ER26-3515-002 · 2026-11-09 · PJM

FERC rendition of the electronically filed tariff records

FERC rendition of the electronically filed tariff records in Docket No. ER26-03515-002
Filing Data:
Tariff Record Data:
CID
Filing Title
Company Filing
Identifier
Type of Filing
Code
Associated
Filing Identifier
C000030
Compliance Filing re Large
Load Definition and Large
Load Registry
11706
80
11543
Tariff Title
Tariff ID
Payment
Confirmation
Suspension
Motion
Intra-PJM Tariffs
23
Record Content Description
L-M-N
Tariff Record Title
OATT Definitions - L - M - N
Record Version Number
54.1.0
Option Code
A
Record Narrative Name
Definitions - L - M - N
Tariff Record ID
9
Tariff Record Collation Value
6720824
Tariff Record Parent Identifier
3
Proposed Date
2026-10-12
Priority Order
1695
Record Change Type
CHANGE
Record Content Type
4
Associated Filing Identifier

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

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:

“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:

“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

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:

“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:

“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.

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:

“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:

“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

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.

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:

“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.

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:

“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

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

(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.

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:

“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.

Tariff Record Data:
Record Content Description
ATTACHMENT DD-4
Tariff Record Title
OATT ATTACHMENT DD-4 INTERIM RESOURCE
ADEQUACY SERVICE
Record Version Number
0.1.0
Option Code
A
Record Narrative Name
OATT ATTACHMENT DD-4 INTERIM RESOURCE
ADEQUACY SERVICE
Tariff Record ID
2346
Tariff Record Collation Value
680461120
Tariff Record Parent Identifier
1132
Proposed Date
2026-10-12
Priority Order
505
Record Change Type
CHANGE
Record Content Type
4
Associated Filing Identifier

ATTACHMENT DD-4
LARGE LOAD REGISTRY

Tariff Record Data:
Record Content Description
ATTACHMENT DD-4.I
Tariff Record Title
OATT ATTACHMENT DD-4.I INTRODUCTION
Record Version Number
0.1.0
Option Code
A
Record Narrative Name
OATT ATTACHMENT DD-4.I INTRODUCTION
Tariff Record ID
2347
Tariff Record Collation Value
680461130
Tariff Record Parent Identifier
2346
Proposed Date
2026-10-12
Priority Order
505
Record Change Type
CHANGE
Record Content Type
4
Associated Filing Identifier

I.
[RESERVED]

Tariff Record Data:
Record Content Description
ATTACHMENT DD-4.II
Tariff Record Title
OATT ATTACHMENT DD-4.II RESPONSBILITIES
Record Version Number
0.1.0
Option Code
A
Record Narrative Name
OATT ATTACHMENT DD-4.II RESPONSBILITIES
OF THE OFFICE OF THE INTERCONNECTION
Tariff Record ID
2348
Tariff Record Collation Value
680461140
Tariff Record Parent Identifier
2346
Proposed Date
2026-10-12
Priority Order
505
Record Change Type
CHANGE
Record Content Type
4
Associated Filing Identifier

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.

Tariff Record Data:
Record Content Description
ATTACHMENT DD-4.III
Tariff Record Title
OATT ATTACHMENT DD-4.III RESPONSBILITIES
OF ELECTRIC DISTRIB
Record Version Number
0.1.0
Option Code
A
Record Narrative Name
OATT ATTACHMENT DD-4.III RESPONSBILITIES
OF ELECTRIC DISTRIBUTORS
Tariff Record ID
2349
Tariff Record Collation Value
680461150
Tariff Record Parent Identifier
2346
Proposed Date
2026-10-12
Priority Order
505
Record Change Type
CHANGE
Record Content Type
4
Associated Filing Identifier

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.

Tariff Record Data:
Record Content Description
RAA ARTICLE 1
Tariff Record Title
RAA ARTICLE 1 -- DEFINITIONS
Record Version Number
57.1.0
Option Code
A
Record Narrative Name
RAA ARTICLE 1 -- DEFINITIONS
Tariff Record ID
206
Tariff Record Collation Value
917762046
Tariff Record Parent Identifier
205
Proposed Date
2026-10-12
Priority Order
1325
Record Change Type
CHANGE
Record Content Type
4
Associated Filing Identifier

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

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

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

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.

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:

“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:

(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

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

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.

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

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:

“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

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

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:

“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

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.

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:

“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:

“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

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:

“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.

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:

“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.

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

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

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:

“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.

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:

“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

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

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.

Tariff Record Data:
Record Content Description
RAA SCHEDULE 11
Tariff Record Title
RAA SCHEDULE 11
Record Version Number
2.1.0
Option Code
A
Record Narrative Name
RAA SCHEDULE 11 DATA SUBMITTALS
Tariff Record ID
293
Tariff Record Collation Value
980691110
Tariff Record Parent Identifier
205
Proposed Date
2026-10-12
Priority Order
515
Record Change Type
CHANGE
Record Content Type
4
Associated Filing Identifier

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);


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.

(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.