accordance with the applicable provisions of PJM Manual 15, and may only include 
expenses incurred as a result of electric production. 
 
Manual Load Dump Action: 
 
“Manual Load Dump Action” shall mean an Operating Instruction, as defined by NERC, from 
PJM to shed firm load when the PJM Region cannot provide adequate capacity to meet the PJM 
Region’s load and tie schedules, or to alleviate critically overloaded transmission lines or other 
equipment. 
 
Manual Load Dump Warning: 
 
“Manual Load Dump Warning” shall mean a notification from PJM to warn Members of an 
increasingly critical condition of present operations that may require manually shedding load. 
 
Marginal Value:  
 
“Marginal Value” shall mean the incremental change in system dispatch costs, measured as a 
$/MW value incurred by providing one additional MW of relief to the transmission constraint. 
 
Market Monitor: 
 
“Market Monitor” means the head of the Market Monitoring Unit. 
 
Market Monitoring Unit or MMU: 
 
“Market Monitoring Unit” or “MMU” means the independent Market Monitoring Unit defined in 
18 CFR § 35.28(a)(7) and established under the PJM Market Monitoring Plan (Attachment M) to 
the PJM Tariff that is responsible for implementing the Market Monitoring Plan, including the 
Market Monitor.  The Market Monitoring Unit may also be referred to as the IMM or 
Independent Market Monitor for PJM 
 
Market Monitoring Unit Advisory Committee or MMU Advisory Committee: 
 
“Market Monitoring Unit Advisory Committee” or “MMU Advisory Committee” shall mean the 
committee established under Tariff, Attachment M, section III.H. 
 
Market Operations Center: 
Page 8

“Market Operations Center” shall mean the equipment, facilities and personnel used by or on 
behalf of a Market Participant to communicate and coordinate with the Office of the 
Interconnection in connection with transactions in the PJM Interchange Energy Market or the 
operation of the PJM Region. 
 
Market Participant: 
 
“Market Participant” shall mean a Market Buyer, a Market Seller, an Economic Load Response 
Participant, or all three, except when such term is used in Tariff, Attachment M, in which case 
Market Participant shall mean an entity that generates, transmits, distributes, purchases, or sells 
electricity, ancillary services, or any other product or service provided under the PJM Tariff or 
Operating Agreement within, into, out of, or through the PJM Region, but it shall not include an 
Authorized Government Agency that consumes energy for its own use but does not purchase or 
sell energy at wholesale. 
 
Market Participant Energy Injection: 
 
“Market Participant Energy Injection” shall mean transactions in the Day-ahead Energy Market 
and Real-time Energy Market, including but not limited to Day-ahead generation schedules, real-
time generation output, Increment Offers, internal bilateral transactions and import transactions, 
as further described in the PJM Manuals.  
 
Market Participant Energy Withdrawal: 
 
“Market Participant Energy Withdrawal” shall mean transactions in the Day-ahead Energy 
Market and Real-time Energy Market, including but not limited to Demand Bids, Decrement 
Bids, real-time load (net of Behind The Meter Generation expected to be operating, but not to be 
less than zero), internal bilateral transactions and Export Transactions, as further described in the 
PJM Manuals.  
 
Market Revenue Neutrality Offset:  
 
“Market Revenue Neutrality Offset” shall mean the revenue in excess of the cost for a resource 
from the energy, Synchronized Reserve, Non-Synchronized Reserve, and Secondary Reserve 
markets realized from an increase in real-time market megawatt assignment from a day-ahead 
market megawatt assignment in any of these markets due to the decrease in the real-time reserve 
market megawatt assignment from a day-ahead reserve market megawatt assignment in any of 
the reserve markets. 
 
Market Seller Offer Cap: 
 
“Market Seller Offer Cap” shall mean a maximum offer price applicable to certain Market 
Sellers under certain conditions, as determined in accordance with Tariff, Attachment DD. 
section 6 and Tariff, Attachment M-Appendix, section II.E.    
 
Page 9

Market Violation: 
 
“Market Violation” shall mean a tariff violation, violation of a Commission-approved order, rule 
or regulation, market manipulation, or inappropriate dispatch that creates substantial concerns 
regarding unnecessary market inefficiencies, as defined in 18 C.F.R. § 35.28(b)(8). 
 
Material Modification: 
 
“Material Modification” shall mean any modification to an Interconnection Request that has a 
material adverse effect on the cost or timing of Interconnection Studies related to, or any 
Network Upgrades or Local Upgrades needed to accommodate, any Interconnection Request 
with a later Queue Position. 
 
Maximum Daily Starts: 
 
“Maximum Daily Starts” shall mean the maximum number of times that a generating unit can be 
started in an Operating Day under normal operating conditions. 
 
Maximum Emergency: 
 
“Maximum Emergency” shall mean the designation of all or part of the output of a generating 
unit for which the designated output levels may require extraordinary procedures and therefore 
are available to the Office of the Interconnection only when the Office of the Interconnection 
declares a Maximum Generation Emergency and requests generation designated as Maximum 
Emergency to run.  The Office of the Interconnection shall post on the PJM website the 
aggregate amount of megawatts that are classified as Maximum Emergency. 
 
Maximum Facility Output: 
 
“Maximum Facility Output” shall mean the maximum (not nominal) net electrical power output 
in megawatts, specified in the Interconnection Service Agreement, after supply of any parasitic 
or host facility loads, that a Generation Interconnection Customer’s Customer Facility is 
expected to produce, provided that the specified Maximum Facility Output shall not exceed the 
output of the proposed Customer Facility that Transmission Provider utilized in the System 
Impact Study. 
 
Maximum Generation Emergency: 
 
“Maximum Generation Emergency” shall mean an Emergency declared by the Office of the 
Interconnection to address either a generation or transmission emergency in which the Office of 
the Interconnection anticipates requesting one or more Generation Capacity Resources, or Non-
Retail Behind The Meter Generation resources to operate at its maximum net or gross electrical 
power output, subject to the equipment stress limits for such Generation Capacity Resource or 
Non-Retail Behind The Meter resource in order to manage, alleviate, or end the Emergency. 
 
Maximum Generation Emergency Alert:  
Page 10

“Maximum Generation Emergency Alert” shall mean an alert issued by the Office of the 
Interconnection to notify PJM Members, Transmission Owners, resource owners and operators, 
customers, and regulators that a Maximum Generation Emergency may be declared, for any 
Operating Day in either, as applicable, the Day-ahead Energy Market or the Real-time Energy 
Market, for all or any part of such Operating Day. 
 
Maximum Run Time: 
 
“Maximum Run Time” shall mean the maximum number of hours a generating unit can run over 
the course of an Operating Day, as measured by PJM’s State Estimator. 
 
Maximum State of Charge: 
 
“Maximum State of Charge” shall mean the maximum State of Charge that should not be 
exceeded, measured in units of megawatt-hours. 
 
Maximum Weekly Starts: 
 
“Maximum Weekly Starts” shall mean the maximum number of times that a generating unit can 
be started in one week, defined as the 168 hour period starting Monday 0001 hour, under normal 
operating conditions. 
 
Member: 
  
“Member” shall have the meaning provided in the Operating Agreement. 
 
Merchant A.C. Transmission Facilities: 
 
“Merchant A.C. Transmission Facility” shall mean Merchant Transmission Facilities that are 
alternating current (A.C.) transmission facilities, other than those that are Controllable A.C. 
Merchant Transmission Facilities.  
 
Merchant D.C. Transmission Facilities: 
 
“Merchant D.C. Transmission Facilities” shall mean direct current (D.C.) transmission facilities 
that are interconnected with the Transmission System pursuant to Tariff, Part IV and Part VI.  
 
Merchant Network Upgrades: 
 
“Merchant Network Upgrades” shall mean additions to, or modifications or replacements of, 
physical facilities of the Interconnected Transmission Owner that, on the date of the pertinent 
Transmission Interconnection Customer’s Upgrade Request, are part of the Transmission System 
or are included in the Regional Transmission Expansion Plan. 
 
Merchant Transmission Facilities: 
Page 11

“Merchant Transmission Facilities” shall mean A.C. or D.C. transmission facilities that are 
interconnected with or added to the Transmission System pursuant to Tariff, Part IV and Part VI 
and that are so identified in Tariff, Attachment T, provided, however, that Merchant 
Transmission Facilities shall not include (i) any Customer Interconnection Facilities, (ii) any 
physical facilities of the Transmission System that were in existence on or before March 20, 
2003 ; (iii) any expansions or enhancements of the Transmission System that are not identified as 
Merchant Transmission Facilities in the Regional Transmission Expansion Plan and Attachment 
T to the Tariff, or (iv) any transmission facilities that are included in the rate base of a public 
utility and on which a regulated return is earned. 
 
Merchant Transmission Provider: 
 
“Merchant Transmission Provider” shall mean an Interconnection Customer that (1) owns,  
controls, or controls the rights to use the transmission capability of, Merchant D.C. Transmission 
Facilities and/or Controllable A.C. Merchant Transmission Facilities that connect the 
Transmission System with another control area, (2) has elected to receive Transmission Injection 
Rights and Transmission Withdrawal Rights associated with such facility pursuant to Tariff, Part 
IV, section 36, and (3) makes (or will make) the transmission capability of such facilities 
available for use by third parties under terms and conditions approved by the Commission and 
stated in the Tariff, consistent with Tariff, section 38. 
 
Metering Equipment: 
 
“Metering Equipment” shall mean all metering equipment installed at the metering points 
designated in the appropriate appendix to an Interconnection Service Agreement. 
 
Minimum Annual Resource Requirement: 
 
“Minimum Annual Resource Requirement” shall mean, for Delivery Years through May 31, 
2017,   the minimum amount of capacity that PJM will seek to procure from Annual Resources 
for the PJM Region and for each Locational Deliverability Area for which the Office of the 
Interconnection is required under Tariff, Attachment DD, section 5.10(a) to establish a separate 
VRR Curve for such Delivery Year.  For the PJM Region, the Minimum Annual Resource 
Requirement shall be equal to the RTO Reliability Requirement minus [the Sub-Annual 
Resource Reliability Target for the RTO in Unforced Capacity].  For an LDA, the Minimum 
Annual Resource Requirement shall be equal to the LDA Reliability Requirement minus [the 
LDA CETL] minus [the Sub-Annual Resource Reliability Target for such LDA in Unforced 
Capacity]. The LDA CETL may be adjusted pro rata for the amount of load served under the 
FRR Alternative. 
 
Minimum Down Time: 
 
For all generating units that are not combined cycle units, “Minimum Down Time” shall mean 
the minimum number of hours under normal operating conditions between unit shutdown and 
unit startup, calculated as the shortest time difference between the unit’s generator breaker 
Page 12

opening and after the unit’s generator breaker closure, which is typically indicated by 
telemetered or aggregated State Estimator megawatts greater than zero. For combined cycle 
units, “Minimum Down Time” shall mean the minimum number of hours between the last 
generator breaker opening and after first combustion turbine generator breaker closure, which is 
typically indicated by telemetered or aggregated State Estimator megawatts greater than zero. 
 
Minimum Extended Summer Resource Requirement: 
 
“Minimum Extended Summer Resource Requirement” shall mean, for Delivery Years through 
May 31, 2017, the minimum amount of capacity that PJM will seek to procure from Extended 
Summer Demand Resources and Annual Resources for the PJM Region and for each Locational 
Deliverability Area for which the Office of the Interconnection is required under Tariff, 
Attachment DD, section 5.10(a) to establish a separate VRR Curve for such Delivery Year.  For 
the PJM Region, the Minimum Extended Summer Resource Requirement shall be equal to the 
RTO Reliability Requirement minus [the Limited Demand Resource Reliability Target for the 
PJM Region in Unforced Capacity].  For an LDA, the Minimum Extended Summer Resource 
Requirement shall be equal to the LDA Reliability Requirement minus [the LDA CETL] minus 
[the Limited Demand Resource Reliability Target for such LDA in Unforced Capacity].  The 
LDA CETL may be adjusted pro rata for the amount of load served under the FRR Alternative. 
 
Minimum Generation Emergency: 
 
“Minimum Generation Emergency” shall mean an Emergency declared by the Office of the 
Interconnection in which the Office of the Interconnection anticipates requesting one or more 
generating resources to operate at or below Normal Minimum Generation, in order to manage, 
alleviate, or end the Emergency. 
 
Minimum Participation Requirements: 
 
“Minimum Participation Requirements” shall mean a set of minimum training, risk management, 
communication and capital or collateral requirements required for Participants in the PJM 
Markets, as set forth herein and in the Form of Annual Certification set forth as Tariff, 
Attachment Q, Appendix 1.  Participants transacting in FTRs in certain circumstances will be 
required to demonstrate additional risk management procedures and controls as further set forth 
in the Annual Certification found in Tariff, Attachment Q, Appendix 1. 
 
Minimum Run Time: 
 
For all generating units that are not combined cycle units, “Minimum Run Time” shall mean the 
minimum number of hours a unit must run, in real-time operations, from the time after generator 
breaker closure, which is typically indicated by telemetered or aggregated State Estimator 
megawatts greater than zero, to the time of generator breaker opening, as measured by PJM's 
State Estimator. For combined cycle units, “Minimum Run Time” shall mean the time period 
after the first combustion turbine generator breaker closure, which is typically indicated by 
telemetered or aggregated State Estimator megawatts greater than zero, and the last generator 
breaker opening as measured by PJM’s State Estimator. 
Page 13

Minimum State of Charge: 
 
“Minimum State of Charge” shall mean the minimum State of Charge that should be maintained 
in units of megawatt-hours. 
 
MISO: 
 
“MISO” shall mean the Midcontinent Independent System Operator, Inc. or any successor 
thereto. 
 
