- Conforming revision for FERC Order 841: Electric Storage participation (ER19-462) in Section 7.4 to address Energy Storage Resources not being allocated a Peak Load Contribution.
- Section 3.2:
- Updated Small Generation Plant Dispatchers to Small Generation Resource Dispatchers
- Added lower MW threshold for training requirements to accommodate ESR as well as Small Gen Resources
- Updated Energy Storage Device to Energy Storage Resource
- Updated language for training requirements for ESR operators
Updates for compliance with FERC Order 841, Electric Storage Participation in Markets Operated by RTOs and ISOs, Docket No. RM 16-23-000
- Section 13.1 – Note that Direct Charging Energy is not Station Power and end-use charging for an electric vehicle is end-use load.
- Added Section 22 – Energy Storage Resource Charging Energy
- Section 22.1 provides an overview of Energy Storage Resource Charging Energy
- Section 22.2 describes the various charges related to Direct Charging Energy
- Section 22.3 describes charges for Load Serving Charging Energy
- Section 22.4 provides various methods to differentiate Direct Charging Energy from Load Serving Charging Energy for an Energy Storage Resource
- Section 22.5 describes monthly reconciliation for Direct Charging Energy and Load Serving Charging Energy
Updates for compliance with FERC Order 841, Electric Storage Participation in Markets Operated by RTOs and ISOs, Docket No. RM 16-23-000
- Added new Section 8: Energy Storage Resource Charging Energy
- Section 8.1: Describe different categories of Energy Storage Resource charging energy
- Section 8.2: List billing items that apply to Non-Dispatched Charging Energy
- Section 8.3: Description of billing treatment for Load Serving Charging Energy
- Section 8.4: Treatment of Network Service Peak Load and Obligation Peak Load/Peak Load Contribution for Direct Charging Energy
- FERC Order 841 Energy Storage Resources changes:
- Section 11 – Batteries and Flywheels
- Equation clarified in Section 7.3
- Changes were approved by PJM Board on December 4, 2019
- Periodic Review
- Throughout
- Replaced references to Client Manager with Member Relations where applicable
- Corrected typos and capitalized terms where appropriate
- About this Manual
- Added subsection covering “Definitions and Applicability”
- Section 1.2 - Generator Commercial Naming Convention
- Replaced Performance Compliance with Operations Analysis and Compliance
- Section 3.2.4 - Control Center Staffing Requirements
- Remove reference to Section 6 as it relates to training and certification requirements
- Section 4.1.7 – SCADA—Supervisory Control and Data Acquisition
- Corrected typo in heading in Exhibit 6
- Updated Exhibit 6 to include State of Charge for Energy Storage Resources
- Section 4.2.3 – Metering for Individual Generators
- Added metering requirement specific to Energy Storage Resources
- Section 6.2.2 – PJM Transmission Owner (TO) Operator and Generation Dispatcher Certification
- Section 7.1.5 – Generator Operations Under Emergency Conditions
- Corrected typo in Exhibit 9
- Section 7.3 – Critical Information and Reporting Requirements
- Added Energy Storage Resource outage reporting requirements
- Section 7.3.5 – Fuel and Emissions Reporting
- Replaced references to Supplementary Status Report (SSR) with references to Resource Limitations page in Markets Gateway.
- Section 10.2.3 – Implications for Terminating Black Start Units
- Updated to cross reference correct section – Section 9
- Attachment D: PJM Generating Unit Reactive Capability Curve Specification and Reporting Procedures
- Updated to include Energy Storage Resources
- Corrected references to Exhibit 15
- Updated stand-alone document containing D-curve examples
- Attachment E: PJM Generator, Energy Storage and Synchronous Condenser Reactive Capability Testing
- Updated to include Energy Storage Resources
- Updates for FERC Order 814 Electric Storage Resource Participation Model
- Added Section 2.3.4B Energy Storage Resource (ESR) Participation Model and updated Sections 2.3, 3.2, 4.2, 4b.2, 9.1, 11.2 where appropriate
- Update for FERC Order 814 Electric Storage Resource Participation Model
- Attachment A: A.1.2 Minimum Critical Black Start Requirements
- Updated exception to critical cranking power to include non-hydro energy storage resources
- Attachment C: Plant Specific NPIRs Revision History: NPIR revision update
- Section 5: Deleted Gas-Pipeline Contingency Analysis Procedure
- Section 3.9 Assessing Gas Infrastructure Contingency Impacts on the Electric System - Deleted the step for PJM to direct pre-contingency fuel switching from the ‘note’ and replaced with a request for the generation owner to notify PJM if any fuel risk mitigation activities will voluntarily be taken.
- About this Manual Section – corrected review cycle from one to three years to match approved change and chart.
