Topic:"Generation Grid Resources" in M12623

2. Description of what constitutes NPCC Regional Reliability Criteria NPCC Regional Reliability Criteria are contained in Directories. The Directory documents contain the NPCC Regional Reliability Criteria in a specific section of each of...

AI summary The NPCC Regional Reliability Criteria are part of Directories that provide guidelines and procedures to meet reliability objectives. These criteria are not NERC Reliability Standards but are used to implement or augment them, addressing issues beyond the scope of NERC standards, such as resource adequacy. They are regionally specific and contribute to a more robust Bulk Electric System.

Regional Reliability Reference Directory # 5 Reserve Task Force on Coordination of Operations Revision Review Record: December 2, 2010 October 11, 2012 September 27, 2019 September 26, 2025 Adopted by the Members of the Northeast Power Coo...

AI summary The Regional Reliability Reference Directory #5 Reserve outlines the Task Force on Coordination of Operations Revision Review Record, with key dates including December 2, 2010, and September 26, 2025. It was adopted by the Northeast Power Coordinating Council, Inc. on December 2, 2010, following a recommendation by the Reliability Coordinating Committee.

3. NERC ERO Reliability Standard Requirements The NERC ERO Reliability Standards containing requirements that are associated with this Directory include, but may not be limited to: - BAL-002 : Disturbance Control Standard: Contingency Rese...

AI summary This section outlines the NERC ERO Reliability Standards that apply to the Directory, including BAL-002, BAL-005, EOP-011, and INT-009, which cover disturbance control, automatic generation control, emergency operations, and interchange implementation.

Activation of Inter-Balancing Area Reserve - R12. A Balancing Authority providing reserve to another Balancing Authority through direct procurement, bilateral, multi-lateral operating agreements, or through reserve sharing agreements, shal...

AI summary This section outlines the rules for activating inter-Balancing Area reserve, including requirements for reserve provision, limitations on curtailment, and procedures for decision-making and coordination among affected Balancing Authorities and Reliability Coordinators.

Simultaneous Activation of Ten-Minute Reserve R22. Balancing Authorities participating in the "Simultaneous Activation of Ten-Minute Reserve" , (SAR) program shall conform to the procedures, as specified in Attachment B.

AI summary Balancing Authorities participating in the 'Simultaneous Activation of Ten-Minute Reserve' program must follow the procedures outlined in Attachment B.

ACE Diversity Interchange R23. Balancing Authorities participating in the "ACE Diversity Interchange", (ADI) program shall conform to the procedures, as specified in Attachment C.

AI summary The document specifies that Balancing Authorities participating in the ACE Diversity Interchange program must follow the procedures outlined in Attachment C.

2.0 Handling of Radial Source Contingencies with Several Balancing Authorities Receiving Energy If the resource loss is an energy transaction from another Balancing Authority connecting via HVDC lines, see sections 2.0 through 4.0 below fo...

AI summary This section discusses the handling of radial source tie line contingencies when multiple Balancing Authorities receive energy. It outlines the methodology for allocating SAR assistance in cases of single or multiple contingencies on tie lines crossing Balancing Area boundaries.

Example 4 Source BA, intermediary sink BA1, intermediary sink BA2, and sink BA3 The energy is flowing from the radial Source BA, with portions sinking in BA 1, BA 2, and BA3. The rules governing this scenario are the same as presented in E...

AI summary This example describes energy flow from a radial Source BA to intermediary sink BA1, BA2, and sink BA3. The rules for such transactions are similar to Example 3, with limitations on radial source transactions unless all Balancing Authorities on the Scheduling Path are SAR participants.

Example 5. Counter flow Transactions on MSC 7040 PJM Exports 400 MW to HQ-TE on MSC 7040, NYISO Imports 1200 MW:

AI summary This example illustrates a counter flow transaction involving PJM exports of 400 MW to HQ-TE on MSC 7040 and NYISO imports of 1200 MW, highlighting interregional power transfers and grid coordination.