Mixed Technology Facility: 
 
“Mixed Technology Facility” shall mean a facility composed of distinct generation and/or 
electric storage technology types behind the same Point of Interconnection.  Co-Located 
Resources and Hybrid Resources form all or part of Mixed Technology Facilities. 
 
MOPR Floor Offer Price: 
 
“MOPR Floor Offer Price” shall mean a minimum offer price applicable to certain Market 
Seller’s Capacity Resources under certain conditions, as determined in accordance with Tariff, 
Attachment DD, sections 5.14(h), 5.14(h-1), and 5.14(h-2). 
 
Multi-Driver Project: 
 
“Multi-Driver Project” shall have the same meaning provided in the Operating Agreement. 
 
Native Load Customers: 
 
“Native Load Customers” shall mean the wholesale and retail power customers of a 
Transmission Owner on whose behalf the Transmission Owner, by statute, franchise, regulatory 
requirement, or contract, has undertaken an obligation to construct and operate the Transmission 
Owner’s system to meet the reliable electric needs of such customers. 
 
Near-Term Transmission Service: 
 
“Near-Term Transmission Service” shall mean Transmission Service which ends not more than 
10 days after the Transmission Service request date.  When the description of obligations below 
refers to either a request for information about the availability of potential Transmission Service 
(including, but not limited to, a request for ATC), or to the posting of ATC or other information 
related to potential service, the date that the information is requested or posted will serve as the 
Transmission Service request date.  “Near-Term Transmission Service” includes any Point-To-
Point Transmission Service and Network Integration Transmission Service where the start and 
end date of the designation or request is within the next 10 days. 
 
NERC: 
Page 14

“NERC” shall mean the North American Electric Reliability Corporation or any successor 
thereto. 
 
NERC Interchange Distribution Calculator: 
 
“NERC Interchange Distribution Calculator” shall mean the NERC mechanism that is in effect 
and being used to calculate the distribution of energy, over specific transmission interfaces, from 
energy transactions. 
 
Net Benefits Test:  
 
“Net Benefits Test” shall mean a calculation to determine whether the benefits of a reduction in 
price resulting from the dispatch of Economic Load Response exceeds the cost to other loads 
resulting from the billing unit effects of the load reduction, as specified in Operating Agreement, 
Schedule 1, section 3.3A.4 and the parallel provisions of Tariff, Attachment K-Appendix, section 
3.3A.4. 
 
Net Cost of New Entry:   
 
“Net Cost of New Entry” shall mean the Cost of New Entry minus the Net Energy and Ancillary 
Service Revenue Offset. 
 
Net Obligation: 
  
“Net Obligation” shall mean the amount owed to PJMSettlement and PJM for purchases from the 
PJM Markets, Transmission Service, (under Tariff, Parts II and III , and other services pursuant 
to the Agreements, after applying a deduction for amounts owed to a Participant by 
PJMSettlement as it pertains to monthly market activity and services.  Should other markets be 
formed such that Participants may incur future Obligations in those markets, then the aggregate 
amount of those Obligations will also be added to the Net Obligation. 
 
Net Sell Position: 
  
“Net Sell Position” shall mean the amount of Net Obligation when Net Obligation is negative. 
 
Network Customer: 
 
“Network Customer” shall mean an entity receiving transmission service pursuant to the terms of 
the Transmission Provider’s Network Integration Transmission Service under Tariff, Part III. 
 
Network External Designated Transmission Service: 
 
“Network External Designated Transmission Service” shall have the meaning set forth in 
Reliability Assurance Agreement, Article I. 
 
Page 15

Network Integration Transmission Service: 
 
“Network Integration Transmission Service” shall mean the transmission service provided under 
Tariff, Part III. 
 
Network Load: 
 
“Network Load” shall mean the load that a Network Customer designates for Network 
Integration Transmission Service under Tariff, Part III.  The Network Customer’s Network Load 
shall include all load (including losses, Non-Dispatched Charging Energy, and Load Serving 
Charging Energy) served by the output of any Network Resources designated by the Network 
Customer.  A Network Customer may elect to designate less than its total load as Network Load 
but may not designate only part of the load at a discrete Point of Delivery.  Where an Eligible 
Customer has elected not to designate a particular load at discrete points of delivery as Network 
Load, the Eligible Customer is responsible for making separate arrangements under Tariff, Part 
II for any Point-To-Point Transmission Service that may be necessary for such non-designated 
load.  Network Load shall not include Dispatched Charging Energy. 
 
Network Operating Agreement: 
 
“Network Operating Agreement” shall mean an executed agreement that contains the terms and 
conditions under which the Network Customer shall operate its facilities and the technical and 
operational matters associated with the implementation of Network Integration Transmission 
Service under Tariff, Part III. 
 
Network Operating Committee: 
 
“Network Operating Committee” shall mean a group made up of representatives from the 
Network Customer(s) and the Transmission Provider established to coordinate operating criteria 
and other technical considerations required for implementation of Network Integration 
Transmission Service under Tariff, Part III.  
 
Network Resource: 
 
“Network Resource” shall mean any designated generating resource owned, purchased, or leased 
by a Network Customer under the Network Integration Transmission Service 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, except for purposes of fulfilling obligations under a reserve sharing 
program. 
 
Network Service User: 
 
“Network Service User” shall mean an entity using Network Transmission Service. 
 
Network Transmission Service: 
Page 16

“Network Transmission Service” shall mean transmission service provided pursuant to the rates, 
terms and conditions set forth in Tariff, Part III, or transmission service comparable to such 
service that is provided to a Load Serving Entity that is also a Transmission Owner. 
 
Network Upgrades: 
 
“Network Upgrades” shall mean modifications or additions to transmission-related facilities that 
are integrated with and support the Transmission Provider’s overall Transmission System for the 
general benefit of all users of such Transmission System. Network Upgrades shall include: 
 
 
(i) Direct Connection Network Upgrades which are Network Upgrades that are not part 
of an Affected System; only serve the Customer Interconnection Facility; and have no impact or 
potential impact on the Transmission System until the final tie-in is complete.  Both 
Transmission Provider and Interconnection Customer must agree as to what constitutes Direct 
Connection Network Upgrades and identify them in the Interconnection Construction Service 
Agreement, Schedule D.  If the Transmission Provider and Interconnection Customer disagree 
about whether a particular Network Upgrade is a Direct Connection Network Upgrade, the 
Transmission Provider must provide the Interconnection Customer a written technical 
explanation outlining why the Transmission Provider does not consider the Network Upgrade to 
be a Direcct Connection Network Upgrade within 15 days of its determination. 
 
 
(ii) Non-Direct Connection Network Upgrades which are parallel flow Network 
Upgrades that are not Direct Connection Network Upgrades. 
 
Neutral Party: 
 
“Neutral Party” shall have the meaning provided in Tariff, Part I, section 9.3(v). 
 
New Entry Capacity Resource with State Subsidy: 
 
“New Entry Capacity Resource with State Subsidy” shall mean (1) starting with the 2022/2023 
Delivery Year, the MWs (in installed capacity) comprising a Capacity Resource with State 
Subsidy that have not cleared in an RPM Auction pursuant to its Sell Offer at or above its 
resource-specific MOPR Floor Offer Price or the applicable default New Entry MOPR Floor 
Offer Price or (2) starting with the Base Residual Auction for the 2022/2023 Delivery Year, any 
of those MWs (in installed capacity) comprising a Capacity Resource with State Subsidy that 
was not included in an FRR Capacity Plan at the time of the Base Residual Auction or the 
subject of a Sell Offer in a Base Residual Auction occurring for a Delivery Year after it last 
cleared an RPM Auction and since then has yet to clear an RPM Auction pursuant to its Sell 
Offer at or above its resource-specific MOPR Floor Offer Price or the applicable default New 
Entry MOPR Floor Offer Price.  Notwithstanding the foregoing, any Capacity Resource that 
previously cleared an RPM Auction before it became entitled to receive a State Subsidy shall not 
be deemed a New Entry Capacity Resource, unless, starting with the Base Residual Auction for 
the 2022/2023 Delivery Year, the Capacity Resource with State Subsidy was not the subject of a 
Page 17

Sell Offer in a Base Residual Auction or included in an FRR Capacity Plan at the time of the 
Base Residual Auction for a Delivery Year after it last cleared an RPM Auction. 
New PJM Zone(s): 
 
“New PJM Zone(s)” shall mean the Zone included in the Tariff, along with applicable Schedules 
and Attachments, for Commonwealth Edison Company, The Dayton Power and Light Company 
and the AEP East Operating Companies (Appalachian Power Company, Columbus Southern 
Power Company, Indiana Michigan Power Company, Kentucky Power Company, Kingsport 
Power Company, Ohio Power Company and Wheeling Power Company). 
 
New Service Customers: 
 
“New Service Customers” shall mean all customers that submit an Interconnection Request, a 
Completed Application, or an Upgrade Request that is pending in the New Services Queue. 
 
New Service Request: 
 
“New Service Request” shall mean an Interconnection Request, a Completed Application, or an 
Upgrade Request. 
 
New Services Queue: 
 
“New Services Queue” shall mean all Interconnection Requests, Completed Applications, and 
Upgrade Requests that are received within each six-month period ending on March 31 and 
September 30 of each year shall collectively comprise a New Services Queue. 
 
New York ISO or NYISO: 
 
“New York ISO” or “NYISO” shall mean the New York Independent System Operator, Inc. or 
any successor thereto. 
 
Nodal Reference Price: 
  
The “Nodal Reference Price” at each location shall mean the 97th percentile price differential 
between day-ahead and real-time prices experienced over the corresponding two-month 
reference period in the prior calendar year.   Reference periods will be Jan-Feb, Mar-Apr, May-
Jun, Jul-Aug, Sept-Oct, Nov-Dec.  For any given current-year month, the reference period 
months will be the set of two months in the prior calendar year that include the month 
corresponding to the current month.  For example, July and August 2003 would each use July-
August 2002 as their reference period. 
 
No-load Cost:  
 
“No-load Cost” shall mean the hourly cost required to theoretically operate a synchronized unit 
at zero MW. It consists primarily of the cost of fuel, as determined by the unit’s no load heat 
Page 18

(adjusted by the performance factor) times the fuel cost. It also includes operating costs, 
Maintenance Adders, and emissions allowances. 
 
Nominal Rated Capability: 
 
“Nominal Rated Capability” shall mean the nominal maximum rated capability in megawatts of 
a Transmission Interconnection Customer’s Customer Facility or the nominal increase in 
transmission capability in megawatts of the Transmission System resulting from the 
interconnection or addition of a Transmission Interconnection Customer’s Customer Facility, as 
determined in accordance with pertinent Applicable Standards and specified in the 
Interconnection Service Agreement. 
 
Nominated Demand Resource Value: 
 
“Nominated Demand Resource Value” shall mean the amount of load reduction that a Demand 
Resource commits to provide either through direct load control, firm service level or guaranteed 
load drop programs.  For existing Demand Resources, the maximum Nominated Demand 
Resource Value is limited, in accordance with the PJM Manuals, to the value appropriate for the 
method by which the load reduction would be accomplished, at the time the Base Residual 
Auction or Incremental Auction is being conducted. 
 
Nominated Energy Efficiency Value:  
 
“Nominated Energy Efficiency Value” shall mean the amount of load reduction that an Energy 
Efficiency Resource commits to provide through installation of more efficient devices or 
equipment or implementation of more efficient processes or systems. 
 
Non-Curtailment Charge: 
 
“Non-Curtailment Charge” shall mean the charge applicable to Demand Resources and Price 
Responsive Demand as defined in Tariff, Attachment DD, section 10B(b). 
 
Non-Dispatched Charging Energy:  
 
“Non-Dispatched Charging Energy” shall mean all Direct Charging Energy that an Energy 
Storage Resource Model Participant or Open-Loop Hybrid Resource receives from the electric 
grid that is not otherwise Dispatched Charging Energy. 
 
Non-Firm Point-To-Point Transmission Service: 
 
“Non-Firm Point-To-Point Transmission Service” shall mean Point-To-Point Transmission 
Service under the Tariff that is reserved and scheduled on an as-available basis and is subject to 
Curtailment or Interruption as set forth in Tariff, Part II, section 14.7.  Non-Firm Point-To-Point 
Transmission Service is available on a stand-alone basis for periods ranging from one hour to 
one month. 
 
Page 19

Non-Firm Sale: 
 
“Non-Firm Sale” shall mean an energy sale for which receipt or delivery may be interrupted for 
any reason or no reason, without liability on the part of either the buyer or seller. 
 
Non-Firm Transmission Withdrawal Rights: 
 
“No-Firm Transmission Withdrawal Rights” shall mean the rights to schedule energy 
withdrawals from a specified point on the Transmission System. Non-Firm Transmission 
Withdrawal Rights may be awarded only to a Merchant D.C. Transmission Facility that connects 
the Transmission System to another control area. Withdrawals scheduled using Non-Firm 
Transmission Withdrawal Rights have rights similar to those under Non-Firm Point-to-Point 
Transmission Service. 
 
Non-PAI Event: 
 
“Non-PAI Event” shall mean, effective for the 2028/2029 Delivery Year and subsequent 
Delivery Years, any intervals when a Demand Resource is dispatched or when Price Responsive 
Demand is required to respond and a Performance Assessment Interval is not in effect for such 
intervals for the same registration. 
 
Non-Performance Charge: 
 
“Non-Performance Charge” shall mean the charge applicable to Capacity Performance 
Resources as defined in Tariff, Attachment DD, section 10A(e). 
 
Nonincumbent Developer: 
 
“Nonincumbent Developer” shall have the same meaning provided in the Operating Agreement. 
 
