Manual Updates

• 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• Updated Outdated Hyperlinks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• Remove outdated references to DASR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.

• Added a missing footnote in Attachment A

• Revisions proposed from cover-to-cover periodic review:
• Revised outdated language
• Minor revisions to correct grammar, spelling, punctuation, consistency of terms and document references.
• Section 3: Added battery storage to forecasted items.

• Changes to grammar in 1.3.2 Economic Planning
• Added a new subsection 1.4.2.4 Incorporation of EOL Needs into the RTEP
• Added new language detailing analysis in 2.1.2 Reliability Planning
• Added new graphics in 2.2.1 Reliability Planning
• Updated language to include Winter Peak Cases in 2.3.8 NERC P3 and P6 “N-1-1” Analysis
• Changed the title of subsection 2.3.15 to Extreme Event Review
• Added new objectives in 2.6 RTEP Market Efficiency Planning
• Added language in the following Attachments
• B.2 and B.3
• C.2.6
• D.1
• F
• G.9.2 and G.9.6
• H.1.2 and H.1.3

• Section 6.6
• Increased bid limits to 15,000 per corporate entity, auction round, and period
• Section 9.1
• Added reference to the Network Model User Guide on the FTR section of PJM.com

Periodic cover-to-cover review

Section 1.2 Generator Commercial Naming Convention

• Clarified and provided additional guidance on acceptable Generating Facility naming

Section 2.3 Generator Market Remodel

• Added new section under the Responsibilities of Generation Owners section to detail the generator market remodel process.

Section 2.4 eDART Modeling

• Added new section under the Responsibilities of Generation Owners section to describe eDART modeling requirements previously covered in section 5.3.4 eDART.

Section 3.3 Voice Communication Requirements for Generating Entities

• Removed references to ring-down phone lines to generating entities

Section 5.3.3 PJM eRPM

• Renamed to PJM Capacity Exchange and removed references to eRPM

Section 5.3.4 eDART

• Removed the last two paragraphs from this section and moved it to the new section 2.4 eDART Modeling.

Section 5.4.4 Grid Accounting

• Replaced references to eRPM with Capacity Exchange

Section 5.7.2.7 eRPM account

• Renamed to Capacity Exchange account

Section 5.7.3 Process Timeline

• Corrected the duration of attaining PJM membership after all required paperwork has been signed and received by PJM from 60 to 90 days.

Section 7.3.1 Planned Outage

• Clarified that eDART tool is used for submitting Planned Outages

Section 7.3.2 Maintenance Outage

• Clarified applicability to all generation resources

Section 7.3.5 Fuel and Emissions Reporting

• Renamed section to Fuel Emissions and Operational Data Reporting
• Clarified requirements and necessity for responding to PJM data requests

Section 7.3.6 Generation Owner Periodic Tasks and Data Submittals

• Added new section with guidelines to assist Generation Owners tracking periodic tasks, testing and data submittals.

Section 8.2.1 Data Requirements for Wind Forecast Set Up

• Clarified language, including title of section, to indicate that data is required for forecasting when there is a change to a wind farm in addition to when a wind farm first comes online

Section 8.2.3 Real Time Meteorological Tower (or mutually agreed upon alternative source)

• Modified format of temperature unit in table to be consistent with other parameters

Section 8.2.6 Wind Power Forecast

• Modified names and descriptions of types of forecasts to reflect the manner in which PJM currently uses forecast products

Section 8.3 Forecast Data Usage

• Aligned names and descriptions of types of forecasts with changes made in 8.2.6

Section 9.1.1 Generator Deactivation Request

• Renamed to Generator Deactivation Notice
• Updated Black Start resource termination requirements to reflect current Tariff requirements
• Updated language to be consistent with current business practice

Section 9.1.2 Initial Analysis

• Renamed to Deactivation Analysis
• Updated language to be consistent with current business practice

Section 9.1.3 Analysis Results

• Updated language to be consistent with current business practice and to reflect current Tariff requirements
• Updated Black Start resource termination revenue impacts to reflect current Tariff requirements

Section 12.2.1 Data Requirements for Solar Forecast Set Up

• Clarified language, including title of section, to indicate that data is required for forecasting when there is a change to a solar park in addition to when a solar park first comes online
• Added language stating that solar parks with multiple components (e.g. multiple panel models) need to provide data for each component
• Modified list to separate Maximum Facility Output (MW) from AC installed capacity of each component (MW)

