N-1Notice of Filing of Amendments to the Bylaws 6/29/2010
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BEFORE THE NOVA SCOTIA UTILITIES AND REVIEW BOARD THE PROVINCE OF NOVA SCOTIA NORTH AMERICAN ELECTRIC ) RELIABILITY CORPORATION ) NOTICE OF FILING OF AMENDMENTS TO THE BYLAWS OF THE NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION
AI summary The document is a notice of filing of amendments to the bylaws of the North American Electric Reliability Corporation (NAERC) before the Nova Scotia Utilities and Review Board.
I. INTRODUCTION The North American Electric Reliability Corporation ("NERC") respectfully submits notice of amendments to Article III, sections 1 and 2 of NERC's Bylaws. The amendments were approved by the NERC Member Representatives Commi...
AI summary NERC submitted amendments to its bylaws to expand the Board of Trustees from 11 to 12 members, approved by the MRC and FERC. The amendments aim to address increased workload and responsibilities, with FERC approving the changes in October 2009. NERC directed the Nominating Committee to propose a new trustee for election in 2010.
II. NOTICES AND COMMUNICATIONS Notices and communications with respect to this filing may be addressed to: Gerald W. Cauley Rebecca J. Michael President and Chief Executive Officer Assistant General Counsel David N. Cook Holly A. Hawkins V...
AI summary This section provides contact information for North American Electric Reliability Corporation (NERC) regarding notices and communications related to a filing, including names, titles, addresses, and email contacts of key personnel.
IV. APPROVAL PROCESS FOR THE BYLAWS AMENDMENTS Article XIV, §1 of the NERC Bylaws sets forth the required procedure for approval of amendments to the Bylaws: Section 1 ¾ Amendments to the Bylaws ¾ These Bylaws may be altered, amended, or r...
AI summary The approval process for NERC bylaws amendments requires majority votes from the board and Member Representatives Committee (MRC), with 10–60 days' notice. Amendments were approved on August 4–5, 2009, following proper procedures, including quorum presence and prior notice. The process adhered to Article XIV, §1 requirements, including potential sector-based approval by two-thirds of sectors.
rm of Membership — Membership in the Corporation shall be retained as long as a member meets its respective qualifications, obligations, and conditions of membership as set forth in this Article II. Section 6 — Removal — In addition to ter...
AI summary The section outlines membership retention requirements and termination procedures. Membership is retained if qualifications are met, while the board may terminate membership for violations via a two-thirds vote, with an appeal right to the Commission or relevant Canadian/Mexican authority.
Section 3 — Election of Members of the Member Representatives Committee a. Unless a sector adopts an alternative election procedure, the annual election of representatives from each sector to the Member Representatives Committee, and any e...
AI summary This section outlines the election process for the Member Representatives Committee (MRC), including nomination periods, voting rules requiring a simple majority, and procedures for handling elections with no majority winner. It also allows sectors to adopt alternative procedures if approved by two-thirds of members and subject to Board review.
ARTICLE X Agreements with Regional Entities Section 1 ¾ Delegation Agreements with Regional Entities ¾ The Corporation may, in accordance with appropriate governmental authority, enter into agreements with regional entities pursuant to whi...
AI summary The Corporation may delegate authority to regional entities to enforce reliability standards in North America, requiring board approval and compliance with policies. Agreements must meet criteria to ensure effective bulk power system reliability administration.
ARTICLE XI Rules of Procedure Section 1 ¾ Development of Rules of Procedure ¾ The Corporation shall develop and implement such Rules of Procedure as in the judgment of the board are necessary or appropriate to carry out the purposes of the...
AI summary The Corporation must develop and implement rules of procedure for reliability standards, committee operations, and compliance enforcement. The Board approves rules, requiring public comment for proposals. Rules must be submitted to the Commission and other authorities for approval before becoming effective in the U.S., Canada, or Mexico.
Section 2 ¾ Preparation and Adoption of Annual Budget, Business Plan, and Funding Mechanism ¾ The board shall prepare or cause to be prepared an annual budget for the administrative and other expenses of the Corporation, including the expe...
AI summary The board is required to prepare and approve an annual budget, business plan, and funding mechanism for the Corporation, including reserves and special projects. These documents must be approved at least 135 days before the fiscal year begins to ensure timely submission to governmental authorities.
ARTICLE XIV Amendments to the Bylaws Section 1 ¾ Amendments to the Bylaws ¾ These Bylaws may be altered, amended, or repealed by a majority vote of both the board and the Member Representatives Committee at respective meetings of the board...
AI summary Amendments to bylaws require a majority vote from both the board and Member Representatives Committee (MRC) with prior written notice. Sector voting allows two-thirds approval for changes, subject to regulatory filing and approval requirements by the Commission and other authorities.
N-3Notice of Filing of Revised Pro Forma Delegation Agreement, Relevant Revised Delegation Agreement, and Amendments to the NERC Rules of Procedure 6/29/2010
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I. INTRODUCTION The North American Electric Reliability Corporation ("NERC") respectfully provides notice of the following documents: - Revised pro forma Delegation Agreement with Regional Entities ( Attachment 1 to this filing) - Revised...
AI summary NERC notifies revisions to Delegation Agreements with Regional Entities and updates to NERC Rules of Procedure (ROP), including changes to multiple sections and appendices. The filings were submitted to FERC and Canadian authorities, with specific revisions detailed in attachments.
A. Process for Development of Revised Pro Forma Delegation Agreement NERC and the Regional Entities have negotiated a revised pro forma Delegation Agreement, and individual Delegation Agreements based on the new pro forma agreement, in res...
AI summary NERC and Regional Entities updated the Delegation Agreement due to operational issues identified in the 2008-2009 ERO Assessment Report. Stakeholder input was sought, and FERC approved a one-year extension for the agreement's expiration. The revised agreement was finalized in 2010 after stakeholder feedback and board approvals.
at its board approved the revised Delegation Agreement on the date stated above. ("CMEP"), Appendix 4C to the NERC ROP. 4 (Revised pro forma Delegation Agreement, §2(a)(iii) and Exhibit D.)
AI summary The board approved the revised Delegation Agreement, referencing Appendix 4C to the NERC ROP and specific sections of the Revised pro forma Delegation Agreement.
2. Detailed Description of Changes in the Revised Pro Forma Delegation Agreement This subsection provides a detailed description, on a section-by-section basis, of the changes from the current pro forma Delegation Agreement to the revised...
AI summary This section details changes to the revised pro forma Delegation Agreement compared to the current version, emphasizing section-by-section updates and improved consistency in defined terms and capitalization, as shown in Attachment 1B's redlined format.
rds. In §5(a)(ii), a reference to a section of the NERC ROP has been changed to be consistent with the revised ROP. Other revisions have been made to §5 to use defined terms and for greater clarity. Section 6, Enforcement of Compliance wit...
AI summary Revisions to sections 5 and 6 of the Base Delegation Agreement align terminology with the revised NERC ROP, clarify enforcement processes for reliability standards, and specify FERC and NERC roles in reviewing violations, penalties, and CMEP changes. Defined terms like 'Possible Violation' and 'Confirmed Violation' are emphasized for consistency and transparency.
s and assessments. The proposed business plan and budget and proposed assessment shall also provide for reasonable reserve mechanisms for unforeseen and extraordinary expenses and other contingencies. Section 3 addresses the allocation of...
AI summary The document outlines cost allocation mechanisms for a Regional Entity, requiring reserve funds for unforeseen expenses. It specifies that assessments are allocated based on Net Energy Load (NEL) among Load-Serving Entities (LSEs), subject to NERC and FERC approval. The Regional Entity's role as a billing agent for NERC is detailed, with compliance to prior FERC requirements.
A. Process for Development of Proposed Amendments NERC and the Regional Entities developed a set of proposed amendments to the NERC ROP in conjunction with their development of the revised pro forma Delegation Agreement. The origin of the...
AI summary NERC and Regional Entities developed proposed amendments to the NERC ROP, driven by issues in the Three-Year ERO Assessment Report. Revisions target compliance enforcement, certification, and monitoring processes. Stakeholder feedback was solicited, leading to revisions approved by the NERC Board of Trustees on May 12, 2010.
2. Amendments to Section 400 – Compliance Enforcement Two recurring reasons for amendments in §400 are: (1) to adopt new or revised terminology adopted in amended Appendix 4C, such as the terms "possible violation," "alleged 12 Article XI,...
AI summary Amendments to Section 400 focus on aligning terminology with Appendix 4C (e.g., 'possible violation,' 'confirmed violation') and removing redundant text to avoid confusion. This follows NERC Bylaws requiring public comment on ROP amendments before approval by the NERC Board of Trustees.
materials in accordance with the format developed by NERC and the Regional Entities (including content listed in the existing text of this section). The specific amendments to §1104.1 are as follows: Each regional entity shall submit its p...
