Manual Updates

• Added omitted language from Fuel Requirement for Black Start Resources (FRBSR)
• Section 4.5.10 - Added certification of fuel and non-fuel consumables and removed six month fuel/energy verification requirement
• Section 4.5.12 - Added certification of fuel inventory requirements
• Section 4.5.13 - Added certification documentation to testing records
• Section 4.5.14 - Added exceptions to fuel inventory requirements

• Conforming changes for Synchronous Condensing Cost definitions (ER24-2203) effective 08/06/2024
  ◦ Section 5.2.1: Added clarifying language for Synchronous Condensing Cost  definitions
  ◦ Section 5.2.3: Added clarifying language for Synchronous Condensing Cost definitions
  ◦ Section 5.2.8: Added clarifying language for Synchronous Condensing Cost definitions
  ◦ Section 6.2.3: Added clarifying language for Synchronous Condensing Cost definitions
  ◦ Section 19.2.3: Added clarifying language for Synchronous Condensing Cost definitions

• Conforming changes with addition of Tariff/OA definitions for Synchronous Condensing Costs
  ◦ Section 6.7: Added Tariff/OA Definitions and clarifying language to section
  ◦ Section 7.7: Added Tariff/OA Definitions and clarifying language to section

• Conforming changes with addition of Tariff/OA definitions for Synchronous Condensing Costs
  ◦ Section 4.2.5.3: Added clarifying language to conform with Tariff/OA definitions
  ◦ Section 4.4.4: Added clarifying language to conform with Tariff/OA definitions

• Periodic Review
  • Updated section 1.3 to ensure that operational decesions on coordination calls are followed with a a call between control rooms
  • Updated section 3.3.1 for cold weather advisory for freeze protection actions
  • Updated 3.8.2 GMD Action to align with conservative operations section 3.2
  • Updated PAI trigger language for load shed directives in section 5.7
  • Annual update of Attachment E & F. Added note for EOP-001-4 Emergency Operations standard update
  • Updated link for OE 417 form in attachment J and added step #27 for IBR reporting
• Updated manual ownership from Donald Bielak to Kevin Hatch

• EGCSTF Package Changes (2.3.1, New Section 2.5.4)

• Manual will be retired as of 6/1/2025. Its contents are contained within M21B.

• Initial version of Manual 21B containing the process and procedure for establishing: i) the capability of generation capacity resources ii) the accreditation of capacity resources and iii) the ELCC classifications 

• Initial version of Manual 20A describing business practices for performing resource adequacy studies namely, the Reserve Requirement Study, the Capacity Emergency Transfer Objective study, the Effective Load Carrying Capability study. Also, this initial version describes the resource adequacy criteria employed at the RTO level and at the Locational Deliverability Area (LDA) level to perform the studies

• Added clarifications to sections C.2.1.4, C.2.4, and C.2.5 that reflect the changes to the calculation of CETO and reliability targets based on the FERC approved docket ER24-99.
• Conforming changes were made to the following sections to incorporate provisions of FERC's CIFP-RA order (ER24-99):
• C.2.1.4 General Procedures
• C.2.4 Capacity Emergency Transfer Objective (CETO) Procedure
• C.2.5 Capacity Emergency Transfer Limit (CETL) Procedure

• Conforming changes were made to the following sections to incorporate provisions of FERC's CIFP-RA order (ER24-99) and CONE Area 5 order (ER24-462):
• 1.2.2 Participation of Resource Providers
• 2.1.1 Installed Reserve Margin
• 2.1.2 Peak Load Forecasts
• 2.1.3.1 Pool-wide Average EFORd (Through 2024/2025 Delivery Year)
• 2.1.3.2 Pool-wide average Accredited UCAP Factor (Starting with 2025/2026 Delivery Year)
• 2.1.4 Forecast Pool Requirement
• 2.1.5 Effective Load Carrying Capability and ELCC Resources in Capacity Exchange
• 2.2 Role of Load Deliverability in the Reliability Pricing Model
• 2.3 Locational Constraints in the Reliability Pricing Model
• 2.3.1 Locational Constraints in the Reliability Pricing Model
• 2.4 Reliability Requirements
• 3.3 Parameters of the Variable Resource Requirement
• 3.3.1 Cost of New Entry
• 3.4 Plotting the Variable Resource Requirement Curve
• 4.2.1 Existing Generation Capacity Resource – Internal
• 4.2.2 Existing Generation Capacity Resources – External
• 4.2.3 Planned Generation Capacity Resources – Internal
• 4.2.3.1 Binding Notice of Intent to Offer (Effective with the 2025/2026 Delivery Year)
• 4.2.4 Planned Generation Capacity Resources – External
• 4.2.5 Equivalent Demand Forced Outage Rate
• 4.2.7 Accredited UCAP for ELCC Resources
• 4.3.1 Requirements of Load Management Products in RPM
• 4.3.8 Determination of the UCAP Value of Load Management
• 4.4 Energy Efficiency Resources
• 4.6.2 Entering Unit-Specific Bilateral Transactions
• 4.6.3 Exporting a Generation Resource
• 4.6.5 Treatment of Unit-Specific Capacity Transactions that Start/End Mid-Delivery Year
• 4.6.8 Locational Unforced Capacity (UCAP) Transactions
• 4.7.1 Resource Position for Generation Capacity Resources
• 4.7.2 Resource Position for Demand Resources
• 5.2 RPM Auction Timeline
• 5.3. RPM Auction Parameters
• 5.4.1 Resource-Specific Sell Offer Requirements
• 5.4.3 New Entry Pricing Adjustment
• 5.4.4 Sell Offer Caps
• 5.4.8.4 Default MOPR Floor Offer Prices
• 5.7.1 Participation in the Base Residual Auction
• 5.8.1 Participation in the Incremental Auctions
• 8.1 Overview of Resource Performance Assessments
• 8.2.1 Generation (RPM Commitment Compliance)
• 8.2.2 Demand Resources (RPM Commitment Compliance)
• 8.4A Non-Performance Assessment
• 8.7 Load Management Test Compliance
• 8.8 Replacement Resources
• 9.1.9 Non-Performance Charge/Bonus Performance Credit
• 11.1.3 Participation in the FRR Alternative
• 11.2.1 Preliminary Unforced Capacity Obligation
• 11.3 Capacity Plan
• 11.4.1 Resource Portfolio
• 11.4.7 Load Management Products
• 11.8.1 FRR Capacity Resource Deficiency Charges

• Manual will be retired as of 6/1/2025. Its contents are contained within M20A.

• Manual will be retired as of 6/1/2025. Its contents are contained within M21B.

• Periodic Review
• Section 1.1: Updated note regarding registered Transmission Operator (TOP) exceptions
• Section 2.1.1.2: Updated Dynamic Line Rating Notice Requirement
• Section 3.2 and 3.9: Added transient voltage criteria and controlling actions
• Section 4.2.9: Added rescheduling rules for cancelled tickets
• Attachment A: Removed Homer City RAS due to retirement

• Cover to Cover Periodic Review
• Updated list of Transmission Operators in PJM footprint
• Remove version number from NERC standards 
• Attachment G: Updated Table 1, Annual Restoration Plan Review Deadlines, with current list of Transmission Owners 
• Attachment H: Updated Under Frequency Load Shed table with new data

Administrative Change (Approved by Monica Burkett 05/06/2024):

• Updated Cover to reflect Membership Process & Services as the maintainer
• Updated Approval page to Membership & Services from Knowledge Management Center
• Updated "and" to "&" within Membership Process & Services

Revision 18 (04/25/2024):

• Updated Section 6.1 to allow PJM to release certain ELCC information
• Manual Ownership updated from Anita Patel to Monica Burkett
• Manual Department updated from Knowledge Management Center to Membership Process & Services

• Periodic Review
• Section 3.1.2 Real time market application process flow diagram updated to match M-11
• Section 3.1.2 Changed "or" to "and" for solar and wind resources
• Section 4.3.3 Updated bi-lateral regulation to reference M-11
• Section 4.4.8 Deleted reference to compensation for regulation resources
• Section 4.5.4 & 4.5.15 Grammatical & typo cleanup
• Attachment B Updated with solar-hybrid resource information
• Attachment F Updated references to match manuals from 14A to 14H

• Addition of Interface Prices section (2.20)

• Periodic cover to cover review
• Revised or added the following sections to address FAC-011-4 and FAC-014-3
  • 3.1 PJM SOL Methodology
  • 3.2 Common Facility Ratings
  • 3.3 System Voltage Limits
  • 3.4 Stability Limits
  • 3.5 SOL Contingency Set for Stability Determination
  • 3.6 SOL Performance and Exceedance Determination
  • 3.7 SOL Exceedance Communication
  • 3.8 IROL Identification and Criteria
  • 3.9 SOL Methodology Posting and Sharing Obligations
  • 3.10 Establishing and Communicating System Operating Limits
  • 3.11 Providing SOLs and IROLs
  • 3.12 Monitoring of SOL and IROL Limits
• Section 3.10 – Removed references to M-03 - Section 5 and replaced with M-03B
• Section 5.1 and Attachment A: Appendix B - Added LGE and KU to the Joint Reliability Coordination Agreement
• Attachment A: Added TSA and IROL studies for next day operations
• Attachment A: Appendix D – Removed ITCI

• Quick Fix
• Removed PJM Compliance Bulletin reference
• Aligned Manual BES definitions with the NERC-approved BES definition

• Periodic Review

• Updated title of NERC Continuing Education Program to NERC Credential Maintenance Program throughout
• Section 1.3: Clarified roles and responsibilities of Member Training Liaison and Dispatcher Training Subcommittee representative
• Section 1.5.4: Updated binary pronoun usage in order to support PJM's diversity, equity and inclusion efforts
• Section 2: Removed references to the PJM Markets (voluntary) certification exam
• Section 2.3.4: Clarified the process for calculating roll-over hours
• Section 3: Clarified the applicability of training and certification requirements on a role basis
• Section 3: Removed subsection for Transmission Owner Operators/Generation Dispatchers, as individuals performing this role are subject to the requirements outlined for both Transmission Owner Operators and Generation Dispatchers, respectively. Renumbered remaining subsections.
• Section 3.3: Clarified the responsibility of the Training Liaison for compliance monitoring
• Section 3.5: Updated the reference to the TO/TOP Matrix to include all applicable NERC standards