- Section 2 – Pluralized “Definitions”
- Section 6.2.2 – Added requirement to review work plan prior to assigning work
- Section 6.7
- Added new matrix “New Issue Assignment Guidelines”
- Section 8.6
- Added new section 8.6.1 – “Quick Fix”
- Added new section 8.6.4 – Critical Issue Fast Path (CIFP)
- Renumbered to accommodate two new sections
- 8.6.1 now 8.6.2
- 8.6.2 now 8.6.3
- 8.6.3 now 8.6.5
- 8.6.4 now 8.6.6
- Section 10.2 – Added new “page turn” review of business rules
- Section 10.4 – Added new three day posting and notification process for review of draft tariff language for filing
- Section 11.4
- Added language regarding PJM’s continual review of schedules and prioritization
- Added detailed scheduling standards and best practices
- Added language about ending meetings by the posted end time
- Added language empowering the MC Secretary with meeting prioritization decisions
- Added ability for PJM to hold one “high priority/ time critical topic” meeting day per month.
- Section 13.1 – Added new requirement to review the MC Work Plan at least quarterly, and prior to the approval of a new Issue Charge
- Capitalization of lists in sections: 1; 3; 4, 4.1, 4.2, 4.5; 6.1, 6.2, 6.7, 6.8, 6.12; 7.1, 7.2, 7.3, 7.4, 7.5; 8.2, 8.3, 8.4, 8.5; 10.3; 11.2; 13, 13.3, 13.5; 14.3, 14.4; 15.1, 15.4;
- Punctuation edits in sections: 1; 6.2; 7.3, 7.4; 14.4; 15.4, 15.5
- Exhibit Update:
- Communication Between Parent Committee and Assigned Group
- Three Key Issue Initiating Documents
- Decision Making Methodology
- Decision Making Methodology
- Grammatical edits
- Appendix A
- Clarified the reporting, netting, and operational requirements for Non-Retail Behind the Meter Generation
- Section 2.3.2 – Real-time Emergency Procedures (Warnings and Actions) - Defined triggers to load Non-Retail Behind the Meter Generators
- Section 5.2 – Transmission Security Emergency Procedures – Defined triggers to load Non-Retail Behind the Meter Generators
- Section 5.2 – Transmission Security Emergency Procedures, Step 2 Emergency Load Reduction Action – Added missing PJM Member Actions
- Section 7.01 –TOP EOO-011 Operating Plan Submission Process – Corrected email address to EOP-001forms@pjm.com
Administrative Change (09/26/2019):
- Removed references to SSR in Attachments B and J
- Document ownership updated from Lisa Morelli to Philip D’Antonio
- Section 3.2.9: Inclusion of process for addressing regulation historic performance scores for an operating day that fail to bridge over into the market clearing system
- Section 4.2.2: Clarifying language on reserve requirement determination for market clearing purposes
- Changes to section 2.6.8 Market Efficiency project reevaluation process
- Updated manual ownership from David Egan to Jason Connell
- Removed language in Manual 14A section 2.3.1: New Service Request deficiency reviews
- Section 5: Deleted Gas-Pipeline Contingency Analysis Procedure
- Section 3.9 Assessing Gas Infrastructure Contingency Impacts on the Electric System - Deleted the step for PJM to direct pre-contingency fuel switching from the ‘note’ and replaced with a request for the generation owner to notify PJM if any fuel risk mitigation activities will voluntarily be taken.
- About this Manual Section – corrected review cycle from one to three years to match approved change and chart.
- Section 2 – Pluralized “Definitions”
- Section 6.2.2 – Added requirement to review work plan prior to assigning work
- Section 6.7
- Added new matrix “New Issue Assignment Guidelines”
- Section 8.6
- Added new section 8.6.1 – “Quick Fix”
- Added new section 8.6.4 – Critical Issue Fast Path (CIFP)
- Renumbered to accommodate two new sections
- 8.6.1 now 8.6.2
- 8.6.2 now 8.6.3
- 8.6.3 now 8.6.5
- 8.6.4 now 8.6.6
- Section 10.2 – Added new “page turn” review of business rules
- Section 10.4 – Added new three day posting and notification process for review of draft tariff language for filing
- Section 11.4
- Added language regarding PJM’s continual review of schedules and prioritization
- Added detailed scheduling standards and best practices
- Added language about ending meetings by the posted end time
- Added language empowering the MC Secretary with meeting prioritization decisions
- Added ability for PJM to hold one “high priority/ time critical topic” meeting day per month.