AI summary Amendments to §1104.1 mandate regional entities to submit annual budgets to NERC by July 1 of the prior year, with detailed justification for funding. §1104.3 is deleted, as NERC's review authority is already covered by the Delegation Agreement. Budgets must align with NERC and regional entity-developed formats and be approved by FERC and other ERO authorities.
7. Amendments to Section 1200 – Regional Delegation Agreements Section 1205, Sub-delegation. Section 1205 has been amended to remove the absolute prohibition on sub-delegation by a Regional Entity of its delegated responsibilities and auth...
AI summary Amendments to Section 1205 allow Regional Entities to sub-delegate responsibilities to other Regional Entities with NERC, FERC, and ERO approvals, provided resource sharing does not lead to cross-subsidization or sub-delegation. The change removes an absolute prohibition on sub-delegation while maintaining oversight requirements.
e. Section 6.5 – Review and Acceptance or Rejection of Mitigation Plans A minor revision for clarity has been made to the first sentence of the first paragraph in §6.5. Additionally, a paragraph has been added to §6.5 to provide for the pr...
AI summary Section 6.5 allows provisional acceptance of mitigation plans by the Regional Entity before completing its review of violations. If new facts emerge, the plan must be revised. This enables early implementation of corrective actions, enhancing Bulk Power System reliability, while ensuring adjustments if further evidence arises. NERC will publicly post approved plans.
N-7Notice of Filing of NERC's 2010 Business Plan and Budget and the 2010 Business Plans and Budgets of Regional Entities and the Proposed Assessments to Fund Budgets 6/29/2010
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he Regions, and the proposed assessments to the load-serving entities (LSE) within each Region to collect the allocated statutory funding requirements. This filing includes the following attachments: Attachment 1: Summary tables showing NE...
AI summary The filing outlines NERC's 2010 budget and funding requirements, along with proposals from regional reliability organizations, including detailed attachments on statutory funding, business plans, and goal achievement reports. It emphasizes allocation of statutory funding to load-serving entities and regional entities' operational metrics.
Attachment 10 : Western Electricity Coordinating Council proposed Business Plan and Budget for 2010 I. INTRODUCTION 1 requirement Entity; aggregate WIRAB. by the 2010 2010 program; funding Canadian the requirement ERO proposed 2010 for Sec...
AI summary The document presents a series of proposed business plans and budgets for various reliability organizations and councils in 2010, including the Western Electricity Coordinating Council, NERC, Florida Reliability Coordinating Council, and others.
Attachment 11 : Western Interconnection Regional Advisory Body proposed Business Plan and Budget for 2010 Attachment 12: Discussion of Comments Received During Development of NERC's 2010 Business Plan and Budget. Attachment 13: Calculation...
AI summary The text lists various attachments related to NERC's 2010 business plan, budget, and related reports, including financial statements, reliability assessments, and administrative cost metrics for the Western Interconnection Regional Advisory Body and other regional entities.
I. INTRODUCTION The North American Electric Reliability Corporation (NERC) submits: - (1) NERC's proposed Business Plan and Budget as the electric reliability organization (ERO), for the year ending December 31, 2010; - (2) the proposed Bu...
AI summary NERC submits its 2010 budget and business plan, along with proposals from eight regional reliability entities and WIRAB, detailing statutory funding allocations and load-serving entity assessments. The filing includes budget summaries and funding requirements for reliability activities under the Federal Power Act.
nal Entities have adopted several changes in accounting methodology for presentation of their budgets, which are detailed on page 14 of Attachment 2 . The more significant of these changes include: - All expenses for the administrative ser...
AI summary NERC and Regional Entities revised 2010 budget accounting methods, including allocating indirect expenses by FTE ratios, classifying capital expenditures as Fixed Assets, and adjusting depreciation handling. FERC directed NERC to define 'indirect costs' consistently in the 2010 Business Plan and Budget.
Electric Company, Virginia Electric and Power Company, and We Energies. Attachment 12 discusses how concerns expressed in the comments were addressed in NERC's final 2010 Business Plan and Budget. the Regional Entities in March 2009 to dis...
AI summary The text outlines NERC's process for developing its 2010 Business Plan and Budget, including stakeholder input, coordination with Regional Entities, and the role of the FAC in reviewing the initial draft. Discussions focused on budget assumptions, accounting methodology changes, and program goals for 2010.
21 The arrangements, including the compensation mechanisms and amounts, by which compliance monitoring and enforcement services will be provided for the reliability functions for which FRCC and SPP RE are the registered entities, have not...
AI summary NERC discusses uncertainty in 2010 budget requirements for compliance monitoring of FRCC and SPP RE reliability functions, contingent on agreements with SERC. If no agreement is reached, NERC may need to allocate additional resources, referencing FERC orders and prior compliance processes with WECC.
6. SPP RE SPP RE's total 2010 statutory budget is $8,138,783, an increase of $1,657,747 over its 2009 Budget. SPP RE plans total staffing for statutory and administrative programs of 24.3 FTEs, an increase of 7.1 FTEs over its 2009 Budget....
AI summary SPP RE's 2010 statutory budget increased by $1.66M, with 7.1 additional FTEs, focusing on CMEP and compliance programs. Budget highlights include a 156% rise in direct expenses for CMEP, reduced indirect expense rates, and a $1.38M reduction in the requested 2010 assessment due to projected working capital reserves. FERC's 2009 order on budget procedures is referenced.
VIII. ENHANCEMENTS TO NERC'S DATA COLLECTION AND CHECKING PROCESSES FOR RELIABILITY ASSESSMENTS In the July 16 , 2009 Budget Compliance Order , FERC stated: With respect to the Reliability Assessment and Performance Analysis Program, the C...
AI summary FERC accepted NERC's proposal to enhance data collection processes for reliability assessments but required a status report in the 2010 business plan. NERC has implemented initiatives described in its 2009 Summer Reliability Assessment and Three-Year ERO Performance Assessment Report.
N-8NERC's Three-Year Electric Reliability Organization Performance Assessment Report 6/29/2010
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ents between NERC and the Regional Entities, and thus the designation of the Regional Entities, in an Order issued April 19, 2007. North American Electric Reliability Corp. , 119 FERC ¶61,060 (2007). NERC and the Regional Entities also dev...
AI summary NERC and Regional Entities conducted a stakeholder survey, receiving responses from 236 entities. The results, including stakeholder concerns and responses, are detailed in Attachment 5. This followed a 2007 order establishing Regional Entities' roles in reliability standards.
A. Background In the wake of the cascading outages that occurred in the Western Interconnection in July and August 1996, concerns regarding the ability of the electric industry to continue to rely exclusively on voluntary means to ensure r...
AI summary The 1996 Western Interconnection outages and the 2003 blackout prompted the U.S. Congress to enact §215 of the FPA via the Energy Policy Act of 2005, establishing mandatory reliability standards for the bulk power system. These standards, enforced by an ERO under FERC, replaced prior voluntary measures and addressed gaps in compliance mechanisms.
B. NERC Has Developed a Comprehensive Body of Reliability Standards for the Bulk Power System Using its American National Standards Institute-accredited and Commission-approved reliability standards development procedure, embodied in Secti...
AI summary NERC has developed a comprehensive set of reliability standards for the bulk power system, approved by FERC. As of May 31, 2009, 95 continent-wide standards were approved, with 94 in effect in the U.S. and several Canadian provinces. These standards cover various areas like resource balancing, communications, and protection and controls, and are developed through an open, stakeholder-driven process.
Section 215 also authorizes FERC to order the Electric Reliability Organization to submit to the Commission a proposed reliability standard or a modification to a reliability standard that addresses a specific matter if the Commission cons...
AI summary Section 215 empowers FERC to direct ERO to propose reliability standards or modifications. FERC emphasizes industry input and Canadian participation to ensure effective, internationally aligned standards. It has expressed concerns about the standards process being slow and producing weak, least-common-denominator outcomes.
and NPCC compliance program costs to Ontario and Québec. See North American Electric Reliability Corporation, Order on Compliance Filing , 128 FERC ¶ 61,025 (2009) (July 16, 2009 Order), at PP 32-42. fair and impartial procedures for the e...
AI summary The text discusses the enforcement of reliability standards by NERC, including fair procedures for compliance monitoring, conflict of interest avoidance, and due process for hearings and appeals related to compliance issues.
F. NERC Has Established Rules That Provide Appropriate Steps to Gain Recognition in Canada and Mexico NERC's Certificate of Incorporation states that one of NERC's corporate purposes is "to act as the electric reliability organization for...