Section 12.2.2 Real Time Output

• Added clarifying language regarding criteria that require real-time output telemetry
• Expanded requirements for hybrids and collocated resources to apply to all combinations of solar and other resources in addition to solar and storage resources

Section 12.2.3 Real Time Meteorological Tower (or mutually agreed upon alternative source)

• Clarified that type of real-time irradiance data required is Plane of Array (POA) irradiance
• Modified format of temperature unit in table to be consistent with other parameters

Section 12.2.5 Solar Power Forecast

• Modified names and descriptions of types of forecasts to reflect the manner in which PJM currently uses forecast products

Section 12.3 Forecast Data Usage

• Aligned names and descriptions of types of forecasts with changes made in 12.2.5

Attachment N: Cold Weather Preparation Guideline and Checklist

• Update existing links and added links to additional industry guidance for generation resource cold weather preparation
• Added recommendation to create “Emergency Freeze Protection Kits” at various plant locations

Periodic Cover to Cover Review

Section 2.1 Generation Outage Reporting Overview

• Clarified eDART ticket requirements for units that do not have a day-ahead must offer requirement
• Corrected use of eDART Reportable MW

Section 2.2 Planned Outages

• Clarified the language defining the Peak Period Maintenance Season

Section 2.2.4 Planned Outage Restrictions for Black Start Units

• Moved to new Section 2.5.1 Outage Restrictions for Black Start Units

Section 2.3 Maintenance Outages

• Clarified the language defining the Peak Period Maintenance Season

Section 2.3.1 Maintenance Outage General Information

• Removed examples and clarified language when a generation resource fails prior to the scheduled start time of an outage.

Section 2.5.1 Outage Restrictions for Black Start Units

• Moved from Section 2.2.4 and expanded to include both Planned Outages and Maintenance Outages in accordance with updated OATT language.
• Clarified Black Start Unit substitution rules.

Section 2.5.2 Outage Reporting for Cranking Diesels and Auxiliary Equipment

• Moved existing manual language to new section under Section 2.5 Outage Reporting for Facilities Providing PJM Black Start Service

• Attachment E Exhibit 1 the Eastern Portion of Mid-Atlantic Region table deleted

• Added “Forums” definition (Section 2) and language in sections 4.2 and 5.5. Renumbered old Section 5.5 content as 5.6

• Attachment F: Revisions made throughout to make the Attachment permanent for all Exceptional Circumstances rather than only the COVID-19 Pandemic.

• Updated Attachment C to agree with Operating Agreement (OA)

Section 2.3.2 Real-Time Emergency Procedures (Warnings and Actions)

• Updated and added Note under PJM Member Actions for Step 10 (Real-time): Manual Load Dump Action to articulate expectations of Member Load shed plans

Section 5.5 Interconnection Reliability Operating Limits (IROL) Manual Load Dump Warning/Action

• Added Note under PJM Member Actions to articulate expectations of Member Load shed plans

Attachment E: Manual Load Dump Allocation Tables

• Updated Exhibit 7: PJM Manual Load Dump Allocation Table with 2021 information
• Corrected name of Exhibit 7

Attachment F: PJM Manual Load Dump Capability

• Updated Exhibit 8: Manual Load Dump Capability with 2021 information
• Corrected name of Exhibit 8

Attachment N: IROL Load Dump Tables

• Revised table with updated information

• Section 4.2.2 & 4.2.4 – Removed reference to PRC-001 standard due to retirement.
• Attachment A: Removed Elgin Unit Stability Trip Scheme due to upgrades in the area.
• Attachment A: Removed Susquehanna 500kV Catty Corner Scheme.