Non-Regulatory Opportunity Cost: 
 “Non-Regulatory Opportunity Cost” shall mean the difference between (a) the forecasted cost to 
operate a specific generating unit when the unit only has a limited number of starts or available 
run hours resulting from (i) the physical equipment limitations of the unit, for up to one year, due 
to original equipment manufacturer recommendations or insurance carrier restrictions, (ii) a fuel 
supply limitation, for up to one year, resulting from an event of Catastrophic Force Majeure; and,  
(b) the forecasted future Locational Marginal Price at which the generating unit could run while 
not violating such limitations.  Non-Regulatory Opportunity Cost therefore is the value 
associated with a specific generating unit’s lost opportunity to produce energy during a higher 
valued period of time occurring within the same period of time in which the unit is bound by the 
referenced restrictions, and is reflected in the rules set forth in PJM Manual 15.  Non-Regulatory 
Opportunity Costs shall be limited to those resources which are specifically delineated in 
Operating Agreement, Schedule 2.  
 
Non-Retail Behind The Meter Generation: 
 
Page 20

“Non-Retail Behind The Meter Generation” shall mean Behind the Meter Generation that is used 
by municipal electric systems, electric cooperatives, or electric distribution companies to serve 
load. 
 
Non-Synchronized Reserve: 
 
“Non-Synchronized Reserve” shall mean the reserve capability of non-emergency generation 
resources that can be converted fully into energy within ten minutes of a request from the Office 
of the Interconnection dispatcher, and is provided by equipment that is not electrically 
synchronized to the Transmission System. 
 
Non-Synchronized Reserve Event: 
 
“Non-Synchronized Reserve Event” shall mean a request from the Office of the Interconnection 
to generation resources able and assigned to provide Non-Synchronized Reserve in one or more 
specified Reserve Zones or Reserve Sub-zones, within ten minutes to increase the energy output 
by the amount of assigned Non-Synchronized Reserve capability. 
 
Non-Variable Loads: 
“Non-Variable Loads” shall have the meaning specified in Operating Agreement, Schedule 1, 
section 1.5A.6, and the parallel provisions of Tariff, Attachment K-Appendix, section 1.5A.6. 
 
Non-Zone Network Load: 
 
“Non-Zone Network Load shall mean Network Load that is located outside of the PJM Region. 
 
Normal Maximum Generation: 
 
“Normal Maximum Generation” shall mean the highest output level of a generating resource 
under normal operating conditions. 
 
Normal Minimum Generation: 
 
“Normal Minimum Generation” shall mean the lowest output level of a generating resource 
under normal operating conditions. 
 
Page 21

ATTACHMENT DD-4 
LARGE LOAD REGISTRY 
Page 22

I. 
[RESERVED] 
 
 
Page 23

III. 
RESPONSBILITIES OF ELECTRIC DISTRIBUTORS 
 
Electric Distributors shall coordinate with the Office of the Interconnection in developing and 
maintaining the Large Load Registry by providing the Office of the Interconnection any 
information or data the Electric Distributor believes appropriate to facilitate an accurate Large 
Load Registry, including applicable state or RERRA retail tariff or contractual obligations. 
 
Page 24

II. 
RESPONSBILITIES OF THE OFFICE OF THE INTERCONNECTION  
 
The Office of the Interconnection shall maintain the Large Load Registry, pursuant to Reliability 
Assurance Agreement, Schedule 11. 
Page 25

Revisions to the 
PJM Reliability Assurance Agreement  
 
(Clean Format) 
 
Page 26

ARTICLE 1 – DEFINITIONS 
 
 
Unless the context otherwise specifies or requires, capitalized terms used herein shall 
have the respective meanings assigned herein or in the Schedules hereto, or in the PJM Tariff or 
PJM Operating Agreement if not otherwise defined in this Agreement, for all purposes of this 
Agreement (such definitions to be equally applicable to both the singular and the plural forms of 
the terms defined).  Unless otherwise specified, all references herein to Articles, Sections or 
Schedules, are to Articles, Sections or Schedules of this Agreement. As used in this Agreement: 
 
 
Accredited UCAP: 
 
“Accredited UCAP” shall mean the quantity of Unforced Capacity, as denominated in Effective 
UCAP, that an ELCC Resource is capable of providing in a given Delivery Year. 
 
Accredited UCAP Factor: 
 
“Accredited UCAP Factor” shall mean, through the 2024/2025 Delivery Year, one minus 
EFORd, and for 2025/2026 Delivery Year and subsequent Delivery Years, the ratio of the 
Capacity Resource’s Accredited UCAP to the Capacity Resource’s installed capacity. 
 
Agreement: 
 
 
“Agreement” shall mean this Reliability Assurance Agreement, together with all Schedules 
hereto, as amended from time to time. 
 
Annual Demand Resource: 
 
“Annual Demand Resource” shall mean a resource that is placed under the direction of the 
Office of the Interconnection  during the Delivery Year, and will be available for an unlimited 
number of interruptions during such Delivery Year by the Office of the Interconnection, and will 
be capable of maintaining each such interruption between the hours of 10:00AM to 10:00PM 
Eastern Prevailing Time for the months of June through October and the following May, and 
6:00AM through 9:00PM Eastern Prevailing Time for the months of November through April 
unless there is an Office of the Interconnection approved maintenance outage during October 
through April.  The Annual Demand Resource must be available in the corresponding Delivery 
year to be offered for sale or Self-Supplied in an RPM Auction, or included as an Annual 
Demand Resource in an FRR Capacity Plan for the corresponding Delivery Year. 
 
Annual Energy Efficiency Resource: 
 
“Annual Energy Efficiency Resource” shall mean a project, including installation of more 
efficient devices or equipment or implementation of more efficient processes or systems, 
meeting the requirements of  Reliability Assurance Agreement, Schedule 6 and exceeding then-
current building codes, appliance standards, or other relevant standards, designed to achieve a 
continuous (during the summer and winter periods described in such Schedule 6 and the PJM 
Manuals) reduction in electric energy consumption that is not reflected in the peak load forecast 
Page 27

prepared for the Delivery Year for which the Energy Efficiency Resource is proposed, and that is 
fully implemented at all times during such Delivery Year, without any requirement of notice, 
dispatch, or operator intervention. 
 
Applicable Regional Entity: 
 
 
“Applicable Regional Entity” shall have the same meaning as in the PJM Tariff.   
 
Base Capacity Demand Resource: 
 
“Base Capacity Demand Resource” shall mean, for the 2018/2019 and 2019/2020 Delivery 
Years, a resource that is placed under the direction of the Office of the Interconnection and that 
will be available June through September of a Delivery Year, and will be available to the Office 
of the Interconnection for an unlimited number of interruptions during such months, and will be 
capable of maintaining each such interruption for at least a 10-hour duration between the hours 
of 10:00AM to 10:00PM Eastern Prevailing Time.  The Base Capacity Demand Resource must 
be available June through September in the corresponding Delivery Year to be offered for sale or 
self-supplied in an RPM Auction, or included as a Base Capacity Demand Resource in an FRR 
Capacity Plan for the corresponding Delivery Year.   
 
Base Capacity Energy Efficiency Resource:  
 
“Base Capacity Energy Efficiency Resource” shall mean, for the 2018/2019 and 2019/2020 
Delivery Years, a project, including installation of more efficient devices or equipment or 
implementation of more efficient processes or systems, meeting the requirements of RAA, 
Schedule 6 and exceeding then-current building codes, appliance standards, or other relevant 
standards, designed to achieve a continuous (during the summer peak periods as described in 
Reliability Assurance Agreement, Schedule 6 and the PJM Manuals) reduction in electric energy 
consumption that is not reflected in the peak load forecast prepared for the Delivery Year for 
which the Base Capacity Energy Efficiency Resource is proposed, and that is fully implemented 
at all times during such Delivery Year, without any requirement of notice, dispatch, or operator 
intervention. 
 
Base Capacity Resource:  
 
“Base Capacity Resource” shall have the same meaning as in Tariff, Attachment DD. 
 
Base Residual Auction: 
 
 
“Base Residual Auction” shall have the same meaning as in Tariff, Attachment DD. 
 
 
Behind The Meter Generation: 
 
 
“Behind The Meter Generation” shall refer to a generating unit that delivers energy to load 
without using the Transmission System or any distribution facilities (unless the entity that owns 
or leases the distribution facilities consented to such use of the distribution facilities and such 
Page 28

consent has been demonstrated to the satisfaction of the Office of the Interconnection; provided, 
however, that Behind The Meter Generation does not include (i) at any time, any portion of such 
generating unit’s capacity that is designated as a Generation Capacity Resource or DER Capacity 
Aggregation Resource or (ii) in any hour, any portion of the output of such generating unit that is 
sold to another entity for consumption at another electrical location or into the PJM Interchange 
Energy Market. 
 
 
Black Start Capability: 
 
 
“Black Start Capability” shall mean the ability of a generating unit or station to go from a 
shutdown condition to an operating condition and start delivering power without assistance from 
the power system. 
 
 
Capacity Emergency Transfer Objective (CETO): 
 
 
“Capacity Emergency Transfer Objective” or “CETO” shall mean, through the 2024/2025 
Delivery Year, the amount of electric energy that a given area must be able to import in order to 
remain within a loss of load expectation of one event in 25 years when the area is experiencing a 
localized capacity emergency, as determined in accordance with the PJM Manuals.  Without 
limiting the foregoing, CETO shall be, for Delivery Years through 2024/2025, calculated based 
in part on EFORD determined in accordance with Reliability Assurance Agreement, Schedule 5, 
Paragraph C. Beginning with the 2025/2026 Delivery Year, CETO shall mean the amount of 
electric energy that a given area must be able to import in order to satisfy a normalized expected 
unserved energy for the area that is equal to forty percent of the normalized expected unserved 
energy for the RTO when at the annual reliability criteria, where normalized expected unserved 
energy is the expected unserved energy (for the area or RTO, as appropriate) divided by  the 
forecasted annual energy (for the area or RTO, as appropriate), when the area is experiencing a 
localized capacity emergency, as determined in accordance with the PJM Manuals. 
 
 
Capacity Emergency Transfer Limit (CETL): 
 
 
Capacity Emergency Transfer Limit” or “CETL” shall mean the capability of the transmission 
system to support deliveries of electric energy to a given area experiencing a localized capacity 
emergency as determined in accordance with the PJM Manuals. 
 
 
Capacity Import Limit: 
 
For any Delivery Year up to and including the 2019/2020 Delivery Year, “Capacity Import 
Limit” shall mean, (a) for the PJM Region, (1) the maximum megawatt quantity of external 
Generation Capacity Resources that PJM determines for each Delivery Year, through appropriate 
modeling and the application of engineering judgment, the transmission system can receive, in 
aggregate at the interface of the PJM Region with all external balancing authority areas and 
deliver to load in the PJM Region under capacity emergency conditions without violating 
applicable reliability criteria on any bulk electric system facility of 100kV or greater, internal or 
external to the PJM Region, that has an electrically significant response to transfers on such 
interface, minus (2) the then-applicable Capacity Benefit Margin; and (b) for certain source 
Page 29

zones identified in the PJM manuals as groupings of one or more balancing authority areas, (1) 
the maximum megawatt quantity of external Generation Capacity Resources that PJM 
determines the transmission system can receive at the interface of the PJM Region with each 
such source zone and deliver to load in the PJM Region under capacity emergency conditions 
without violating applicable reliability criteria on any bulk electric system facility of 100kV or 
greater, internal or external to the PJM Region, that has an electrically significant response to 
transfers on such interface, minus the then-applicable Capacity Benefit Margin times (2) the ratio 
of the maximum import quantity from each such source zone divided by the PJM total maximum 
import quantity.  As more fully set forth in the PJM Manuals, PJM shall make such 
determination based on the latest peak load forecast for the studied period, the same computer 
simulation model of loads, generation and transmission topography employed in the 
determination of Capacity Emergency Transfer Limit for such Delivery Year, including external 
facilities from an industry standard model of the loads, generation, and transmission topography 
of the Eastern Interconnection under peak conditions.  PJM shall specify in the PJM Manuals the 
areas and minimum distribution factors for identifying monitored bulk electric system facilities 
that have an electrically significant response to such transfers on the PJM interface.  Employing 
such tools, PJM shall model increased power transfers from external areas into PJM to determine 
the transfer level at which one or more reliability criteria is violated on any monitored bulk 
electric system facilities that have an electrically significant response to such transfers.  For the 
PJM Region Capacity Import Limit, PJM shall optimize transfers from other source areas not 
experiencing any reliability criteria violations as appropriate to increase the Capacity Import 
Limit.  The aggregate megawatt quantity of transfers into PJM at the point where any increase in 
transfers on the interface would violate reliability criteria will establish the Capacity Import 
Limit.  Notwithstanding the foregoing, a Capacity Resource located outside the PJM Region 
shall not be subject to the Capacity Import Limit if the Capacity Market Seller seeks an 
exception thereto by demonstrating to PJM, by no later than five (5) business days prior to the 
commencement of the offer period for the relevant RPM Auction, that such resource meets all of 
the following requirements: 
(i)  
it has, at the time such exception is requested, met all applicable requirements to 
be pseudo-tied into the PJM Region, or the Capacity Market Seller has committed in writing that 
it will meet such requirements, unless prevented from doing so by circumstances beyond the 
control of the Capacity Market Seller, prior to the relevant Delivery Year; 
 
(ii)  
at the time such exception is requested, it has long-term firm transmission service 
confirmed on the complete transmission path from such resource into PJM; and 
 
(iii) 
it is, by written commitment of the Capacity Market Seller, subject to the same 
obligations imposed on Generation Capacity Resources located in the PJM Region by Tariff, 
Attachment DD, section 6.6 to offer their capacity into RPM Auctions; provided, however, that 
(a) the total megawatt quantity of all exceptions granted hereunder for a Delivery Year, plus the 
Capacity Import Limit for the applicable interface determined for such Delivery Year, may not 
exceed the total megawatt quantity of Network External Designated Transmission Service on 
such interface that PJM has confirmed for such Delivery Year; and (b) if granting a qualified 
exception would result in a violation of the rule in clause (a), PJM shall grant the requested 
exception but reduce the Capacity Import Limit by the quantity necessary to ensure that the total 
quantity of Network External Designated Transmission Service is not exceeded. 
Page 30

Capacity Only Option: 
 
“Capacity Only Option” shall mean participation in Emergency Load Response Program or Pre-
Emergency Program which allows, pursuant to Tariff, Attachment DD and as applicable, a 
capacity payment for the ability to reduce load during a pre-emergency or emergency event. 
 