AI summary NERC seeks recognition as the ERO in Canada and Mexico. In Canada, provincial authorities handle electricity regulation, requiring NERC to secure agreements with provinces. Recognition has been achieved in Alberta, Manitoba, New Brunswick, and Ontario. In Mexico, CFE oversees reliability, with WECC agreements in Baja California Norte. NERC continues efforts to enforce reliability standards in remaining provinces.
B. NERC and the Regional Entities Have Developed Effective Business Planning and Budgeting, Accounting and Financial Reporting, and Assessment Processes NERC and the Regional Entities have developed a comprehensive process for developing t...
AI summary NERC and Regional Entities maintain consistent annual business planning and budgeting processes, submitting plans to FERC for approval. These processes, evolved since 2006, enable comparison of budgets to prior years and actual results, with member input opportunities. The formats facilitate transparency across entities and statutory program areas.
C. NERC Has Developed an Effective Set of Rules of Procedure NERC's predecessor organization had rules of procedure in place covering a number of areas of its activities. For purposes of its ERO certification application, NERC organized th...
AI summary NERC's Rules of Procedure, developed and updated post-ERO certification, cover reliability standards, compliance monitoring, and administrative processes. All amendments were submitted to and approved by FERC, ensuring alignment with FPA and FERC regulations. The rules address areas like training, infrastructure security, and information handling.
N-9Northeast Power Coordinating Council, Inc. Criteria Filing 6/30/2010
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VIA FEDERAL EXPRESS Ms. Nancy McNeil Regulatory Affairs Officer/Clerk Nova Scotia Utility and Review Board 1601 Lower Water Street, 3rd Floor Halifax, Nova Scotia B3J 3P6 RE: Application For Approval of Regional Reliability Criteria Dear M...
AI summary Nova Scotia Power Incorporated has submitted an application for the approval of Regional Reliability Criteria in Nova Scotia, in accordance with a 2010 Memorandum of Understanding with the North American Reliability Corporation and the Northeast Power Coordinating Council, Inc.
Margaret Mayora, NPCC 1 BEFORE THE 2 NOVA SCOTIA UTILITY AND REVIEW BOARD 3 OF THE PROVINCE OF NOVA SCOTIA 4 5 6 NORTHEAST POWER ) 7 COORDINATING COUNCIL, INC. ) 8 9 10 11 APPLICATION FOR APPROVAL OF REGIONAL RELIABILITY CRITERIA 12 13 14...
AI summary The Northeast Power Coordinating Council, Inc. (NPCC) is applying for approval of Regional Reliability Criteria by the Nova Scotia Utility and Review Board (NSUARB). The application is supported by a Memorandum of Understanding (MOU) with Nova Scotia Power Incorporated (NSPI) and the North American Reliability Corporation (NERC), aimed at implementing mandatory reliability standards and regional criteria.
1 ensuring that each Regional Standard serves a purpose in support of the reliability of the 2 regional bulk power system. Each Regional Reliability standard shall also be consistent 3 with all of pertinent reliability principles and crite...
AI summary The document discusses the importance of Regional Reliability Standards in supporting the reliability of the regional bulk power system. It mentions the NPCC's PRC-002-NPCC standard and outlines the directories containing reliability criteria, including design, emergency operations, and generator capabilities.
Directory # 12, - Underfrequency Load Shedding Program Requirements 1 Criteria A-8, - Reliability Enforcement and Compliance Program 2 Criteria A-10, - Classification of Bulk Power System Elements 3 Criteria A-15, - Disturbance Monitoring...
AI summary The document outlines the NPCC's request to the NSUARB for approval of the application of Regional Reliability Criteria in Nova Scotia. It includes information on the adoption of these criteria by NPCC members and the submission of the filing by NPCC, with a request for feedback from the Province.
Directory 7, Special Protection Systems Approved, December 27, 2007 Provide the basic criteria for Special Protection Systems such that the Bulk Power System in NPCC Inc. member Areas is operated reliably. The documents outlines the approv...
AI summary Directory 7 establishes criteria for approving Special Protection Systems (SPS) on the NPCC Bulk Power System, categorizing them as Type 1, 2, or 3 based on operational impact. Type 1 SPSs require rigorous examination, analysis, and approvals due to their potential to significantly affect system reliability.
Directory 8, System Restoration Approved, October 21, 2008 The purpose of this Directory is to present the basic criteria with which each applicable entity must plan for and perform power system restoration following a major or a total bla...
AI summary Directory 8 establishes criteria for power system restoration after major blackouts, requiring entities to comply with restoration plans reviewed annually by the NPCC Inc. Task Force. The NPCC's regional restoration plan aggregates reviewed individual plans, ensuring coordination among operating entities.
5.7 Extreme System Conditions Assessment The bulk power system can be subjected to wide range of other than normal system conditions that have low probability of occurrence. One of the objectives of extreme system conditions assessment is...
AI summary The document outlines procedures for assessing extreme system conditions on the bulk power system, including peak load scenarios and fuel shortages. It emphasizes planning studies to evaluate system robustness and dynamic performance, with responsibilities assigned to Transmission Planners and Planning Coordinators. Mitigation measures are discussed, along with a multi-step approval process for revising planning directories through NPCC and RCC.
Appendix B - Guidelines and Procedures for NPCC Area Transmission Reviews
AI summary Appendix B outlines guidelines and procedures for NPCC Area Transmission Reviews, focusing on ensuring reliability, compliance with NERC/IEEE standards, and stakeholder coordination. It emphasizes processes for evaluating transmission system performance, addressing reliability concerns, and aligning with regulatory requirements.
4.0 Types and Frequency of Reviews Each Planning Coordinator is required to present an annual transmission review to TFSS. However, the review presented by the Planning Coordinator may be one of three types: a Comprehensive (or Full) Revie...
AI summary The document outlines three types of annual transmission reviews (Comprehensive, Intermediate, Interim) required for Planning Coordinators, detailing their scope, frequency, and submission timelines. Comprehensive Reviews occur every five years unless system changes necessitate more frequent assessments, while Interim Reviews address minor changes and Intermediate Reviews handle moderate or localized changes. Proposals must be submitted in March, with reports due by year-end or April of the following year.
Review of Exclusions to the Basic Criteria . Review any exclusions granted under the NPCC Guidelines for Requesting Exclusions to Sections 5.4.1(b) and 5.5.1(b) Directory #1 Design and Operation of the Bulk Power System (Appendix F). A Com...
AI summary The document outlines the review of exclusions to the Basic Criteria under NPCC guidelines, emphasizing the need for Comprehensive and Intermediate Reviews. The latter focuses on exclusions impacted by system changes since their last review, ensuring alignment with current system performance.
4.3 Introduction - 4.3.1 Reference the previous NPCC Area Review. - 4.3.2 Compare the proposed resources and load forecast covered in this NPCC review with that covered in the previous review
AI summary The introduction references the previous NPCC Area Review and outlines a comparison between the proposed resources and load forecasts in this review and those from the prior review, focusing on changes in resource planning and demand projections.
B. Other Factors, If Any, Considered in Establishing Reserve Requirement Documentation The documentation required to meet the requirements of the above format should be in the form of summaries of studies performed within a Planning Coordi...
AI summary The documentation for reserve requirements must include summaries of studies conducted within Planning Coordinator Areas, along with references to applicable reports and submissions made to regulatory agencies. This ensures compliance with established regulatory formats and standards.
C. Task Force Follow-Up Procedures Once a specific Planning Coordinator has made a presentation or a series of presentations to the Task Force on Coordination of Planning, the latter shall: - 1. Prepare a brief summary of key issues discus...
AI summary The Task Force on Coordination of Planning must prepare a summary of key issues, note information requests, identify items requiring study, and recommend approval to the Reliability Coordinating Committee (RCC) following presentations by a Planning Coordinator.
1.0 Introduction The Northeast Power Coordinating Council (NPCC) was formed to promote the reliability and efficiency of electric service of the interconnected bulk power system of the members of the NPCC by extending the coordination of t...
AI summary The Northeast Power Coordinating Council (NPCC) ensures reliability and efficiency of the interconnected bulk power system through standardized design and operation criteria. Specific contingencies, such as simultaneous faults on multi-circuit towers, are addressed with risk-based exclusion procedures requiring Reliability Coordinating Committee (RCC) approval. Directory #1 outlines these standards and exclusion processes.
3.0 Procedure for obtaining an Exclusion The following procedure shall be used in obtaining exclusion to Sections 5.4.1(b) or 5.5.1(b) of Directory #1: - 3.1 The entity requesting the exclusion (the Requestor) shall submit the request and...