• New Sections
• Section 2.5.1 Ancillary Service Optimizer (ASO
• Section 2.5.2 Intermediate Term Security Constrained Economic Dispatch (IT SCED)
• Section 2.5.3 Real-time Security Constrained Economic Dispatch
• Section 2.5.3.1 Real-time Security Constrained Economic Dispatch Optimization
• Section 2.5.3.2 Real-time Security Constrained Economic Dispatch Marginal Resource Identification
• Section 2.5.3.3 Real-time Security Constrained Economic Dispatch Methodology
• Section 2.5.3.4 Real-time Security Constrained Economic Dispatch Timeline and Instruction Set
• Section 2.5.3.5 Real-time Security Constrained Economic Dispatch Inputs
• Section 3.2.8.1 Hydropower Operation
• Updated to provide clarity on how Five (5) Minute Dispatch & Pricing will impact the current business rules
• Section 2.3.3.1
• Section 2.5
• Section 2.6
• Section 2.7
• Section 3.2.2
• Section 3.2.7.4
• Section 3.2.7.5
• Section 3.2.7.6
• Section 3.2.7.7
• Section 3.2.8
• Section 4.2.4
• Section 4b.2.3
• Terminology Changes
• Market Applications updated to Market Clearing Engines
• Hydro updated to Hydropower

• Updated section 2.2 Pre-Qualification Application to include execution of NDA when necessary.
• Updated subsection 8.1.1 Initial Review and Screening to include critical substation planning analysis.
• Updated subsection 8.2.1 Primary Considerations to include critical substation planning analysis.

• Added a new subsection 1.4.1.8 Maintaining reliability associated with critical substations
• Added a new bullet in section 2.1 Transmission Planning
• Added a new section 2.9 Critical Substation Planning Analysis

• Updates to Section 2.4.5 to reflect new EE Addback methodology to be used in all RPM Auctions conducted for the 2023/2024 Delivery Year and all subsequent delivery years.

Section 6.4 Resource Limitation Reporting

• Updated the Operation of Resource Limited Units when PJM will request or require units to be bid in the Maximum Emergency category
• Updated Exhibit5: Resource Limitation reporting
• Added Note to indicate a short-term exception for when PJM may put a unit in the Maximum Emergency category

• Appendix A, Behind the Meter Generation Business Rules
• Documented the processes related to designating capability as Generation Capacity Resource and/or Energy Resource
• Clarified options for BTMG to participate in PJM Load Response and process to indicate a Behind the Meter Generation unit is participating in PJM Load Response
• Clarified the load impacts due to Behind the Meter Generation status changes
• Clarified the performance obligation impacts due to Behind the Meter Generation status changes
• Administrative updates – added section headings and corrected references to business rule numbers

The following sections were updated to clarify and more adequately document processes related to Behind the Meter Generation business rules on status changes:

• Section 1.6 - Updated terminology to ensure consistency with the Behind the Meter Generation definition in the OATT.
• Section 1.6.1 -Updated to clarify information required in generation interconnection request to designate capability as Generation Capacity Resource and/or Energy Resource.

• Section 4.5
• Updated public meetings/ media participation procedure and expanded rules to apply to include any individual or organization disseminating information on a public platform.
• Updated photography review and release process

• Added Section 13 Black Start Capital Recovery Factor Guidelines

• Section 4.6:
• Updated references to the PJM Tariff and PJM manuals
• Updated capitalization of defined terms
• Section 4.6.9:
• Added conditions for Black Start Units entering Black Start Service on or after June 6, 2021 to provide service for capital cost recovery period plus remaining life of the unit
• Added conditions for these units to terminate Black Start Service
• Section 4.6.14:
• Added 90 day period to make repairs to Black Start Unit including one year extension period with PJM approval
• Added language that Black Start revenues may be deferred until the following month if a Black Start Unit submits its black start test after the 25th day of the month
• Added Section 4.6.16
• Added conditions for Black Start Unit substitution

• Section 9.1.1
• Clarified Black Start Service termination notification requirements
• Section 10.1.1
• Updated requirements for responding to Black Start RFP, applicable rates and commitment period.