MSC 7040 flow = 800 MW HQ-TE – NYISO transaction = 1200 MW HQ-TE – PJM transaction = -400 MW (flow is PJM to HQ-TE) Area Initial Share/ Assistance Sought First Pass Secon d Pass Total Generation Picked Up When SAR Energy Is Supplied Fully...

AI summary The document provides data on energy flows and transactions between different balancing authorities, including IESO, ISO-NE, NYISO, and PJM, with specific values for initial shares, generation picked up, and total generation after adjustments. The MSC 7040 flow is noted as 800 MW from HQ-TE, with a NYISO transaction of 1200 MW and a PJM transaction of -400 MW.

Attachment C – ACE Diversity Interchange (ADI) ACE Diversity Interchange (ADI) is a method of regional regulation among participating Balancing Authorities that can achieve a mutual reduction in requirements for reserve on Automatic Genera...

AI summary ACE Diversity Interchange (ADI) is a regional regulation method among Balancing Authorities that reduces reserve requirements on Automatic Generation Control (AGC) by leveraging the sign diversity of Area Control Error (ACE) values. Participation requires forming an electrically contiguous area and approval from the Task Force on Coordination of Operation (TFCO).

1.0 ADI General Requirements In order to participate in ADI, Balancing Authorities shall establish the appropriate data exchange and apply the ADI term to their respective ACE in AGC. Transmission limits or other internal constraints that...

AI summary The document outlines general requirements for ADI (Automated Demand Response Integration), including data exchange protocols, handling of transmission limits, and the use of standardized signs for ACE (Area Control Error). It also addresses inadvertent interchange and how ADI allocations may be used to correct imbalances among participants.

Appendix C – Participation Request Form - Simultaneous Activation of Ten-Minute Reserve and ACE Diversity Interchange Instructions NPCC Balancing Authorities and adjacent Balancing Authorities must complete this form to request participati...

AI summary This appendix outlines a participation request form for Balancing Authorities in the NPCC region to join the Simultaneous Activation of Ten-Minute Reserve (SAR) and ACE Diversity Interchange (ADI) programs. The form must be completed and submitted to the NPCC Task Force on Coordination of Operation (TFCO) for approval.

Reserve Task Force on Coordination of Operations Revision Review Record: December 2nd. 2010 October 11, 2012 September 27, 2019 Adopted by the Members of the Northeast Power Coordinating Council, Inc. this December 2, 2010 based on recomme...

AI summary The document outlines the adoption of the Task Force on Coordination of Operations Revision Review Record by the Northeast Power Coordinating Council, Inc., on December 2, 2010, following a recommendation from the Reliability Coordinating Committee and in accordance with the NPCC Amended and Restated Bylaws.

Version History Version Date Action Change Tracking (New, Errata or Revisions) 1.6.1 Functional Entities (Responsible Entities)4 1.6.2 Applicability of NPCC Criteria4 2Defined Terms 5 3 NERC ERO Reliability Standard Requirements 5 4NPCC Re...

AI summary The document outlines version history and various sections related to reliability standards and compliance requirements under the North American Electric Reliability Corporation (NERC) and the North American Electric Reliability Corporation (NPCC). It includes appendices and attachments detailing monitoring procedures, reserve calculations, and contingency measures.

Activation of Inter-Balancing Area Reserve R12. A Balancing Authority providing reserve to another Balancing Authority through direct procurement, bilateral, multi-lateral operating agreements, or through reserve sharing agreements, shall...

AI summary The text outlines rules for activating inter-Balancing Area reserve, detailing requirements for reserve provision, limitations on curtailment, decision-making authority, and notification procedures. Key requirements include restrictions on resource activation, limitations to adjacent Balancing Authorities, and coordination with the TFCO and NPCC.

Energy Scheduling and Managing Reserve - R17 . A Balancing Authority providing (allocating or activating) inter- Balancing Area reserve, not as part of a Reserve Sharing Group, shall not count that reserve to meet its own reserve requireme...