Capacity Performance Resource: 
 
“Capacity Performance Resource” shall have the same meaning as in Tariff, Attachment DD. 
 
Capacity Resources: 
 
 
“Capacity Resources” shall mean megawatts of (i) net capacity from Existing Generation 
Capacity Resources or Planned Generation Capacity Resources meeting the requirements of the 
Reliability Assurance Agreement, Schedules 9 and Reliability Assurance Agreement, Schedule 
10 that are or will be owned by or contracted to a Party and that are or will be committed to 
satisfy that Party's obligations under the Reliability Assurance Agreement, or to satisfy the 
reliability requirements of the PJM Region, for a Delivery Year; (ii) net capacity from Existing 
Generation Capacity Resources or Planned Generation Capacity Resources not owned or 
contracted for by a Party which are accredited to the PJM Region pursuant to the procedures set 
forth in such Schedules 9 and 10; or (iii)  load reduction capability provided by Demand 
Resources or Energy Efficiency Resources that are accredited to the PJM Region pursuant to the 
procedures set forth in the Reliability Assurance Agreement, Schedule 6; or (iv) generation and 
load reduction capability provided by a DER Capacity Aggregation Resource, pursuant to the 
procedures set forth in the Reliability Assurance Agreement, Schedule 6.2 and the PJM Manuals. 
 
 
Capacity Resource Provider: 
 
“Capacity Resource Provider” shall mean a Member that (1) owns, or has the contractual 
authority to control the output of, a Generation Capacity Resource, that has not transferred such 
authority to another entity; (2) or a DER Aggregator that has a contractual relationship to use a 
Component DER within a DER Aggregation Resource that is linked to a DER Capacity 
Aggregation Resource. 
 
Capacity Storage Resource Class: 
 
“Capacity Storage Resource Class” shall mean the ELCC Classes specified in Schedules 9.1 and 
9.2, section B of this Agreement, each of which is composed of (1) Capacity Storage Resources 
with the same specified characteristic duration of 4, 6, 8, and 10 hours or; (2) storage device 
Component DER. The characteristic duration of an Energy Storage Resource Class is the ratio of 
the modeled MWh energy storage capability of members of the class to the modeled MW power 
capability of members of the class. 
 
Capacity Transfer Right: 
 
 
Page 31

“Capacity Transfer Right” shall have the meaning specified in Tariff, Attachment DD. 
 
Coal Class: 
 
 
“Coal Class” shall mean an ELCC Class consisting of Unlimited Resources primarily 
fueled by coal. 
 
Combination Resource: 
 
“Combination Resource” shall mean a Generation Capacity Resource, or a generation 
Component DER within a DER Aggregation Resource that is linked to a DER Capacity 
Aggregation Resource, that has a component that has the characteristics of a Limited Duration 
Resource combined with (i) a component that has the characteristics of an Unlimited Resource or 
(ii) a component that has the characteristics of a Variable Resource. 
 
Compliance Aggregation Area (CAA): 
 
“Compliance Aggregation Area” or “CAA” shall have the same meaning as in the Tariff. 
 
Complex Hybrid Class: 
 
“Complex Hybrid Class” shall mean an ELCC Class composed of Combination Resources that 
combine three or more components, whereby one component is a class of Limited Duration 
Resource, and the other components are different Variable Resource classes, and such 
Combination Resources cannot be included in any other Combination Resource class. A resource 
that is a member of a Complex Hybrid Class has a single Point Of Interconnection, unless the 
resource is controlled in an integrated fashion, is at a single site, and is approved by PJM to be 
considered a single resource in accordance with the PJM Manuals. 
 
Consolidated Transmission Owners Agreement, PJM Transmission Owners Agreement or 
Transmission Owners Agreement: 
 
 
“Consolidated Transmission Owners Agreement,” “PJM Transmission Owners Agreement” or 
“Transmission Owners Agreement” shall mean that certain Consolidated Transmission Owners 
Agreement, dated as of December 15, 2005, by and among the Transmission Owners and by and 
between the Transmission Owners and PJM Interconnection, L.L.C. on file with the 
Commission, as amended from time to time. 
 
 
Control Area: 
 
“Control Area” shall mean an electric power system or combination of electric power systems 
bounded by interconnection metering and telemetry to which a common generation control 
scheme is applied in order to: 
 
 
Page 32

(a) 
match the power output of the generators within the electric power system(s) and 
energy purchased from entities outside the electric power system(s), with the load within the 
electric power system(s); 
 
 
 
(b) 
maintain scheduled interchange with other Control Areas, within the limits of 
Good Utility Practice; 
 
 
 
 (c) 
maintain the frequency of the electric power system(s) within reasonable limits in 
accordance with Good Utility Practice and the criteria of NERC and each Applicable Regional 
Entity; 
 
 
 
(d) 
maintain power flows on transmission facilities within appropriate limits to 
preserve reliability; and 
 
 
 
(e) 
provide sufficient generating capacity to maintain operating reserves in 
accordance with Good Utility Practice. 
 
 
Daily Unforced Capacity Obligation: 
 
 
“Daily Unforced Capacity Obligation” shall mean the capacity obligation of a Load Serving 
Entity during the Delivery Year, determined in accordance with the Reliability Assurance 
Agreement, Schedule 8 or, as to an FRR Entity, in the Reliability Assurance Agreement, 
Schedule 8.1. 
 
 
Delivery Year: 
 
 
“Delivery Year” shall mean a Planning Period for which a Capacity Resource is committed 
pursuant to the auction procedures specified in Tariff, Attachment DD or pursuant to an FRR 
Capacity Plan under RAA, Schedule 8.1. 
 
 
Demand Resource (DR): 
 
 
“Demand Resource” or “DR” shall mean a Limited Demand Resource, Extended Summer 
Demand Resource, Annual Demand Resource, Base Capacity Demand Resource or Summer-
Period Demand Resource with a demonstrated capability to provide a reduction in demand or 
otherwise control load in accordance with the requirements of RAA, Schedule 6 that offers and 
that clears load reduction capability in a Base Residual Auction or Incremental Auction or that is 
committed through an FRR Capacity Plan.   
 
Demand Resource Factor or DR Factor: 
 
 
“Demand Resource Factor” or “DR Factor” shall mean, for Delivery Years through May 31, 
2018, that factor approved from time to time by the PJM Board used to determine the unforced 
capacity value of a Demand Resource in accordance with Reliability Assurance Agreement, 
Schedule 6 
 
Page 33

Demand Resource Officer Certification Form: 
 
“Demand Resource Officer Certification Form” shall mean a certification as to an intended 
Demand Resource Sell Offer, in accordance with Reliability Assurance Agreement, Schedule 6 
and Reliability Assurance Agreement, Schedule 8.1 and the PJM Manuals. 
 
 
Demand Resource Registration: 
 
“Demand Resource Registration” shall mean a registration in the Full Program Option or 
Capacity Only Option of the Emergency or Pre-Emergency Load Resource Program in 
accordance with Tariff, Attachment K-Appendix, section 8. 
 
Demand Resource Sell Offer Plan: 
 
“Demand Resource Sell Offer Plan” shall mean the plan required by Reliability Assurance 
Agreement, Schedule 6 and Reliability Assurance Agreement, Schedule 8.1 in support of an 
intended offer of Demand Resources in an RPM Auction, or an intended inclusion of Demand 
Resources in an FRR Capacity Plan. 
 
Diesel Utility Class: 
 
"Diesel Utility Class" shall mean an ELCC Class consisting of Unlimited Resources of the diesel 
technology type that is not primarily fueled by landfill gas. 
 
DER Aggregator Officer Certification Form:  
 
“DER Aggregator Officer Certification Form” shall mean a DER Aggregator’s certification as to 
an intended DER Capacity Aggregation Resource Sell Offer, in accordance with Reliability 
Assurance Agreement, Schedule 6.2 and Reliability Assurance Agreement, Schedule 8.1 and the 
PJM Manuals. 
 
DER Capacity Aggregation Resource Sell Offer Plan:  
 
“DER Capacity Aggregation Resource Sell Offer Plan” shall mean the plan required by 
Reliability Assurance Agreement, Schedule 6.2 and Reliability Assurance Agreement, Schedule 
8.1 in support of an intended offer of a DER Capacity Aggregation Resource in an RPM 
Auction, or an intended inclusion of a DER Capacity Aggregation Resource in an FRR Capacity 
Plan. 
 
Effective Nameplate Capacity: 
 
“Effective Nameplate Capacity” shall mean (i) for each Variable Resource and Combination 
Resource that is a Generation Capacity Resource, the resource’s Maximum Facility Output (or, 
for a Co-Located Resource, the applicable share of the Mixed Technology Facility’s Maximum 
Facility Output); (ii) for each Variable Resource and Combination Resource, that is an individual 
Component DER within a DER Aggregation Resource that is linked to a DER Capacity 
Page 34

Aggregation Resource, the device’s maximum energy production capability, as defined by the 
resource’s state interconnection agreement; or (iii) for each Limited Duration Resource, the 
sustained level of output that the device can provide and maintain over a continuous period, 
whereby the duration of that continuous period matches the characteristic duration of the 
corresponding ELCC Class, with consideration given to ambient conditions expected to exist at 
the time of PJM system peak load, to the extent that such conditions impact such resource’s 
capability, not to exceed the Maximum Facility Output (or, for a Co-Located Resource, the 
applicable share of the Mixed Technology Facility’s Maximum Facility Output).  For the 
2025/2026 Delivery Year and subsequent Delivery Years, the Effective Nameplate Capacity of 
each Limited Duration Resource shall not exceed the greater of the Capacity Interconnection 
Rights of such Limited Duration Resource, or the transitional system capability as limited by the 
transitional resource MW ceiling as defined in the PJM Manuals, awarded for the applicable 
Delivery Year. 
 
Effective UCAP: 
 
“Effective UCAP” shall mean a unit of measure that represents the capacity product transacted in 
the Reliability Pricing Model and included in FRR Capacity Plans.  One megawatt of Effective 
UCAP has the same capacity value of one megawatt of Unforced Capacity. 
 
ELCC Class: 
 
“ELCC Class” shall mean a defined group of ELCC Resources that share a common set of 
operational characteristics and for which effective load carrying capability analysis, as set forth 
in RAA, Schedules 9.1 and 9.2, will establish a unique ELCC Class UCAP and corresponding 
ELCC Class Rating(s). ELCC Classes shall be defined in the Schedules 9.1 and 9.2, section B of 
this Agreement.  Members of an ELCC Class shall share a common method of calculating the 
ELCC Resource Performance Adjustment, provided that the individual ELCC Resource 
Performance Adjustment values will generally differ among ELCC Resources. 
 
ELCC Class Rating: 
 
“ELCC Class Rating” shall mean the rating factor, based on effective load carrying capability 
analysis, that applies to ELCC Resources that are members of an ELCC Class as part of the 
calculation of their Accredited UCAP. 
 
ELCC Class UCAP: 
 
“ELCC Class UCAP” shall mean the aggregate Effective UCAP all modeled ELCC Resources in 
a given ELCC Class are capable of providing in a given Delivery Year.  
 
ELCC Portfolio UCAP: 
 
“ELCC Portfolio UCAP” shall mean the aggregate Effective UCAP that all modeled ELCC 
Resources are capable of providing in a given Delivery Year. 
 
Page 35

ELCC Resource: 
 
“ELCC Resource” shall mean a Component DER within a DER Aggregation Resource that is 
linked to a DER Capacity Aggregation Resource, a Generation Capacity Resource or a Demand 
Resource. 
 
ELCC Resource Performance Adjustment: 
 
“ELCC Resource Performance Adjustment” shall mean the performance of a specific ELCC 
Resource relative to the aggregate performance of the ELCC Class to which it belongs as further 
described in RAA, Schedule 9.1, section F and RAA, Schedule 9.2, section D. 
 
Electric Cooperative: 
 
 
“Electric Cooperative” shall mean an entity owned in cooperative form by its customers that is 
engaged in the generation, transmission, and/or distribution of electric energy. 
 
 
Electric Distributor: 
 
 
“Electric Distributor” shall mean a Member that 1) owns or leases with rights equivalent to 
ownership of electric distribution facilities that are used to provide electric distribution service to 
electric load within the PJM Region; or 2) is a generation and transmission cooperative or a joint 
municipal agency that has a member that owns electric distribution facilities used to provide 
electric distribution service to electric load within the PJM Region. 
 
 
Emergency: 
 
 
“Emergency” shall mean (i) an abnormal system condition requiring manual or automatic action 
to maintain system frequency, or to prevent loss of firm load, equipment damage, or tripping of 
system elements that could adversely affect the reliability of an electric system or the safety of 
persons or property; or (ii) a fuel shortage requiring departure from normal operating procedures 
in order to minimize the use of such scarce fuel; or (iii) a condition that requires implementation 
of emergency procedures as defined in the PJM Manuals. 
 