• Conforming changes to support the FERC Order (ER19-2722) for Fast-Start Pricing
• Sections 5.1, 5.2: added reference to Dispatch Differential Lost Opportunity Cost credits
• Section 5.2.1: Describe the offset to Day-ahead Operating Reserve credits to account for double counting of commitment costs
• Section 5.2.9: new section to describe the settlement calculations for resources that are eligible to receive Dispatch Differential Lost Opportunity Cost credits
• Section 5.3.6: new section to describe the allocation of Dispatch Differential Lost Opportunity Cost credits as charges to market participants based on ratio share of real-time load plus exports
• Periodic Review to address:
• Updated/correct terminology
• Section 2: added 2.2 and 2.3; removed language regarding specific rules associated with CPLE, DUKE and NCMPA1 due to termination in 2020
• Section 3: added 3.10
• Section 4: added 4.2.1, 4.2.2, 4.2.2.1, 4.2.2.2, 4.3.1 and 4.3.2
• Section 5.2.1: changed ‘Flexible Resources’ back to ‘Combustion Turbine units’ due to be being inadvertently changed during Intra-day Offer (IDO) implementation
• Section 5: added 5.3.1, 5.3.2, 5.3.2.1, 5.3.2.2, 5.3.2.3, 5.3.2.4, 5.3.2.5, 5.3.3, 5.3.4 and 5.3.5
• Section 6: added 6.2.1, 6.2.2, 6.3.1, 6.3.2 and 6.3.3
• Section 7: added 7.2.1, 7.2.2, 7.3.1 and 7.3.2

• New Sections
• Section 2.1 Overview of PJM Energy Markets
• Section 2.1.1 Fast-Start Capable Resources
• Section 2.1.2 Fast-Start Capable Adjustment Process
• Section 2.1.3 Eligible Fast-Start Resources
• Section 2.1.4 Day-ahead Energy Market
• Contains existing language with minor modifications
• Section 2.1.5 Real-time Energy Market
• Contains existing language with minor modifications
• Section 2.3.6.3 Generation Resource Composite Energy Offer Screening Process for Composite Offers more than $1,000/MWh
• Section 2.7.1 Energy Offers used in Real-time Price Calculation
• Section 2.7.3 Determination of LMPs for Generation Resources with Composite Energy Offers greater than 1,000/ MWh and equal to or below $2,000/MWh
• Section 2.7.5 Determination of LMPs for Composite Energy Offers Greater than $2,000/MWh
• Section 5.2.7.1 Day-ahead Integer Relaxation
• Section 5.2.7.2 Energy Offers used in Day-ahead Price Calculation
• Section 5.2.7.3 Determination of LMPs for Generation Resources with Composite Energy Offers Greater Than $1,000/MWh and equal to or below $2,000/MWh
• Section 5.2.7.4 Determination of LMPs for Generation Resources with Offers Greater than $2,000/MWh
• Section 5.2.7.5 Determination of LMPs for Composite Energy Offers Greater than $2,000/MWh
• Section 10.3.1 Economic Load Response Resource Composite Energy Offer Screening Process for Composite Offers more than $1,000/MWh
• Section 10.3.2 Determination of LMPs for Economic Load Response Resources with Composite Energy Offers greater than 1,000/ MWh and equal to or below $2,000/MWh
• Section 10.3.3 Determination of LMPs for Composite Energy Offers Greater than $2,000/MWh
• Updated to provide clarity on how Fast-Start Pricing will impact the current business rule(s)
• Section 2.2
• Section 2.3.2.3
• Section 2.3.6.1
• Section 2.5
• Section 2.7
• Section 2.8
• Section 2.9
• Section 2.9.1
• Section 2.17
• Section 3.1
• Section 3.2.7.4
• Section 3.2.7.5
• Section 4.1
• Section 4.2.6
• Section 4b.1
• Section 4b.2.4
• Section 7.2
• Section 7.3.4
• Section 11.2.3
• Section 11.2.5
• Attachment D
• Retired
• Section 2.13
• Renumbered
• Section 2.7.2
• Previously 2.7.1
• Section 2.7.4
• Previously 2.7.2
• Section 5.2.6.1
• Renamed to Section 5.2.7
• Section 10.3.4
• Previously 10.3.1
• Title and language updated to use proper terminology
• Section 2.4

• Updates to Section 8.4A to clarify Scheduled MW used for Excusal and Bonus purposes in Performance Assessment Interval settlement is calculated using Dispatch Run LMP due to Fast Start Pricing implementation on 9/1/2021.

• Section 9.5 - Corrected previously approved language related to Motion Voting Order; and added a footnote clarifying truncated voting rules at Senior Standing Committees.

• Revisions proposed as a result of a Cover to Cover Periodic Review.
• Revisions needed to clean-up outdated language and ensure language follows current processes.
• Minor revisions to correct grammar, spelling, punctuation, consistency of terms and document references.
• Based on the above, the following sections include revisions: 1.2, 1.4, 1.6, 1.7, 1.8, 1.9, 2.1, 3.2, 3.3 and 4.3.
• Section 5.2 and 5.3 were updated for format changes only.