• Retirement of Real Time Values section (2.3.4.4) and additions to Parameter Limited Schedule Exceptions section (2.3.4.3)

• Periodic Review
  • Attachment A: Removed ITCI
  • Attachment A: Updated discrete unit outages based on last three seasons

• Added missing "Workshops" definition to Section 2 previously endorsed in Revision 16

• 3.1.2 PJM Control Implementation
  • Added language to show inclusion of solar resources
• Attachment B.1: Non-Cost Measures
  • Added language to show the inclusion of solar resources
  • Revised language to clarify how curtail resources
• Attachment B.2: Generation Re-Dispatch
  • Note 3: Revised language to clarify definition of an Intermittent Resource's Economic Minimum
  • PJM Member Actions: Added language to show the inclusion of solar resources
• Attachment F: Dynamic Transfers
  • Added Language to show inclusion of solar resources

• 4.2.2 Metering Plan
  • Added missing information for Wind Farms
• Section 8: Wind Farm Requirements
  • Added reference to solar resources
• 8.1 EMS Data Exchange
  • Remove reference to the "curtailment indicator"
• 12 Solar Park Requirements
  • Added reference to updated Attachment L and M
• 12.2.2 Real Time Output
  • Added reference to Attachment M
• Attachment L: Jointly Owned Resource Communication Model
  • Updated to include solar resources
  • Removed reference to the "curtailment indicator"
  • Added reference to respond to SCED basepoint
• Attachment M: Wind and Solar Unit Dispatchability
  • Changed title and added details to include solar resources
  • Removed references to curtailment flag
  • Section 2: Updated guidance for updating parameter limits for wind and solar

• 2.4.2 Minimum Generation Alert
  • PJM Member Actions Note 3
  • Revised language to clarify definition of an Intermittent Resource's Economic Minimum
    
    
• 2.4.4 Minimum Generation Emergency Declaration
  • Updated to include solar resources

• Fixed Attachment E table image
  

• Section 4.5 Black Start Service
  • Added Fuel Assured Black Start Units as a type of Black Start Unit and clarified that Black Start Service can be provided by either fuel assured or non-fuel assured units participating in the restoration plan.
• Section 4.5.2 Restoration Assumptions
  • Added responsibility of PJM, with the Transmission Owners, to select fuel assured black start generation to meet zonal fuel assurance requirements.
• Section 4.5.4 Jurisdiction
  • Added note that black start generators may be fuel assured or non-fuel assured.
• Section 4.5.4 Definitions
  • Added definition for "Fuel Assured Black Start Unit", and clarified that a "Black Start Plant" includes Black Start Units and/or Fuel Assured Black Start Units.
• Section 4.5.7 Minimum Critical Unit Requirements
  • Revised section heading to include both Black Start Unit and Fuel Assured Black Start Unit requirements.
  • Added clarifying language and reference to Manual 36 for zonal fuel assurance requirements.
  • Added zonal black start fuel assurance requirements to selection criteria for black start resources.
• Section 4.5.8 Product Description
  • Added section on Fuel Assured Black Start Unit Qualifications.
• Section 4.5.9 Generator Owner's Commitment
  • Added commitment period, cost recovery, cost documentation, and alternate fuel designation provisions for Fuel Assured Black Start Units as applicable to existing Black Start Units on the base formula rate, new Black Start Units, and/or new Fuel Assured Black Start Units on a capital recovery rate.
• Section 4.5.10 Performance Standards
  • Added performance standards for Fuel Assured Black Start Units.
• Section 4.5.11 PJM Obligations
  • Added calculation details for PJM to determine qualification of run of river hydro resources as Fuel Assured Black Start Units.
  • Added calculation details for PJM to determine qualification of intermittent and hybrid resources as Fuel Assured Black Start Units.
• Section 4.5.12 Testing
  • Added provision for testing of Dual Fuel Black Start Units.
• Section 4.5.13 Testing and Training Standards and Records
  • Added requirement to indicate fuel being used on black start testing records.
• Section 4.5.14 Non-Performance
  • Added requirement for Fuel Assured Black Start Units with dual fuel to have a successful black start test within the past 13 months.
• Section 4.5.15 Termination of Black Start Service
  • Added clarification for Black Start Units with a lifetime commitment must also meet the requirements of Manual 12 Section 4.5.9.

• Cover-to-cover periodic review. Minor grammar/style corrections in Section 1 and 2.
• Section 4.4 Interpersonal Communication Capability Failure. Clarifying text added for requirements to notify of interpersonal communication system failure.
• Attachment A: Data Specification and Collection. Note added to clarify gen unit operating limit update requirements.
• Attachment B: Schedule of Data Submittals, "Recommend (date)" changed to "Recommended by (date)"

• Periodic Review

• Monitored facilities clarification regarding Security Analysis

• Aligned data collection process for Transmission Owners submitting modeling data

• Zonal Factors Updates (2.3.2.4)

• Conforming revisions to the definition of Effective Nameplate Capacity in Section 1.2

• Periodic Review
• Definitions and Applicability

  • Replaced definitions with reference to the PJM Governing Agreements

• References

  • Added reference to new manual M14-H: New Service Requests Cycle Process

• Section 1.1 Generator Interconnection Process: Markets and Operations Phase

  • Modified language to include references to Generation Interconnection Agreement (GIA)

  • Replaced references to eRPM with Capacity Exchange

• Section 1.2 Generator Commercial Naming Convention

  • Updated referenced agreement name from ISA to GIA

• Section 2.1 Generation Owners' Responsibilities

  • Added reference to Manual 14C Section 1.6.1 for definition of "commercial operation"

• Section 2.2 Transfers of a Generation Facility and Name Changes of Generation Owners and Project Developers

  • Updated Interconnection Customer terminology to Project Developer

• Section 2.2.2 Generation Owner or Project Developer Name and/or contact information Changes

  • Updated Interconnection Customer terminology to Project Developer

  • Updated PJM Contact Information

• Section 3.2.4 Control Center Staffing Requirements

  • Removed language " As a general guideline" from first sentence of paragraph

• Section 4.3.4 Data Exchange and Management Requirements

  • Removed reference to Phasor Data Quality Task Force which has been sunset.

  • Added reference to OATT for guidance

• Section 5.1.3 PJM Reserve Markets

  • Modified description of PJM Reserve Market to align with Tariff defined terms.

• Section 5.4.2 The Day-ahead Energy Market

  • Updated title of section by adding the word "Energy"

  • Added "Energy" between "Day-ahead" and "Market" wherever "Day-Ahead Market appears in this section

• Section 5.7.2.8

  • Updated language to reflect updated Section 3.3 title

• Section 6.3.3 Test Energy

  • Added GIA to final agreement list

• Section 7.1.2 Voltage and Reactive Control

  • Updated terminology for New Service Request

  • Added VoltageSchedules@pjm.com for questions regarding voltage schedules.

• Section 7.3: Critical Information and Reporting Requirements

  • Clarified notification by phone to PJM dispatch

• Section 7.3.6: Periodic Task Document Periodic Review

  • Updated document as part of periodic review

• Section 7.5.2 Generation Resource Preparation and Cold Weather Checklist

  • Clarified requirement for all generation resources to prepare resources for cold weather operation

• Section 13.1 Marketing and Classification of Mixed Technology Facilities

  • Updated terminology to reference GIA

• Section 13.2: Other Requirements

  • Removed reference to Section 4.1.7

• Attachment A: New Generator Checklist

  • Replaced references to eRPM with Capacity Exchange

• Attachment D: PJM Generating Unit Reactive Capability Curve Specification and Reporting Procedures

  • Clarified that the 95 degree temperature applies to thermal resources

  • Added ReactiveTesting@pjm.com for questions regarding reactive capability

• Attachment E: PJM Generator and Synchronous Condenser Reactive Capability Testing

  • Added ReactiveTesting@pjm.com for questions regarding reactive testing

  • Reformatted table of reactive testing requirements for readability

• Attachment N: Cold Weather Checklist

  • Added additional winter preparation guidance for combustion turbine intake preparation based on NERC Lessons Learned

  • Add additional guidance applicable to inverter-based resources

  • Added other best practices based on industry events

•  
• Appendix A: Behind the Meter Generation Business Rules

• Clarified reference wording for metering requirements

• Removed statement requiring BTMG generation to modeled in the PJM EMS in order for telemetry and metering to be communicated to PJM

• Removed outdated reference to Manual 3A, Appendix D

• Modified instances of Interconnection Customer to Project Developer

• Included references to GIA in final agreements

• Updated reference from M14A/M14G to new M14H

• Periodic Review
• Updated manual ownership to Andew Gledhill
• Section 3.2: Updated to reflect to change to hourly model and provide more clarity to load management and price responsive demand forecast procedure.
• Conforming revisions related to FERC Order ER20-217-000 in Attachment A.
• Updated Attachment B to reflect more transparency in data needs and documentation from requesting EDCs/LSEs. Examples provided updated to reflect recent requests.
• Minor revisions to correct grammar, spelling, punctuation, consistency of terms and document references in Attachment D.

• Administrative Change (Donnie Bielak approved 12/14/2023):

  • Updated tables in Attachment F and Attachment N to reflect correct data

  Revision 91 (11/15/2023):

  • Section 2.3.2: Edited notes concerning PAI triggers; included steps for PJM dispatch to issue DOE-417 reports

  • Section 5.2: Edited notes concerning PAI triggers; included steps for PJM dispatch to issue DOE-417 reports

  • Attachment A: Public notifications updated to account for changes to PJM's writing & grammar style; highlight the urgency of a conservation request; clarify the request for conservation is for all users; provide more specific energy conservation tips

• Periodic Review is up to date with no changes
• Manual ownership changed from Tom Falin to Andrew Gledhill

• Fixed note duplication in Section 1.1

• Conforming changes to support the Market Participation for Hybrid Resources and other Mixed Technology Facilities ("Hybrids-Phase II") FERC Order (ER23-2484-000).

  Section 22.1: Update to hybrid resource and open-loop hybrid definitions.