- Section 13.1 – Added new requirement to review the MC Work Plan at least quarterly, and prior to the approval of a new Issue Charge
- Capitalization of lists in sections: 1; 3; 4, 4.1, 4.2, 4.5; 6.1, 6.2, 6.7, 6.8, 6.12; 7.1, 7.2, 7.3, 7.4, 7.5; 8.2, 8.3, 8.4, 8.5; 10.3; 11.2; 13, 13.3, 13.5; 14.3, 14.4; 15.1, 15.4;
- Punctuation edits in sections: 1; 6.2; 7.3, 7.4; 14.4; 15.4, 15.5
- Exhibit Update:
- Communication Between Parent Committee and Assigned Group
- Three Key Issue Initiating Documents
- Decision Making Methodology
- Decision Making Methodology
- Grammatical edits
Periodic Review updated to address:
- Corrections/Clarifications of Existing Provisions
- Clarify Delivery Year applicability of Limited Resource Constraint, Sub-Annual Resource Constraint, Base Capacity Demand Resource Constraint, and Base Capacity Resource Constraint for FRR Alternative in Sections 2.4.3A, 2.4.3B and 5.3
- Clarify treatment of Qualifying Transmission Upgrade once in service in Section 4.5
- Clarify Behind the Meter Generation provisions in Sections 4.3.3 and 7.3.1
- Correct Non-Performance Charge Rate in Sections 8.4A, 9.1.11 and 11.8.8
- Clarify replacement capacity rules when remaining import capability into an LDA in Section 8.9
- Add Aggregate Resource to list of capacity resources in Sections 4.1, 5.7.1 and Glossary
- Clarify charges applicable to Owner in Authorization to Self-Schedule Capacity in Attachment B
- Deletion of Outdated Provisions
- Capacity Performance Transition IAs in Sections 1.5, 4.6.2, 4.6.6, 5.1, 5.8 and 5.9
- Minimum Annual and Extended Summer Requirements in Sections 2.4.3, 2.4.4, 2.4.5, 3.5, 5.3, 5.7.2, 5.8.5, 5.9, 11.1.3, 11.3 and 11.8
- EE adjustments for 2016/17 – 2018/2019 Delivery Years in Section 2.4.5
- Short-term Resource Procurement Target in Sections 3.3, 3.5, 5.1, 5.4.3, 5.8, 6.1, 7.2.2, 11.1.3 and Glossary
- Demand Response Legacy Direct Load Control Transition Provision in Sections 3.5 and 5.9
- Limited Resource Constraint and Sub-Annual Resource Constraint (when it relates to RPM Auctions) in Sections 3.5, 5.7.2, 5.8.5, and 5.9
- Product types (Limited DR, Extended Summer, and Annual) for RPM Auctions in Sections 4.1, 4.5, 4.6.2, 4.6.7, 4.6.8, 4.8.3, 5.5, 8.2.2, and 8.9
- Out-dated qualification requirements for generation resource prior to 2019/2020 Delivery Year in Section 4.2.3
- Legacy Direct Load Control Programs in Section 4.3.1
- Credit-Limited Offers in Section 4.8.4
- Coupled Sell Offers in Section 5.4
- Peak Season Maintenance Compliance in Sections 8.1, 8.6, 9.1.6, 9.1.8 and 11.8.5
- Load Management Event Compliance in Sections 8.1, 8.7, 9.1.9 and 11.8.6
- Non-Performance Assessment provisions for 2016/2017 – 2017/2018 Delivery Years in Sections 8.4A, 9.1.4 and 9.1.11
- Conforming Revisions for FERC Orders
- OVEC Integration (ER18-459, ER18-460) in Section 2.3.1
- Periodic Review of Variable Requirement Curve Shape and Key Parameters (Quadrennial Review) (ER19-105-001,002) in Sections 3.3 and 3.4
- Energy Efficiency Resources Compliance with Authorized Relevant Electric Retail Regulatory Authority (RERRA) Rules to Opt-Out or Restrict Sales of EE Resources (ER18-870) in Sections 3.5, 4.4 and 5.9
- Minimum Offer Price Rule Remand (ER13-535-005, 006) in Sections 5.2 and 5.4.5
- FERC Order 841: Electric Storage Participation (ER19-462) in Section 5.4.1
- Periodic Review – no changes were identified as part of this review
- Section 2.1 - Generation Outage Reporting Overview
- Added clarification for outage ticket end date as it relates to deactivation date
- Section 2.5 - Outage Reporting for Facilities Providing PJM Black Start Service
- Clarified requirement for black start test ticket submission
Revisions as a result of Periodic Review:
- Clarified manual focuses on measurement and verification of both Nominated EE Value and Capacity Performance value of EE Resources (Introduction section)
- Clarified EE Resource may be modeled at sub-zonal LDA level (Sections 1.3 & 3.1.2)
- Clarified EE Resource may be used as a replacement resource for another EE Resource in accordance with Section 8.8 of Manual 18. (Section 5.1.3)
- Added conforming revision for FERC Order ER18-870 to ensure EE Resources are subject to rules in Manual 18 that facilitate the implementation of any restrictions that may be imposed on EE Resources by an Authorized RERRA to opt-out or restrict sales of EE Resources (Section 1.1)
- Added conforming revisions for FERC Order ER17-367 to implement Seasonal Capacity Performance Resources (Summer-Period EE Resources) (Section 1.1)
- Deleted outdated Delivery Year information (Section 1.1, 1.2, & 10.1)
- Replaced RAA Schedule 6 (section M) reference with RAA Schedule 6 (section L) (Section 1.1)
- Replaced eRPM system with Capacity Exchange system (Sections 1.3, 5.1.3, & 5.1.4)
- Added conforming changes to section 8.6 to account for FTR Forfeiture Rule calculation change from month to period
- Conform changes for context and alignment of terms (multiple locations)
- Update links for PJM.com
- Section 1.1, 1.3.4:
- Provide additional clarity as to the process of integrating Supplemental Projects in the RTEP
- Section 1.3:
- Define the applicability of modeling requirements associated with the RTEP
- Section 1.4:
- Update outline numbering
- Conform discussions for Customer Funded Upgrades to the definitions and processes from the Tariff
- Section 1.4.2:
- Clarify how overlapping needs are addressed in the RTEP
- Section 1.4.3:
- Provide information as to the process used for the removal of projects from the RTEP under various conditions
- Section 2.7: Added section to address the need for coordination between the Transmission Owner and the Nuclear Plant Generator Operator regarding Remedial Action Schemes and Under Frequency Load Shedding/Under Voltage Load Shedding schemes and their identification in plant interface agreements.
