Manual Updates

• Cover to Cover Periodic Review
• Updated Manual Owner to Paul Dajewski, Manager Reliability Engineering
• Administrative Updates throughout the Manual
  • Corrected links
  • Consistency in style
  • Added links to references where applicable
  • Added clarification language
• Aligned TOP Language with PJM Compliance Bulletin 026 - Coordination with External Transmission Operators
• Section 2.4.2: Updated 'Enterprise Change Management Standard' to 'Standard Change Control Standard'
• Section 3.2:
  • Added a reference to PJM Manual 03A Appendix C for details on Transmission Facilities
  • Add clarification to default 'Baseline Voltage Limits' to 'PJM Baseline Voltage Limits'
• Section 3.7: Removed 'Security Analysis' from comparing results
• Attachment A:
  • Section D - Removed posting time requirement for next day study results
  • Section E - Added reliability assessment to include RTCA, Transient Stability Analysis (TSA)

• Cover to Cover Periodic Review

• Changes made throughout:

◦ Grammar, Punctuation, Typo, Syntax Consistency, Term, Reference Updates

◦ Updated Outdated Hyperlinks and addition of hyperlinks

◦ Addition of clarifying words and phrases

◦ Deletion of duplicate material

◦ Paragraph Spacing

◦ Remove outdated references to DASR

• Section 2

◦ Added descriptor for Interface Prices at top of section

◦ Addition that notice of coming online for self scheduled resources is 20 minutes in Real-time only. (2.3.3)

◦ New paragraph detailing dual fuel offer guidance. (2.3.3.2)

◦ Clarification that unit specific values applies to Generation Capacity Resources (2.3.4.3)

◦ Removal of "congestion charges" term. (2.3.4A)

◦ Removed redundant sentence. (2.3.8)

◦ Removed reference to retired NSR Opportunity Cost. (2.5.2)

◦ Section Retired, moved to Manual 28, (2.12)

◦ Clarification of call-on language (2.14)

◦ Replacement of "station" with "maximum units online" (2.18.1)

◦ Clarification of the shortage condition to trigger PAI and Data Miner 2 location of data. (2.19)

• Section 4

◦ Clarification that any resource must be able to provide 0.1MW of reserve capability. (4.2.1)

◦ Additional language detailing use and duration of this exception request. (4.2.2.1)

◦ Clarification regarding self-scheduling for energy. (4.2.3)

◦ Clarification that units for shutdown cost are in $, not $/MWh. (4.2.3)

◦ Clarification of when reserve information is posted to Markets Gateway. (4.4.3)

◦ Clarification of flexible reserve posting in Markets Gateway. (4.4.3)  

◦ Clarification that reserve data referenced is from pricing run. (4.4.3)

◦ Clarification that of action within 30 minutes "of the start of the event" (4.5.1)

◦ Rewrite of section to clarify assignments, shortfall charges, and penalties. (4.5.2)

• Section 5

◦ Additional language to define PJM InSchedule application. (5.2.2)

◦ Rewrite of section to reflect updated load forecasting process (5.2.3)

◦ Updated Energy Market Daily graphic to correct rebid period timing (5.2.4)

◦ Clarification of SPD outputs. (5.2.6)

◦ Updated graphic to reflect name change of PJM EES to PJM ExSchedule. (5.2.7)

• Section 10

◦ Update of Reserve definitions (10.2)

◦ New clarifying sentence on registering locations and removal of reference to DR Hub user guide. (10.2.2)

◦ Addition of data centers to examples of a Business Segment (10.2.2)

◦ Updated footnote references in table. (10.4.2)

• Cover to Cover Periodic Review, including:
  • Corrected capitalization, punctuation, and administrative errors throughout entire manual.
  • Updated cross-references to governing documents and Manual 34 sections throughout entire manual.
  • Section 2, Definitions:
    • Clarified that a Chair is also known as a facilitator;
    • Updated the definition of Charge to note that it can be self-assigned and that it is also known as an Issue Charge;

    • Updated the definition of Fails to mirror the definition of Passes;

    • Added Risk Management Committee to the definition of Standing Committee;

    • Added Senior Standing Committee to the definition of Subcommittee;

    • Struck "or Group" from Stakeholder Group or Group to add greater clarity with a single defined term; and