• Offer Verification Updates (2.3.6.2, Attachment D, Attachment C Retired)
• Hybrids Phase 2 Conforming Language (2.3.3, 2.3.4C.1)
• PAI Triggers Conforming Language (New Section 2.19)
• Renewable Dispatch Conforming Language (2.3.3.1)
• Regulation Reference Update (3.2.8)
• Reserves Reference Update (4.3)
• NSRMCP Formula Clarification (4.4.1)

• Updated language in "Section 2 Definitions" to document posting timeline revisions within the definition of Complete and Timely Notice including the addition of a time of day deadline and documenting seven days prior to the meeting for Standing Committees.
• Addition of language in "Section 4.5 Code of Conduct" to clarify certain longstanding stakeholder process rules for clarity and efficiency
• Updated language in "Section 9.7 Motion Voting Order" document concurrent voting for timely offered amendments/alternative motions
• Addition of language in "Section 11.2 Agendas" to include the addition of a time of day deadline for material posting and to add Criteria for Chair's Discretion in the event of untimely materials

• Conforming changes for interconnection process (ER22-2110)
• Section 4.7.1, 4.2.6, 4.2.7: RAA updated for Transitional MW (Docket No. ER23-1067-000)
• Section 7.4: Conforming language for Order 841 and Hybrid Order (ER22-1420)
• Section 8.2.2: Remove reference to DR Factor
• Section 3.3 and 3.4: Conforming to approved quad review filing (ER22-2984-000)
• Section 8.4A: Change to PAI Trigger (ER23-1996-000)
• Section 5.4.8.4: Updated Default Gross CONE and Gross ACR for MOPR (ER23-1700)

• Periodic Review
• Section 1.1 - Updated note regarding registered Transmission Operator (TOP) exceptions in PJM and added M03_change@pjm.com email for requesting updates to the manual.
• Section 3.9.1 - Updated note regarding stability limit documentation, and added Generation Interconnection Agreement (GIA) to the mention of Interconnection Service Agreement (ISA).
• Section 4.2.3 - Added language detailing end date extension of 'cut-in' tickets missing critical parameters.
• Attachment B - Added language detailing end date extension of 'cut-in' tickets missing critical parameters.

• Periodic cover-to-cover review
• Section 2.1 – Clarified eDART Reportable MW requirements in Exhibit 3
• Section 3.1.1 "Day-ahead" Reserves
  • Added "Real-Time" to section title
  • Added "and real-time" to anywhere after day-ahead appears in this section
• Labeled Basis for eDART Reportable MW as Exhibit 3
  • Renumbered subsequent exhibits

• Section 2.2.1: Added new section for advance RTEP outage coordination.

• Section 7.1.6:
• Added requirements for Fuel Assured Black Start Unit to notify PJM if their fuel inventory falls below 16 hours
• Section 10.1.1:
• Added Fuel Assured Black Start Units to those included in Black Start RFP
• Added fuel assurance needs to RFP technical requirements development
• Added eligibility provisions for existing Black Start Units, new Black Start Resources in the Generation Interconnection Queue, and existing units requiring upgrades to provide Black Start Service and Fuel Assured Black Start Service for submission of RFP proposals
• Added fuel assurance to RFP proposal evaluation criteria
• Added selection provisions for Black Start Units on the Base Formula Rate that meet the fuel assurance criteria without requiring additional capital costs
• Added reference to M36 fuel assurance zonal minimum and incremental increase in restoration time to Fuel Assurance section of RFP proposal evaluation
• Added fuel assurance to review criteria for selection process review with TOs
• Section 10.2 Black Start Incremental RFP Process
• Added Fuel Assured Black Start Unit owner and fuel assurance criteria to "triggering events" process
• Section 10.2.3 Implication for Terminating Black Start Units
• Added Fuel Assured Black Start Units to Black Start Units which need to be replaced if a Black Start Unit is terminating
• Section 10.3.1 Reliability Backstop Process Step 1
• Added failure to meet Black Start fuel assurance criteria to Reliability Backstop trigger provisions
• Section 10.3.2 Reliability Backstop Process Step 2
• Added failure to meet black start fuel assurance criteria to the Reliability Backstop Process for PJM, TO and affected State(s)
• Section 10.3.3 Reliability Backstop Process Step 3
• Added Fuel Assured Black Start Unit to Reliability Backstop requirement for proposed unit to be used solely for black start purposes only
• 10.3.4 Reliability Backstop Process Step 4
• Added Fuel Assured Black Start generation acquired in Reliability Backstop RFP must adhere to Fuel Assured Black Start testing and performance requirements

•  Section 7.2 Black Start Service Credits:

◦ Added provision for monthly credit reduction for Fuel Assured Black Start Units recovering Fuel Assurance Capital Costs.

◦ Wording edits and new provisions for conditions where Fuel Assured Black Start Units would have monthly Black Start Revenues forfeited. 

• Section 4 (Regulation Accounting): Conforming changes to Section 4.2.1 associated with FERC order EL21-83-000 (Undefined RegA Mileage Ratio), Effective 4/4/2023
• Periodic Review
  • Grammar, punctuation, typos, syntax consistency, reference updates, addition of clarifying words and phrases, removal of terminated business rules, and deletion of duplicate material throughout manual
  • Section 3 (Spot Market Energy Accounting): Updated for consistent use of fully metered EDC, day-ahead, and balancing terminology
  • Section 5 (Operating Reserve Accounting):
    • Replaced UDS basepoint MW with dispatch signal MW
    • Replaced UDS LMP desired MW with dispatch lmp desired MW
    • Corrected Balancing Operating Reserve Target calculation for consistency with PJM OATT
    • Included nuclear unit eligibility description in Section 5.2.1
    • Updated submittal process for condense to generation costs - submitted via Market Gateway, not manually submitted
    • Reformatted balancing energy market value for easier understanding
    • Removed references to Demand Resources since the calculations are covered in Section 11
    • Added references to Secondary Reserves
    • Added up-to congestion transactions to Day-Ahead Operating Reserves charge denominator
    • Added Section 5.3.2.3A, Calculation of Ramp Limited Desired MW consistent with Manual 11
    • Reworded Section 5.3.5 Reactive Services
  • Section 6 (Synchronized Reserve Accounting): Clarifications to shortfall MW and charge calculations
  • Sections 6, 7, and 19 (Synchronized Reserve, Non-Synchronized Reserve, and Secondary Reserve Accounting): Added obligation calculation details if real-time assignments are zero
  • Section 8 and 9 (Transmission Congestion & Transmission Losses Accounting): Added explicit charge details for up-to congestion transactions
  • Section 9.4 (Transmission Loss Credits): Replaced specific non-firm export reduction factor percentage with calculation description for consistency with PJM OATT
  • Section 11 (PJM Load Response Programs Accounting): Replaced description of LM testing allocation ratio with formula
  • Sections 12 (Metering Reconciliation Accounting) and 18 (Inadvertent Interchange Accounting): Clarification of business rules for Direct Charging Energy for consistency with PJM OATT
  • Section 14 (Unscheduled Transmission Service (Loop Flow) Accounting): Clarified description for consistency with PJM OATT description
  • Section 15 (Market Revenue Neutrality Offset Accounting): Corrected cost component of LOC Credit Due to Reduction for Non-Synchronized Reserve
  • Section 16 (FTR Auctions Settlements): Updated to reflect changes allowing self-scheduling by class type
  • Section 16 (FTR Auctions Settlements) and 17 (ARR Settlements): Clarified inclusion of long-term FTR auctions
  • Section 17 (ARR Settlement): Added ARR allocation business rule for Direct Charging Energy consistent with PJM OATT
  • Section 20 (Billing): Updated to reflect current billing statement line items
  • Section 22 (Open-loop Hybrid & Energy Storage): Corrected placement of following dispatch within 10% business rule
  • Section 23 (Fuel Cost Policy Penalty Settlements): New section added describing settlements methodology consistent with Operating Agreement Schedule 2

• Attachment A:

◦ (A.1.1 Goal) Added fuel assurance needs to Black Start goals

◦ (A.1.2 Minimum Critical Black Start Requirement):

▪ Added fuel assurance criteria to minimum critical Black Start requirements

▪ Added fuel assurance requirements as a criteria for selecting Black Start Resources for a system restoration plan 

• Updated section 4.1.2 to include clarifying language under "PJM Actions" & "Member Actions" for resources to respond to synchronized reserve event when either an initiating signal is received via EMS datalinks (ICCP or DNP3 protocols), or the PJM All-Call message

• Administrative Change included in this publish to fix the Attachment F.5 Table

•  Section 2.3.2 Step 10 NOTE: Added clarifying language to include provisions in the TO's load shed plan in accordance with EOP-011-3 
•  Section 5.2 Step 10 NOTE: Added clarifying language to include provisions in the TO's load shed plan in accordance with EOP-011-3
•  Attachment F NOTE: Added language to minimize overlap of circuits that are designated for manual load shed & circuits that are utilized for UFLS 

• Updated references from TPL-001-4 to TPL-001-5.1.

• Revised Manual 14B language to align with updated requirements in TPL-001-5.1:

o 2.3.11 Spare Equipment Strategy Review

o H.1.2 Load Flow Modeling Requirements

• Updated Attachment I: Steady State & Stability Performance Planning Events table to align with TPL requirements.

Administrative Change (Jason Shoemaker Approved 08/04/2023):

• Updated to include Generator Deliverability Procedure missed in previous publication as endorsed at the January 25, 2023 MRC
  • Section 4.3.1

Revision 30 (07/26/2023):

• Manual 14A updates to incorporate Interconnection Process Reform Tariff changes filed in Docket ER22-2110-000.
  • Introduction was updated to include applicability language.

• Updated section 4.1 to describe methods to develop heat input curves
• Updated section 5.1 to describe three methods for Combined Cycle heat input curves
• development and provide examples
• Added new section 12.7.9 to describe minimum run time logic in IMM Opportunity Cost Calculator

• This is a new Manual.
• This Manual guides Project Developers, Eligible Customers, Upgrade Customers, Surplus Project Developers and Affected System Customers through the planning and study phase of their proposed project up to the request for facility construction.