- Section 3.6: Added section to address the process by which the NPIRs will be discontinued after a nuclear plant deactivates and retires.
- Section 3.7: Added section to address the coordination between Reliability Coordinators when a non-PJM member is identified by an Nuclear Plant Generator Operator as a Transmission Entity.
- Attachment B: Attachment title updated and note section updated
- Attachment C: NPIR revision update
- Periodic Review to address:
- Three-year Nuclear Generators Owners Users Group (NGOUG) review per Section 3.5
- Language clarification in Section 1.1
Periodic Review updated to address:
- Section 3.4 – Add process to handle condition when state-estimator loss MWh is unavailable
- Section 5.2.5 – Remove entire section as Quick Start Reserve is obsolete
- Section 5.2.8 – Update to describe Reactive Operating Reserve as being credited hourly
- Section 19.3 - Provide consistency on terms used for Day Ahead Scheduling Reserve settlement
- Correct various typos
- Added specific wording, in section 1.1.6, for combined cycle components and other grouped units that report in aggregate pertaining to the CIR evaluation method in section 1.1.5
- Added specific wording for Combined Cycle units with once through cooling in Section 1.3
- Separated run of river hydro units (with pooling/storage/dispatch capability) from the Capacity Storage Resources category to conform to the changes in the OATT
Cover to Cover Periodic Review
- Replaced section 6.7 with reference to PJM Tariff, Attachment Q and Credit Overview document
- Changes to 6.8 to reflect replacement of FTR liquidation process with settlement process
- Miscellaneous updates to sections 3.2 and 5.3 to align with OASIS refresh
Manual 14G Updates and Corrections to Links/References
- Section 1.7 Demand Response: Updated Content
- Section 2.4 Site Control:
- Term for Site Control must be 3 years (2 years for 20 MW or less) commencing on the first day of the New Services Queue in which the Interconnection Customer submits its Generation Interconnection Request.
- Extensions to site control must have been already exercised by the Developer at the time site control evidence is provided to PJM. (If initial term is less than the required 2 or 3 year term)
- Attachment B-2: System Impact Study Data Form: Stability Models
- Modified Section on Stability Models to be consistent with PJM requirements to meet the following NERC Standards:
- MOD 26 – Plant Modeling: Volt/VAR Control
- MOD 27 – Plant Modeling: Power/Frequency Control
- MOD 32 – Data for Power System Modeling and Analysis
- References link to NERC’s Acceptable Models List
- Corrections to References/Links:
- Sections Section 2, Attachments A, A-1, B, B-2 and C6: Corrected Queue Point Link
- Section 4.5: Removed reference to PJM Manual
- Section 5.3: Removed incorrect reference banner for System Impact Studies
- Section 5.5: Removed incorrect Attachment reference.
Administrative Change (6/27/2019):
- Updated effective date of revision 26 from 6/20/2019 to 6/27/2019 to align posting and effective dates.
Revision 26 (06/27/2019):
- Cover to cover annual review. Changed terminologies and corrected grammar throughout.
- Throughout: Updated NERC standard references from EOP-005-2 and EOP-006-2 to EOP-005-3 and EOP-006-3.
- References Section: Removed TO/EOP-005 mapping link and replaced with TO/TOP Matrix site.
- 3.1.7 and 7.2: Added section description and purpose statements.
- Attachment F: Changed title from Transmission Owner and Black Start Supporting Documentation References to Transmission Owner Special Procedures. Removed language in reference to training record, black start database, and Transmission Owner plan reference to EOP-005-2.
- Attachment G: Added coordination review with neighbors in case of conflicts with a particular restoration plan. Modified distribution list for M-36. Added DOE PORTS to Table 1.
- Attachment H: Updated attachment with new UFLS data.
- Attachment I: Deleted attachment which had specified M-36 Sections corresponding to EOP-005 and EOP-006 Requirements.
Administrative Change (06/10/2019):
*Revision 20 was published with current change information in the Revision History that should have appeared in the Current Revision section.*
Moved misplaced Current Revision information, which mistakenly appeared in Revision History during publishing on January 24 2019, back into the Current Revision section for Revision 20:
- [Removed testing requirements from Sections 4.4, 4.5, 4.6, and 4.7 and consolidated all requirements in a separate Section 4.2.6.
- Changed OJT Instructor to OJT Trainer
- Added footnote 1 defining Master Dispatcher
- Added footnote 2 defining OTS versus DTS
- Added clarifying language throughout Section 4
- Updated Exhibit 4 “Threat Error Management” ]
Revision 20 (01/24/2019):
- Cover to Cover Periodic Review
- Updated co-ownership to Richard Brown
- Section 3: Removed references to legacy training requirements
- Removed testing requirements from Sections 4.4, 4.5, 4.6, and 4.7 and consolidated all requirements in a separate Section 4.2.6.