 
End-Use Customer: 
 
 
“End-Use Customer” shall mean a Member that is a retail end-user of electricity within the 
PJM Region.  For purposes of Members Committee sector classification, a Member that is a 
retail end-user that owns generation may qualify as an End-Use customer if:  (1) the average 
physical unforced capacity owned by the Member and its affiliates in the PJM region over the 
five Planning Periods immediately preceding the relevant Planning Period does not exceed the 
average PJM capacity obligation for the Member and its affiliates over the same time period; or 
(2) the average energy produced by the Member and its affiliates within the PJM region over the 
five Planning Periods immediately preceding the relevant Planning Period does not exceed the 
average energy consumed by that Member and its affiliates within the PJM region over the same 
Page 36

time period.  The foregoing notwithstanding, taking retail service may not be sufficient to qualify 
a Member as an End-Use Customer. 
 
 
 
Energy Efficiency Resource: 
 
 
“Energy Efficiency Resource” shall mean a project, including installation of more efficient 
devices or equipment or implementation of more efficient processes or systems, meeting the 
requirements of RAA, Schedule 6 and exceeding then-current building codes, appliance 
standards, or other relevant standards, designed to achieve a continuous (during the periods 
described in Reliability Assurance Agreement, Schedule 6 and the PJM Manuals) reduction in 
electric energy consumption that is not reflected in the peak load forecast prepared for the 
Delivery Year for which the Energy Efficiency Resource is proposed, and that is fully 
implemented at all times during such Delivery Year, without any requirement of notice, dispatch, 
or operator intervention.  Annual Energy Efficiency Resources, Base Capacity Energy Efficiency 
Resources and Summer-Period Energy Efficiency Resources are types of Energy Efficiency 
Resources. 
 
Exigent Water Storage: 
 
“Exigent Water Storage” shall mean water stored in the pondage or reservoir of a hydropower 
resource which is not typically available during normal operating conditions (as those conditions 
are described in the relevant FERC hydropower license), but which can be drawn upon during 
emergency conditions (as described in the FERC hydropower license), including in order to 
avoid a load shed.  In an effective load carrying capability analysis, exigent storage capability 
from an upstream hydro facility can be considered relative to a downstream hydro facility by 
assessing cascading storage and flows. 
 
Existing Demand Resource: 
 
“Existing Demand Resource” shall mean a Demand Resource for which the Demand Resource 
Provider has identified existing end-use customer sites that are registered for the current Delivery 
Year with PJM (even if not registered by such Demand Resource Provider) and that the Demand 
Resource Provider reasonably expects to have under a contract to reduce load based on PJM 
dispatch instructions by the start of the Delivery Year for which such resource is offered. 
 
Existing DER Capacity Aggregation Resource: 
 
“Existing DER Capacity Aggregation Resource” shall mean a DER Capacity Aggregation 
Resource for which the DER Aggregator has identified existing Component DER that are 
registered in a DER Capacity Aggregation Resource for the current Delivery Year with PJM 
(even if not registered by such DER Aggregator) and that the DER Aggregator reasonably 
expects to have under a contract to generate or reduce load based on PJM dispatch instructions 
by the start of the Delivery Year for which such DER Capacity Aggregation Resource is offered. 
 
Existing Generation Capacity Resource: 
Page 37

“Existing Generation Capacity Resource” shall mean, for purposes of the must-offer requirement 
and mitigation of offers for any RPM Auction for a Delivery Year, a Generation Capacity 
Resource that, as of the date on which bidding commences for such auction: (a) is in service; or 
(b) is not yet in service, but has cleared any RPM Auction for any prior Delivery Year.  A 
Generation Capacity Resource shall be deemed to be in service if interconnection service has 
ever commenced (for resources located in the PJM Region), or if it is physically and electrically 
interconnected to an external Control Area and is in full commercial operation (for resources not 
located in the PJM Region).  The additional megawatts of a Generation Capacity Resource that is 
being, or has been, modified to increase the number of megawatts of available installed capacity 
thereof shall not be deemed to be an Existing Generation Capacity Resource until such time as 
those megawatts (a) are in service; or (b) are not yet in service, but have cleared any RPM 
Auction for any prior Delivery Year. 
 
Extended Summer Demand Resource: 
 
“Extended Summer Demand Resource” shall mean, for Delivery Years through May 31, 2018, 
and for FRR Capacity Plans Delivery Years through May 31, 2019, a resource that is placed 
under the direction of the Office of the Interconnection and that will be available June through 
October and the following May, and will be available for an unlimited number of interruptions 
during such months by the Office of the Interconnection, and will be capable of maintaining each 
such interruption for at least a 10-hour duration between the hours of 10:00AM to 10:00PM 
Eastern Prevailing Time. The Extended Summer Demand Resource must be available June 
through October and the following May in the corresponding Delivery Year to be offered for sale 
or Self-Supplied in an RPM Auction, or included as an Extended Summer Demand Resource in 
an FRR Capacity Plan for the corresponding Delivery Year.   
 
 
Facilities Study Agreement: 
 
 
“Facilities Study Agreement” shall have the same meaning as in Tariff, Part VI, section 206. 
 
 
 
FERC or Commission: 
 
 
“FERC” or “Commission” shall mean the Federal Energy Regulatory Commission or any 
successor federal agency, commission or department exercising jurisdiction over the Tariff, 
Operating Agreement and Reliability Assurance Agreement. 
 
 
Firm Point-To-Point Transmission Service: 
 
 
“Firm Point-To-Point Transmission Service” shall have the meaning specified in the Tariff. 
 
 
Firm Service Level: 
 
“Firm Service Level” or “FSL” of Price Responsive Demand shall mean the level, determined at 
a PRD Substation level, to which Price Responsive Demand shall be reduced during the Delivery 
Year when the Locational Marginal Price exceeds the price associated with such Price 
Page 38

Responsive Demand identified by the PRD Provider in its PRD Plan. “Firm Service Level” or 
“FSL” of Demand Resource shall mean the pre-determined level to which an end-use customer’s 
load shall be reduced, upon notification from the Curtailment Service Provider’s market 
operations center or its agent. 
 
Firm Transmission Service: 
 
 
“Firm Transmission Service” shall mean transmission service that is intended to be available at 
all times to the maximum extent practicable, subject to an Emergency, an unanticipated failure of 
a facility, or other event beyond the control of the owner or operator of the facility or the Office 
of the Interconnection. 
 
 
Fixed Resource Requirement Alternative or FRR Alternative: 
 
 
“Fixed Resource Requirement Alternative” or “FRR Alternative” shall mean an alternative 
method for a Party to satisfy its obligation to provide Unforced Capacity hereunder, as set forth 
in the Reliability Assurance Agreement, Schedule 8.1. 
 
Fixed-Tilt Solar Class: 
 
“Fixed-Tilt Solar Class” shall mean an ELCC Class consisting of Variable Resources that 
produce electrical energy with solar panels that are primarily mounted in a fixed orientation. 
 
 
Forecast Pool Requirement: 
 
 
“Forecast Pool Requirement” or “FPR” shall mean the amount equal to one plus the unforced 
reserve margin (stated as a decimal number) for the PJM Region required pursuant to this 
Reliability Assurance Agreement, as approved by the PJM Board pursuant to Reliability 
Assurance Agreement, Schedule 4.1. 
 
 
FRR Capacity Plan or FRR Plan: 
 
 
“FRR Capacity Plan” or “FRR Plan” shall mean a long-term plan for the commitment of 
Capacity Resources and Price Responsive Demand to satisfy the capacity obligations of a Party 
that has elected the FRR Alternative, as more fully set forth in the Reliability Assurance 
Agreement, Schedule 8.1. 
 
 
FRR Entity: 
 
 
“FRR Entity” shall mean, for the duration of such election, a Party that has elected the FRR 
Alternative hereunder. 
 
 
FRR Service Area: 
 
 
“FRR Service Area” shall mean (a) the service territory of an IOU as recognized by state law, 
rule or order; (b) the service area of a Public Power Entity or Electric Cooperative as recognized 
Page 39

by franchise or other state law, rule, or order; or (c) a separately identifiable geographic area that 
is: (i) bounded by wholesale metering, or similar appropriate multi-site aggregate metering, that 
is visible to, and regularly reported to, the Office of the Interconnection, or that is visible to, and 
regularly reported to an Electric Distributor and such Electric Distributor agrees to aggregate the 
load data from such meters for such FRR Service Area and regularly report such aggregated 
information, by FRR Service Area, to the Office of the Interconnection; and (ii) for which the 
FRR Entity has or assumes the obligation to provide capacity for all load (including load growth) 
within such area.  In the event that the service obligations of an Electric Cooperative or Public 
Power Entity are not defined by geographic boundaries but by physical connections to a defined 
set of customers, the FRR Service Area in such circumstances shall be defined as all customers 
physically connected to transmission or distribution facilities of such Electric Cooperative or 
Public Power Entity within an area bounded by appropriate wholesale aggregate metering as 
described above.   
 
 
Full Program Option: 
 
“Full Program Option” shall mean participation in Emergency Load Response Program or Pre-
Emergency Program which allows, pursuant to Tariff, Attachment DD and as applicable, (i) an 
energy payment for load reductions during a pre-emergency or emergency event, and (ii) a 
capacity payment for the ability to reduce load during a pre-emergency or emergency event. 
 
Full Requirements Service: 
 
 
“Full Requirements Service” shall mean wholesale service to supply all of the power needs of a 
Load Serving Entity to serve end-users within the PJM Region that are not satisfied by its own 
generating facilities. 
 
Gas Combined Cycle Class: 
 
“Gas Combined Cycle Class” shall mean an ELCC Class consisting of Unlimited Resources of 
the combined cycle technology type that is primarily fueled by natural gas, but does not meet the 
requirements to be included in the Gas Combined Cycle Dual Fuel Class. 
 
Gas Combined Cycle Dual Fuel Class: 
 
“Gas Combined Cycle Dual Fuel Class” shall mean an ELCC Class consisting of Unlimited 
Resources of the combined cycle technology type that is primarily fueled by natural gas, and that 
attests that it has the capability to start independently using onsite sources and operate 
independently on alternate onsite fuel source(s) up to its maximum capacity level during the 
winter season of the applicable Delivery Year in which it is providing capacity, and capable of 
operating on the alternate fuel for two 16-hour periods over two consecutive days at its 
maximum capacity level.  
 
Gas Combustion Turbine Class: 
 
Page 40

“Gas Combustion Turbine Class” shall mean an ELCC Class consisting of Unlimited Resources 
of the combustion turbine technology type that is primarily fueled by natural gas, but does not 
meet the requirements to be included in the Gas Combustion Turbine Dual Fuel Class. 
 
Gas Combustion Turbine Dual Fuel Class: 
 
“Gas Combustion Turbine Dual Fuel Class” shall mean an ELCC Class consisting of Unlimited 
Resources of the combustion turbine technology type that is primarily fueled by natural gas, and 
attests that it has the capability to start independently using onsite sources and operate 
independently on alternate onsite fuel source(s) up to its maximum capacity level during the 
winter season of the applicable Delivery Year in which it is providing capacity, and capable of 
operating on the alternate fuel for two 16-hour periods over two consecutive days at its 
maximum capacity level. 
 
 
Generation Capacity Resource: 
 
 
“Generation Capacity Resource” shall mean a Generating Facility, or the contractual right to 
capacity from a specified Generating Facility, that meets the requirements of RAA, Schedule 9 
and RAA, Schedule 10, and, for Generating Facilities that are committed to an FRR Capacity 
Plan, that meets the requirements of RAA, Schedule 8.1.  A Generation Capacity Resource may 
be an Existing Generation Capacity Resource or a Planned Generation Capacity Resource.  
 
Generation Owner: 
 
 
“Generation Owner” shall mean a Member that owns or leases with rights equivalent to 
ownership, or otherwise controls and operates one or more operating generation resources 
located in the PJM Region.  The foregoing notwithstanding, for a planned generation resource to 
qualify a Member as a Generation Owner, such resource shall have cleared an RPM auction, and 
for Energy Resources, the resource shall have a FERC-jurisdictional interconnection agreement 
or wholesale market participation agreement within PJM.   Purchasing all or a portion of the 
output of a generation resource shall not be sufficient to qualify a Member as a Generation 
Owner.  For purposes of Members Committee sector classification, a Member that is primarily a 
retail end-user of electricity that owns generation may qualify as a Generation Owner if:  (1) the 
generation resource is the subject of a FERC-jurisdictional interconnection agreement or 
wholesale market participation agreement within PJM; (2) the average physical unforced 
capacity owned by the Member and its affiliates over the five Planning Periods immediately 
preceding the relevant Planning Period exceeds the average PJM capacity obligation of the 
Member and its affiliates over the same time period; and (3) the average energy produced by the 
Member and its affiliates within PJM over the five Planning Periods immediately preceding the 
relevant Planning Period exceeds the average energy consumed by the Member and its affiliates 
within PJM over the same time period. 
 
 
Generator Forced Outage: 
 
 
“Generator Forced Outage” shall mean an immediate reduction in output or capacity or removal 
from service, in whole or in part, of a generating unit by reason of an Emergency or threatened 
Page 41

Emergency, unanticipated failure, or other cause beyond the control of the owner or operator of 
the facility, as specified in the relevant portions of the PJM Manuals.  A reduction in output or 
removal from service of a generating unit in response to changes in market conditions shall not 
constitute a Generator Forced Outage. 
 
 
Generator Maintenance Outage: 
 
 
“Generator Maintenance Outage” shall mean the scheduled removal from service, in whole or in 
part, of a generating unit in order to perform repairs on specific components of the facility, if 
removal of the facility qualifies as a maintenance outage pursuant to the PJM Manuals. 
 
 
Generator Planned Outage: 
 
 
“Generator Planned Outage” shall mean the scheduled removal from service, in whole or in part, 
of a generating unit for inspection, maintenance or repair with the approval of the Office of the 
Interconnection in accordance with the PJM Manuals. 
 
 
Good Utility Practice: 
 
 
“Good Utility Practice” shall mean any of the practices, methods and acts engaged in or 
approved by a significant portion of the electric utility 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 is intended to include acceptable 
practices, methods, or acts generally accepted in the region; including those practices required by 
Federal Power Act Section 215(a)(4).  
 