    • Relocated Truncated Voting from Manual 34, section 9.5 footnote to definitions

  • Section 4, Roles and Responsibilities:
    • Section 4.1 clarified that the roles and responsibilities apply to Members and other participants;
    • Section 4.2 added that we develop solution options along with proposals and clarified that they are developed as needed, added other participants to staying on track with the agenda, and replaced specific stakeholder group types with defined term Stakeholder Groups;
    • Section 4.3 added IMM acronym and corrected defined term references;
    • Section 4.4 added link to June 2005 Memorandum of Understanding between the OPSI Board and the PJM Board; and
    • Section 4.5 clarified Member votes and stakeholder polls, updated acronym references, replaced specific stakeholder group types with defined term Stakeholder Groups, and noted that media attribution applies to all participants.
  • Section 5, Structure of the PJM Stakeholder Process
    • Section 5.1 - Corrected from three to four Standing Committees and added Risk Management Committee; updated PJM Stakeholder Process Structure (Exhibit 1) to include Risk Management Committee and subcommittees reporting to Senior Standing Committee, added PJM to title, and removed s from Markets Implementation Committee; and updated Voting Progress Through the MRC and MC (previously Exhibits 2 and 3) to consolidate into a single graphic (Exhibit 2) and include footnotes in the exhibit for added details.
    • Section 5.2 - Corrected references to defined terms for Committee and Parent Committee.
  • Section 6: Identification of Issues, Their Placement and Charging and Chartering Stakeholder Groups to Address Issues
    • Section 6.1 - Clarified that Subcommittees may consider items within their Charters to align with Section 6.3 and corrected references to defined terms for Committee.
    • Section 6.2.1 and 6.2.2 - Corrected references to defined term for Committee.
    • Section 6.2.3 - Corrected reference of stakeholder approval to appropriately reflect Member approval, included (Senior) reference with Task Force, updated reference to template to more specifically note Issue Charge, corrected committee references to more appropriately reflect Stakeholder Group as Charters apply to Stakeholder Groups beyond Committees, and updated Three Key Issue Initiating Documents exhibit (Exhibit 3) to correct administrative typos, capitalize terms, include clarification under the Issue Charge: "May serve as Charter for new (Senior) Task Forces. Captures logistical details for the intended work including:", and added Charter bullets for Scope of the Stakeholder Group, Milestones and deadlines, Responsibilities and expected deliverables, and Charge or purpose, goals, and objectives of the Stakeholder Group.
    • Section 6.3 - Included (Senior) reference with Task Force, added reference to Issue Charge rather than Charge where applicable, updated CBIR acronym to reference stakeholder process generally, added Stakeholder Group for reference to an accepted issue, updated members to stakeholders for raising new issues, and added MRC to references where MC was listed.

    • Section 6.5 - Struck specific reference that a potential issue needed to be related to the operation of PJM, added MC to clarify Secretary reference, corrected references to defined term for Committee, and corrected cross references.

    • Section 6.7 - Corrected references to the defined term for Committee, clarified that the Issue Charge includes the stakeholder process type and the process to be utilized, added Senior Task Force as an issue assignment location, added reference to Issue Charge rather than Charge, added a note that an Issue Charge may also include an alternative stakeholder process to Consensus Based Issue Resolution (CBIR) and reference to Section 8.6, and replaced the New Issue Assignment Guidelines table (formerly Exhibit 5) into two new table graphics (Exhibit 4) with administrative clean-up and updated text to correspond to Manual 34 language.

    • Section 6.8 - Corrected references to the defined term for Committee.

    • Section 6.10 - Added Issue to Charge and spelled out sector-weighted.

    • Section 6.11 - Moved and renumbered reference for Invite technical specialists as required and corrected reference to the defined term for Parent Committee.

    • Section 6.12 - Corrected references to the defined term for Parent Committee, corrected Appendix cross-reference, updated graphic called Requirements for Charging and Chartering (Exhibit 5) including administrative clean-up, reformatted numbering, and updated text to correspond to Manual 34 language, and updated graphic called Interaction Between Parent and Assigned Stakeholder Group (Exhibit 6) including updated headings, capitalized terms, and clarification that the parent approves sunset of the Stakeholder Group.