• Periodic Review
• Periodic review is up to date with no changes.
• Compliance Reliance ACA Update
• Updated Section 2.2 to clarify instructions for a Transmission Owner to add, remove, and/or convert a flow device and submit the associated ratings.

• Cover to Cover Periodic Review
• Conforming changes per ER21-520-000
• Section 6.8 - Conforming changes for addressing a defaulting Members FTRs with various options versus settlement only
• Clarifications, corrections, formatting, grammar, and punctuation
• Section 1.2.1 – Punctuation
• Section 4.4 – Formatting
• Section 4.9.1 – Grammar
• Section 6.1 – Prompt-month clarification
• Section 9.1 – Grammar
• Section 10.1 – Grammar, Correction of SFT counterflow accounting for Obligations

• Manual 14 A updates to incorporate Tariff changes to PJM’s New Services Queue closing timeline and deficiency review requirements. The following sections were impacted:
  • Sections 2.2.1, 2.3, 4.2 and B.2.1: Updated the New Service Queue request submission deadline and references to the deficiency review schedule.

• Initial version of Manual 21A describing business practices for collecting information to develop ELCC Class Ratings and for calculating Accredited UCAP values based on ELCC Class Ratings.

• Section 1.5 – added an expiration date for the application of Manual 21 provisions to various types of renewable and storage resources that together are the ELCC Resources in order to transition such rules to Manual 21A.
• Section 2.1 – deleted the “10 hour rule” which caps the net capability of limited duration resources. This is now the “X-hour rule” in Manual 21A.

• Added Section 5 that describes key elements of the Effective Load Carrying Capability (ELCC) methodology. This methodology is used to determine the Accredited UCAP values of ELCC Resources.

• Added to Section 6.1 to include FERC transparency requirements for Operating Reserve Demand Curve

Section 1.1 Policy Statements

• Added a bullet under PJM Actions to recognize that PJM may issue a Production System Change Freeze during Emergency Operations
• Added explanations for the acronyms SOS, SOS-T and SOS-J

Section 3.2 Conservative Operations

• Updated PJM and Member Actions to include participation in SOS conference calls

  Section 6.4 Fuel Limitation Reporting

• Reference to OE-417 updated to DOE-417

  Attachment A Public Notification Statements

• Updated SOST to SOS-T

  Attachment J Disturbance Reporting - US Department of Energy

• Updates to reflect changes made by the U.S. Department of Energy (DOE) to the OE-417 Electric Emergency Incident and Disturbance Report which has been updated and renamed to DOE-417 effective June 1, 2021
  • All references to OE-417 updated to DOE-417
  • Corresponding updates to the PJM Operating Plan for EOP-004 (R1 and R2) table
    • Event Type numbering changed to reflect updated form
    • New Event Types #2 and #14 added
    • Threshold for Reporting updated for Event Type #3
    • Deadline to submit the report to regulatory organizations updated to reflect 72hrs or final DOE-417 report for all Event Types
    • Updated the incomplete Entity responsible for providing report to PJM for Event Type #4
    • Removed duplicate # sign in Event Type for row 1
    •  Added #16 in Event Type for row 2

• Attachment F COVID date extended from June 30, 2021 to December 31, 2021

• Updated manual ownership from Mark Sims to Augustine Caven.

• Updated manual ownership from Mark Sims to Augustine Caven

• Added new Section 2.3.3.4 Public Distribution Microgrid Generators

• New paragraph in Section 8.4A to clarify treatment of Public Distribution Microgrid Generators that are Generation Capacity Resources for Non-Performance Assessment.
• PRD – Approved as per Docket Nos. ER21-1243--0000 and ER21-1243-001 on 4/28/2021, effective on 06/01/2021:
• Removed reference to LSE from PRD Provider description (Section 1.2.3)
• Revised PRD Provider description, changed PRD Credit recipient from LSE to PRD Provider (Section 3A.1)
• Removed LSE-specific requirements for PRD (Section 3A.4.2)
• Removed section 3A.4.2.1 - Verification of Retail Rate Structure with LSE
• Removed reference to LSE (Section 3A.4.2.2)
• Removed identification of LSE from registration requirement (Section 3A.5)
• Changed PRD Credit recipient from LSE to PRD Provider (Section 9.4.4)