AI summary The procedure outlines steps for requesting exclusions from specific directory sections, involving submission to TFSS, review by multiple task forces, and RCC approval. NPCC's alternative dispute resolution policy is referenced for unresolved disputes.
4.2 Facilities Notification List The NPCC Facilities Notification List, Attachment D, has two components: - 1) the NPCC Transmission Facilities Notification List; and - 2) the list of NPCC Type I special protection systems . The Facilities...
AI summary The NPCC Facilities Notification List includes transmission facilities and Type I special protection systems, updated annually by RC Areas with coordination via TFCO and TFSP. Revisions are handled securely due to sensitive information, and temporary network changes may impact unlisted facilities, requiring timely RC notifications.
shall also provide the TFSP with advance notification of non-member protection facilities as required per NPCC Bylaws . Notification will be made to the TFSP early in the engineering design stage. - 4.1 Additional Requirements for Presenta...
AI summary The document outlines requirements for notifying the Task Force on System Protection (TFSP) about protection facilities, including presentations during design stages and submission of detailed data. It specifies criteria for reviewing protection systems, relaying configurations, and equipment details as per NPCC bylaws.
4.4 TFSP Procedures - 4.4.1 The TFSP will review the material presented and develop a position statement concerning the proposed protection system . This statement will indicate one of the following: - 4.4.1.1 The need for additional infor...
AI summary The TFSP reviews proposed protection systems and issues position statements indicating acceptance, conditional acceptance, rejection, or the need for additional information. Nonconformance areas are documented in minutes, letters to owners, or referrals to the RCC. Reviews are recorded for transparency and compliance with NPCC criteria.
ded, manual vs. automatic, etc. - . Reason for the installation - . Comments, explanations, such as "temporary until such time…" - . Company, owner - . SPS Number, drawn by NPCC staff - . Current Status, i.e. New, Changed or Removed - . Ty...
AI summary The document outlines procedures for installing, modifying, or retiring Special Protection Systems (SPS), emphasizing review by the Reliability Coordinating Committee (RCC) and Task Force on Coordination of Planning (TFCP). It details requirements for reporting SPS changes, determining system types, and updating NPCC databases.
3.6 Review by TFSP The TFSP will review the material presented and develop a position statement concerning the proposed protection system. This statement will indicate one of the following: - 3.6.1 The need for additional information to en...
AI summary The TFSP will review a proposed protection system and issue a position statement indicating acceptance, conditional acceptance, rejection, or a need for additional information. Nonconformance with NPCC criteria may trigger corrective recommendations. Results will be documented in meeting minutes and letters to TO, GO, or DP.
7.0 Compliance Monitoring Adherence to these Criteria shall be reported by the responsible entity in a manner and form designated by the Compliance Committee. ________________________________________________________________________ Prepare...
AI summary Compliance with criteria is mandated by the Compliance Committee, with revisions requiring NPCC Open Process review, RCC approval, and updates every three years to align with NERC standards. Task Forces on Coordination of Operation and System Studies lead the process, involving Full Member Representatives for final approval.
ata, or performance tracking for the same previous seasonal verification period for this generator or generation facility. For new generators only, the Generator Owner shall submit commissioning data. - 1. Adverse impact on transmission sy...
AI summary The text outlines requirements for Generator Owners to submit commissioning data for new generators, exemptions for verification testing, and obligations to document and report verified power capabilities. Transmission Operators must notify exemptions and manage discrepancies in declared versus verified capabilities, with resolution plans required.
- 3. Governmental regulatory or operating license limitations - 5.5.2 The Transmission Operator shall, within 30 days of receiving notification by a Generator Owner that it cannot perform verification testing for the required seasonal peri...
AI summary The text outlines procedures for exempting generators from seasonal capability testing, requiring performance data submission, and reporting discrepancies in reactive power capabilities. Generator Owners must coordinate with the Transmission Operator to reschedule testing and provide verified data, ensuring compliance with seasonal auxiliary load reporting requirements.
NPCC Regional Reliability Reference Directory # 12 Under frequency Load Shedding Program Requirements Task Force on Coordination of Operations Revision Review Record: June 26th, 2009 March 3rd, 2010 Adopted by the Members of the Northeast...
AI summary The NPCC adopted the Under Frequency Load Shedding Program Requirements on June 26, 2009, following the Reliability Coordinating Committee's recommendation. The adoption aligns with the NPCC's amended bylaws dated July 24, 2007, addressing regional reliability and coordination of operations.
5.5 UFLS Program Assessment Requirements - 5.5.1 Studies shall be performed by the associated Transmission Operator to ensure satisfactory voltage and loading conditions after automatic load shedding . - 5.5.2 The Task Force on System Stud...
AI summary Section 5.5 outlines requirements for UFLS program assessments, including studies by Transmission Operators to ensure voltage/loading conditions post-load shedding and triennial coordination by the Task Force on System Studies with NPCC Balancing Authorities. Compliance monitoring is mandated, with revisions to the NPCC Directory requiring RCC and Full Member approval.
1.0 Introduction The NPCC Glossary of Terms (the Glossary) originated as Appendix A to the Criteria for Review and Approval of Documents (Document A-1). It includes terms from NPCC Criteria (A), Guideline (B) and Procedure (C) Documents, a...
AI summary The NPCC Glossary of Terms originated as Appendix A to the Criteria for Review and Approval of Documents. It incorporates terms from NPCC, NERC, and IEEE sources, with definitions organized alphabetically and sub-definitions under main terms.
1.1 Non- member Facilities A Member, through whose facilities a non-member connects with or proposes to connect with the NPCC Inc. bulk power system shall use its best efforts to assure that the arrangements for such connection are consist...
AI summary A Member must ensure non-member connections to the NPCC Inc. bulk power system comply with NPCC Inc. bylaws and criteria. This requirement emphasizes alignment with established reliability and operational standards for interconnections.
2.3 Review of Appendix A Requirements CMAS, in conjunction with the appropriate NPCC Inc. Task Forces, shall annually review the requirements included in Appendix A to assure that the effectiveness of the Reliability Compliance and Enforce...
AI summary The document outlines annual reviews of Appendix A requirements by CMAS and NPCC Task Forces to ensure the Reliability Compliance and Enforcement Program's effectiveness. Task Forces must recommend amendments to Appendix A based on NPCC Criteria Document reviews, with CMAS submitting proposals for RCC endorsement and NPCC approval.
Full (100%) Compliance An annual Area Transmission Review Report, including all supporting documentation in accordance with Document B-4 was submitted to TFSS and the Area's planned bulk power system meets the requirements of Document A-2....
AI summary The Area submitted an annual Area Transmission Review Report to TFSS, complying with Document B-4 and A-2 requirements. Reports for Interim/Intermediate Reviews must be submitted by year-end, while Comprehensive Reviews by April 1st of the following year.
4.1 Addition of Elements to the Bulk Power System List When application of this methodology identifies an element that was not part of the bulk power system should be classified as a bulk power system element , documentation of the analysi...
AI summary The process for classifying and adding new elements to the Bulk Power System (BPS) List involves TFSS analysis, RCC approval, and TFSP compliance planning. Once approved, all task forces and the Compliance Committee are notified, and a compliance plan must be submitted within three months.
4.2 Re moval of Elements from the Bulk Power System List When application of this methodology identifies a bulk power system element that no longer should be classified as a bulk power system element , documentation of the analysis shall b...
AI summary The process for removing elements from the NPCC Bulk Power System List involves submitting analysis to TFSS, with reclassification requiring RCC approval. Task forces including TFSS, TFCO, TFSP, and TFIST review the process, which is evaluated every four years using referenced documents.
Disturbance Monitoring Equipment Criteria Adopted by the Members of the Northeast Power Coordinating Council on August 23, 2007 based on recommendation by the Reliability Coordinating Committee, in accordance with paragraph IX, subheading...
AI summary The Northeast Power Coordinating Council (NPCC) adopted Disturbance Monitoring Equipment (DME) criteria on August 23, 2007, following a recommendation by the Reliability Coordinating Committee (RCC), in accordance with the NPCC's Amended and Restated Bylaws dated July 24, 2007.
N-10Reliability Standards of the North American Electric Reliability Corporation 7/5/2010
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VIA ELECTRONIC FILING Nancy McNeil Regulatory Affairs Officer/Clerk Nova Scotia Utility and Review Board 3rd Floor 1601 Lower Water Street Halifax, Nova Scotia B3J 3P6 Re: North American Electric Reliability Corporation Dear Ms. McNeil: Th...