  • Section 7: Processes for Consideration of Issues and Development of Resolution at the Task Force and Subcommittee Levels

    • Section 7.1 - Added references for Issue Charge and updated graphic for Consensus Based Issue Resolution (CBIR) Process Summarized (Exhibit 7) to correct title, capitalized terms, and clarify that final proposals are reviewed against interest criteria.

    • Section 7.2 - Updated language for consistency in the use of step versus process, added references for Issue Charge and Charter (if applicable), updated footnote to reference governing documents more generically, and updated Problem Investigation graphic (Exhibit 8) including headings, capitalized terms, and updated instances of members to stakeholders.

    • Section 7.3 - Removed incorrect reference to problem statement being refined, removed specific column references for the matrix, moved last bullet under Develop options for each design component to be the first bullet instead, added more clarity to the bullets included under Develop comprehensive packages, including details around population of status quo, and updated graphics for Proposal Matrix (Exhibit 10) to align with example in Options Matrix (Exhibit 9) and Proposal Development (Exhibit 11) to update headers, IMM acronym, and added Solution Proposal Generation text.

    • Section 7.4 - Clarified that draft manuals, Tariff or OA revisions may be reviewed rather than developed by the Task Force or Subcommittee, added stakeholders who participated to the final report rather than just Members, updated registration list to attendance list, clarified the use of proposal or proposals versus options which holds a different meaning in CBIR, updated tariff or OA to governing document generally, and added Senior Task Force along with Subcommittee as reporting to Senior Standing Committee and voting.

    • Section 7.5 - Added reference for Issue to Charge.

• Section 8: Consensus Based Issue Resolution at the Standing Committee Level (other than the Senior Standing Committees)

  • Clarified that Task Forces and Subcommittees develop recommendations rather than resolution of an issue.

  • Section 8.2 - Consolidated language and struck unnecessary wording, moved cross-reference to section 7, and added lower to Stakeholder Groups to clarify reporting to Standing Committee.

  • Section 8.4 - Added wording to clarify Voting Members and Affiliate Members vote and added simple majority support to clarify voting threshold.

  • Section 8.5 - Added reference to preference over status quo voting threshold, added secretary as a role who may also draft the final report, updated options to proposals to match CBIR terminology, and noted shall be identified in the report for clarity.

  • Section 8.6 - Added Quick Fix and Critical Issue Fast Path (CIFP) as alternative processes with others in the opening paragraph.

  • Section 8.6.2 - Struck problem statement as being approved, added Issue to Charge, and corrected expedited to expected.

  • Section 8.6.3 - Spelled out Liaison Committee acronym, corrected White Paper to briefing paper, added Standing to Senior Standing Committee Report, updated use of caucus to coalition for language consistency, updated Enhanced Liaison Committee Process graphic (Exhibit 12) to reflect capitalized terms, and updated Enhanced Liaison Committee Schedule graphic (Exhibit 13) for administrative changes in gray boxes.

  • Section 8.6.4 - Corrected CIFP acronyms, corrected voting references to remove PS/IC and reflect voting on an Issue Charge, spelled out instances of problem statement and Issue Charge for clarity, corrected whitepaper to briefing paper, corrected reference from step to Stage 4, and clarified sector-weighted support.

  • Section 8.6.6 - Updated stakeholders to Members for having the right to appeal.

• Section 9: Rules of Procedure for Senior PJM Committees (Members and Markets & Reliability Committees)

  • Consolidated language in the open paragraph for greater clarity.

  • Section 9.2 - Added reference to sector-weighted to clarify that a two-thirds vote is sector-weigthed.

  • Section 9.3 - Updated Members to stakeholders seeking recognition for the floor.

  • Section 9.4 - Updated CBIR to stakeholder process generally, added language to clarify that a Main Motion can be created through a motion at a Senior Standing Committee and that it would require a mover and a second in doing so (this is intended to clarify that Main Motions are not just created by a subordinate Stakeholder Group as noted in the opening sentence) and new Section 9.4.1 moved from Section 9.5.1 Other Motions (Members Committee Only) to align with the section on Main Motions rather than Alternative Motions.

  • Section 9.5 - Relocated footnote language as follows: first sentence moved to Section 2 - Definitions as it defines Truncated voting rules and moved second sentence to be new paragraph under Section 9.5. New paragraph moved from footnote was further updated to consistently reflect Alternative Motion rather than alternative solution. Alternative Motion references were updated to match the defined term.