 
Hybrid Resource Class: 
 
“Hybrid Resource Class” shall mean the ELCC Classes specified in RAA Schedules 9.1 and 9.2 
Section B.  Each Hybrid Resource Class has a specified combination of two components, 
whereby, absent being part of a Combination Resource, the individual components would be in a 
Capacity Storage Resource Class, a Variable Resource Class or would be an Unlimited 
Resource.  A resource that is a member of a Hybrid Resource Class has a single Point Of 
Interconnection, unless the resource is controlled in an integrated fashion, is at a single site, and 
is approved by PJM to be considered a single resource in accordance with the PJM Manuals. 
 
Hydropower With Non-Pumped Storage: 
 
“Hydropower With Non-Pumped Storage” shall mean a hydropower facility that can capture and 
store incoming stream flow, without use of pumps, in pondage or a reservoir, and the Generation 
Owner has the ability, within the constraints available in the applicable operating license, to exert 
material control over the quantity of stored water and output of the facility throughout an 
Operating Day. 
Page 42

Hydropower With Non-Pumped Storage Class: 
 
“Hydropower With Non-Pumped Storage Class” shall mean an ELCC Class consisting of 
Combination Resources that are Hydropower With Non-Pumped Storage resources. 
 
Incremental Auction: 
 
 
“Incremental Auction” shall mean any of several auctions conducted for a Delivery Year after 
the Base Residual Auction for such Delivery Year and before the first day of such Delivery Year, 
including the First Incremental Auction, Second Incremental Auction, Third Incremental 
Auction, or Conditional Incremental Auction.  Incremental Auctions (other than the Conditional 
Incremental Auction), shall be held for the purposes of: 
 
(i) 
allowing Market Sellers that committed Capacity Resources in the Base Residual 
Auction for a Delivery Year, which subsequently are determined to be unavailable 
to deliver the committed Unforced Capacity in such Delivery Year (due to 
resource retirement, resource cancellation or construction delay, resource 
derating, EFORd increase, Accredited UCAP Factor decrease, a decrease in the 
Nominated Demand Resource Value of a Planned Demand Resource, delay or 
cancellation of a Qualifying Transmission Upgrade, or similar occurrences) to 
submit Buy Bids for replacement Capacity Resources; and  
 
(ii) 
allowing the Office of the Interconnection to reduce or increase the amount of 
committed capacity secured in prior auctions for such Delivery Year if, as a result 
of changed circumstances or expectations since the prior auction(s), there is, 
respectively, a significant excess or significant deficit of committed capacity for 
such Delivery Year, for the PJM Region or for an LDA. 
 
 
Intermittent Hydropower Class: 
 
“Intermittent Hydropower Class” shall mean an ELCC Class consisting of Variable Resources 
that are run-of-river hydropower generators that must generally pass incoming water and 
therefore cannot appreciably store water to later increase the output of the facility. Resources in 
the Intermittent Hydropower Class are not Hydropower with Non-Pumped Storage resources. 
 
IOU: 
 
 
“IOU” shall mean an investor-owned utility with substantial business interest in owning and/or 
operating electric facilities in any two or more of the following three asset categories:  
generation, transmission, distribution. 
 
Intermittent Landfill Gas Class: 
 
Page 43

“Intermittent Landfill Gas Class” shall mean an ELCC Class consisting of Variable Resources 
fueled by landfill gas that, because of fuel availability patterns, cannot run consistently at 
installed capacity levels for 24 or more hours. 
 
Large Load: 
 
“Large Load” shall mean end-use customer(s) load that has a cumulative peak load of 50 
megawatts or greater at a single electrical site behind one or more points of interconnection, 
where for configurations involving multiple affiliated load facilities or multiple points of 
interconnection with affiliated load facilities behind them, all affiliated load facilities within a 
one-mile radius will be considered a single electrical site as further described in the PJM 
Manuals. 
 
Large Load Adjustment: 
 
“Large Load Adjustment” shall mean any MW quantity of adjustments to summer peak load at 
the “zone/area” level and summed by Zone as further detailed in PJM Manuals.  For purposes of 
this definition, a “zone/area” is an area within a Zone for which the relevant Electric Distributor 
specifies a separate Obligation Peak Load MW value.  A zone/area is a service area of an 
Electric Distributor that is a separately identifiable, geographic area bounded by wholesale 
metering (e.g., the service territory of an operating company of a Transmission Owner). 
 
Limited Demand Resource: 
 
 
“Limited Demand Resource” shall mean, for Delivery Years through May 31, 2018, and for FRR 
Capacity Plans Delivery Years through May 31, 2019, a resource that is placed under the 
direction of the Office of the Interconnection and that will, at a minimum, be available for 
interruption for at least 10 Load Management Events during the summer period of June through 
September in the Delivery Year, and will be capable of maintaining each such interruption for at 
least a 6-hour duration.  At a minimum, the Limited Demand Resource shall be available for 
such interruptions on weekdays, other than NERC holidays, from 12:00PM (noon) to 8:00PM 
Eastern Prevailing Time.  The Limited Demand Resource must be available during the summer 
period of June through September in the corresponding Delivery Year to be offered for sale or 
Self-Supplied in an RPM Auction, or included as a Limited Demand Resource in an FRR 
Capacity Plan for the corresponding Delivery Year. 
 
Limited Duration Resource: 
 
“Limited Duration Resource” shall mean a Generation Capacity Resource or a generation 
Component DER within a DER Aggregation Resource that is linked to a DER Capacity 
Aggregation Resource, that is not a Variable Resource, that is not a Combination Resource, and 
that is not capable of running continuously at Maximum Facility Output for 24 hours or longer.  
A Capacity Storage Resource is a Limited Duration Resource. 
 
 
Load Serving Entity or LSE: 
 
 
Page 44

“Load Serving Entity” or “LSE” shall mean any entity (or the duly designated agent of such an 
entity), including a load aggregator or power marketer, (i) serving end-users within the PJM 
Region, and (ii) that has been granted the authority or has an obligation pursuant to state or local 
law, regulation or franchise to sell electric energy to end-users located within the PJM Region.  
Load Serving Entity shall include any end-use customer that qualifies under state rules or a 
utility retail tariff to manage directly its own supply of electric power and energy and use of 
transmission and ancillary services. 
 
 
Locational Reliability Charge: 
 
 
“Locational Reliability Charge” shall mean the charge determined pursuant to RAA, Article 7, 
section 2. 
 
 
Markets and Reliability Committee: 
 
 
“Markets and Reliability Committee” shall mean the committee established pursuant to the 
Operating Agreement as a Standing Committee of the Members Committee.  
 
 
Maximum Emergency Service Level: 
 
“Maximum Emergency Service Level” or “MESL” of Price Responsive Demand for the 
2017/2018 through the 2021/2022 Delivery Years shall mean the level, determined at a PRD 
Substation level, to which Price Responsive Demand shall be reduced during the Delivery Year 
when a Maximum Generation Emergency is declared and the Locational Marginal Price exceeds 
the price associated with such Price Responsive Demand identified by the PRD Provider in its 
PRD Plan. 
 
Member: 
 
 
“Member” shall have the meaning provided in the Operating Agreement. 
 
 
Members Committee: 
 
 
“Members Committee” shall mean the committee specified in Operating Agreement, section 8 
composed of the representatives of all the Members. 
 
 
NERC: 
 
 
“NERC” shall mean the North American Electric Reliability Corporation or any successor 
thereto. 
 
Network External Designated Transmission Service: 
 
“Network External Designated Transmission Service” shall mean the quantity of network 
transmission service confirmed by PJM for use by a market participant to import power and 
energy from an identified Generation Capacity Resource located outside the PJM Region, upon 
Page 45

demonstration by such market participant that it owns such Generation Capacity Resource, has 
an executed contract to purchase power and energy from such Generation Capacity Resource, or 
has a contract to purchase power and energy from such Generation Capacity Resource contingent 
upon securing firm transmission service from such resource. 
 
Network Resources: 
 
 
“Network Resources” shall have the meaning set forth in the PJM Tariff. 
 
 
Network Transmission Service: 
 
 
“Network Transmission Service” shall mean transmission service provided pursuant to the rates, 
terms and conditions set forth in Tariff, Part III or transmission service comparable to such 
service that is provided to a Load Serving Entity that is also a Transmission Owner. 
 
Nominal PRD Value:  
 
“Nominal PRD Value” shall mean, as to any PRD Provider, an adjustment, determined in 
accordance with Reliability Assurance Agreement, Schedule 6.1, to the peak-load forecast used 
to determine the quantity of capacity sought through an RPM Auction, reflecting the aggregate 
effect of Price Responsive Demand on peak load resulting from the Price Responsive Demand to 
be provided by such PRD Provider.    
 
Nominated Demand Resource Value: 
 
 
“Nominated Demand Resource Value” shall have the meaning specified in Tariff, Attachment 
DD. 
 
 
Non-Retail Behind the Meter Generation: 
 
 
“Non-Retail Behind the Meter Generation” shall mean Behind the Meter Generation that is used 
by municipal electric systems, electric cooperatives, and electric distribution companies to serve 
load. 
 
 
Nuclear Class: 
 
“Nuclear Class” shall mean an ELCC Class consisting of Unlimited Resources primarily fueled 
by nuclear fuel. 
 
Obligation Peak Load: 
 
 
“Obligation Peak Load” shall have the meaning specified in Reliability Assurance Agreement, 
Schedule 8. 
 
 
Office of the Interconnection: 
 
 
Page 46

“Office of the Interconnection” shall mean the employees and agents of PJM Interconnection, 
L.L.C., subject to the supervision and oversight of the PJM Board, acting pursuant to the 
Operating Agreement. 
 
Offshore Wind Class: 
 
“Offshore Wind Class” shall mean an ELCC Class consisting of Variable Resources that produce 
electrical energy with offshore wind turbines located in the ocean. 
 
Onshore Wind Class: 
 
“Onshore Wind Class” shall mean an ELCC Class consisting of Variable Resources that produce 
electrical energy using wind turbines and that are not in the Offshore Wind Class. 
 
 
Operating Agreement of the PJM Interconnection, L.L.C., Operating Agreement or PJM 
Operating Agreement: 
 
 
“Operating Agreement of the PJM Interconnection, L.L.C.,”  “Operating Agreement” or “PJM 
Operating Agreement” shall mean that agreement, dated as of April 1, 1997 and as amended and 
restated as of June 2, 1997, including all Schedules, Exhibits, Appendices, addenda or 
supplements hereto, as amended from time to time thereafter, among the Members of the PJM 
Interconnection, L.L.C, on file with the Commission. 
 
 
Operating Day: 
 
“Operating Day” shall have the same meaning as provided in the Operating Agreement. 
 
 
Operating Reserve: 
 
 
“Operating Reserve” shall mean the amount of generating capacity scheduled to be available for 
a specified period of an Operating Day to ensure the reliable operation of the PJM Region, as 
specified in the PJM Manuals. 
 
Ordinary Water Storage: 
 
“Ordinary Water Storage” shall mean water stored in the pondage or reservoir of a hydropower 
resource which is typically available during normal operating conditions pursuant to the FERC 
license governing the operation of the hydropower resource. 
 
 
Other Limited Duration Class: 
 
“Other Limited Duration Class” shall mean the ELCC Classes specified in RAA Schedules 9.1 
and 9.2 section B of this Agreement, each of which has a specified characteristic duration and 
consists of Limited Duration Resources that are not Capacity Storage Resources. The 
characteristic duration of an Other Limited Duration Class is the maximum period of time 
represented in the ELCC model that the resources of the class can run at a stated capability. 
Page 47

Other Limited Duration Combination Class: 
 
“Other Limited Duration Combination Class” shall mean the ELCC Classes specified in RAA 
Schedules 9.1 and 9.2 section B. Each Other Limited Duration Class has a specified combination 
of two components, whereby, absent being part of a Combination Resource, one component 
would be in an Other Limited Duration Class, and the other component would be in a Variable 
Resource Class or would be an Unlimited Resource. A resource that is a member of an Other 
Limited Duration Combination Class has a single Point Of Interconnection, unless the resource is 
controlled in an integrated fashion, is at a single site, and is approved by PJM to be considered a 
single resource in accordance with the PJM Manuals. 
 
Other Supplier: 
 
 
“Other Supplier” shall mean a Member that: (i) is engaged in buying, selling or transmitting 
electric energy, capacity, ancillary services, Financial Transmission Rights or other services 
available under PJM’s governing documents in or through the Interconnection or has a good faith 
intent to do so, and (ii) is not a Generation Owner, Electric Distributor, Transmission Owner or 
End-Use Customer. 
 
 
Other Unlimited Resource Class: 
 
“Other Unlimited Resource Class” shall mean an ELCC Class consisting of Unlimited Resources 
that do not qualify for any other ELCC Class specified in RAA Schedule 9.2, section D. 
 
Other Variable Resource Class: 
 
“Other Variable Resource Class” shall mean an ELCC Class consisting of Variable Resources 
that are not in any other Variable Resource class, including Variable Resources that are 
composed of multiple components, each of which would be a Variable Resource. A resource 
composed of both fixed-tilt solar panels and tracking solar panels is not in this class. A resource 
that is a member of a Other Variable Resource Class has a single Point Of Interconnection, 
unless the resource is controlled in an integrated fashion, is at a single site, and is approved by 
PJM to be considered a single resource in accordance with the PJM Manuals. 
 
Partial Requirements Service: 
 
 
“Partial Requirements Service” shall mean wholesale service to supply a specified portion, but 
not all, of the power needs of a Load Serving Entity to serve end-users within the PJM Region 
that are not satisfied by its own generating facilities. 
 
Party: 
 
“Party” shall mean an entity bound by the terms of the Operating Agreement. 
 