- Changed OJT Instructor to OJT Trainer
- Added footnote 1 defining Master Dispatcher
- Added footnote 2 defining OTS versus DTS
- Added clarifying language throughout Section 4
- Updated Exhibit 4 “Threat Error Management”
Language to address a credible gas contingency(s) in the calculation for increasing the Day-Ahead Scheduling Reserve Requirement:
- Section 11.2.1 Day-Ahead Scheduling Reserve Market Reserve Requirement
Language added to clarify the reserve market eligibility of resources impacted by a credible gas pipeline contingency(s):
- Section 4.2.1 Synchronized Reserve Market Eligibility
- Section 4b.2.1 Non-Synchronized Reserve Resource Eligibility
- Section 11.2.2 Day-Ahead Scheduling Reserve Market Eligibility
- Cover to cover periodic review. Updated links and terminology throughout.
- Section 3.3: Added NextEra to Voltage Limit table.
- Section 3.9: Added language for TSA real-time monitoring and control for dynamic stability.
- Section 4.2.2: Added on-time criteria for hotline work that may have system impact and a clarification note concerning RTU outages not requiring an eDART ticket.
- Section 5: Updated RTO NPIR Voltage limits for North Anna, Surry, and Peach Bottom. Clarified Susquehanna voltage.
- Section 5: Removed the ComEd Dresden Bus Operation procedure.
- Section 5: Updated the ComEd Powerton Stability procedure.
- Section 5: Updated the ComEd Normally Open Bus Tie procedure.
- Section 5: Removed the ComEd/MISO Pleasant Prairie-Zion Conservative Operation procedure.
- Section 5: Removed the FE West Mansfield Unit 2 Reclosing Restriction.
- Section 5: Updated the FE EAST Hunterstown/Conemaugh stability procedure for the interconnection of the Fairview CC.
- Section 5: Updated the FE East Birdsboro Plant Stability Restriction.
- Section 5: Updated the AEP Rockport operating guide limits.
- Section 5: Removed the AEP Conesville 345 kV plant procedure.
- Section 5: Added new FE East Asylum/Liberty Stability procedure.
- Section 5: Updated the PSEG Artificial Island Stability procedure.
- Section 5: Removed the Dominion North Hampton RAS Procedure.
- Section 5: Updated the Peach Bottom Transformer outage procedure for Muddy Run regulation.
- Section 5: Updated NY/NJ PAR Coordination and NYISO Ramapo Par Operating Instruction for Hudson reconfiguration to Marion.
- Section 5: Updated RTO NY/NJ PAR Coordination General Principles tap change language.
- Attachment A: Updated the Lisle RAS description.
- Gas Contingency Impacts on Reserves
- Section 2.2 Reserve Requirements – Language to address a credible gas contingency(s) in the calculation for increasing the Day-Ahead Scheduling Reserve Requirement
- Section 3.9 Assessing Gas Infrastructure Contingency Impacts on the Electric System – Language added to clarify the reserve market eligibility of resources impacted by a credible gas pipeline contingency(s)
- Cover to cover Periodic Review
- Section 2.2 – Removed reference to SERC BAL-002 reserve policy (retired). Updated RF BAL-002 document link and naming from ‘Requirement’ to ‘Regional Criteria’.
- Section 2.4.7 – Updated M-3 section reference section 3.7
- Section 4.1, 4.3, 4.4, 4.5, 5.1 – Removed of mention of Supplementary Status Report (SSR) where not needed
- Section 4.4.3 – updated link and version number to the new NERC Reliability Guideline: Generating Unit Operations During Complete Loss of Communications – Version 3
- Section 7.1: Revised email address from dispsup@pjm.com to EOP011forms@pjm.com
- Attachments E and F updated with 2019 summer peak data
- Cover to Cover Periodic Review.
- Section 1: Renamed eRPM to Capacity Exchange.
- Section 3.2.4: Corrected references to subsections of Section 3.2.4 within the text.
- Section 3.3.2: Section reviewed for clarity. New table added to define the data quality requirements.
- Section 3.8: Renamed PJM Client Managers to PJM Member Relations.
- Attachment A: Added State of Charge as a required data point to be sent to PJM via SCADA/ICCP for Energy Storage Resources.
- Attachment B: References to EOP-005 and EOP-008 NERC Standards are updated with the new version of these standards.
- Attachment E: New Attachment describing reliability guidelines to mitigate the unplanned loss of EMS Real Time Assessment capabilities. These guidelines were developed by the members of System Operating Subcommittee – Transmission (SOS-T).
- Section 2.3.1 and Section 2.7: Added reference to the new Attachment E for the reliability guidelines to mitigate the unplanned loss of EMS Real Time Assessment capabilities.