• Periodic Review
  • Section 2.2, 2.3.2 Grammatical cleanup
  • Section 2.3.2, 5.2 Replaced eCapacity reference with Capacity Exchange
  • Section 3.3.2 Removed extra bullets & adjusted bullets under PJM actions to clearly show sequence
  • Section 3.9 Note cleanup
  • Section 4.2 Removed the PJM Shift Supervisor’s phone number reference
  • Section 5.4 Removed extra bullet
  • Attachment E Manual Load Dump Allocation table updated for 2023
  • Attachment F Exhibit 6 updated for 2023

• A general note was added to the Introduction section to describe how the new changes impact existing customers’ ISAs.
• Reference to ISA updated to GIA in Sections 1.1, 1.1.1, 1.1.5, 1.1.6, 1.1.7, 1.3.1, 1.3.5, and Appendix B
• Section 1.1.2 – Reference to delivery year updated to base case study year and reference to System Impact Study cycle added. 
• Section 2.1 – Reference to Feasibility Study Agreement updated to Application and Studies Agreement.

• A general note was added to the Introduction section to describe how the new changes impact existing customers’ ISAs.
• Section 5.1 – updated references from Interconnection Service Agreement to Generation Interconnection Agreement
• Sections 5.3 and 5.4 – updated to reference the interconnection queue

• A general note was added to the Introduction section to describe how the new changes impact existing customers’ ISAs.
• Section 4.3 #13 – Reference to ISA is updated to Generation Interconnection Agreement (GIA).

• All Sections of this manual were reviewed and updated to incorporate the new interconnection process changes and terminology filed in Docket ER22-2110-000. Process diagrams were updated to reflect the new process terminology, or deleted if outdated.
• Introduction
  • Definition of Transition Date for the new interconnection process
• Section 1
  • The Summary of Agreements section distinguishes between those agreements applicable prior to the Transition Date, and agreements applicable prior to the Transition Date.
  • Minor clarifying changes made to the descriptions of agreements applicable prior to the Transition Date. New definitions provided for the new agreements applicable prior to the Transition Date. 
  • References to the Tariff form for the related interconnection related agreements have been added.
• Manual Ownership changed from Augustine Caven to Jason Shoemaker.

• Interconnection Process Reform Taskforce nomenclature updates
  • Section 4.2.3: Updated terminology for IPRTF updates
  • Section 4.2.4: Updated terminology for IPRTF updates
  • Section 4.5: Updated terminology for IPRTF updates
  • Section 4.8.2: Updated terminology for IPRTF updates
  • Section 4.8.5: Updated terminology for IPRTF updates
  • Section 4.10: Updated terminology for IPRTF updates
  • Section 5.4.7: Updated terminology for IPRTF updates
  • Section 6.1: Updated terminology for IPRTF updates
  • Section 6.1.2: Updated terminology for IPRTF updates
  • Section 8.8: Updated terminology for IPRTF updates
  • Section 11.4.6: Updated terminology for IPRTF updates
  • Glossary A: Updated terminology for IPRTF updates

• Section 4.9.1
  • Updated section title to Transmission Interconnection and Upgrade Customer IARRs
  • Replaced Interconnection Customer with Transmission Project Developer or Upgrade Customer
  • Replace new generation interconnection and Merchant Transmission Expansion projects with New Service Requests or Upgrade Requests
  • Clarified existing language

• Conforming changes associated with ER22-2110-000 (Interconnection Process Reform)
• Section 5.2: updated references to Interconnection Service Agreement (ISA) to Generation Interconnection Agreement (GIA)

• Conforming changes associated with ER22-2110-000 (Interconnection Process Reform)
  • Section 1.1.1 clarified planning studies conducted by PJM.

• Manual 14G updates to incorporate Interconnection Process Reform Tariff changes filed in Docket ER22-2110-000.
  • Introduction section was updated to include applicability language.

• Manual 14E updates to incorporate the Interconnection Process Reform Tariff changes filed in Docket ER22-2110-000.
  • Introduction was updated to include applicability language.

• Introduction: Revised terminology to align with new tariff language, updated references
• Section 1A.3.1.1: Updated terminology
• Section 1.1: Updated terminology/references
• Section 1.4.1.6: Updated terminology/references
• Section 1.4.2.3: Updated terminology
• Section 1.4.3: Updated terminology
• Section 2.1.1.1: Updated terminology/references
• Section 2.1.2: Updated terminology
• Section 2.2: Updated terminology, revised note to clarify potential impact of generation retirements
• Section 2.3.1: Updated terminology
• Section 2.3.3: Updated terminology
• Section 2.4: Updated terminology/references, streamlined language
• Section 2.5: Updated reference
• Section 2.9: Format and terminology correction
• Attachment A, A.1: Updated reference
• Attachment A, A.2: Updated reference
• Attachment B, B.3: Updated terminology
• Attachment B, B.4: Updated terminology
• Attachment C, C.2.6: Updated terminology
• Attachment C, C.3.1.3: Updated terminology throughout, removed statement referencing serial queue process in step 2, and revised statement on commercial probability to align with IPRTF material in step 5a
• Attachment C, C.4: Updated terminology
• Attachment G, G.1: Updated terminology
• Attachment G, G.2.1: Updated terminology/references
• Attachment G, G.2.2: Updated terminology and stability language to align with current process
• Attachment G, G.3: Updated terminology
• Attachment G, G.3.1: Updated terminology/references
• Attachment G, G.3.2: Updated terminology/references and stability language to align with current process
• Attachment G, G.5: Updated terminology/references, and removed section G.5.1 – Wind
• Project Final Impact Study Data
• Attachment G, G.7: Updated reference
• Attachment G, G.9.1: Updated terminology and added reference to Transmission Owner Planning Criteria
• Attachment G, G.9.4: Addition of ComEd transient voltage recovery criteria
• Attachment H, H.1.2: Updated terminology
• Attachment H, H.1.4: Updated terminology
• Attachment H, H.1.5: Updated terminology

• References: Administrative change to correct outdated manual names and add Manual
• 14H.
• Using this Manual: Added ‘note’ explaining queue reform Transition Date.
• Section 1.3.2: Updated terminology, OATT references and process steps.
• Section 1.5: Updated terminology and made changes for clarity.
• Section 3 (introduction): Updated terminology and details of the deliverability study
• process for Long Term Firm requests. Updated Exhibit 4.
• Section 3.1: Administrative change to correct grammar. Updated terminology.
• Section 3.3: Administrative updates to manual references. Clarifying changes to
• transmission service product applicability.
• Section 3.4: Administrative change to correct grammar.
• Section 3.5: Updated terminology and manual references.
• Section 3.6: Updated terminology, process steps and OATT reference.

• Conforming revisions to Sections 13 and 22 to incorporate rules for Open-Loop Hybrid Resources as approved by FERC Docket ER22-1420-002, effective 6/1/2023.
• Section 5.2.1 – add clarification of what intervals are included in segments for determination of Balancing Operating Reserve credits per FERC Docket ER23-557-000, effective 6/1/2023.

• Conforming revisions to Section 8 to incorporate rules for Open-Loop Hybrid Resources as approved by FERC Docket ER22-1420-002, effective 6/1/2023.

• Cover to cover Periodic Review
• Attachment G: Updated Table 1, Annual Restoration Plan Review Deadlines, with current list of Transmission Owners
• Attachment H: Updated Under Frequency Load Shed table with new data

• Real Time Values Updates (2.3.4.4)
• Transmission Constraint Penalty Factor Conforming Language (2.17)
• Hybrids Phase 1 Conforming Language (2.1.1, 2.3.3, 2.3.4C, 2.3.4C.1, 4.2.1, 4.2.2, 4.2.3, 9.1)

• Updated Section 1.1.1 to identify the CIR Level an Unlimited Resource can request
• Added that M21A is the official manual for ELCC resource capability starting with the 2023/2024 Delivery Year.
• Manual ownership changed from Thomas Falin to Andrew Gledhill

• Manual ownership changed from Thomas Falin to Andrew Gledhill
• Section 5.3 Resource Performance: Conforming revisions for FERC Order ER23-1067-000 to cap hourly output and adjust for historical curtailments in the ELCC analysis.

• Corrected outdated Exhibit 11 Image for Generation Deactivation Process Flow

• Revised Section 2.6 to provide guidance to Market Sellers on variable operating and maintenance costs for:
• units submitting major maintenance
• units submitting minor maintenance or using default minor maintenance adder
• units submitting operating costs or using default operating costs adder
• new submission and review timelines
• definition and examples of major maintenance, minor maintenance and unallowable expenses
• requirements for supporting documentation
• Provide guidance to Market Sellers on Start-Up Cost in Sections 1.7.2, 2.4, 3.4, 4.4, 5.4, & 6.4 for:
• units with and without a soak process
• clarifications to the Start-Up Cost equation
• station service calculations
• clarification to the start maintenance adder
• removal of start additional labor cost
• clarifications for aggregated, pseudo-tied, and cogeneration units
• Provide guidance to Market Sellers on changes to emissions costs and environmental credits in Section 2.2:
• Adjust review of emissions rates from annual to periodic
• Clearly document standards of review for emissions allowance adders
• Remove reference to ‘Emissions Policy’
• Any resource that receives PTCs and/or RECs and submits non-zero cost-based offers, must
• account for such credits in the resource’s Fuel Cost Policy

• Periodic Review
• Changed manual ownership from Simon Tam to Nicole Scott.
• Introduction Section – Removed EMS User’s Manual as a reference.
• Section 4.2.10 – Added language for clarity.
• Section 4.4 – Updated “RFC” references to now reference “RF”.
• Attachment A – Updated “RFC” references to now reference “RF” and Removed Kincaid Scheme due to retirement.
• Attachment C – Updated submission process email address.

• Section 2.2 - Added clarification for establishing Reliability Reserve Requirement.

• Section 4.3 – Added clarification for establishing Reliability Reserve Requirement

• Periodic Review
• Section 4.2 : Removed Native Network Load and replaced with Generation To Load to align with revised terminology from the implementation of OATI Parallel Flow Viewer (PFV)
• Section 5.2.2 : Added Hot & Cold Weather to the Extreme Weather Section

• Section 2.4.7 Removed bullet point for FE South in member actions as it is no longer needed
• Updated Attachment E: PJM EMS Load dump allocation table to reflect the new OSI EMS

• Section 1.1 updates to specific terms for environment and EMS subsystems due to the May 2023 change of PJM EMS platforms.