  • Section 9.6 and 9.7 - Alternative Motion references were updated to match the defined term. The first footnote under 9.7 was also removed as Truncated voting rules is under Section 2 - Definitions.

  • Section 9.8 - Updated language to clarify that motions require greater than 2/3 sector-weighted vote in order to pass. This is in line with language in OA Section 8.4(c).

• Section 10: Process for Review and Effective Dates of Governing Document Revisions

  • Section 10.2 - Updated Task Force or other Subcommittee to defined term for Stakeholder Group.

  • Section 10.3 - Updated roster references to more appropriately reflect email list in this usage.

  • Section 10.4 - Updated graphic titled Sample Timeline for Review of Proposed Governing Documents Revisions (Exhibit 14) to reflect capitalized terms and correct 7 business days to calendar days.

• Section 11: Additional Rules of Procedure

  • Section 11.2 - 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 11.3 - Updated section to strike references to meeting notes. Secretaries produce meeting minutes rather than meeting notes.

  • Section 11.4 - Updated committee to Stakeholder Group as defined, updated conference call/WebEx to more general use of remote, struck second instance of duplicated sentences, and reworded sentence use of Publish.

  • Section 11.5 - Removed unneeded reference and clarified wording.

  • Section 11.7 - Updated graphic called Sample Proposal Approval Schedule (Exhibit 15) to reflect the correct Board meeting timing.

  • Section 11.9 - 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 11.10 - Added Senior Standing Committee as a Stakeholder Group which may create subordinate Stakeholder Groups, added Risk Management Committee with other Standing Committees, and added Senior Task Force if applicable to Task Force.

  • Section 11.11 - Struck sentence duplicated in section.

  • Section 11.12 - Clarified that stakeholders rather than just Members can seek to speak.

  • Section 11.17 - Updated CBIR specific references to the more general use of stakeholder process and updated calls to meetings.

• Section 12: Minority Rights

  • Section 12.2 - Added Subcommittee along with Task Force references for moving an issue to a Standing Committee, updated Members Committee threshold to note greater than two-thirds majority, updated sub option to portion to avoid confusion with option as used in CBIR, updated email address for support needed with the voting proxy form, and added reference to voting proxy section.

• Section 13: Members Annual Work Planning

  • Section 13.2 - 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 13.3 - Added Committee to Members Committee Annual Plan.

  • Section 13.5 - Added exhibit number to graphic called Issue Categorization (Exhibit 18), updated graphic headings and updated Stakeholder to Members for decision-making.

• Section 15: Information Transparency and Communication Between the Board and Members

  • Section 15.4 - Struck unneeded text and replaced with direct hyperlinks and updated the PJM.com page title for reference.

  • Section 15.5 - Replaced use of whitepaper with briefing paper.

• Appendix I: FERC Compliance Filing Protocol - Corrected references to sector-weighted and greater than 2/3 sector-weighted.

• Appendix II: PJM Stakeholder Process Quick Guides & Templates - Replaced individual links with single link to PJM.com location for quick guides and templates.

• Appendix III: Process Charts - Updated graphics to provide greater clarity, to reflect correct terminology, and to update cross references where applicable.

  • PJM Stakeholder Process Summarized (Exhibit 19) - updated title and capitalized terms, updated boxes to reflect the correct terminology and coloring, added RMC, and added two footnotes to provide clarity.

  • PJM Stakeholder Process Workflow (Exhibit 20) - updated title and capitalized terms, consolidated process flow for voting on Issue Charge and updated subsequent assignment paths, and extended arrows where appropriate.

  • Decision-Making Methodology (Exhibit 21) - updated headings and capitalized terms, added RMC, added (Polling) for Non-Voting section, updated participants for non-voting, added references for truncated voting, included section references, clarified the threshold for polling and simple majority, added preference over status quo language, and included an additional footnote for subcommittee voting.

  • Committee Voting Process Flow (Exhibit 22) - streamlined graphic, updated title, added RMC, added preference over status quo and truncated voting note, clarified thresholds, and included footnote details.

• Appendix IV: Facilitation Tool Box - 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, clarified polling language to remove confusion from voting related terminology where possible (replaced votes with submissions, voters with participants, and voting with responding for example). simplified language to consistently use option or options rather than using various terms (replaced choices, proposals, and candidates for example), corrected bullet indenting levels and spacing, and updated graphic for Facilitator Tools and Polling Strategies (Exhibit 24) to update title and headings, deleted row for keypad polling, and updated Web/Paper Surveys to be Surveys.