- Revised language in Section 1 reflecting the applicable effective date of Manual revisions
- Revised reference in Appendix D to M-14G Attachment C and D, which were previously incorporated in M-14A
- Added technical reference in Appendix D reflecting industry standard updates, including IEEE 1547-2018
- Cover to Cover Periodic Review
- Revise Revision History to update with the correct Revision 7 information
- Removed welcome language at the start of each section for brevity
- Section 2
- Section 3
- Section 4
- Section 5
- Section 6
- Section 7
- Section 8
- Section 9
- Section 10
- Section 11
- Section 12
- Section 13
- Section 14
- Section 15
- Section 1: Grammatical edits
- Section 2:
- removed bullet points from text
- corrected bullet formatting
- clarified definition of Standing Committees
- added definition of Consensus Based Issue Resolution
- added new definition of Consensus Based Issue Resolution Process
- Section 4.5: Replaced language on identification of speakers at PJM meetings
- Section 5.1:
- Added content from deleted Section 5.2.
- Added content from retired Manual 33 regarding five sectors and one primary and three alternate representatives.
- Added clarifying language on which committees apply
- Added clarifying language on which committees require a first read
- Deleted sentence regarding required number of MC-MRC meetings per year.
- Section 5.2:
- Deleted section: moved content to Section 5.1
- corrected “table and graphic” to “exhibits” for correct terminology
- Section 5.4.1:
- Deleted reference to “senior representatives” as irrelevant
- Section 5.5:
- User Groups content moved into new section 8.6.3
- Added new section describing “Special Sessions” designation
- Added new section describing “Special Meetings” designation
- Section 5.6: Renumbered as Section 5.5 to accommodate move
- Section 6: Updated and expanded topic list
- Section 6.1:
- Added clarifying grammatical edits
- Updated language to reflect current process.
- Section 6.2:
- Moved text from Sections 6.2. Issue Identification, Section 6.4 - Charging a New Issue, and Section 6.4.2 here.
- Updated topic lists for inclusion in Problem/Opportunity Statement, Issue Charge, and Charter.
- Added clarifying language and updated language to reflect current processes around Problem/Opportunity Statement, Issue Charge, and Charters, and new process
for requiring a vote to approve only the Issue Charge, rather than the Problem Statement and Issue Charge.
- Added language regarding updated procedure for review of Charter.
- Added section heading “Work Plan” including language moved from 6.4.2.
- Deleted duplicative last bullet on list
- 6.2.3: Added clarifying language to align with new Charter creation and approval process
- 6.2.3: Corrected grammar for clarity
- Deleted Exhibit 4: Issue Creation and Assignment (redundant information)
- Section 6.3:
- Moved text from Section 6.2 Issue Identification, and old Section 6.3.
- Deleted Exhibit 4: Issue Creation and Assignment as redundant with other graphics and descriptive text
- Section 6.4:
- Created new section heading
- Clarified intent of Problem Statement
- Moved text from Section 6.2 Issue Identification
- Section 6.5:
- Created new section heading
- Deleted sentence covered in more detail elsewhere
- Moved text from Section 6.2 Issue Identification
- Section 6.6:
- Created new section heading.
- Moved text from Section 6.2 Issue Identification.
- Corrected Problem Statement / Issue Charge reference to reflect new process.
- Corrected lower to upper case for titles of Chair and Secretary as defined terms
- Section 6.7:
- Created a new section heading.
- Added new language clarifying process.
- Moved text from sections 6.2, 6.4, 6.4.1.
- Changed note into a regular bullet
- Deleted OA 8.6.3 language as redundant
- Deleted “in consultation with members” as inaccurate
- Section 6.8:
- Created new section heading
- Moved text from Sections 6.3, 6.4
- Deleted redundant text
- Corrected grammar
- Corrected bullet alignment
- Section 6.9:
- Created new section heading.
- Added text from section 6.3
- Section 6.10:
- Created new section heading.
- Added text from section 6.4.3
- Edited language around complexity
- Corrected language to reflect new charging and charter processes
- Section 6.11:
- Created new section heading.
- Corrected “member” to “Stakeholder” for accuracy
- Added text from section 6.4.1
- Deleted language about reviewing Charge that does not match new process
- Added fourth item on list regarding inviting technical specialists
- Section 6.12:
- Created new section heading.
- Added text from section 6.5. Rewording for clarity.
- Section 7.1:
- Corrected “chapter” to “section”.
- Capitalized defined terms.
- Corrected “chart” to “exhibit”.
- Section 7.1.1: Moved to new section 8.6.1
- Section 7.3:
- Corrected typo and added clarifying language.
- Added introduction to exhibits.
- Section 7.4:
- Clarified practice of recording member participation in final report.
- Added subject matter expert and Facilitator as eligible representatives to present a stakeholder’s option to the Parent Committee.
- Section 8.2: Deleted extraneous language and added specific section reference.
- Section 8.3: Added clarifying language regarding status quo
- Section 8.4: Clarified voting rule application and a grammatical edit.
- Section 8.5: Deleted footnote definition of 3/2 rule and moved to Section 2: Definitions.
- Section 8.6: New section including content moved from 5.5, 7.1.1, and 15.2.2 along with new content.