• Updates to the Generator Deliverability Procedure to implement block dispatch
• New Exhibit 4 – Block Dispatch for RTEP Cases
• Section 2.3
• Sections 2.3.11 (Light Load) and 2.3.13 (Winter Peak) removed, now addressed in 2.3.10
• Attachment B
• Attachment C.3
• Attachment D-1
• Attachment D-2 and D-3 removed, now addressed in C.3
• Section 1A.3.2 added to clarify PJM CEII Handling
• Added Attachment K: CIR for ELCC Transition

• Section 3.1.7 updated to reflect the increased capabilities of the EMS

Administrative Change (Approved by Peter Langbein 04/28/2023):

• Removed reference to Manual 10 Section 6 in Section 8.5. Justification for this change is due to the decision for Section 6’s removal stated in M10 ”based on RFC Standard MOD-024-RFC-01, which permits verification of winter gross Real Power capability by adjusting the summer verification, eliminating the need for exemption program. Revisions approved by stakeholders at MRC on November 30, 2009”

Revision 56 (02/09/2023):

• Change to Section 8.8 to allow early replacement actions for export under specific conditions as approved at 11/16/22 MRC.

Cover to Cover Periodic Review

Changes made throughout:

• Grammar, Punctuation, Typo, Syntax Consistency, Reference Updates
• Updated Outdated Hyperlinks
• Addition of clarifying words and phrases
• Deletion of duplicate material
• Paragraph Spacing
• Change all references of “Office of the Interconnection” to “PJM”
• Remove outdated references to DASR
• Add references to SecR

Section 2

• Added descriptor for Stability Limits at top of section.
• Section 2.1.2 Reword of Fast-Start Capable Adjustment Process section
• Section 2.3.3.1: Clarification that run times consider notification or startup times
• Section 2.3.3.1: Additional detail about the maximum number of MW/Price segments allowed
• Section 2.3.4.2: Updated method to communicate Unit Specific Parameter Adjustments
• Section 2.3.6.2: Updated method to submit exception requests from the previously used template to Markets Gateway form and PJM Connect website.
• Section 2.3.8: Clarification that Up-To Congestion Transactions are modeled in the RSC
• Section 2.5.2: Clarification that IT SCED has two hour look ahead period
• Section 2.14: Removed opening paragraph that is redundant from M28

Section 4

• Section 4.7: Clarify submission time of Bilateral Reserve Transactions from 14:15 to 13:30

Section 5

• Section 5.2: Remove outdated reference to “Transmission Outage Data System”
• Section 5.2.3: Rewrite of Load Forecasting Procedure to replace outdated information and detail updated processes
• Section 5.2.6: Addition of paragraphs to detail the objective of the SPD and RSC software packages
• Section 5.2.7.3: Additional language to clarify Composite Energy Offer adjustments and their relation to the OA

Section 7

• Section 7.3.2: Additional detail about how RT SCED treats CTS transactions.

Section 9

• Section 9.1: Additional detail about Hourly State of Charge of an ESR

Section 10

• Section 10.3: Updated language to “and/or” as defined by PJM for how location of a DSR is determined.
• Section 10.4.2: Removal of Weather Sensitivity Adjustment from bulleted list detailing CBL notes.

Section 12

• Section 12.2.4: Deleted references to detail about Price-Demand curves in prior delivery years

Attachments C and D

• Updated email alias used to submit supporting documentation

• Cover to Cover Periodic Review

• Section 1
  • Added ISA project milestones on Site Permits and Acquisition of major electrical equipment.
• Section 4
  • Added posting requirement of historical ITO interconnection standards.

• Conforming corrections and clarifications associated with ER19-1486 (Reserve Price Formation) effective October 1, 2022.
• Section 5.2: Corrected how the Market Revenue Neutrality Offset is applied to the Balancing Operating Reserve Credit calculations (plus changed to minus)
• Section 6.2.2 and 19.2.2: Corrected the Capped Real-time Reserve Assignment equation to reflect a result that is positive or zero.
• Section 6.2.3 and 19.2.3:
• Day-ahead Opportunity Cost – Clarified that expected energy output or load reduction level is from the dispatch run
• Real-time Opportunity Cost – Clarified that expected energy output or load reduction level is from the pricing run
• Clarified the Day-ahead and Real-time Opportunity Cost calculations for Economic Load Response Participants
• Section 19.2.3:
• Clarified the Secondary Reserve Day-ahead Opportunity Cost calculation for condensers
• Clarified that Secondary Reserve Day-ahead and Real-time Opportunity Cost is $0 for off-line resources
• Section 15.2
• Clarified how Balancing Clearing Price Credits are calculated when determining the LOC Credit due to reduction for each reserve market.
• Updated manual ownership from Rebecca Stadelmeyer to Susan Kenney

• Updated section 3A.3 and Attachment C to prohibit Critical Natural Gas Infrastructure

• Section 6.6
  • Increased bid limit to 20,000 per Effective FTR Holder, auction round, and period

• Periodic Review
  • Sections 1.3.2, 2.2.4, 2.3.4, 3.2, 3.2.1, 3.2.2, 3.2.3, 3.2.4.1, 3.2.4.2, 3.2.5 and 3.3: Updated binary pronoun usage (e.g., “he/she,” “his or her” to a gender-neutral equivalent (e.g., “their,” “they,” etc.) in order to support PJM’s diversity, equity and inclusion efforts.
  • Section 3.2.5: Updated three instances of the phrase “Regulation and Synchronized Reserve markets” to instead read “Regulation and Reserve Markets” to reflect changes in PJM’s Reserve Market

• Section 2.2.1.5: conforming changes associated with FERC Order ER22-26 settlement approval. Updates describe Schedule 9-PJM Settlement calculation methodology effective February 1, 2023.
• Section 2.5: conforming changes associated with FERC Order ER22-26 settlement approval. Updates to recognize the two sub-parts of component two for 9- PJMSettlement and where reconciliation is applied effective February 1, 2023.

• Approvals
  • Updated Manager Markets Settlements Development Department from Rebecca Stadelmeyer to Susan Kenney
• Section 2.2
  • Replaced “path” with “source and sink” for clarity
• Section 4.1
  • Updated language to reflect expanded sources and sinks for Stage 1B per AFMTF
  • Updated language to reflect reduction from 3 to 2 rounds for Stage 2 per AFMTF
• Section 4.2
  • Updated language to reflect nomination MW change from ZBL to 60% NSPL for Stage 1A per AFMTF
• Section 4.3
  • Updated language to reflect expanded sources for Stage 1B per AFMTF
• Section 4.4
  • Updated language to reflect reduction from 3 to 2 rounds for Stage 2 per AFMTF
• Section 4.5
  • Updated language to reflect expanded sinks for Stage 2 per AFMTF
  • Updated language to reflect reduction from 3 to 2 rounds for Stage 2 per AFMTF
• Section 4.7
  • Updated language to reflect nomination MW change from ZBL to 60% NSPL for Stage 1A per AFMTF
• Section 4.8
  • Updated language to reflect nomination MW change from ZBL to 60% NSPL for Stage 1A per AFMTF
• Section 4.9.3
  • Updated language to reflect changes to sources and sinks for IARRs per AFMTF
• Section 6.1
  • Updated language to reflect self-scheduling by class type per AFMTF

• Updated section 10.2.2 to prohibit Critical Natural Gas Infrastructure locations in the registration.

• Fixed Section 4.5.16 in the Table of Contents

• Fixed spelling error and incorrect reference in Section 2.5.1
• Fixed incorrect reference in Revision 43

• Added “Cover to Cover Periodic Review” language to Revision 16

• Added “Cover to Cover Periodic Review” language to Revision 30

• Added “Cover to Cover Periodic Review” language to Revision 96

• Section 3.1: Added bullet for Transmission Owners conducting Day Ahead analysis should compare results with PJM Day Ahead report.
• Attachment A: Updated OATF scope.
• Attachment B: Updated Reliability Analysis procedure.

• Cover to cover Periodic Review
• Introduction: Updated hyperlinks to posted documents.
• Section 1 (introduction): Added ‘cross-border’ language to clarify applicability.
• Section 1: Added ‘cross-border’ term and other changes throughout the section to clarify applicability to cross-border transmission service.
• Section 1.1.2: Administrative change to correct terminology.
• Section 1.2: Rewrote section to align with current processes for becoming cross-border transmission service customer.
• Section 1.3: Administrative updates.
• Section 1.3.2: Administrative update to clarify LTF application is no longer submitted in hardcopy format.
• Section 1.4, 1.5: Administrative changes to correct capitalization of un-defined terms.
• Section 2.3.1: Updated hyperlink to posted document.

• Periodic Review is up to date with no changes
• Section 5.1.2 and 5.1.5: Updated binary pronoun usage (e.g., “he or she,” “his/her” to a gender-neutral equivalent (e.g., “they,” “their” etc.) in order to support PJM’s diversity, equity and inclusion efforts

• Section 1A.3.1.1: Updated binary pronoun usage (e.g., “his or her” to a gender-neutral equivalent (e.g., “their,” etc.) in order to support PJM’s diversity, equity and inclusion efforts.

• Section 10.2.2.2: Updated binary pronoun usage (e.g., “he or she” to a gender-neutral equivalent (e.g., “they,” etc.) in order to support PJM’s diversity, equity and inclusion efforts.

• Section 5.4.8.3: Updated binary pronoun usage (e.g., “his/her” to a gender-neutral equivalent (e.g., “their,” etc.) in order to support PJM’s diversity, equity and inclusion efforts.