• Appendix V: Consensus Based Issue Resolution (CBIR) Process Illustrative Example - 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, replaced members with stakeholders throughout section, and clarified a few instances of the words packages and options.

• Appendix VI: Manual Review Process and Schedule - Added manual references and updated periodic review timing where applicable.

• Attachment C: Plant Specific NPIRs Revisions History: NPIR Revision Update

• Addition of a new section 11.18 Rejected FERC Filings to provide guidance in the instance where FERC rejects a filing made as the result of a completed stakeholder process

• Added section 3.10 for wildfire procedures

• Periodic Review
• Updated Division Name from "State and Member Services" to "Governmental and Member Services to reflect PJM organizational changes
• Updated References section to include "PJM Manual for Generator Operation Requirements (M-14D)"
• Section 1.3.2: Added the following sentence: "Periodically, PJM will request verification of personnel data. Training Liaisons and/or alternate Training Liaisons are required to respond to these requests."
• Section 3.2.2: Updated "Small Generation Plant Dispatcher" to "Small Generation Resource Dispatcher"
• Section 3.2.3.2: Removed sub-section "Company or Vendor Sponsored Equivalent Training

• Periodic Review and removal of the outdated reference to Manual 35

Periodic Review:

• Section 1.10 Planning Systems, Added reference to Manual 20A Resource Adequacy Analysis.
• Section 3.2.4.1

  • Requirements for Electronic Alternate Data Communication Method.

  • Replaced original text (#2 section of table) of early iterations of alternative non-EMS SCADA communications with latest description and guidance, including diagram.

  • Updates to all rating and monitored equipment language to be consistent for alignment Tariff and M03A.

• Section 4.5.3 Definitions

  • Update "rating" to "Transmission Facility Rating" to be consistent for alignment with Tariff and M03A.

  • Replaced "When the final Step is cancelled" to "When all Capacity Emergency Procedure Steps (1-10) are cancelled" for clarity and precision.

  • Replaced "Load shed" with "Load Shed Directive" for appropriate term use.

• Section 4.5.3, Update "facility rating" to "Transmission Facility Rating" for alignment with Tariff and M03A.
• Attachment A: Data Specification and Collection, Table B: EMS Services, changed definition of #8 for row B.6, which makes state of charge required for Open-Loop Hybrid Resources in addition to existing Energy Storage Resource Model Participant
• Attachment E: Reliability Guidelines to Mitigate the Unplanned Loss of EMS Real Time Assessment (RTA) Capabilities, added text based on recent enhancements to View-Only Mode to cover downstream output links.
• Attachment F: Overview and Requirements for Remote Operations of Market Operations Centers due to Exceptional Circumstances, updated PJM personnel contacts.

• Periodic Review
• Section 3.1: Updated OPA report and removed posting time requirement.
• Attachment A: Updated OATF scope.
• Attachment B: Removed OPA report posting time requirement.

• Periodic Review updated to address:
  • Spelling and grammar corrections in Sections 2, 3, 4, 5, 8
  • Section 1.2 – Removed outdated references to Expansion Costs, RTO Start-up Cost Recovery
  • Section 4.1 – Removed language stating PJM has no types of transmission customers that use transmission service to serve load located within PJM given it is too specific to be codified in a Manual.
  • Section 2.2.1.3 – Clarified Point to Point transactions used to export out of PJM are considered in the usage calculation for Schedule 9-3 Market Support Service Charges.
  • Sections 5.2.1 and 5.2.2 – Added descriptions for determination of Non-Zone Network load responsibility for Network Customers as defined in the OATT
  • Section 5.3 – Removed reference to Firm Point-to-point load service customers in NITS overview
  • Section 8 – Added reference to Manual 28, Section 22 for additional information on open loop hybrid and ESR Model Participants

• Periodic Review

• Reorganized the content in Section 6.5 Proposal Window Communications

• Removed an out-of-date reference to the Appendix of M14B in Section 8.2.1.4

• Removed an out-of-date reference to an Appendix in Section 8.2.5

• The reference to a video in Attachment A was changed to a generic "Instructions" to include the posted Word document (with a step by step walk through)