AI summary The text outlines rules for energy scheduling and managing reserve among Balancing Authorities. It specifies how reserve energy is counted, the conditions for recallable energy, and requirements for maintaining operating reserve. These rules ensure proper allocation and management of energy resources across different Balancing Authorities.

Example 4 Source BA, intermediary sink BA1, intermediary sink BA2, and sink BA3 The energy is flowing from the radial Source BA, with portions sinking in BA 1, BA 2, and BA3. The rules governing this scenario are the same as presented in E...

AI summary This example describes an energy flow scenario where energy moves from a radial source Balancing Authority (BA) to three intermediary and sink BAs. The rules for this scenario are similar to Example 3, with limitations on radial source transactions unless all BAs on the Scheduling Path are SAR participants.

4.2 Modification to the SAR Procedure The SAR procedure is modified to allocate portions of the total delivery to Balancing Authorities in addition to the directly connected Balancing Authority during an ordinary simultaneous activation of...

AI summary The SAR procedure is modified to allocate energy from the tie line to Balancing Authorities during a contingency, with each recipient contributing to and receiving assistance based on mutual support principles. The reserve requirement for the directly connected Balancing Authority remains based on the largest internal contingency or its share of the tie line flow. The methodology involves iterative allocation of shares and is illustrated with examples.

Example 1. PJM Buys 400 MW from HQ-TE on MSC 7040, NYISO Buys 1200 MW: MSC 7040 flow = 1600 MW HQ-TE – NYISO Transaction = 1200 MW HQ-TE – PJM Transaction = 400 MW Area Initial Share/ Assistance Sought First Pass Second Pass Total Generati...

AI summary In Example 1, PJM buys 400 MW from HQ-TE, and NYISO buys 1200 MW. The table outlines the flow and distribution of energy across different balancing authorities. Initial shares are assigned based on purchases, and assistance is sought for the contingency amount of 800 MW under ordinary SAR rules.

MSC 7040 flow = 1600 MW HQ-TE – NYISO Transaction = 400 MW HQ-TE – PJM Transaction = 1200 MW

AI summary The text outlines energy flow and transaction details between various entities, including HQ-TE, NYISO, and PJM, with specific figures for MSC 7040 and associated transactions.

Sandy Pond flow = 1600 MW HQ-TE – NY transaction = 200 MW HQ-TE – NE transaction = 1200 MW HQ-TE – PJM transaction = 200 MW

AI summary The document outlines various energy transactions involving Hydro-Quebec (Transmission Entity) (HQ-TE) with different entities, including NY, NE, and PJM, specifying the flow and transaction amounts in megawatts.

Radial Source Contingencies with Counter flow Transactions Example 5. Counter flow Transactions on MSC 7040 PJM Exports 400 MW to HQ-TE on MSC 7040, NYISO Imports 1200 MW: MSC 7040 flow = 800 MW HQ-TE – NYISO transaction = 1200 MW

AI summary This example illustrates a counter flow transaction on MSC 7040, where PJM exports 400 MW to HQ-TE, while NYISO imports 1200 MW, resulting in a net flow of 800 MW from HQ-TE to NYISO.

HQ-TE – PJM transaction = -400 MW (flow is PJM to HQ-TE) Area Initial Share/ Assistance Sought First Pass Second Pass Total Generation Picked Up When SAR Energy Is Supplied Fully Total Gen. Picked Up After SAR Is Canceled And All ACEs = 0...

AI summary The document describes a PJM to HQ-TE transaction of -400 MW, with a table showing initial shares and assistance sought by various entities. NYISO and PJM are assigned half of their respective flows, and the net assistance sought is 400 MW for the contingency amount.

First Pass – The NYISO is provided 600 MW of assistance. These shares are allocated equally, 200 MW each, among the other three participants – including PJM. Second Pass – PJM is provided -200 MW of assistance. These shares are allocated e...

AI summary The text discusses the allocation of assistance among Balancing Authorities, including the NYISO and PJM, and how negative shares reduce the net pick-ups required. It also references the restoration of the composite NPCC/PJM ACE and the cancellation of the SAR procedure, with an example involving ISO-NE purchasing power from multiple entities.