Peak Shaving Adjustment:  
Page 48

“Peak Shaving Adjustment” shall mean a load forecast mechanism that allows load reductions by 
end-use customers to result in a downward adjustment of the summer load forecast for the 
associated Zone. Any End-Use Customer identified in an approved peak shaving plan shall not 
also participate in PJM Markets as Price Responsive Demand, Demand Resource, Base Capacity 
Demand Resource, Capacity Performance Demand Resource, or Economic Load Response 
Participant. 
 
Percentage Internal Resources Required: 
 
 
“Percentage Internal Resources Required” shall mean, for purposes of an FRR Capacity Plan, the 
percentage of the LDA Reliability Requirement for an LDA that must be satisfied with Capacity 
Resources located in such LDA. 
 
Performance Assessment Interval: 
 
“Performance Assessment Interval” shall have the meaning specified in Tariff, Attachment DD. 
 
 
PJM: 
 
 
“PJM” shall mean PJM Interconnection, L.L.C., including the Office of the Interconnection as 
referenced in the PJM Operating Agreement.  When such term is being used in the RAA it shall 
also include the PJM Board. 
 
 
PJM Board: 
 
 
“PJM Board” shall mean the Board of Managers of the  LLC, acting pursuant to the Operating 
Agreement, except when such term is being used in Tariff, Attachment M, in which case PJM 
Board shall mean the Board of Managers of PJM or its designated representative, exclusive of 
any members of PJM Management. 
 
PJM Manuals: 
 
 
“PJM Manuals” shall mean the instructions, rules, procedures and guidelines established by the 
Office of the Interconnection for the operation, planning and accounting requirements of the PJM 
Region. 
 
PJM Region: 
 
 
“PJM Region” shall have the same meaning as provided in the Operating Agreement. 
 
 
PJM Region Installed Reserve Margin: 
 
 
“PJM Region Installed Reserve Margin” shall mean the percent installed reserve margin for the 
PJM Region required pursuant to Reliability Assurance Agreement, Schedule 4.1, as approved 
by the PJM Board. 
Page 49

PJM Tariff, Tariff, O.A.T.T., OATT or PJM Open Access Transmission Tariff: 
 
 
“PJM Tariff,” “Tariff,” “O.A.T.T., “OATT” or “PJM Open Access Transmission Tariff” shall 
mean that certain PJM Open Access Transmission Tariff, including any schedules, appendices, 
or exhibits attached thereto, on file with FERC and as amended from time to time thereafter. 
 
 
Planned Demand Resource: 
 
 
“Planned Demand Resource” shall mean any Demand Resource that does not currently have the 
capability to provide a reduction in demand or to otherwise control load, but that is scheduled to 
be capable of providing such reduction or control on or before the start of the Delivery Year for 
which such resource is to be committed, as determined in accordance with the requirements of 
Reliability Assurance Agreement, Schedule 6.  As set forth in Reliability Assurance Agreement, 
Schedule 6 and Reliability Assurance Agreement, Schedule 8.1, a Demand Resource Provider 
submitting a DR Sell Offer Plan shall identify as Planned Demand Resources in such plan all 
Demand Resources in excess of those that qualify as Existing Demand Resources. 
 
 
Planned DER Capacity Aggregation Resource: 
 
A “Planned DER Capacity Aggregation Resource” shall mean any DER Capacity Aggregation 
Resource that does not currently have the capability to provide generation or reduction in 
demand, but that is scheduled to be capable of providing such generation or reduction in demand 
on or before the start of the Delivery Year for which such resource is to be committed, as 
determined in accordance with the requirements of Reliability Assurance Agreement, Schedule 
6.2.  As set forth in Reliability Assurance Agreement, Schedule 6.2 and Reliability Assurance 
Agreement, Schedule 8.1, a DER Aggregator submitting a DER Capacity Aggregation Resource 
Sell Offer Plan shall identify in such plan all DER Capacity Aggregation Resources in excess of 
those that qualify as Existing DER Capacity Aggregation Resources.  A Planned DER Capacity 
Aggregation Resource must comply with all provisions of the DER Aggregator Participation 
Model described in Tariff, Attachment K-Appendix, section 1.4B and Operating Agreement, 
Schedule 1, section 1.4B, prior to the applicable Delivery Year. 
 
Planned External Generation Capacity Resource: 
 
 
“Planned External Generation Capacity Resource” shall mean a proposed Generation Capacity 
Resource, or a proposed increase in the capability of a Generation Capacity Resource, that (a) is 
to be located outside the PJM Region, (b) participates in the generation interconnection process 
of a Control Area external to PJM, (c) is scheduled to be physically and electrically 
interconnected to the transmission facilities of such Control Area on or before the first day of the 
Delivery Year for which such resource is to be committed to satisfy the reliability requirements 
of the PJM Region, and (d) is in full commercial operation prior to the first day of such Delivery 
Year, such that it is sufficient to provide the Installed Capacity set forth in the Sell Offer forming 
the basis of such resource’s commitment to the PJM Region.  Prior to participation in any Base 
Residual Auction for such Delivery Year, the Capacity Market Seller must demonstrate that it 
has documentation which is functionally equivalent to an approved Decision Point I submission 
Page 50

under the PJM Tariff Part VII or VIII as applicable or, for resources which are greater than 
20MWs participating in a Base Residual Auction for the 2019/2020 Delivery Year and 
subsequent Delivery Years, an agreement or other documentation which is functionally 
equivalent to an approved Decision Point II submission under the PJM Tariff Part VII or VIII as 
applicable, with the transmission owner to whose transmission facilities or distribution facilities 
the resource is being directly connected, and, as applicable, the transmission provider.  Prior to 
participating in any Incremental Auction for such Delivery Year, the Capacity Market Seller 
must demonstrate it has entered into an interconnection agreement, or such other documentation 
that is functionally equivalent to a Generation Interconnection Agreement under the PJM Tariff, 
with the transmission owner to whose transmission facilities or distribution facilities the resource 
is being directly connected, and, as applicable, the transmission provider.  A Planned External 
Generation Capacity Resource must provide evidence to PJM that it has been studied as a 
Network Resource, or such other similar interconnection product in such external Control Area, 
must provide contractual evidence that it has applied for or purchased transmission service to be 
deliverable to the PJM border, and must provide contractual evidence that it has applied for 
transmission service to be deliverable to the bus at which energy is to delivered, the agreements 
for which must have been executed prior to participation in any Reliability Pricing Model 
Auction for such Delivery Year. Any such resource shall cease to be considered a Planned 
External Generation Capacity Resource as of the earlier of (i) the date that interconnection 
service commences as to such resource; or (ii) the resource has cleared an RPM Auction, in 
which case it shall become an Existing Generation Capacity Resource for purposes of the 
mitigation of offers for any RPM Auction for all subsequent Delivery Years.   
 
 
Planned Generation Capacity Resource: 
 
 
“Planned Generation Capacity Resource” shall mean a Generation Capacity Resource, or 
additional megawatts to increase the size of a Generation Capacity Resource that is being or has 
been modified to increase the number of megawatts of available installed capacity thereof,  
participating in the generation interconnection process under Tariff, Part IV, Subpart A, Part VII 
or Part VIII, as applicable, for which: (i) Interconnection Service is scheduled to commence on 
or before the first day of the Delivery Year for which such resource is to be committed to RPM 
or to an FRR Capacity Plan; (ii) for any such resource seeking to offer into a Base Residual 
Auction, or for any such resource of 20 MWs or less seeking to offer into a Base Residual 
Auction, all the requirements for an approved Decision Point I submission have been met under 
Tariff Part VII or VIII (or, for resources for which a Decision Point I submission is not required, 
has such other agreement or documentation that is functionally equivalent to a an approved 
Decision Point I submission) prior to the Base Residual Auction for such Delivery Year; (iii) for 
any such resource of more than 20 MWs seeking to offer into a Base Residual Auction for the 
2019/2020 Delivery Year and subsequent Delivery Years, all the requirements for an approved 
Decision Point II submission have been met under Tariff Part VII or VIII (or, for resources for 
which a Decision Point II submission is not required, has such other agreement or documentation 
that is functionally equivalent to an approved Decision Point II submission) has been executed 
prior to the Base Residual Auction for such Delivery Year; and (iv) a Generation Interconnection 
Agreement or Wholesale Market Participation Agreement has been executed prior to any 
Incremental Auction for such Delivery Year in which such resource plans to participate.  For 
purposes of the must-offer requirement and mitigation of offers for any RPM Auction for a 
Page 51

Delivery Year, a Generation Capacity Resource shall cease to be considered a Planned 
Generation Capacity Resource as of the earlier of (i) the date that Interconnection Service 
commences as to such resource; or (ii) the resource has cleared an RPM Auction for any 
Delivery Year, in which case it shall become an Existing Generation Capacity Resource for any 
RPM Auction for all subsequent Delivery Years.   
 
 
Planning Period: 
 
 
“Planning Period” shall mean the 12 months beginning June 1 and extending through May 31 of 
the following year, or such other period approved by the Members Committee. 
 
 
Portfolio Expected Unserved Energy: 
 
“Portfolio Expected Unserved Energy” shall mean the annual amount of expected unserved 
energy, in MWh, that is expected for the RTO when at the annual reliability criteria that provides 
an acceptable level of reliability consistent with the Reliability Principles and Standards. 
 
PRD Curve: 
 
“PRD Curve” shall mean a price-consumption curve at a PRD Substation level, if available, and 
otherwise at a Zonal (or sub-Zonal LDA, if applicable) level, that details the base consumption 
level of Price Responsive Demand and the decreasing consumption levels at increasing prices. 
 
PRD Provider:  
 
“PRD Provider” shall mean a PJM Member that has entered contractual arrangements with end-
use customers that satisfy the eligibility criteria for and provides Price Responsive Demand. 
 
PRD Provider’s Zonal Expected Peak Load Value of PRD:  
 
“PRD Provider’s Zonal Expected Peak Load Value of PRD” shall mean the expected 
contribution to Delivery Year peak load of a PRD Provider’s Price Responsive Demand, were 
such demand not to be reduced in response to price, based on the contribution of the end-use 
customers comprising such Price Responsive Demand to the most recent prior Delivery Year’s 
peak demand, escalated to the Delivery Year in question, as determined in a manner consistent 
with the Office of the Interconnection’s load forecasts used for purposes of the RPM Auctions. 
 
PRD Reservation Price: 
 
“PRD Reservation Price” shall mean an RPM Auction clearing price identified in a PRD Plan for 
Price Responsive Demand load below which the PRD Provider desires not to commit the 
identified load as Price Responsive Demand. 
  
PRD Substation: 
 
Page 52

“PRD Substation” shall mean an electrical substation that is located in the same Zone or in the 
same sub-Zonal LDA as the end-use customers identified in a PRD Plan or PRD registration and 
that, in terms of the electrical topography of the Transmission Facilities comprising the PJM 
Region, is as close as practicable to such loads. 
 
Price Responsive Demand: 
 
“Price Responsive Demand” or “PRD” shall mean end-use customer load registered by a PRD 
Provider pursuant to Reliability Assurance Agreement, Schedule 6.1 that have, as set forth in 
more detail in the PJM Manuals, the metering capability to record electricity consumption at an 
interval of one hour or less, Supervisory Control capable of curtailing such load (consistent with 
applicable RERRA requirements) at each PRD Substation identified in the relevant PRD Plan or 
PRD registration in response to a Performance Assessment Interval that triggers a PRD 
performance assessment or a Non-PAI Event, and a retail rate structure, or equivalent contractual 
arrangement, capable of changing retail rates as frequently as an hourly basis, that is linked to or 
based upon changes in real-time Locational Marginal Prices at a PRD Substation level and that 
results in a predictable automated response to varying wholesale electricity prices. 
 
Price Responsive Demand Credit: 
 
“Price Responsive Demand Credit” shall mean a credit, based on committed Price Responsive 
Demand, as determined under Reliability Assurance Agreement, Schedule 6.1. 
 
Price Responsive Demand Plan or PRD Plan: 
 
“Price Responsive Demand Plan” or “PRD Plan” shall mean a plan, submitted by a PRD 
Provider and received by the Office of the Interconnection in accordance with Reliability 
Assurance Agreement, Schedule 6.1 and procedures specified in the PJM Manuals, claiming a 
peak demand limitation due to Price Responsive Demand to support the determination of such 
PRD Provider’s Nominal PRD Value. 
 
Public Power Entity: 
 
 
“Public Power Entity” shall mean any agency, authority, or instrumentality of a state or of a 
political subdivision of a state, or any corporation wholly owned by any one or more of the 
foregoing, that is engaged in the generation, transmission, and/or distribution of electric energy. 
 
 
Qualifying Transmission Upgrades: 
 
 
“Qualifying Transmission Upgrades” shall have the meaning specified in Tariff, Attachment DD. 
 
 
Relevant Electric Retail Regulatory Authority: 
 
“Relevant Electric Retail Regulatory Authority” or “RERRA” shall have the meaning specified 
in the PJM Operating Agreement. 
 
Page 53

Reliability Principles and Standards: 
 
 
“Reliability Principles and Standards” shall mean the principles and standards established by  the 
Office of the Interconnection that define, among other things, an acceptable probabilistic of loss 
of load criteria due to inadequate generation or transmission capability, as amended from time to 
time. 
 
 
Required Approvals: 
 
 
“Required Approvals” shall mean all of the approvals required for the Operating Agreement to 
be modified or to be terminated, in whole or in part, including the acceptance for filing by FERC 
and every other regulatory authority with jurisdiction over all or any part of the Operating 
Agreement. 
 
 
Self-Supply: 
 
 
“Self-Supply” shall have the meaning provided in Tariff, Attachment DD. 
 
Small Commercial Customer: 
 
“Small Commercial Customer” shall have the same meaning as in the PJM Tariff. 
 