AI summary The North American Electric Reliability Corporation (NERC) submits an application for approval of its reliability standards to the Nova Scotia Utility and Review Board. The submission includes contact details for NERC's attorney, Davis Smith, and the Board's regulatory affairs officer, Nancy McNeil.
harged with developing mandatory and enforceable Reliability Standards, which are subject to FERC review and approval. & lt;sup>3 16 U.S.C. § 824o(f) (2006). & lt;sup>4 See Memorandum of Understanding between Nova Scotia Utility and Review...
AI summary The document discusses the implementation of NERC Reliability Standards and NPCC Regional Reliability Criteria in Nova Scotia, referencing memoranda of understanding between the Nova Scotia Utility and Review Board and NERC, as well as between Nova Scotia Power Incorporated and the Northeast Power Coordinating Council and NERC.
A. NERC Filing of All Proposed Reliability Standards NERC is filing all FERC approved Reliability Standards for approval by the NSUARB. The Reliability Standards, in the instant filing, are provided in two parts. The first part consists of...
AI summary NERC is filing FERC-approved reliability standards with the NSUARB, distinguishing between current and future effective standards. It requests approval of associated VRFs and VSLs, which determine penalties for noncompliance. NERC excludes the full developmental record due to its volume but commits to making it available upon request. It emphasizes collaboration with the NSUARB to address Canadian and provincial issues.
A. Benchmarks of an Excellent Reliability Standard To translate the attributes stated above into objective measures, NERC has adopted ten benchmarks for use in the development of Reliability Standards. NERC believes these benchmarks, descr...
AI summary NERC outlines ten benchmarks for reliability standards, emphasizing applicability to specific entities, clear purpose, and performance requirements. It urges the NSUARB to consider these benchmarks when evaluating proposed standards, focusing on system reliability and compliance.
e repeated, although experience indicates that even the most complex standards converge within two or three postings. More narrowly defined projects can be completed with a single posting for comment. - Each standard is reviewed to determi...
AI summary The text outlines a structured process for developing reliability standards, emphasizing stakeholder engagement, field testing criteria, ballot procedures, and approval requirements. It details iterative commenting, ballot formation, and the use of weighted voting to ensure balanced stakeholder interests in standard approval.
VI. CONCLUSION By this filing, NERC requests that the NSUARB approve the Reliability Standards and NERC Glossary of Terms used in Reliability Standards, as set out in Exhibits C and E. NERC also requests that the NSUARB approve the VRFs an...
AI summary NERC requests NSUARB approval of Reliability Standards, associated Glossary of Terms, VRFs, and VSLs (Exhibits C, E, F, G). NERC also seeks feedback from the Province of Nova Scotia on information adequacy and guidance for future filings.
Applicability: - Balancing Authorities - Reserve Sharing Groups (Balancing Authorities may meet the requirements of Standard 002 through participation in a Reserve Sharing Group.) - Regional Reliability Organizations On January 7, 2005, BA...
AI summary The text outlines the approval history of BAL-002-0 by NERC, FERC, and a registered ballot body, along with the description of Standard BAL-003-0.1b, which establishes a method for calculating the Frequency Bias component of ACE.
Applicability: • Balancing Authorities On October 29, 2008, BAL-003-0.1b was approved by the NERC Board of Trustees. On May 13, 2009, BAL-003-0.1b was approved by the Federal Energy Regulatory Commission. Version BAL-003-0.1b resulted from...
AI summary The document outlines the approval history of BAL-003-0.1b by NERC and FERC, noting its derivation from BAL-003-0 via errata and interpretation changes. It also introduces BAL-004-0, which mandates Time Error Corrections to maintain Interconnection reliability.
Current Reliability Standards and NERC Glossary of Terms for Approval
AI summary The document outlines the current reliability standards and the NERC Glossary of Terms for approval, detailing key terms and standards relevant to electric reliability in Nova Scotia. It emphasizes compliance with protocols and terminology governed by NERC and related regulatory bodies.
Version History Version Date Action Change Tracking 0 February 8, 2005 BOT Approval New 0 April 1, 2005 Effective Implementation Date New 0 August 8, 2005 Removed "Proposed" from Effective Date Errata 0 July 24, 2007 Corrected R3 to refere...
AI summary The document outlines the version history of a regulatory standard, detailing multiple revisions, corrections, and approvals by the NERC Board of Trustees and FERC. Key changes include errata corrections, effective date updates, and appendices added.
Standard BAL-003-0.1b — Frequency Response and Bias 2007 approved by BOT on October 23, 2007 0a January 16, 2008 Section F: added "1."; changed hyphen to "en dash." Changed font style for "Appendix 1" to Arial. Errata 0b February 12, 2008...
AI summary The document outlines the history and approvals of Standard BAL-003-0.1b, focusing on frequency response and bias. Key updates include errata changes approved by the NERC Board of Trustees in 2008 and FERC approval in 2009, with effective dates and version updates documented.
Appendix 1 Request: PGE requests clarification regarding the measuring devices for which the requirement applies, specifically clarification if the requirement applies to the following measuring devices: - Only equipment within the operati...
AI summary PGE seeks clarification on the scope of measuring device requirements, specifically whether they apply to equipment in control rooms, AGC ACE calculations, SCADA systems, BA-owned equipment, new/replacement devices, or all BA-operated equipment.
4. Applicability: 4.1. Balancing Authorities. 5. Effective Date: Immediately after approval of applicable regulatory authorities
AI summary Section 4 outlines the applicability of regulations, focusing on Balancing Authorities and specifying that the effective date follows approval by applicable regulatory authorities. The text emphasizes procedural timelines tied to regulatory oversight.
E. Regional Differences 1. MISO RTO [Inadvertent Interchange Accounting](http://www.nerc.com/docs/standards/sar/Waver_Inadvertant_Interchange_Accounting.pdf) Waiver approved by the Operating Committee on March 25, 2004. This regional diffe...
AI summary A waiver for MISO RTO's Inadvertent Interchange Accounting was approved by the Operating Committee on March 25, 2004, and later extended to include SPP effective May 1, 2006, reflecting regional differences in regulatory standards.
Version History Version Date Action Change Tracking 0 April 1, 2005 Effective Date New 0 August 8, 2005 Removed "Proposed" from Effective Date Errata 1 November 1, 2006 Adopted by Board of Trustees Amended A. Introduction
AI summary The document outlines the version history of a regulatory proceeding, including effective dates and amendments made by the Board of Trustees. It provides a record of changes over time, starting from April 1, 2005, with subsequent updates in August 2005 and November 2006.
4. Applicability - 4.1. Balancing Authorities. - 4.2. Reliability Coordinators. - 4.3. Load-Serving Entities. - 5. Effective Date: May 13, 2009
AI summary The document outlines the applicability of regulations to Balancing Authorities, Reliability Coordinators, and Load-Serving Entities, with an effective date of May 13, 2009.
Version History Version Date Action Change Tracking 0 April 1, 2005 Effective Date New 0 August 8, 2005 Removed "Proposed" from Effective Date Errata 1 September 19, 2006 Changes R7. to refer to "Requirement 6" instead of "Requirement 7" E...
AI summary The document outlines the version history of a regulatory proceeding, detailing amendments and approvals. Key changes include errata corrections, numbering adjustments, and adoption by the Board of Trustees (BOT) and Federal Energy Regulatory Commission (FERC) approval in 2009.
NERC Interconnection Reliability Operating Limit and Preliminary Disturbance Report 1. Organization filing report. 2. Name of person filing report. 3. Telephone number. 4. Date and time of disturbance. Date:(mm/dd/yy) Time/Zone: 5. Did the...
AI summary This document is a template for reporting disturbances related to the NERC Interconnection Reliability Operating Limit. It includes sections for filing details, disturbance description, generation and transmission impacts, and restoration times. It also references the U.S. Department of Energy's disturbance reporting requirements under EOP-004.
All DOE OE-417 Schedule 2 reports are to be filed within 48-hours after the start of an incident or disturbance
AI summary The document specifies that all DOE OE-417 Schedule 2 reports must be filed within 48 hours following the start of an incident or disturbance.
All entities required to file a DOE OE-417 report (Schedule 1 & 2) shall send a copy of these reports to NERC simultaneously, but no later than 24 hours after the start of the incident or disturbance. Incident No. Incident Threshold Report...
AI summary The text outlines the requirements for entities to file DOE OE-417 reports with NERC within 24 hours of an incident or disturbance. It also provides a table detailing various incident types, thresholds, and reporting requirements, including the types of reports and timeframes for submission.
5. Effective Dates: - 5.1. One calendar year from the date of adoption by the NERC Board of Trustees for Requirements 1 and 2. - 5.2. Sixty calendar days from the date of adoption by the NERC Board of Trustees for Requirements 3 and 4.