• Periodic Cover-to-Cover Review
• Section 2.1 Generation Owner Responsibilities
• Added clarification for the requirement to complete eDART GO Contact Survey
• Section 3 Control Center Requirements
• Aligned language with Manual 1: Control Center Requirements for consistency
• Removed language that is duplicative with Manual 1 and referenced M-1 where appropriate
• Section 3.2.4 Control Center Staffing Requirements
• Added reference to M-1: Attachment F: Overview and Requirements for Remote Operations of Market Operations Centers due to Exceptional Circumstances
• Section 4 Data Exchange and Metering Requirements
• Section 4.1 – Renamed from Computer System Data Exchange to EMS Data Exchange
• Aligned language with Manual 1: Control Center Requirements for consistency
• Removed language that is duplicative with Manual 1 and referenced M-1 where appropriate
• Section 5.1.3 PJM Reserve Markets
• Updated language to reflect changes related to Energy Price Formation filing that were effective on 10/1/22
• Section 5.4.2 The Day-Ahead Market
• Updated language to reflect changes related to Energy Price Formation filing that were effective on 10/1/22
• Section 5.4.4 Grid Accounting
• Removed duplicative language and replaced with references to appropriate settlements and accounting manuals
• Section 7.1.1 Generator Real-Power Control
• Clarified the expectation that Generating Facilities are expected to follow economic basepoint unless operating as non-dispatchable
• Section 7.3.1 Planned Outage
• Clarified requirement for TO approval of outages for Black Start Units
• Section 7.3.2 Maintenance Outage
• Clarified requirement for TO approval of outages for Black Start Units
• Section 7.3.3 Unplanned Outage
• Clarified expected time for submitting an Unplanned Outage ticket
• Section 8.1 – Renamed from Computer System Data Exchange to EMS Data Exchange
• Section 10.1.1: Black Start Selection - Frequency
• Added reference to PJM’s obligation to perform black start studies every 5 years and clarified expectations for resources currently providing Black Start Service
• Various spelling and grammatical changes throughout
• Capitalized Black Start Units and Black Start Service for consistency with PJM governing documents
• Replaced references to voice communications with interpersonal communications to align with NERC Standard COM-001.
• Section 12.1 – Renamed from Computer System Data Exchange to EMS Data Exchange
• Attachment “N”: Cold Weather Preparation Guideline and Checklist
• Removed outdated link to RF Winterization Guideline
• Manual ownership changed from David Schweizer to Michael Zhang

• Updated/correct terminology
• Section 2: re-organized and added more detailed calculations in section 2.3 and 2.4
• Section 3: added considerations for filing to assist in smoother billing process in section 3.2; added sub-section 3.3.1 and 3.3.2 to distinguish Zone and Non-Zone charge calculations
• Section 5: added sub-section 5.2.1 and 5.2.2 to distinguish between the calculation of the annual Network Service Peak Load (NSPL) and Network Integration Transmission Service (NITS) charge; re-organized section 5.3, clarification added in section 5.4, 5.5, 5.6 and 5.7
• Section 7: added sub-section 7.3.1 and 7.3.2 to distinguish Zone and Non-Zone charge calculations
• Section 10: added new section for Transmission Enhancement (TEC) (Schedule 12) Accounting
• Manual ownership changed from Rebecca Stadelmeyer to Susan Kenney

• Attachment F: Updated binary pronoun usage (e.g., “his or her” to a gender-neutral equivalent (e.g., “their,” etc.) in order to support PJM’s diversity, equity and inclusion efforts.

• Section 6.1.1, 8.1, 8.1.3: Updated binary pronoun usage (e.g., “he or she” to a gender-neutral equivalent (e.g., “their,” “them” etc.) in order to support PJM’s diversity, equity and inclusion efforts.

• Attachment G: Updated binary pronoun usage (e.g., “he/she” to a gender-neutral equivalent (e.g., “they,” etc.) in order to support PJM’s diversity, equity and inclusion efforts.

• Section 6.4 updated to reflect changes to resource limitations
• Exhibit 5: Resource Limitations Reporting updated

• Periodic Review
• Section 2.1.1.2 - Corrected misspellings of ‘temperature’.
• Section 2.1.2 – Added statement on process to update STE rating.
• Section 3.8 - Updated BC/PEPCO interface definition.
• Attachment A – Added note concerning Homer City STS-1.

• Periodic Review
• Link to Tie-Line Information updated
• Model Management Department aligned to Power Systems Modeling
• Deterministic explanation for EMS solution
• Monitoring Priorities Clarifications

• Periodic Review
• Updated references to Manual 03 Section 5 to Manual 03B throughout the manual
• Sect 1.1 Reworded explanation of Nuclear Plant Interface Requirements (NPIRs)
• Sect 1.2 and 2.4.2 Added reference to eDART’s Nuclear Voltage Limit feature
• Sect 2.4 Clarifying language on communication of off-cost and redispatch
• Sect 3.1 Added language addressing company name changes
• Sect 3.2 Updated reference to Manual 13 Attachment L to Manual 13 Attachment J and added Attachment K reference
• Sect 3.5 Updated reference to Nuclear Generator Owner User Group to Nuclear Generator Owners/Operators Forum
• NPIR Revision as part of periodic review process no longer applicable
• Attachment A.6 Added definition of Off-cost to Key Transmission Terms
• Attachment A.8 Added Reference to COM-002
• Appendix 1 Updated NERC information
• Attachment C: Plant Specific NPIRs Revisions History: Asset Owner name and NPIR revision updates
• Corrected typographical errors and capitalization in multiple sections

• Corrected the CDS mission statement to reflect MIC, not MRC, as the parent committee in Section 1.5
• Corrected the Incremental Heat Rate equation in Section 2.1
• Corrected the Basic Nuclear Fuel Cost equation in Section 3.3.1
• Replaced “other Fuel Related Costs” with “Operating Costs” in Sections 4.2 and 6.3.1
• Removed reference to annual Fuel Cost Policy submission in Section 9.2
• Corrected section titles in Section 9.7 and Section 13.3 Exhibit 28
• Added missing chart and removed outdated no-load calculation in Attachment B

• Section 5.2.1: Associated with the Operating Reserve Clarification for Resources Operating as Requested by PJM problem statement – removed sentence that states “For Combustion Turbine units, operating at PJM direction, the actual five minute interval real-time output is used as the Operating Reserve Desired MW value”. Removal aligns with incentives to follow PJM dispatch.

Section 7.3.5: Fuel, Emissions and Operational Data Reporting

• Seasonal Fuel and Emissions Reporting
• Added Generating Facility minimum design temperature annual verification
• Real Time Reporting
• Added reference to new Emergency Procedure: “Cold Weather Advisory”
• Added requirement for Generation Owners to enter/review/update Generating Facility cold weather operating limit temperature in eDART / Markets Gateway

Attachment N: Cold Weather Preparation Guideline and Checklist

• Added recommendation to take into account the effects of precipitation and wind during cold weather preparation.

• Conforming changes to Section 3: Reserve Requirements to account for Reserve Price Formation implementation to take effect 10/1/2022 (FERC Dockets: EL19-58-000 and ER19-1486-000).

• Section 4.1.7 – SCADA
• Clarify required telemetry values for Hybrid Resources.
• Section 4.2.3 Metering for Individual Generators
• Specify what and where settlement and telemetry meters are required for Mixed Technology Facilities.
• Section 7.1.2 Voltage and Reactive Control
• How to aggregate units at a Mixed Technology Facility for purposes of size thresholds for applicability of voltage schedules.
• Section 7.3 eDART reporting
• How Hybrid Resources must submit outage information
• Section 8.3.3 LOC rule clarification
• Section 12.2.4 outage reporting clarification
• Add a new Section 13 for Mixed Tech Facilities
• Including definitional concepts, classification rules, and applicability of other rules.
• Attachment D – Reactive Capability
• Specify what D-curves will look like for Mixed Technology Facilities.
• Attachment E – Reactive Tests
• Specify how to do reactive testing at Mixed Technology Facilities
• Attachment L – Jointly Owned Resource Communication Model
• Single MOC for the Mixed Technology Facility components.

• Reserve Price Formation changes are reflected in Sections 4.7, 5.7, 6.7, 7.7, 8.1 and 11.7
• Removed references to Tier 1 and Tier 2 due to the Tier 1/Tier 2 consolidation
• The Variable Operations and Maintenance component was removed from Synchronized Reserve offers
• The existing $7.50/MWh offer margin was reduced to the expected value of the penalty
• Added the expected value of the penalty calculations
• Removed Exhibit 10: Steam Unit Synchronized Reserve Example

Administrative Change (Dave Anders approved 9/22/2022):

• Deleted “External Resource Must Offer Agreement” in Attachment F, section F.2. Capacity Market Seller’s written commitment to the RPM must-offer requirement is to be demonstrated through the External Resource Officer Certification in accordance with Manual 18, rev. 54.

Revision 47 (10/1/2022):

• Section 3.1.2 PJM Control Implementation
• removed reference to Tier 2 Reserve
• Section 4.3 VACAR Reserve Sharing
• removed to coincide with Dominion-Virginia Power exiting VACAR reserve sharing group.
• Adjusted bullet numbering and references in section 4.3 through 4.6
• Update to Attachment F exhibit 16 removing Day Ahead Scheduling Reserve from Market Service, update Requirement from Reserve Credits to Secondary Reserve

• Conforming changes associated with ER19-1486 (Reserve Price Formation)
• Section 2.2.1: removed reference to Day-ahead Scheduling Reserve charges, Added description for Secondary Reserve charges and Updated the description for Load Reconciliation charges
• Section 2.3.1: removed reference to Day-ahead Scheduling Reserve credits, Added description for Secondary Reserve credits and Updated the description for Synchronized Reserve credits and Non-Synchronized Reserve credits

• Conforming changes associated with ER19-1486 (Reserve Price Formation)
• Section 8.1: removed the reference of Tier II