 
State Consumer Advocate: 
 
 
“State Consumer Advocate” shall mean a legislatively created office from any State, all or any 
part of the territory of which is within the PJM Region, and the District of Columbia established, 
inter alia, for the purpose of representing the interests of energy consumers before the utility 
regulatory commissions of such states and the District of Columbia and the FERC.  
 
 
State Regulatory Structural Change: 
 
 
“State Regulatory Structural Change” shall mean as to any Party, a state law, rule, or order that, 
after September 30, 2006, initiates a program that allows retail electric consumers served by such 
Party to choose from among alternative suppliers on a competitive basis, terminates such a 
program, expands such a program to include classes of customers or localities served by such 
Party that were not previously permitted to participate in such a program, or that modifies retail 
electric market structure or market design rules in a manner that materially increases the 
likelihood that a substantial proportion of the customers of such Party that are eligible for retail 
choice under such a program (a) that have not exercised such choice will exercise such choice; or 
(b) that have exercised such choice will no longer exercise such choice, including for example, 
without limitation, mandating divestiture of utility-owned generation or structural changes to 
such Party’s default service rules that materially affect whether retail choice is economically 
viable. 
 
Steam Class: 
 
Page 54

“Steam Class” shall mean an ELCC Class consisting of Unlimited Resources of the steam 
technology type and the primary fuel is not coal or nuclear. 
 
Summer-Period Demand Resource: 
 
Summer-Period Demand Resource shall mean, for the 2020/2021 Delivery Year and subsequent 
Delivery Years, a resource that is placed under the direction of the Office of the Interconnection, 
and will be available June through October and the following May of the Delivery Year, and will 
be available for an unlimited number of interruptions during such months by the Office of the 
Interconnection, and will be capable of maintaining each such interruption between the hours of 
10:00AM to 10:00PM Eastern Prevailing Time.  The Summer-Period Demand Resource must be 
available June through October and the following May in the corresponding Delivery Year to be 
offered for sale in an RPM Auction, or included as a Summer-Period Demand Resource in an 
FRR Capacity Plan for the corresponding Delivery Year. 
 
Summer-Period Energy Efficiency Resource:  
 
Summer-Period Energy Efficiency Resource shall mean, for the 2020/2021 Delivery Year and 
subsequent Delivery Years, a project, including installation of more efficient devices or 
equipment or implementation of more efficient processes or systems, meeting the requirements 
of Reliability Assurance Agreement, Schedule 6 and exceeding then-current building codes, 
appliance standards, or other relevant standards, designed to achieve a continuous (during the 
summer peak periods as described in Reliability Assurance Agreement, Schedule 6 and the PJM 
Manuals) reduction in electric energy consumption that is not reflected in the peak load forecast 
prepared for the Delivery Year for which the Summer-Period Energy Efficiency Resource is 
proposed, and that is fully implemented at all times during such Delivery Year, without any 
requirement of notice, dispatch, or operator intervention. 
 
Supervisory Control: 
 
“Supervisory Control” shall mean the capability to curtail, in accordance with applicable 
RERRA requirements, load registered as Price Responsive Demand at each PRD Substation 
identified in the relevant PRD Plan or PRD registration in response to a Maximum Generation 
Emergency declared by the Office of the Interconnection.  Except to the extent automation is not 
required by the provisions of the Operating Agreement, the curtailment shall be automated, 
meaning that load shall be reduced automatically in response to control signals sent by the PRD 
Provider or its designated agent directly to the control equipment where the load is located 
without the requirement for any action by the end-use customer. 
 
 
Threshold Quantity: 
 
 
“Threshold Quantity” shall mean, as to any FRR Entity for any Delivery Year, the sum of (a) the 
Unforced Capacity equivalent (determined using the Pool-Wide Average EFORD through the 
2024/2025 Delivery Year, or pool-wide average Accredited UCAP Factor effective with the 
2025/2026 Delivery Year) of the Installed Reserve Margin for such Delivery Year multiplied by 
the Preliminary Forecast Peak Load for which such FRR Entity is responsible under its FRR 
Page 55

Capacity Plan for such Delivery Year, plus (b) the lesser of (i) 3% of the Unforced Capacity 
amount determined in (a) above or (ii) 450 MW.  If the FRR Entity is not responsible for all load 
within a Zone, the Preliminary Forecast Peak Load for such entity shall be determined in 
accordance with Reliability Assurance Agreement, Schedule 8.1, section D.2. 
 
 
Tracking Solar Class: 
 
“Tracking Solar Class” shall mean an ELCC Class consisting of Variable Resources that produce 
electrical energy with solar panels that are primarily mounted on trackers that align the panels 
with incoming sunlight over the course of the day. 
 
Transmission Facilities: 
 
 
“Transmission Facilities” shall mean facilities that:  (i) are within the PJM Region; (ii) meet the 
definition of transmission facilities pursuant to FERC’s Uniform System of Accounts or have 
been classified as transmission facilities in a ruling by FERC addressing such facilities; and (iii) 
have been demonstrated to the satisfaction of the Office of the Interconnection to be integrated 
with the PJM Region transmission system and integrated into the planning and operation of the 
PJM Region to serve all of the power and transmission customers within the PJM Region. 
 
 
Transmission Owner: 
 
 
“Transmission Owner” shall mean a Member that owns or leases with rights equivalent to 
ownership Transmission Facilities and is a signatory to the PJM Transmission Owners 
Agreement.  Taking transmission service shall not be sufficient to qualify a Member as a 
Transmission Owner. 
 
 
Unforced Capacity: 
 
 
“Unforced Capacity” shall mean installed capacity rated at summer conditions that is not on 
average experiencing a forced outage or forced derating, calculated for each Capacity Resource 
on the 12-month period from October to September without regard to the ownership of or the 
contractual rights to the capacity of the unit. 
 
Unlimited Resource: 
 
“Unlimited Resource” shall mean a generating unit having the ability to maintain output at a 
stated capability continuously on a daily basis without interruption.  Through the 2024/2025 
Delivery Year, an Unlimited Resource is a Generation Capacity Resource that is not an ELCC 
Resource. 
 
Variable Resource: 
 
“Variable Resource” shall mean a Generation Capacity Resource or a generation Component 
DER within a DER Aggregation Resource that is linked to a DER Capacity Aggregation 
Resource, with output that can vary as a function of its energy source, such as wind, solar, run of 
Page 56

river hydroelectric power without storage, and landfill gas units without an alternate fuel source.  
All Intermittent Resources are Variable Resources, with the exception of Hydropower with Non-
Pumped Storage. 
 
 
Winter Peak Load (or WPL): 
 
“Winter Peak Load” or “WPL” shall mean the average of the Demand Resource customer’s 
specific peak hourly load between hours ending 7:00 EPT through 21:00 EPT on the PJM 
defined 5 coincident peak days from December through February two Delivery Years prior the 
Delivery Year for which the registration is submitted.  Notwithstanding, if the average use 
between hours ending 7:00 EPT through 21:00 EPT on a winter 5 coincident peak day is below 
35% of the average hours ending 7:00 EPT through 21:00 EPT over all five of such peak days, 
then up to two such days and corresponding peak demand values may be excluded from the 
calculation.  Upon approval by the Office of the Interconnection, a Curtailment Service Provider 
may provide alternative data to calculate Winter Peak Load, as outlined in the PJM Manuals, 
when there is insufficient hourly load data for the two Delivery Years prior to the relevant 
Delivery Year or if more than two days meet the exclusion criteria described above. 
 
Zonal Capacity Price: 
 
 
“Zonal Capacity Price” shall mean the clearing price required in each Zone to meet the demand 
for Unforced Capacity and satisfy Locational Deliverability Requirements for the LDA or LDAs 
associated with such Zone.  If the Zone contains multiple LDAs with different Capacity 
Resource Clearing Prices, the Zonal Capacity Price shall be a weighted average of the Capacity 
Resource Clearing Prices for such LDAs, weighted by the Unforced Capacity of Capacity 
Resources cleared in each such LDA.   
 
 
Zone or Zonal: 
 
 
“Zone” or “Zonal” shall refer to an area within the PJM Region, as set forth in Tariff, 
Attachment J and RAA, Schedule 15, or as such areas may be (i) combined as a result of mergers 
or acquisitions or (ii) added as a result of the expansion of the boundaries of the PJM Region.  A 
Zone shall include any Non-Zone Network Load located outside the PJM Region that is served 
from such Zone under Tariff, Attachment H-A. 
 
Zonal Winter Weather Adjustment Factor (ZWWAF): 
 
“Zonal Winter Weather Adjustment Factor” or “ZWWAF” shall mean the PJM zonal winter 
weather normalized  coincident peak  divided by PJM zonal average of 5 coincident peak loads in 
December through February. 
 
Page 57

SCHEDULE 11 
 
DATA SUBMITTALS 
 
A. 
To perform the studies required to determine the Forecast Pool Requirement and Daily 
Unforced Capacity Obligations under this Agreement and to determine compliance with the 
obligations imposed by this Agreement, each Party and other owner of a Capacity Resource shall 
submit data to the Office of the Interconnection in conformance with the following minimum 
requirements: 
 
1. 
All data submitted shall satisfy the requirements, as they may change from time to time, of 
any procedures adopted by the Members Committee. 
 
2. 
Data shall be submitted in an electronic format, or as otherwise specified by the Markets 
and Reliability Committee and approved by the PJM Board. 
 
3. 
Actual outage data for each month for Generator Forced Outages, Generator Maintenance 
Outages and Generator Planned Outages shall be submitted so that it is received by such 
date specified in the PJM Manuals. 
 
4. 
On or before the date specified in the PJM Manuals, planned and maintenance outage data 
for all Generation Resources shall be submitted. 
 
 
The Parties acknowledge that additional information required to determine the Forecast Pool 
Requirement is to be obtained by the Office of the Interconnection from Electric Distributors in 
accordance with the provisions of the Operating Agreement. 
 
B. 
1. 
(a) 
Each entity bound by the Operating Agreement shall submit, or cause to be 
submitted, to the Office of the Interconnection the following information, as may be further 
described in the PJM Manuals, related to each Large Load served by the entity bound by 
the Operating Agreement: 
 
• Eligible Customer/Network Customer for Large Load; 
• Description of Large Load; 
• Location(s) (Control Zone, Electric Distributor zone/area, where a 
zone/area is an area within a Zone for which the relevant Electric 
Distributor specifies a separate Obligation Peak Load MW value. A 
zone/area is a service area of an Electric Distributor that is a separately 
identifiable, geographic area bounded by wholesale metering); 
• In-service date for each increment of load; 
• Peak shaving adjustment value pursuant to a state program codified in 
state law and whether and how it meets the requirements of Tariff, 
Attachment DD-2; 
• Delivery point / Point(s) of interconnection (include all if more than 
one); 
Page 58

• Peak load quantity (MW) and ramp schedule, if applicable; 
• Telemetry specifications; 
• Backup generation (MW), including fuel type and relevant permitting 
limitations; 
• Contracts or service agreements between the Large Load and the LSE; 
• Points of contact at the applicable Transmission Owner, Electric 
Distributor, and Load Serving Entity; 
• EMS B1/B2/B3 name (for the applicable Transmission Owner, Electric 
Distributor); and  
• Additional details and contents as necessary, in accordance with the 
PJM Manuals. 
 
(b) 
The entities bound by the Operating Agreement acknowledge that 
information related to the development and maintenance of the Large Load Registry may 
be obtained by the Office of the Interconnection from Electric Distributors in accordance 
with the provisions of the Operating Agreement and the Tariff.   
 
(c) 
The Office of the Interconnection may review information and coordinate 
with the applicable Transmission Owner and Electric Distributor as needed, regarding the 
validity of the information provided, including through requesting additional information 
as the Office of the Interconnection deems necessary, as further set forth in the PJM 
Manuals.  The Office of the Interconnection also may consult with the Large Load. 
 
(d) 
Based on the information provided, or caused to be provided, by each entity 
bound by the Operating Agreement, as well as other information provided by, for example, 
Electric Distributors, the Office of the Interconnection shall maintain a registry of all Large 
Loads, and update it periodically.  To the extent such documents, data, or other information 
provided to the Office of the Interconnection has been designated as confidential by an 
entity bound by the Operating Agreement, Electric Distributor, or other entity supplying 
the information, the Office of the Interconnection shall maintain the confidentiality of the 
information provided under this RAA, Schedule 11, section B consistent with its 
obligations under Operating Agreement, section 18.17.  Information maintained in the 
Large Load registry may be available to Authorized Commissions, Transmission Owners, 
Electric Distributors, Load Serving Entities, the Market Monitoring Unit, and FERC 
subject to appropriate data protection safeguards required by Operating Agreement, section 
18.17. 
 
(e) 
The Office of the Interconnection shall post aggregate data from the Large 
Load Registry on the PJM website, aggregated by Electric Distributor zone/area, where 
possible and in a manner consistent with existing confidentiality protections in the PJM 
Governing Agreements. 
 
2. 
(a) 
Each entity bound by the Operating Agreement serving or contracted to 
serve a Large Load that is or will be in service prior to June 1, 2027, shall provide the 
information required by RAA, Schedule 11.B.1 to the Office of the Interconnection by 
March 1, 2027.  
Page 59

(b) 
Each entity bound by the Operating Agreement serving or contracted to 
serve a Large Load that will be in service on or after June 1, 2027, shall provide the 
information required by RAA, Schedule 11.B.1 to the Office of the Interconnection before 
the in-service date of the Large Load. 
 
Each entity bound by the Operating Agreement shall promptly inform the Office of the 
Interconnection of any change in the information required by RAA, Schedule 11.B.1 with 
respect to a Large Load served by such entity bound by the Operating Agreement, including 
whether the entity bound by the Operating Agreement no longer serves the Large Load or 
has acquired the contractual right to serve a registered Large Load. 
Page 60