• Periodic Review:
  • Section 1.7: Removed applicability date and added email contact and timeline
  • Section 3.4.2 and 3.5.4: NPIR changes for eDART nuclear voltage limits.
  • Section 4.2.9: Added clarification language for rescheduling outages longer than 30 days into a different planning year.
  • Added new Attachment G: Transmission Outage Ticket Best Practices

• Section 6.3 – Added procedural language clarifying ownership of an issue and ability of a Member to bring an issue directly to the MC
• Section 9.4 – Added procedural language clarifying control of a Main Motion and Alternate Motions presented by a subordinate or other Member to a parent committee.
• Section 9.5 – Added procedural language clarifying the relevance, posting, and handling of Alternate motions

• Periodic review updated as follows:
• Attachment B Exhibit 16: Replaced with clearer image
• Attachment F: Removed information; Linden and Neptune restoration plans are in eDART
• 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 and added note regarding PRC-006 R10

Section 5.3.7 Resource Tracker

• Changed Market Participants are requested to Generator Owner, or designated agent, is required
• Changed the Transferee (“to” Member/Company) must confirm the resource to Generation Owner, or designated agent, is required to confirm the ownership information

Administrative change

• Periodic Review is up to date with “no changes”
• Updated manual ownership from Jeff Schmitt to Ryan Nice

• Periodic Review
• Throughout: Replace NERC TLR with “TLR”, NERC IDC with “IDC”, and NERC E-tags with “OATI webSmartTag”, and PJM logs with “PJM SmartLogs”
• Throughout: Corrected grammatical errors
• Section 1.1: Updated links
• Section 1.1: Updated the PJM timing to reference Attachment C
• Section 3.1: Added language for an alternative method for simulating transfers
• Section 3.1: Updated hyperlink for PJM Transmission Facilities page
• Section 5.1: Update hyperlink for VACAR Agreement
• Attachment A: Added Hyperlinks for each section in the Table of Contents
• Attachment A: In Appendix B updated the links and combine the MISO JOA/CMP into one entry
• Attachment A: In Appendix D updated PJM TOs and TOPs to include NextEra Energy Transmission MidAtlantic Indiana as TO, Silver Run Electric as TO, and Wabash Valley Power Association as TO

Cover to cover periodic review.

• Updated grammar, spelling, terminology and hyperlinks throughout.
• Sections 2.3.3A.2, 2.3.3A.3, 2.3.4, 2.3.4.1, 2.3.4.2, 2.3.4.4, 2.3.4.5: Removed all language related to Base Capacity Resources
• Section 2.3.4B: Removed language related to the first day of the ESR Participation Model
• Section 2.12: Update all UDS terms to Dispatch Signal
• Section 5.2.3.1: Removed
• Section 3.2.10: Removed most of section, information contained in other parts of the Manual

• Cover to Cover Periodic Review
• ‘About PJM Manuals’ section: Administrative change to update category names
• ‘About This Manual’ section: Administrative changes to fix broken hyperlinks and update reference document titles
• Section 1.1:
• Added reference to Firm Redirect for completeness
• Deleted outdated language related to secondary non-firm service
• Section 1.3: Administrative change to fix broken hyperlink
• Section 1.3.2: Updated LTF request process steps to align with current OATT language and refreshed OASIS application
• Sections 1.3.5 and 1.3.6: merged these two sub-sections and moved them to more appropriate location within document (new sub-section 1.4.1)
• Section 1.5: Added clarification to align with current OATT language
• Section 2.1: Minor language update to align with refreshed OASIS application
• Section 2.4: Minor language change to reflect current location of OASIS information

Administrative change

• Updated manual ownership from Ryan Nice to Jeff Schmitt

Administrative change

• Updated manual ownership from Jason Connell to Jason Shoemaker

Administrative change

• Updated manual ownership from Jason Connell to Jason Shoemaker

Administrative change

• Updated manual ownership from Jason Connell to Jason Shoemaker

Administrative change

• Attachment B:  Aligned bullet and section title

Administrative change

• Updated manual ownership from Ray Fernandez to Rebecca Stadelmeyer

Administrative change

• Updated manual ownership from Ray Fernandez to Rebecca Stadelmeyer

Administrative Change

• Updated manual ownership from David Budney to Natasha Holter

Administrative Change

• Attachment B:  Aligned bullet and section title

• Periodic Review
• Section 3.2.1: updated language to annual task training requirement to include reference to applicable NERC Standards