- Section 8.6.6: New section on “Final Attempt at a Resolution”
- Section 9.2:
- Changed sentence structure to help readability
- Added MRC for clarity
- Added note on proper treatment of a consent agenda item
- Section 9.4: Changed text to bullets for ease of reading
- Section 10.6: Edited date formatting
- Section 11.2:
- Removed duplicate secretary reference.
- Added clarifying “business days” to deadline.
- Section 11.5:
- Added new “Proxy Voting Protocol” section
- Renumbered “Decision Making” section to 11.6
- Section 11.6: Renamed to “Decision Making” (old section 11.5)
- Section 11.7:
- Renamed to “Allowing Sufficient Opportunity for Review” (old section 11.6)
- Clarified wording
- Section 11.8:
- Renamed to “Antitrust Guidelines” (old section 11.7)
- Added “or his/her designee” to The President of PJM for duty to assign Chairs to stakeholder groups.
- Removed duplicate language.
- Changed text to bullets for ease of reading.
- Section 11.9: Renamed to “Stakeholder Group Chairmanship” (old section 11.8)
- Section 11.10:
- Renamed to “Committees” (old section 11.9)
- Moved Vice Chair sector schedule up for more logical flow.
- Indented order of election bullets.
- Added language regarding voting by acclamation
- Section 11.11: Renamed to “Elections” (old section 11.10)
- Section 11.12: Renamed to “Speakers” (old section 11.11)
- Section 11.13: Renamed to “Sector Designation Announcement” (old section 11.12)
- Section 11.14:
- Renamed to “Consultation with Transmission Owners and Members” (old section 11.13)
- Reworded for clarity
- Section 11.15:
- Renamed to “Manual Revisions” (old section 11.14)
- Added clarifying words
- Section 11.16: Renamed to “Chairs Prerogative” (old section 11.15)
- Section 11.17: Renamed to “Consensus Based Issue Resolution Process” (CBIR) Implementation Forum (old section 11.16)
- Section 12.2:
- Added reference to Voter Designation Form for proxy voting.
- Added section number for User Group reference
- Updated language from “ex parte letter” to “Board Communication letter” and adjusted grammar accordingly.
- Added Liaison Committee to list of communication opportunities
- Added hyperlink to Board Communication page of PJM website
- Section 13.1: Changed text to bullets for ease of reading.
- Section 13.3:
- Added Exhibit numbers for ease of reference.
- Corrected grammatical edits.
- Deleted text referring to a previous version of the chart.
- Section 13.4: Corrected typo
- Section 15.1:
- Removed duplicative bullet
- Updated reference from “Ex Parte Communication” to “Board Communication”
- Section 15.2:
- Added and re-organized bullets for clarity.
- Reworded sentences for clarity.
- Corrected typo and added reference to Appendix.
- Shifted bullets for better formatting.
- Section 15.2.2:
- Moved into new section 8.6
- Updated references from “Ex parte letter” to “Board Communication”
- Section 15.4:
- Changed language from “Ex Parte” Communication to “Board Communication” for clarity and to address negative connotations of “ex parte”.
- Added hyperlink to Board Communications page on pjm.com
- Added clarity on communication methodology
- Edited to update all references of “Ex Parte” to “Board Communication” with proper grammatical context.
- Section 15.5: Updated reference from “ex parte communication” to “board communication”
- Appendix I: Added introductory paragraph. Corrected typo.
- Appendix II:
- Update hyperlinks for Charter and Work Plan
- Remove reference to Issue Tracking as this is an internal form
- Appendix III:
- Removed chart references to “RR” (Robert’s Rules)
- Standardized formatting of M34 references
- Added clarifying language on motion to reconsider
- Appendix IV:
- Changed “electronic whiteboard” to more generic “shared document” to allow for tool choice by facilitator.
- Changed “surfacing” to “capturing” for better understanding.
- Removed “Key Pad” term to account for different technology solutions
- Added options as polling option.
- Grammatical edit.
- Appendix V:
- Clarified approval process for Problem Statement and Issue Charge
- Clarified timing of steps in CBIR process.
- Deleted language clarifying that this is an example for brevity.
- Replaced “facilitator’s assistant” with “secretary”.
- Deleted “electronic whiteboard” and replaced with “interests tab of the matrix” for accuracy.
- Corrected “cooking” to “baking” for accuracy.
- Corrected placement of bullets in Sub-Step 2D.
- Swapped exhibits for Winnowing Options Matrix and Final Options Matrix for correct order.
- Grammatical edits.
- Appendix VI:
- Per stakeholder approval votes, revised M14B review schedule from 1 to 2 years.
- Revised M34 review schedule from 2 to 3 years per Stakeholder Process Forum recommendation
- Revised M39 review schedule from 1 to 3 years to comply with manual.