• Conforming changes associated with ER19-1486 (Reserve Price Formation)
• Section 1: updated service accounting definitions
• Section 5:
• Section 5.1: Added inclusion of Secondary Reserve and Market Revenue Neutrality Offset into different Operating Reserve calculations and Added language regarding Nuclear Units eligibility for Operating Reserve credits from Manual 11
• Section 5.2: Added inclusion of Secondary Reserve and Market Revenue Neutrality Offset into different Operating Reserve calculations
• Section 5.3: Clarify generator deviation calculation with the inclusion of Secondary Reserves
• Section 6:
• Overall clean-up for Tier I and Tier II language
• Section 6.1: Clarification of how the Obligation is calculated between RTO zone and Sub-Zone
• Section 6.2: Renamed and reworded for Day-ahead and Balancing Synchronized Reserve Market Clearing Price Credit; added 6.2.3 for Synchronized Reserve Lost Opportunity Cost Credit
• Section 6.3: Added more details for the new charge calculations of Clearing Price and LOC; Re-word Retroactive Penalty Charge section for organization
• Section 6.4: added clarification regarding the billing determinants per Reserve and Sub-zone
• Section 7: Updated all sections to reflect all associated calculations for credits and charges
• Section 7.1: Clarification of how the Obligation is calculated between RTO zone and Sub-Zone
• Section 7.2: Renamed and reworded for Day-ahead and Balancing Non-Synchronized Reserve Market Clearing Price Credit; added 7.2.3 for Non-Synchronized Reserve Lost Opportunity Cost Credit
• Section 7.3: Added more details for the new charge calculations of Clearing Price and LOC
• Section 7.4: added clarification regarding the billing determinants per Reserve and Sub-zone
• Section 15: was used for Ramapo PAR Facilities but now re-used for Market Revenue Neutrality Offset associated calculations. Ramapo PAR Facilities did not go away with ER19-1486. The PAR calculation moved into the Market-Market calculation
• Section 19: was used for Day-ahead Scheduling Reserves (DASR), but ER19-1486 removed this product. Re-used for new Secondary Reserves and all associated calculations for credits and charges.
• Section 20: updated Billing Line Item names

• Section 2.2 Reserve Requirement updated to reflect changes to reserve requirements based on PJM Manual 11 Energy and Ancillary Services Market Operations.
• Remove reference to Day Ahead Scheduling reserve
• Remove reference to Load Forecast Error and Forced Outage Rate Components of reserve requirement
• Add language clarifying 30 minute reserve product and requirement
• Remove reference to SERC VACAR Reserve Requirement
• Update Reserve Requirement Table
• Section 2.3 clarified Advisory language to include Weather/Environmental Emergency
• Section 3.3 updated to include Cold Weather Advisory
• Section 3.3.1 Cold Weather Advisory added to address NERC Standards EOP-011, IRO-010, TOP-003
• Renumber 3.3.2 Cold Weather Alert
• Section 6.4 Seasonal and Periodic Reporting eDART based survey updated to eDART data request

• Conforming changes to account for Reserve Price Formation implementation to take effect 10/1/2022 (FERC Dockets: EL19-58-000 and ER19-1486-000).
  • Merged existing Reserve Sections listed below into one complete Section 4: PJM Reserve Markets
    • 4: Overview of the PJM Synchronized Reserve Market
    • 4b: Overview of the PJM Non-Synchronized Reserve Market
    • 11: Overview of the Day-ahead Scheduling Reserve Market
  • Added new subsections in Section 4: PJM Reserve Market to describe Day-ahead and Real-time Reserve Market structure
    • 4.1 Overview of the PJM Reserve Markets
    • 4.2 PJM Reserve Markets Offer Business Rules
    • 4.3 Reserve Requirement Determination
    • 4.4 Reserve Market Clearing
    • 4.5 Event Performance
    • 4.6 Reserve Obligations
    • 4.7 Bilateral Transactions
    • 4.8 Settlements
  • Edited the following sections:
    • 1 – Overview
    • 1.1 – PJM Responsibilities
    • 2.3.3.2 – Generation Schedules
    • 2.3.7 - Mechanical/Technical Rules
    • 2.7 – Locational Pricing Calculator (LPC)
    • 2.8 – The Calculation of Locational Marginal Prices (LMPs) During Emergency Procedures
    • 2.9 – Shortage Pricing2.14 – Balancing Operating Reserve Cost Analysis
    • 3.1 – Overview of the PJM Regulation Market
    • 3.2 – PJM Regulation Market Business Rules
    • 5.2.4 – Markets Database System
    • 10.1 – Overview of Demand Resource Participation
    • 10.2 – Demand Resource Registration Requirements
    • 10.4.1 – Metered Data
    • 10.5 – Aggregation for Economic, Pre-Emergency and Emergency Demand Resources
• In addition to the conforming changes for Reserve Price Formation, the following changes are also included:
  • Section 2.5.3.3 - Real-time Security Constrained Economic Dispatch Methodology
    • Updated Achievable Target MW calculation
    • Updated definition of up/down ramp rate used o Updated diagram to reflect these changes
  • Updated DA Market Ops Manual owner from Mike Ward to Joe Ciabattoni

• Section 2.1: Generation Outage Reporting Overview
• Updated eDART Reportable MW table for Hybrid Resources

Revisions as a result of Periodic Review:

• Deleted outdated Delivery Year information (Section 1.1 and 5.1.3)
• Updated tool name to Capacity Exchange system (Section 1.3)
• Updated EE Modification process to reflect current practice (Section 1.3)
• Added Nominated EE Value Template requirement to reflect current practice (Section 2.2)
• Clarified the basis for ICAP Owned on EE Resource (Section 5.1.3)
• Added Capacity Performance Value where missing (Section 5.2.2, 5.2.3, and throughout Section 10)
• Corrected the definition of equation terms (Section 9.2.3 and 9.3.1)
• Clarified Capacity Performance value may be offered/committed on annual basis and difference between Nominated EE Value and Capacity Performance value may be offered/committed on summer period basis (Section 10.1)

• Periodic Review
• Section 6.1
• Added definitions of new class types and clarified remaining timeframe for existing OffPeak class type per AFMTF
• Added new rule of minimum price for clearing Options per AFMTF
• Manual owner changed to Eric Hsia in approval section
• Removal of text in section 8.1 for FTRs that cover multiple planning years as they are no longer available and existing FTRs of this type (YRALL) have expired
• Revised general statement about ARR sources and sinks in section 2.1 and 3.1.1 to be applicable to all rounds of ARR Allocation
• Update section 8.6 to reflect the new forfeiture rule, which removes the penny test and replace it with forfeitures based on constraint contribution

• Periodic Review updates include:
• Update the process for Capacity Market Seller to demonstrate written commitment to must-offer requirement for an External Resource via Officer Certification Form as opposed to External Resource Must Offer Agreement (Section 4.2.2)
• Updates to include certain Hybrid Resources in the exemption to the RPM must offer requirement (Sections 4.7.1, 5.4.1, 5.7.1, and 5.8.1)

• Reinserted the 3.2.1.1 paragraphs from Revision 44 that did not get included in later revisions.

• Added clarifying process language in Section 7.3 around the development and timing of presenting options in the CBIR process.

• Conforming language associated with FERC Order ER20-1590 in Section 11 associated with Load Management Test and Retesting for an energy settlement.

• Conforming revisions for FERC Order ER20-1590-000 issued on September 3, 2020 approving changes to Load Management and Price Responsive Demand testing requirements to make testing more closely simulate actual emergency events. This includes details on scheduling tests, notification of tests, duration of tests and retesting provisions.
• Section 3A.6.3A establishes the testing requirements for PRD effective with 2023/2024 Delivery Year.
• Section 8.7 modified for Load management testing requirements effective with 2023/2024 Delivery Year.

• Section 1.9: Added PJM emergency test event notifications as a type of data retrieved from DR Hub.

• Periodic Review to address:
• Updated/correct terminology
• Section 1 and Section 1.1 – renamed to Billing Overview
• Section 1.2 – renamed to Payments from Net Buyers and to Net Sellers
• Section 1.3 – added new and named Default Allocation Assessment
• Section 1.4 – added new and named Billing Notifications
• Section 1.5 – added new and named Billing Adjustments
• Section 2.1.1 – renumbered to become section 2.2 (Monthly Charges) and added sub-sections of 2.2.1 (Operating Agreement Charges) and 2.2.2 (Open Access Transmission Tariff Charges)
• Section 2.1.2 – renumbered to become section 2.3 (Monthly Credits) and added sub-sections of 2.3.1 (Operating Agreement Credits) and 2.3.2 (Open Access Transmission Tariff Credits)
• Section 2.1.3 – renumbered to become section 2.4 (Other)
• Section 3.1.1 – renumbered to become section 3.2 (Weekly Charges)
• Section 3.1.2 – renumbered to become section 3.3 (Weekly Credits)
• Section 4 – renamed to Billing Support
• Section 4.1 – renamed to Support Overview
• Section 4.1.1 – renumbered to become section 4.2 (Guide to Billing)
• Section 4.3 – added new and named Market Settlements Reporting System (MSRS)

• Updated Section 2.7.2 to reflect new logic for determining LMPs for De-Energized Busses

• Section 3.2.3: Added Dynamic Ratings to the list of required verbal or electronic data during EMS datalink outages.

• Update to section 2.1 to reflect the new ELCC schedule.
• Update to section 5.1 to reflect updated ELCC deadline due to schedule change.
• Update to section 5.2 and 5.2.1 to continue the voluntary process for On-Shore Wind and Solar resources to submit unit-specific backcast data.

• Appendix A: Added information about Dynamic Ratings processing.

Administrative Change:

• Added a cross reference to M03 for the term “Stability Limits” in Section 5.5.

Revision 46 (6/1/2022):

• Section 5.5
• Added new section addressing Stability Limited Generation.

• Revised Section 2.2.1 Submission of and/or Modifications to Fuel Cost Policies
• Revised Section 2.2.2 Fuel Cost Calculation

• Conforming changes to support the FERC Order (ER21-1802) for Stability Limits
• Section 4.2.2.2
• Added clarification language that the Desired MW output will consider the stability limits
• Sections 5.2.6; 5.2.6.1; 5.2.6.2 and 5.2.6.4
• Added clarification language that lost opportunity cost credits are not paid for the MWs associated with a stability limit reduction
• Added clarification language on how the Desired MW output will consider the stability in effect
• Sections 5.2.8 and 5.2.9
• Added clarification language that the Desired MW output will consider the stability limits
• Section 6.2.2
• Added clarification language that the Desired MW output will consider the stability limits

• Added Section 2.18 to describe the modeling, clearing and reporting rules regarding stability limits
• Added Section 2.18.1 to include station stability limit units which are also not eligible for LOC credits for the MW reduction due to stability limits

• Added “Workshops” definition (Section 2) and language in section 5.6.
• Renumbered old section 5.6 content as 5.7

• Attachment D: Replaced System Restoration Coordinators Subcommittee (SRCS) with System Operations Subcommittee (SOS); added scheduling flexibility to the spring and fall restoration drill
• Attachment G: Updated Table 1, Annual Restoration Plan Review Deadlines
• Attachment H: Updated Under Frequency Load Shed table with new data

• Periodic Review
• Section 3.9 – Updated stability limitation process language in accordance with FERC Docket #: ER21-1802-000
• Section 3.11 - Aligned language with the current TO/TOP matrix language and intent for VAR-001 R5.3.
• Attachment A – Added language explaining that Homer City Stability Trip Scheme 1 (STS-1) is non-redundant.
• The Revision History under Revision 60 has been updated to reflect that version 60 was a Periodic Review which was unincluded in the previous publish.