• Updated the wording in Attachment A to reflect how PJM windows are currently closed (a published/provided time that may not be the same clock-time for every window)

 Periodic Review:

◦ Throughout - Standardize No Load, noload, No – Load, etc. to no-load

◦ 2.6.11 - Remove table of original VOM default values to avoid confusion

◦ Update numbering of sections 3.3.1, 3.3.2, 4.3.1, 6.3.1, 6.3.2, 7.3.1 2.4, 4.4, 5.4, 6.4 –

◦ Remove the extra "+" from the of the Startup Cost formula and change TRFC to TFRC

◦ 6.4 - Remove blank Note: box

◦ 7.2 - Remove ()(), fix errant "(", fix summation notation

◦ 11.2.1 - Correct the fuel cost formula by changing the multiplication to division

◦ 13.3 - Remove "Name to be determined" from Exhibit 26

◦ Att. B - Update graphs to have appropriate Y-axis labels 

• Updated Section 2.3.10 Generator Deliverability Analysis to clarify that the P2-1 contingency, opening of a line section w/o a fault, is not included as part of the analysis.
• Updated Attachment C Section C3.1.3 and Attachment H Section H1.5 to reflect that load levels in the light load case can be modelled in excess of 50% of each area's noncoincident summer peak forecast where applicable.
• Updated Attachment F: Determination of System Operating Limits used for planning the Bulk Electric System to align with the retirement of NERC Standard FAC-010-3: System Operating Limits Methodology for the Planning Horizon and with the latest revisions to FAC-014-3: Establish and Communicate System Operating Limits. Updated the definition of System Operating Limit (SOL) to align with the revised definition in the NERC glossary of Terms.
• Updated Attachment G.10 NERC Standard PRC-023 – Transmission Relay Loadability to reflect the latest version: PRC-023-6.
• Added Attachment G.13 NERC Standard PRC-026 – Relay Performance During Stable Power Swings.
• Added Attachment G.14 NERC Standard TPL-007 – Transmission System Planned Performance for Geomagnetic Disturbance Events.

• Updates to Attachment A: Clarification on use of estimated load drops for load management in the Load Forecast.

• Cover to cover Periodic Review
• References
  • Added reference to PJM Manual for Rules and Procedures for Determination of Generating Capability (M-21B)
• Section 4.3.4 Data Exchange and Management Requirements
  • Updated communication protocol for registering Phasor Measurement Units (PMU)
• Section 6.3.4 Other Requirements
  • Clarified requirement for all Generating Facilities to provide reactive capability curves to PJM prior to commercial operation
  • Clarified requirement for applicable Generating Facilities to complete reactive testing no later than 90 days after commercial operations
• Section 7.3.6 Generation Owner Periodic Tasks and Data Submittals
  • Updated the guideline: Generation Owner Periodic Tasks and Data Submittals
• Section 8 Wind Farm Requirements
  • Removed specific references to wind speed and wind direction to generalize to other meteorological parameters
• Section 8.2.1 Data Requirements for Wind Forecast Set Up
  • Updated wind forecast data requirements to apply to wind farms that are rebuilt/repowered
• Section 8.3.3 Real-time Operating Reserve Settlement
  • Updated language to reflect the wind backcast usage in settlements as well as the applicability of hybrid resources
• Section 9.1.1 Generator Deactivation Notice
  • Updated information that may be posted publicly
• Section 10.1 Black Start Selection Process
  • Added note to enhance awareness that Black Start information is CEII and Member Confidential
• Section 11.1 Generator Data Confidentiality Procedures
  • Added language specifically naming cold weather operating limits in generator parameter data sharing procedures
• Section 12.3.3 Real-time Operating Reserve Settlement
  • Added new subsection with language to reflect the solar backcast usage in settlements as well as the applicability to hybrid resources
• Section 13.1 Marketing and Classification of Mixed Technology Facilities
  • Add reference to Manual 21B, Section 2.6
• Attachment D: PJM Generating Unit Reactive Capability Curve Specification and Reporting Procedures
  • Clarified requirements and process for submitting and updating reactive capability
  • Removed reference to AVR status since it is already covered in Section 7: Generator Operations
  • Clarified requirements for wind farms that are rebuilt/repowered to submit reactive capability curves within 6 months of rebuild/repower
• Attachment E, PJM Generator and Synchronous Condenser Reactive Capability Testing, Section E.2
  • Added reference to PJM Manual, 21B - Rules and Procedures for Determination of Generating Capability
  • Clarified requirements for wind farms that are rebuilt/repowered to submit a reactive test within 6 months of commercial operation, even if a reactive test was completed within the last 66 months
• Attachment "N" Cold Weather Preparation Guidelines and Checklist
  • Reformatted and reordered content into additional sections and sub-sections to increase readability
  • Replaced references to "generator" with either generation resource or Generating Facility where applicable
  • Added the following language taken from NERC Generating Unit Winter Weather Readiness Guideline:
    • Incorporated bulleted list of critical components, grouped by conventional generation and inverter based generation
    • Added section covering Management Roles and Expectations
    • Added section focused on Evaluation of Potential Problem Areas with Critical Components
  • References section updated to reflect latest industry best practices and lessons learned
  • Added footnote with link to NOAA map of locational first frost date
• Appendix A: Behind the Meter Generation Business Rules
  • Revised to reflect current business practices
• Corrected typos and references throughout