- Added new manuals 14F (2 years) and 14G (3 years)
- FERC VOM Order Docket No. ER19-210-001 conforming changes:
- Sections 2.3, 2.6, 3.6, 4.6, 5.6, 6.6, 7.6, 9.6
- Revised Exhibit 1: Handy Whitman Index to reflect figures for the year 2019
- Section 1.1 – Proposal Window Type and Duration
- Long-term proposal window start time modified to open in January of odd years
- Cover to cover periodic review
- Added a specific reference in the introduction that this manual augments the RAA Schedule 9
- Addition of Capacity Interconnection Rights and Testing section
- Required testing within defined temperature limits
- Commencing with Delivery Year 2022/2023, simultaneous testing requirements for all Manual 18 defined Capacity Storage and Intermittent Resources (excluding wind and solar)
- Commencing with Delivery Year 2022/2023, PJM required simultaneous multiple generator and full plant testing
- Cover to cover periodic review
- Updated grammar throughout
- Updated “About this Manual” section to account for Additional Manual References
- Reorganized Sections 2.3.2, 2.3.3, 2.3.4, 2.3.6 and 10.2.2 for readability
- Removed irrelevant data in:
- Section 1 (Figure 1)
- Section 1.2.2: Reference to Member Administrative Committee
- Clarified commitment requirements for Capacity Resource Energy Market Offer rules to align with Tariff (Sections 1, 2.3)
- Section 2.3.4: Removed CP Transition Year language
- Section 2.3.4A: Relocated UTC business rules to Section 2.3.2 Market Buyers
- Section 2.3.10: Clarified process for addressing data input/system failures when calculating LMPs under 5-minute Settlements
- Section 2.14: Clarified cap to resource offers includes the lesser of a 10% adder or $100. Added missing Delmarva and OVEC zones to Region lists.
- Section 3.2.7: Clarified use of LOC in Regulation clearing and pricing
- Section 6: Removed most of section, relocated language to existing sections as appropriate
- Section 11.2.1: Incorporated previously approved language that was lost due to versioning issue
- Attachment A: Removed detailed language and provided a reference to OASIS Business Practices Section 2.6
Attachment C: Plant Specific NPIRs Revision History: NPIR revision update
M-13
Emergency Operations
- Attachment J: Updated language for consistency with the new version of NERC EOP-004-4 effective 4/1/2019.
M-37
Reliability Coordination
- Periodic cover-to-cover review
- Minor grammatical / formatting changes throughout
- Attachment A “PJM Reliability Plan”: Updated Appendix D: PJM TOs and TOPs to include AMP Transmission, LLC as TO
- Revisions proposed as result of a Cover to Cover Periodic Review
- Revisions needed to clean-up outdated language and ensure language follows to current processes
- Minor revisions needed to correct grammar, spelling, punctuation, consistency of terms and document references
- Removed references to Demand Resource Factor due to implementation of Capacity Performance
- Deleted Section 5: DR Reliability Target Analysis Procedures and Section 6: Limited-Availability Resource Constraints Procedures due to implementation of Capacity Performance
- Updated references of ReliabilityFirst’s Standard BAL-502-RFC-02 to ReliabilityFirst’s Standard BAL-502-RFC-03 to reflect new version
- Cover to Cover Periodic Review
- Revision to Section 1A on CEII
- Updated Attachment C
- Various updates for clarity and alignment with current processes
- Section C.2
- Added language that non-radial facilities 345 kV and up will only automatically be considered as CETL limits for an LDA if they have greater than a 2% OTDF
- Clarified that PJM may choose to include specific non-PJM transmission facilities in the load deliverability test in order to account for significant loop flows
- Removed sentence that states that Load Deliverability Facility List will be locked down prior to each baseline
- New procedure added to require both thermal and voltage analysis on both Discrete Outage Case and Mean Dispatch Case
- Procedure modified to examine mean thermal loadings instead of median thermal loadings
- Section 7.1.1
- Added requirements associated with FERC Order 824 – Primary Frequency Response for new ISAs effective 10/1/18.
- Section 7.1.2
- Section 7.3.1
- Deleted reference to three working day notification to TO and PJM
- Incorporate Independent Market Monitor Opportunity Cost Calculator methodology
- Updated NSR Eligibility Requirements to require real-time telemetry
- Cover to Cover Periodic Review
- Attachment A: Updated OATF Scope.
- Added Section 2.17 to describe the use of transmission constraint penalty factors in the Day-ahead and Real-time Market Clearing Engines per FERC Order (Docket: ER19-323-000)
- Revise Section 1 and 2 to incorporate references to the Open Access Transmission Tariff, Attachment M-3 process
- Revise Sections 1 and 2 to include improved discussion of workflow and alignment to current processes
- Updated manual owner from Dave Egan to Jason Connell
- Updated Attachment A-1 and B-2 to include latest User Defined Model List for Wind Turbines and Inverter Based Resources
- Cover to Cover Periodic Review
- Updated co-ownership to Richard Brown
- Section 3: Removed references to legacy training requirements
- Conforming change in Section 3.2.7 to specify only resources with a benefits factor of 0.1 or greater may clear in the Regulation Market per FERC Order (Docket: ER19-383-000)
- Updates to Sections 2.7, 2.8, and 2.9.1 to clarify the use of approved RT SCED solution in determination of Shortage Pricing in Locational Pricing Calculator (LPC).
M-13
Emergency Operations
- Section 2.2: Updated the DASR requirement to the new 2019 values.