AI summary The effective dates for NERC requirements are set at one calendar year from adoption for Requirements 1 and 2, and sixty calendar days from adoption for Requirements 3 and 4, as determined by the NERC Board of Trustees.
E. Regional Differences 1. MISO Energy Flow Information Waiver effective on July 16, 2003.
AI summary The document mentions a MISO Energy Flow Information Waiver effective July 16, 2003, highlighting a regulatory action related to energy flow information.
4. Applicability: 4.1. Interchange Authority. 5. Effective Date: August 27, 2008. (U.S.) NERC Board Approval: May 2, 2007
AI summary The applicability section outlines the Interchange Authority under NERC standards, effective August 27, 2008 (U.S.), with NERC Board approval on May 2, 2007. It references compliance with reliability standards and regulatory oversight.
Standard INT-005-2 — Interchange Authority Distributes Arranged Interchange 2 May 2, 2007 Approved by BOT Revised 2 July 21, 2008 Approved by FERC Revised Timing Table
AI summary The document outlines the approval history of Standard INT-005-2 — Interchange Authority Distributes Arranged Interchange, including approvals by the Board of Trustees (BOT) and the Federal Energy Regulatory Commission (FERC) on specific dates.
Version History Version Date Action Change Tracking 0 April 1, 2005 Effective Date New 0 August 8, 2005 Removed "Proposed" from Effective Date Errata 1 August 8, 2005 Revised Attachment 1 Revision 3 February 26, 2007 Revised Purpose and At...
AI summary This version history outlines the evolution of a document, including changes and approvals over time, with key updates such as revisions to attachments, corrections to URLs, and approvals by the Board of Trustees and FERC.
Total Flow Value on a Constrained Facility for Next Hour - 1. The Reliability Coordinator will calculate the change in net flow on a Constrained Facility due to Reallocation for the next hour based on: - Present constrained facility loadin...
AI summary The Reliability Coordinator calculates net flow changes on constrained facilities, manages Interchange Transactions, and uses TLR levels to avoid SOL/IROL violations. Procedures include simultaneous curtailment/reallocation, prioritizing higher-priority transmission, and reloading transactions promptly to prevent recurrence of violations.
Transaction Sub-Priority Examples The following describes examples of Interchange Transactions using Non-firm Transmission Service subpriority setting for an Interchange Transaction under different circumstances of current-hour and nexthou...
AI summary The text provides examples of Interchange Transactions using Non-firm Transmission Service subpriority settings under various scheduling and operational conditions, as modified by the E-Tag tag adjust table. It was approved by the Board of Trustees on April 15, 2009.
Sub-priorities for Transaction MW: Sub-Priority MW Value Explanation S1 10 MW Maintain current curtailed flow S2 +10 MW Reload to current hour Energy Profile S3 +20 MW Load to next hour Energy Profile S4 Approved by Board of Trustees: Apri...
AI summary The text outlines sub-priorities for Transaction MW, including maintaining current curtailed flow, reloading to the current hour's energy profile, and loading to the next hour's energy profile. It also notes the approval by the Board of Trustees on April 15, 2009, with an effective date of December 10, 2009.
Sub-priorities for Transaction MW: Sub-Priority MW Value Explanation S1 10 MW Maintain current curtailed flow S2 +10 MW Reload to lesser of current and next-hour Energy Profile S3 +0 MW Next-hour Energy Profile is 20MW, so no change in MW...
AI summary The text outlines sub-priorities for Transaction MW with specific MW values and explanations, including maintaining current curtailed flow and reloading based on the Energy Profile. The document was approved by the Board of Trustees on April 15, 2009, and became effective on December 10, 2009.
Standard NUC-001-2 — Nuclear Plant Interface Coordination and footnote 1; modifications to bring compliance elements into conformance with the latest version of the ERO Rules of Procedure. 2 August 5, 2009 Adopted by Board of Trustees Revi...
AI summary This section introduces Standard NUC-001-2, which focuses on nuclear plant interface coordination. It outlines the adoption and revision history of the standard by the Board of Trustees and FERC, highlighting updates and compliance with the ERO Rules of Procedure.
Version History Version Date Action Change Tracking 0 April 1, 2005 Effective Date New 0 August 8, 2005 Removed "Proposed" from Effective Date Errata 1 November 1, 2006 Adopted by Board of Trustees Revised Adopted by Board of Trustees: Nov...
AI summary The document outlines the version history of a regulatory proceeding, including effective dates, errata, and adoption by the Board of Trustees on November 1, 2006, with an effective date of January 1, 2007.
Question #2 Are there specific actions required to implement a "study"? In other words, what constitutes a study?
AI summary The question seeks clarification on the definition and implementation requirements for a 'study' within the regulatory proceeding context, focusing on specific actions and criteria that constitute a study.
4. Applicability: - 4.1. Transmission Operators. - 4.2. Reliability Coordinators. - 5. Effective Date: April 1, 2005
AI summary The applicability section outlines that the regulations apply to Transmission Operators and Reliability Coordinators, with an effective date of April 1, 2005.
4. Applicability: - 4.1. Transmission Operators. - 4.2. Purchasing-Selling Entities. - 5. Effective Date: Six months after BOT adoption.
AI summary Section 4 outlines applicability to Transmission Operators and Purchasing-Selling Entities. Section 5 sets an effective date of six months after Board of Trustees (BOT) adoption, establishing procedural timelines for implementation.
1 See 18 CFR 37.6(b)(1) Continent-wide Term Acronym BOT Approved Date FERC Approved Date Definition Balancing Authority [Archive] BA 2/8/2005 3/16/2007 The responsible entity that integrates resource plans ahead of time, maintains load-int...
AI summary The text provides definitions and approval dates for various terms related to electric power systems, including Balancing Authority, Balancing Authority Area, Base Load, and Blackstart Capability Plan. It includes references to regulatory approvals by the BOT and FERC.
The following definitions were developed for use in WECC Regional Standards. WECC Regional Term Acronym BOT Approved Date FERC Approved Date Definition Functionally Equivalent RAS [Archive] FERAS 10/29/2008 A Remedial Action Scheme ("RAS")...
AI summary This document outlines definitions used in WECC Regional Standards, including terms such as Functionally Equivalent RAS, Security-Based Misoperation, Dependability-Based Misoperation, Commercial Operation, and Qualified Transfer Path Curtailment Event, with approval dates and descriptions provided.
Endnotes April 20, 2010 Page 51 of 51 † FERC approved the WECC Tier One Reliability Standards in the Order Approving Regional Reliability Standards for the Western Interconnection and Directing Modifications, 119 FERC ¶ 61,260 (June 8, 200...
AI summary FERC approved WECC's Tier One Reliability Standards in 2007, directing WECC to resolve inconsistencies with NERC's glossary. Replacement standards addressing these issues were filed with FERC in 2009.
Implementation Schedule The following tables identify when Responsible Entities must Begin Work (BW) to become compliant with a requirement, Substantially Compliant (SC) with a requirement, Compliant (C) with a requirement, and Auditably C...
AI summary The document outlines an implementation schedule for Responsible Entities under NERC Functional Model standards, detailing compliance stages such as Begin Work, Substantially Compliant, Compliant, and Auditably Compliant. Different tables apply to various entity types, including Balancing Authorities, Transmission Operators, and Generating Plants.
Table 1 Compliance Schedule for Standards CIP-002-1 through CIP-009-1 Balancing Authorities and Transmission Operators Required to Self-certify to UA Standard 1200, and Reliability Coordinators End of 2nd Qtr 2007 End of 2nd Qtr 2008 End o...
AI summary The table outlines a compliance schedule for various standards (CIP-002-1 through CIP-009-1) related to cybersecurity and reliability in the electricity sector, specifying deadlines for Balancing Authorities, Transmission Operators, and Reliability Coordinators to self-certify to UA Standard 1200.
Future Reliability Standards and List of Effective Dates for Approval Future Standards Future Effective Date CIP-002-3 10/1/2010 - See Exhibit D - CIP Implementation Plan CIP-003-3 10/1/2010 - See Exhibit D - CIP Implementation Plan CIP-00...
AI summary This document outlines future reliability standards and their effective dates for approval, focusing on CIP and INT standards, with implementation plans and specific dates provided for each standard.
Timing Requirements for WECC A В С D If Arranged Interchange (RFI) 4 is Submitted IA Assigned Time Classification IA Makes Initial Distribution of Arranged Interchange BA and TSP Conduct Reliability Assessments IA Compiles and Distributes...