First Pass – ISO-NE is provided 1000 MW of assistance. These shares are allocated equally, 333 MW each, among the other three participants. Second Pass – NYISO is provided -250 MW of assistance. These shares are allocated equally, -83 MW e...

AI summary The text discusses the allocation of generation assistance among Balancing Authorities, including ISO-NE, NYISO, and PJM, and references an example transaction involving HQ-TE and NYISO on MSC 7040. It outlines the process for restoring ACE and canceling the SAR procedure.

3.2 Deficiencies of the Synchronized Reserve Available Within Ten Minutes When a Balancing Authority becomes deficient in the synchronized reserve available within ten minutes but is not deficient in ten-minute reserve , the deficient Bala...

AI summary This section outlines the actions a Balancing Authority may take when it has a deficiency in synchronized reserve within ten minutes, including activating off-line generation, re-dispatching online generation, obtaining external resources, and disconnecting interruptible loads.

2. Description of what constitutes NPCC Regional Reliability Criteria NPCC Regional Reliability Criteria are contained in Directories. The Directory documents contain the NPCC Regional Reliability Criteria in a specific section of each of...

AI summary The NPCC Regional Reliability Criteria are outlined in Directories and serve as supplemental guidelines to NERC Reliability Standards. They are not in conflict with NERC standards but provide more stringent, region-specific requirements to enhance the reliability and security of the Bulk Electric System.

requirements associated with RAS. See clean (Exh. A) and redlined (Exh. B) versions of Directory #7. The proposed revisions are provided in the table below: Section No Title Notable Changes/Additions 1.5 Background This review identified r...

AI summary The document discusses proposed revisions to requirements associated with RAS (Reliability Assessment System) in Directory #7. Changes include the removal of references to PRC-012-2, updates to applicability and terminology, and modifications to sections related to the classification and reclassification of RAS. These revisions aim to align the document with the current single review process and enhance clarity.

1.2 Directory Number 7 The term Remedial Action Scheme ( RAS ) and its definition has been adopted by NPCC in place of the term Special Protection System ( SPS ). For existing documentation, the term RAS or SPS may be used.

AI summary The document discusses the adoption of the term 'Remedial Action Scheme' (RAS) by the Northeast Power Coordinating Council Inc. (NPCC), replacing the term 'Special Protection System' (SPS). Both terms may still be used in existing documentation.

1.6.3 Classification of a RAS For application of NPCC criteria, RAS are sub-divided into three types. Type I A RAS, other than a Limited Impact RAS, that recognizes or anticipates abnormal system conditions resulting from design or operati...

AI summary This section classifies Remedial Action Schemes (RAS) into Type I, Type II, and Limited Impact based on the severity of system conditions they address. Type I handles abnormal conditions from design or operating criteria contingencies, while Type II addresses extreme contingencies. Limited Impact RAS are those that do not cause significant issues in the Bulk Power System (BPS).

3.0 NERC ERO Reliability Standard Requirements The NERC ERO Reliability Standards containing Requirements that are associated with this Directory include, but may not be limited to: - 3.1 PRC-012 [Remedial Action Schemes](http://www.nerc.c...

AI summary This section outlines the NERC ERO Reliability Standards that are relevant to the Directory, specifically mentioning PRC-012 and PRC-017, which pertain to Remedial Action Schemes and their maintenance and testing requirements.

simultaneously by a single event or condition. In addition, physical separation of the communication media Page 12 of 36 PUBLIC outside the substation fence shall be three feet at a minimum. - 5.11.1.2 Teleprotection equipment shall be mon...

AI summary The document outlines technical criteria for teleprotection equipment, including monitoring requirements, communication channel design, power supply specifications, and component separation. It emphasizes the need for 24-hour operational monitoring, automated testing, and independent power sources to ensure reliability and safety.