• Section 8.3 – Added procedural language regarding polling on the Status Quo
• Section 8.4 – Added procedural language regarding polling on the Status Quo

Administrative change

• Updated manual ownership from Ray Fernandez to Rebecca Stadelmeyer

Administrative change

• Updated manual ownership from Ray Fernandez to Rebecca Stadelmeyer

This document is the fourteenth revision of the PJM Manual for Generation and Transmission Interconnection Facility Construction (M-14C). There are some editorial changes throughout this revision that reflect the current PJM Manual structure. The following is a summary of other significant content revisions in the document:

• Cover to Cover Periodic Review
• Introduction
• Added Manual references of M-14F and M-14G
• Section 2
• Revised Manual reference from M-14A to M-14G
• Section 3
• Updated Consent to Assignment template Website link
• Added detailed information required from IC on ownership interest change during implementation phase and the corresponding Agreement assignment and amendment process
• Section 5
• Updated Option-to-Build facility’s title transfer process to the PJM OATT
• Section 6
• Updated project cost tracking of RTEP baseline and supplemental projects to include permitting and approvals that impact project schedule
• Updated periodic cost tracking process of RTEP baseline and supplemental projects
• Attachment F
• Updated RTEP project status code ‘EP’ for quarterly update task
• Attachment G
• Added new Attachment G, Notification Form of Assignments and Entity Changes

• Added language to section 6.6 regarding bid limits for FTR auctions
• Updated manual ownership from Ray Fernandez to Rebecca Stadelmeyer

• Periodic Review:
• Section 2.1.2 PC Applications
• Updated two settlement terminology to day ahead in the MDB application
• Removed reference to the resource scheduling and commitment tool
• Added references to DIMA & RAC
• Section 4.1.1 Monitoring Reserves
• Updated reference from RFC BAL Standards to NERC Resource and Demand Balancing (BAL) Reliability Standards
• Section 4.6.8 Product Description
• Removed specific PJM generator reference and updated to any generator for black start unit starting requirements
• Section 5.3.3 Action in a High – Voltage Situation
• Added reference to PJM M03 Transmission Operations section 3.7 High Voltage Operation & PJM M13 Emergency Operations section 2.4.7 High System Voltage

• Periodic Review to include the following:
  • Section 2.2 Reserve Requirements:
    • Updated note for the amount of contingency reserves that can be made up of interruptible load from 25% to 33%
  • Section 2.3 Capacity Shortages:
    • Modified note #3 and deleted note #5 due to the retirement of Limited DR, Extended Summer DR and Base DR
  • Section 3.9 Assessing Gas Infrastructure Contingency Impacts On the Electric System:
    • Removed reference to pre-defined gas contingencies being identified in M03 CEII version
  • Section 5.2 Transmission Security Emergency Procedures:
    • Modified note #3 and deleted note #5 due to the retirement of Limited DR, Extended Summer DR and Base DR
  • Section 5.4 Post-Contingency Local Load Relief Warning:
    • Added detail to the members action section that TO dispatchers shall check the PCLLRW application to ensure that no PCLLRW status are deficient
  • Attachment A Public Notification Agreements:
    • Updated baseline PJM information in Public Notification statements such as the amount of people in PJM’s footprint, miles of transmission lines, & CEO
  • Attachment H:
    • Updated the image for PJMs Minimum Generation Calculation Worksheet and the Emergency Reducible Generation table
  • Attachment J:
    • Updated email information for reporting requirements for EOP-004 & OE-417 form submission requirements.

• Periodic Review. Made minor grammatical changes and added references to M-03B: Transmission Operating Procedures.

• Conforming changes were made to the following sections to incorporate provisions of FERC’s expanded MOPR order (EL16-49, EL18-178, ER18-1314) and Forward Net EAS order (EL19-58):

• Section 3.3.2 Demand in RPM
• Section 5.4.4 Sell Offer Caps
• Section 5.4.5 Minimum Offer Price Rule (MOPR)
• Section 8.8 Replacement Resources
• Attachment A Glossary of Terms

• Section 2.2: Updated the DASR requirement to the new 2021 values.