AI summary The document outlines timing requirements for the Western Electricity Coordinating Council (WECC) related to the submission and processing of Arranged Interchange (RFI) requests. It specifies different time classifications (ATF, Late, On-time) and the corresponding actions and response times for various entities such as the Independent Administrator (IA), Balancing Authority (BA), and Transmission Service Provider (TSP).
2.Violation Severity Levels R # Lo V S L w er M de V S L te o ra H ig h V S L Se V S L ve re R 5. / N A / N A / N A T he Tr iss ion Se ice an sm rv Pr i de d i d ke he t m t ov r no a A T C I D i la b le he ies to t t av a p ar de i be d i...
AI summary The document outlines violation severity levels, with a focus on a high severity level violation related to transmission service and the provision of information. The text references a specific regulation (R4) and mentions a failure to provide information that was required.
e s r e ac f he 2 hr h 1 0 t t o y ea rs ou g m or e ha 1 3 hs bu t t t n t m n m on o or e , ha 1 6 hs f he la t t ter t t n m on a s , im he lu t t e v a es w er e b l is he d. ta es O R T he Tr iss io P lan i h t an sm n ne r w ia d Tr...
AI summary The text discusses violation severity levels, referencing the Trissio Plan and related matters, including a failed CBM (Cost-Benefit Model) and a reference to R6.1. The content appears to be related to regulatory processes and compliance.
2. Violation Severity Levels: Requirement Lower Moderate High Severe R1 Evidence that relay settings comply with criteria in R1.1 though 1.13 exists, but evidence is incomplete or incorrect for one or more of the subrequirements. Relay set...
AI summary The document outlines violation severity levels for compliance with specific requirements related to relay settings and the management of facilities critical to the Bulk Electric System. It defines criteria for lower, moderate, high, and severe violations under different requirements.
Matrix of Violation Risk Factors for Approval Standard Number Requirement Text of Requirement Violation BAL-002-0 R5.1. The Reserve Sharing Group reviews group ACE (or equivalent) and demonstrates compliance to the DCS. To be in compliance...
AI summary The document presents a matrix outlining violation risk factors for approval, focusing on the BAL-002-0 standard. It details a requirement related to the Reserve Sharing Group demonstrating compliance with the Disturbance Recovery Criterion after implementing reserve sharing schedule changes within the Disturbance Recovery Period.
Matrix of Violation Severity Levels for Approval Standard Number Requirement Number Text of Requirement Lower VSL Moderate VSL High VSL Severe VSL BAL-001-0.1a R1. Each Balancing Authority shall operate such that, on a rolling 12- month ba...
AI summary The document outlines a matrix defining violation severity levels (VSL) for compliance with the BAL-001-0.1a standard, focusing on the performance of Balancing Authorities based on their CPS1 values. The matrix categorizes severity into lower, moderate, high, and severe levels based on the CPS1 percentage.
NERC Approved Reliability Standards Pending At FERC Date Filed with FERC NERC Approved Reliability Standards Pending at FERC April 21, 2010 CIP-005-2a April 21, 2010 CIP-001-1a April 20, 2010 CIP-006-2c December 31, 2009 IRO-008-1 IRO-009-...
AI summary This document lists NERC-approved reliability standards that are pending approval at FERC, with dates filed and the corresponding standards. Some standards are noted as being retired upon FERC approval of specific filings.
N-13NSPI's recommendations with respect to NERC's and NPCC's filings
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RECEIVE DEC 1 7 2010 December 17, 2010 Nova Scotia Utility and Review Board Nancy McNeil Regulatory Affairs Officer/Clerk Nova Scotia Utility and Review Board 1601 Lower Water Street, 3 rd Floor PO Box 1692, Unit "M" Halifax, NS B3J 3S3 Re...
AI summary The document outlines filings by the Northeast Power Coordinating Council (NPCC) and North American Electric Reliability Corporation (NERC) requesting approval of reliability standards and criteria. Nova Scotia Power Inc. (NSPI) intervened, and the Utility and Review Board (UARB) accepted a timeline for the proceeding, with NSPI submitting recommendations.
Background This matter has arisen as a result of the DARB having signed a Memorandum of Understanding with NERC dated December 22, 2006 wherein the UARB and NERC committed to a process for making NERC Reliability Standards mandatory, and a...
AI summary The document outlines Memoranda of Understanding (MOUs) between DARB, UARB, NERC, NSPI, and NPCC regarding NERC Reliability Standards. NSPI asserts compliance with these standards through audits and maintains its bulk power system infrastructure.
Process for Approval of Standards in the Future NSPI's comments in this recommendation are specific to the Reliability Criteria and Reliability Standards filed by NPCC and NERC on June 29, 2010 and June 30, 2010. From time to time, amendme...
AI summary NSPI's comments address the approval process for reliability standards by NPCC and NERC, with an MOU ensuring NSPI's involvement in recommending amendments. NERC commits to notifying the UARB of reliability standard milestones, filing proposals, and coordinating with jurisdictions.
2. CI 40233 - 2011 Protections Upgrades at Tufts Cove In 2008, NPCC approved new criteria (Criteria Document A-IO) for determining whether a substation bus is categorized as bulk power. The criteria is used to identify substation busses th...
AI summary The NPCC established criteria requiring upgrades to the Tufts Cove substation bus for redundancy. NSPI states that UARB approval of NERC and NPCC standards would not automatically approve capital expenditures, which would still require regulatory review under ACE guidelines.
Bulk Electric System Definition Within the NPCC, the definition of Bulk Electric System (BES) has been focused on system elements which could potentially affect system reliability in other jurisdictions. For Nova Scotia, this has been·gene...
AI summary The NPCC defines BES as 345 kV and 230 kV systems, but FERC proposes a 100 kV 'bright-line' standard. Canadian NPCC members, including NSPI, oppose this, citing potential cost increases without reliability benefits. NSPI warns that adopting the standard may require proposing an alternative approach in Nova Scotia.
Recommendation NSPI recommends that the UARB approve the NERC Reliability Standards as requested in its application of June 30, 2010 and the NPCC Reliability Criteria as requested in its application of June 29, 2010. NERC has also requeste...
AI summary NSPI recommends the UARB approve NERC and NPCC reliability standards but opposes approval of VRFs and VSLs, arguing the UARB can independently assess compliance impacts without formal approval. NSPI emphasizes the UARB's discretion in evaluating reliability violations.
General Provisions This Memorandum of Understanding (MOU) between the Nova Scotia Utility and Review Board (Board) and the North American Electric Reliability Corporation (NERC) reflects the desire for a continuing and cooperative relatio'...
AI summary This Memorandum of Understanding (MOU) establishes a cooperative relationship between the Nova Scotia Utility and Review Board (UARB) and NERC to enhance North American bulk power system reliability. It outlines the UARB's regulatory authority under the Nova Scotia Public Utilities Act and NERC's role in developing reliability standards, while clarifying the MOU's non-enforceable nature and mutual expectations regarding standard enforcement and cost allocation.
Development of an Electric Reliability Organization The parties understand that NERC has been certified by the U-S_ Federal Energy Regulatory Commission as the "electric reliability organization" (ERO) under U.S. legislation. NERC agrees t...
AI summary NERC is certified by FERC as the Electric Reliability Organization (ERO) under U.S. legislation. NERC agrees to consult with the Board on bylaw amendments to address Canadian and provincial issues, reflecting the international nature of the North American bulk electric system.
Development of Reliability Standards NERC and the Board acknowledge the importance of the active pclliicipation of electricity sector participants from the Province in NERCls standadls development process. NERC commits to notify the Board...
AI summary NERC and the Board outline a collaborative process for developing reliability standards, including NERC's obligation to notify the Board of milestones, file proposed standards, and coordinate with other jurisdictions. The Board may adopt, remand, or separately adopt standards based on public interest considerations.
Points of Contact The points of contact shall be for NERC: David Cook Vice President &General Counsel 116-390 Village Blvd. Princeton. New Jersey 08540 (609) 452-8060 and for the Board: Regulatory Affairs Clerk/Officer Nova Scotia Utility...
AI summary The document outlines contact details for NERC and the Nova Scotia Utility and Review Board (UARB), specifying that these points of contact may be amended by mutual notification. NERC agrees to include the Board's contact information on its email circulation list.
13 2. Development and Application of NERC Reliability Standards and NPCC Regional Reliability 14 Criteria 15 - 16 In accordance with NSPI's designation as a Registered Entity, NSPI agrees to comply with NERC 17 Reliability Standards and NP...
AI summary NSPI agrees to comply with NERC and NPCC reliability standards and criteria. Upon NSUARB approval, these will be mandatory in Nova Scotia. NERC and NPCC will submit consolidated filings for NSUARB approval, including all approved standards and criteria.