Periodic Review

◦ Updated hyperlinks throughout the manual - Changed "HTTP" to "HTTPS"

◦ Deleted Exhibit 10 - phased out process

◦ Updated manual language for further clarification

▪ Section 1.3, 1.4, 3.3, 4.5, Appendix A, Appendix B

◦ Capitalized non-titled Section summary language - "Transmission Facility, Transmission Facility Ratings" etc

▪ Section 1.2, 1.3, 1.6, 2.2, 2.4, 2.4.1, 2.4.2, 2.4.3, 3.3, 4.2, 4.4, 4.5, Appendix A

• Periodic Review
• Throughout - Changes in alignment with existing practices and language regarding Facility Ratings.
• Introduction - Replaced reference to individual PJM Governing Documents with a link to PJM Governing Documents page.
• Section 1.1 - Updated note regarding Non-PJM TOPs
• Section 1.8 - Moved Automatic Remedial Action Scheme (RAS) Operating Criteria from Manual 03B, Section 1.1.7
• Section 1.9 - Moved Recognition of Automatic Sectionalizing Schemes from Manual 03B, Section 1.1.6
• Section 3.11 - Updated generator voltage schedule availability note.
• Section 3.12 - Updated eDART web links.
• Section 4.2.2 - Updated Hotline Work Requests with a note regarding generator impacts.
• Section 4.2.9 - Clarified language around revisions to on-time transmission outages.

• Periodic cover-to-cover review
• Section 1.1: Pre-scheduling Overview
  • Corrected the closing time of the day ahead market in Exhibit 1 Pre-scheduling, Scheduling, and Dispatching Timeline
• Section 2.1: Generation Outage Reporting Overview
  • Added clarifying language around eDART Reportable MW for inverter based resources
• Section 2.2.2.5: Planned Outage Rules
  • Added clarifying language to ensure consistency with NERC GADS Data Reporting Instructions

• Conforming changes to support Hybrids Phase II and Solar Resources Lost Opportunity Cost calculations (ER23-2484)
     ◦ Section 5.2.6.4: Update section to include Hybrid, Solar, and Energy Storage
       Resource Model Participants

• Section 6.1, 6.2.2, and 6.3.3 revisions to support deploying less than 100% of reserves during a Synchronized Reserve event (Reserve Certainty Senior Task Force

• Updated Section 2.4: Unlimited Resources Classes to reflect the new approved RAA definitions in Docket: ER24-1988-000 for "Gas Combined Cycle Dual Fuel Class" and "Gas Combustion Turbine Dual Fuel Class"
• Revised Section 2.4: Unlimited Resources Classes to align the dual fuel attestation process with the updated requirements as specified in the RAA definitions in Docket: ER24-1988-000

• RCSTF Short Term Reserve Deployment Changes (Section 4.4.8 Deleted)

• 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

• RCSTF Short Term Reserve Deployment Updates (4.5.2)
• Day-ahead Hourly Differentiated Notification Time Updates (2.3.7, 9.1)

• 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

• Updated section 2.2 Reserve Requirements to include Operations Day Ahead Scheduling Reserve (DASR) 30-minute reserve requirement for the purpose of transparency

• 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.