• Section 2.1.1 Facility Ratings – Added new subsection 2.1.1.1 – Ambient Adjusted Ratings and new subsection 2.1.1.2 – Dynamic Ratings

• Attachment E Winter Summer Required Manual Load Dump PJM Mid-Atlantic Region updated with the table and wording
• Attachment F exhibit 7 PJM Manual Load Dump Capability updated table
• Attachment F updated with the Note Only on tab 1 of the attached spreadsheet titled PJM UFLS (Hz)

• Updated language “Section 11.11 – Elections” to offer flexibility to conduct elections of Board Members and the Members Committee Vice Chair using an alternative to written paper ballots.

• Annual periodic review.
• Section 2.5.6: Clarified loss of control center functionality procedures as it relates to EOP-008 and TO/TOP Matrix.
• Section 3.2.1.1: Clarified the responsible party for protecting all Real-time Assessment and Real-time monitoring data while in transit, as it relates to CIP-012.
• Section 4.1.5: Added additional entities with which Member communications are required, as it relates to COM-001 and TO/TOP Matrix.
• Attachment B: Removed EOP-008 R7 reference as this is now covered in Section 2.5.6.

• Periodic Review
• Sections 3.1 and 3.2 were edited to refer users to the existing CEII requirements in PJM Manual 14B.
• Section 4.2 was edited to reference existing CEII information in PJM Manual 14B
• Section 6.1 was edited to include the requirement to use the Competitive Planner Tool for submission of all proposals
• Section 6.2 Redaction Requirements was edited to reflect that all proposals can now be redacted in the Competitive Planner Tool
• Attachment A: Critical Energy Infrastructure Information (CEII) was removed
• Attachment B “Using the Secure File Transfer Tool to Submit Proposals” was changed to Attachment A, and edited to reflect that the Secure File Transfer Tool can be used to send Supplemental Proposal information as required.
• The Secure File Transfer Tool information was clarified as a tool to only be used to submit supplemental proposal information as required
• Reinserted Exhibit 1 which had been accidentally removed from previous revisions

• Update to section 3.3.2 to reflect that Net EAS of the Reference Resource CT is calculated using the forward-looking methodology with application of the 10% adder for only the 2022/2023 Delivery Year. The Net EAS is determined using the historical approach and without application of the 10% adder for all other delivery years.
• Update to section 5.4.1 to reflect that sell offers of existing generation capacity resources above $0/MW-Day must seek unit-specific exception or elect to use MSOC based on gross ACR of applicable resource type, if available, effective 9/2/2021. Added language specifying that sellers may elect to use a default offer cap of 1.1 times the BRA RCP for any 3^rd IA.
• Updated section 5.4.4 to reflect that the Net EAS of units seeking a net ACR-based exception is calculated using the forward-looking methodology for only the 2022/2023 Delivery Year. The Net EAS is determined by historical net revenues for all other delivery years.
• Updated section 5.4.5 to make clear that this section and its sub-sections which describe the MOPR provisions of Sections 5.14(h) and 5.14(h-1) of Attachment DD of the PJM OATT are not applicable after the 2022/2023 Delivery Year. Deleted language in section 5.4.5.2 describing consequences of accepting State Subsidy after electing competitive exemption or certifying that resource is not state subsidized.
• Added new section 5.4.8 to describe the MOPR provisions of Section 5.14(h-2) of Attachment DD of the PJM OATT which are effective with the 2023/2023 Delivery Year.

• Periodic review
• Attachment A: Appendix D: Corrected Silver Run Electric to properly show as TO
• Updated manual ownership from Donnie Bielak to Kevin Hatch

• Periodic Review
• Section 2.3.1 Voltage Reduction Table
• Renamed Est. Peak Load and Est. Load Reduction columns to reflect summer values
• Added columns with Winter values for Est. Peak and Est. Load Reduction
• Section 6.4 Resource Limitation Reporting - Changed note timeline for resource limitations Steam and CT units to be placed in Max Emergency until issue charge is completed.

• Section 3.1.1
• Removed outdated references to former Attachment H under Measurements and Compliance to Attachment E PJM Reporting of NERC BAL Standards
• Section 4.5.5
• Removed Notifies LSEs of a resource’s certification for Regulation within three business days
• Attachment E
• Updated E.1 Daily Data Support, Changed E.3 to E.2 PJM Frequency Bias,
• Removed E.2 Inadvertent Interchange Calculation section, and NERC Disturbance Control Standard Report

• Updated Section 2.3.3.2 to add language to support Pseudo Modeled Combined Cycle Units
• Added Section 2.3.4.6 to address minimum run time for Pseudo Modeled Combined Cycle Units
• Updated the approver from Phil D’Antonio to Brian Chmielewski due to a management change
• Section 2.3.4.3 updated for grammar, punctuation and additional minor clean-up

• Correct/Remove exhibit language in sections 1.2, 3.2, 3.2.1, 3.2.3

• 2.1: Reorganization of wording to distinguish between PJM Administrative Rates and PJM Pass-Through Rates
• 2.2: Added conforming language from FERC Order ER22-26 to describe the PJM Administrative Rates as formulas instead of as stated rates. Created subsections for the administrative rates and pass-through rates.
• 2.5: Renamed and reworded section to only be reconciliation for the PJM Scheduling System Control and Dispatch charges
• 2.6: New section to only be reconciliation for the TO Scheduling System Control and Dispatch charges

• Updated Section 4b.1 to remove inaccurate language
• Updated Section 10.4.1 to indicate correct reference attachment
• Updated Section 9.1.1 to clarify that the generation resource’s fuel cost policy only needs to be updated when opting in to intraday for the cost-based schedule.

• Updated manual ownership from Rebecca Carroll to Donnie Bielak
• Section 4.5.7
• Added language to extend the logic of regulation performance group performance score sharing to the historic performance score.

• Periodic Review
• Updated manual ownership from Mike Sitarchyk to Maureen Curley

• Updated manual ownership from Rebecca Carroll to Donald Bielak
• Section 6.4 Resource Limitation Reporting – Update the Note to indicate a short-term exception for when PJM may put a unit in the Maximum Emergency category

• Periodic cover to cover review.
• Section 1.2: Updated ERAG study and participation.
• Attachment A: Updated OATF scope.

• Revised Section 1.7.3 No-Load Cost Definition
• Revised Section 1.7.4 Incremenatl Energy Cost Definition
• Consolidate Section 2.1 Heat Rate and Section 2.2 Performance Factor into Section 2.1 Heat Rate Input/Rates and Performance Factors
• Revised Section 2.1 Heat Input definition and Heat Input and Incremental Heat Rate equations
• Moved Section 2.3 Fuel Cost Policies and Guidelines to Section 2.2
• Revised Section 2.2.3 and 2.2.4 to replace Other Fuel Related Cost with Operating Cost
• Created new Section Incremental Energy Cost
• Revised Section 2.5.1 No-Load definition, Section 2.5.2 No-load Fuel, and Section 2.5.3 No-Load Calculation
• Added Section 2.9 Ten Percent Adder
• Consolidated Section 3.1 Nuclear Heat Rate and Section 3.2 Performance Factor into Section 3.1 Nuclear Heat Input/Rate and Performance Factor
• Moved Section 3.3 to Section 3.2
• Created New Section 3.3 Incremental Energy Cost
• Consolidated Section 4.1 Heat Rate and Section 4.2 Performance Factor into Section 4.1 Heat Input/Rate and Performance Factor
• Moved Section 4.3 to Section 4.2
• Revised Section 4.2 to replace Other Fuel Related Cost with Operating Cost
• Created New Section 4.3 Incremental Energy Cost
• Consolidated Section 5.1 Heat Rate and Section 5.2 Performance Factor into Section 5.1 Heat Input/Rate and Performance Factor
• Moved Section 5.3 to Section 5.2
• Created New Section 5.3 Incremental Energy Cost
• Revised Section 5.4 to replace Other Fuel related Cost with Operating Cost
• Revised Section 5.6.3 Equivalent Service Hour (ESH)
• Consolidated Section 6.1 Heat Rate and Section 6.2 Performance Factor into Section 6.1 Heat Input/Rate and Performance Factor
• Moved Section 6.3 to Section 6.2
• Revised Section 6.2.1 to replace Other Fuel Related Cost with Operating Cost
• Created New Section 6.3 Incremental Energy Cost
• Revised Section 6.4 to replace Other Fuel Related Cost with Operating Cost
• Revised Section 6.6.3 Equivalent Service Hour (ESH)
• Consolidated Section 7.1 Pumping Efficiency (Pumped Storage Hydro Only) and Section 7.2 Performance Factor into Section 7.1 Pumping Efficiency (Pumped Storage Hydro Only) and Performance Factor
• Moved Section 7.3 to Section 7.2
• Created New Section 7.3 Incremental Energy Cost
• Consolidated Section 9.1 Heat Rate and Section 9.2 Performance Factor into Section 9.1 Heat Input/Rate and Performance Factor
• Moved Section 9.3 to Section 9.2
• Created New Section 9.3 Incremental Energy Cost
• Consolidated Section 10.1 Heat Rate and Section 10.2 Performance Factor into Section 10.1 Heat Input/Rate and Performance Factor
• Moved Section 10.3 to Section 10.2
• Created New Section 10.3 Incremental Energy Cost
• Consolidated Section 11.1 Efficiency Factor and Section 11.2 Performance Factor into Section 11.1 Efficiency Factor and Performance Factor
• Moved Section 11.3 to Section 11.2
• Created New Section 11.3 Incremental Energy Cost

• Updated manual ownership from Aaron Berner to Sami Abdulsalam

Section 2.2

• Updated the DASR requirement to the new 2022 values.