6.0 RAS Review Requirements - 6.1 Each proposing entity, proposing to install a new RAS, to modify an existing RAS, or to retire an existing RAS shall submit documentation to TFCP as requested in Appendix B. - 6.1.1 For Type I and Type II,...

AI summary The document outlines the requirements for reviewing and evaluating Remedial Action Schemes (RAS) in the context of bulk electric system reliability. It specifies submission processes, design criteria, and periodic evaluation procedures to ensure the effectiveness and safety of RAS in preventing system instability and cascading failures.

2.9 RAS Communication - 2.9.1 RAS communication systems should be designed to prevent unwanted operations such as those caused by equipment or personnel. - 2.9.2 Two identical communication equipment models should not be used in independen...

AI summary The document outlines guidelines for designing RAS communication systems to prevent unwanted operations, minimize risks from equipment failure, and ensure reliability through design diversity and signal interference mitigation.

2.13 RAS System Testing and Maintenance - 2.13.1 Test facilities and test procedures should be designed such that they do not compromise the independence of RAS Groups operating for the same system condition. Test devices or switches shoul...

AI summary This section outlines guidelines for testing and maintaining the RAS system, emphasizing the importance of preserving the independence of RAS Groups, simplifying IEC 61850 system configurations, ensuring unique identification of GOOSE messages, and recommending end-to-end testing to ensure proper functionality under dynamic conditions.

2.14 Analysis of RAS Insofar as possible, each active function within a RAS should be included in sequence of events information.

AI summary The text emphasizes the importance of including each active function within a Remedial Action Scheme (RAS) in sequence of events information.

4.0 Retirement of a Limited Impact RAS - 4.1 The proposing entity shall notify TFCP of the proposed retirement and provide the technical justification, after which the limited impact RAS may be retired. A formal agreement is not required....

AI summary The process for retiring a Limited Impact RAS involves notifying TFCP, informing relevant task forces and the RCC, and updating the NPCC RAS list. No formal agreement is required for retirement.

FLOW CHART FOR PLANNED REPLACEMENT OF RAS EQUIPMENT (NO FUNCTIONAL MODIFICATION)

AI summary The document presents a flow chart for the planned replacement of RAS (Remedial Action Scheme) equipment without functional modification. This chart outlines the process for replacing equipment within the Bulk Electric System (BES) while ensuring no changes to the system's functionality.

1.6.3 Classification of a RAS For application of NPCC criteria, RAS are sub-divided into three types. Type I A RAS, other than a limited impactLimited Impact RAS, that recognizes or anticipates abnormal system conditions resulting from des...

AI summary The document classifies Remedial Action Schemes (RAS) into three types based on their impact on the Bulk Electric System (BES) and Bulk Power System (BPS). Type I and Type II RAS address abnormal system conditions from design or operating criteria and extreme contingencies, respectively. Limited Impact RAS do not cause cascading failures or other severe issues and are subject to different criteria.

tection groups shall not share the same component. (This criterion does not apply to Type II RAS unless otherwise noted per criterion 5.2.) - 5.11.1.6.1 The use of a single communication tower for radio communication systems used by the tw...

AI summary The document outlines technical criteria for the installation and separation of teleprotection systems and Remedial Action Schemes (RAS) to ensure system reliability and prevent common-mode failures, including requirements for physical separation, communication diversity, and environmental considerations.

2.17 Control Cable, Wiring and Ancillary Control Devices Control cables and, wiring and ancillary control devices should be highly dependable and secure. Due consideration should be given to published codes and standards, fire hazards, cur...

AI summary This section outlines the requirements for control cables, wiring, and ancillary control devices, emphasizing their reliability, security, and compliance with codes and standards related to fire hazards, insulation, mechanical strength, and environmental factors.

FLOW CHART FOR PLANNED REPLACEMENT OF RAS EQUIPMENT (NO FUNCTIONAL MODIFICATION)

AI summary This section presents a flow chart illustrating the planned replacement of RAS equipment without any functional modifications. It outlines the process for replacing RAS components while maintaining their operational integrity.