Responsibilities and Timeline - 25 NERC and NPCC shall endeavour to file the NERC Reliability Standards and NPCC Regional Reliability - 26 Criteria, for approval, with the Board by no later than the end of Q2 2010. In this and subsequent f...
AI summary NERC and NPCC must file reliability standards with the NSUARB by Q2 2010, with NSPI reviewing and recommending actions such as approval, requesting information, or remanding. NSPI will consult NERC/NPCC and file its recommendation by year-end, proposing a timeline for NSUARB approval.
Notification and Approval of Amendments and/or Additions to NERC Reliability Standards and NPCC Regional Reliability Criteria The signatories anticipate that there will be ongoing amendments and/or additions made to the NERC Reliability St...
AI summary The document outlines a process for approving amendments to NERC Reliability Standards and NPCC Regional Reliability Criteria in Nova Scotia. NERC and NPCC must notify NSUARB and NSPI of proposed changes, with NSPI providing recommendations for approval. This ensures alignment with reliability requirements before implementation.
N-16NERC Responses to Information Requests (IR-1 to IR-16) issued by NSPI 2/10/2011
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Response to IR-2: In summary, in the United States, once a Reliability Standard or revision to a Reliability Standard is approved by the ballot pool in accordance with the it is submitted for approval by the NERC Board of Trustees (Board)....
AI summary The U.S. approval process for NERC Reliability Standards requires ballot pool approval, NERC Board of Trustees endorsement, and FERC final approval. A quorum (75% ballot pool response) and two-thirds majority of weighted segment votes are required for standard approval.
Response to IR-3: The process for approving a NERC Reliability Standard in Canada is the same as the process in the United States. In summary, once a Reliability Standard or revision to a Reliability Standard is approved by the ballot pool...
AI summary NERC explains that its reliability standard approval process in Canada mirrors the U.S. process, involving Board approval followed by submission to Canadian regulators. NERC emphasizes its mission to ensure mandatory adoption of standards and effective oversight in Canada. Compliance Notices are clarified as guidance, not new requirements, with questions about their applicability in Nova Scotia and potential conflicts with UARB-approved standards.
Response to IR-5: 23 24 (a) A Compliance Application Notice (CAN) provides compliance ~UJ,","u.J,J."'''' applies broadly. The target audience for each CAN is identified in the Primary Interest Group section ofthe CAN. 27 28 29 26 (b) No. N...
AI summary NERC clarifies that its Compliance Application Notices (CANs) do not require regulatory approval, do not establish new reliability standards, and compliance is determined by NERC's existing standards. NERC Alerts require acknowledgment but not UARB approval, with UARB-approved standards taking precedence in conflicts. Compliance failures under NERC Alerts are subject to enforcement by NSUARB.
Compliance Accountability in Nova Scotia NSPI, as a Registered Entity, will be subject to NERC's Compliance Monitoring and Enforcement Program ("CMEP") as implemented by NPCC. NPCC in its determination of a NSPI violation may identify the...
AI summary NSPI must comply with NERC's CMEP via NPCC, which assesses violations, risk factors, and severity levels. NPCC may propose non-monetary penalties to the NSUARB, with the Board determining enforcement actions. NERC and NPCC's roles in Canadian enforcement and capital applications are addressed in responses to interrogatories.
Response to IR-14: In summary, once a Reliability Standard or revision to a Reliability Standard is approved by the ballot pool in accordance with the it will be submitted for approval by the Board. After receiving Board approval, the Reli...
AI summary The process for approving reliability standards in Nova Scotia involves approval by a ballot pool, submission to the Board, and final approval by the NSUARB. The NSUARB determines the adoption process, and standards become effective only after their approval. NERC is required to notify the Board of jurisdictional actions regarding proposed standards.
A Summary of Canadian Provincial Adoption of Reliability Standards Framework This document was prepared by the North American Electric Reliability Corporation (NERC) in consultation with the various Canadian and Provincialjurisdictions bas...
AI summary The North American Electric Reliability Corporation (NERC) prepared this informational document summarizing Canadian provincial adoption of reliability standards frameworks. It outlines NERC's understanding of regulatory and standards frameworks in consultation with Canadian jurisdictions, emphasizing that the materials are provided without warranty and contact details for Ric Cameron are included for feedback.
Revision History Doc Number Description Created by Revised by Issued Date LEG-CA-GOV v1 Conformed 12-22-2010 working version of Ric Cameron Davis Smith 02-10-2011 document to NERC Template and issued document internally
AI summary The document provides a revision history for a regulatory document, noting its conformance to NERC standards and the individuals involved in its creation and revision.
es ofthe Alberta Commission and the Market Surveillance Administrator (MSA). Specified penalties for violations ofReliability Standards were adopted by the Alberta Commission, effective November 2010. The AESO established the AESO Reliabil...
AI summary Alberta's regulatory framework for reliability standards involves the Alberta Commission, AESO, and MSA. The AESO established the ARC for stakeholder input on reliability matters, reviews NERC standards with amendments for Alberta's system, and implements a compliance monitoring program. Alberta uses a revised risk-based work plan for reliability standards, diverging from the NERC Functional Model.
British Columbia: The 2007 provincial Energy Plan committed British Columbia (BC) to "ensure that the province remains consistent with North American transmission reliability standards." With the implementation ofthe Utilities Commission A...
AI summary British Columbia's 2007 Energy Plan aligned with North American transmission reliability standards. The 2009 Utilities Commission Amendment Act granted BCUC authority to adopt reliability standards, evaluating public interest and impacts. NERC and WECC are recognized as standard-making bodies, with BCTC (now BC Hydro) required to review standards and report to BCUC.
Manitoba: Manitoba Hydro is currently required to comply with NERC Reliability Standards through its membership in the Midwest Reliability Organization (MRO) and its membership in NERC, subject to exceptions based on provincial law. Pursua...
AI summary Manitoba Hydro must comply with NERC Reliability Standards via its Midwest Reliability Organization (MRO) membership, subject to provincial law exceptions. The 2004 Order in Council approved this compliance, with the 2009 Manitoba Hydro Act establishing enforceable reliability standards and PUB authority for sanctions. Regulations to implement the Act are pending, expected in 2011.
New Brunswick: The Electricity Act in New Brunswick established the New Brunswick System Operator (NBSO) on October 1,2004. NBSO is responsible to direct the operation ofthe transmission grid, to maintain the adequacy and reliability ofthe...
AI summary The New Brunswick Electricity Act established the New Brunswick System Operator (NBSO) in 2004 to manage the transmission grid and ensure system reliability. NERC Reliability Standards are enforced via market rules, with compliance tied to licensing. The Energy and Utilities Board (EUB) succeeded the Public Utilities Board as the sector's regulator.
Nova Scotia: The Nova Scotia Utility and Review Board (NSUARB) exercises general supervision over all electric utilities operating as public utilities within the Province ofNova Scotia, pursuant to the Nova Scotia Public Utilities Act. In...
AI summary The NSUARB oversees Nova Scotia's electric utilities under the Public Utilities Act, collaborating with NERC via an MOU to enforce Reliability Standards. NSPI, as an NPCC member, adheres to NERC standards, with NSUARB ensuring compliance and determining penalties. A final approval process for standards is expected by mid-2011.
Ontario: The Electricity Act, 1998 (Ontario) established the Independent Electricity System Operator (IESO). The IESO is responsible for managing Ontario's bulk electric system and operating the wholesale electricity market. The Electricit...
AI summary Ontario's Electricity Act 1998 established the IESO and Ontario Power Authority. NERC Reliability Standards are enforced via IESO market rules, with compliance required for licenses from the Ontario Energy Board. Bill 44 (2008) grants the Board authority to review NERC standards post-May 2008.
06641Notice of Filing of Informational Filing of the North American Electric Reliability Corporation 3/23/2011
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BEFORE THE NOVA SCOTIA UTILITIES AND REVIEW BOARD THE PROVINCE OF NOVA SCOTIA NORTH AMERICAN ELECTRIC ) RELIABILITY CORPORATION ) NOTICE OF FILING OF INFORMATIONAL FILING OF THE NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION IN RESPONSE T...
AI summary The North American Electric Reliability Corporation (NERC) filed informational documents in response to an order from the Federal Energy Regulatory Commission (FERC) dated September 16, 2010, before the Nova Scotia Utilities and Review Board.
Index to NERC Responses to Directives and Other Actions from September 16, 2010 FERC Order on Three-Year ERO Performance Assessment P No. Directive Page 62 Directs NERC to submit an informational filing six months from the date of this ord...
AI summary The document provides an index to NERC's responses to directives from a September 16, 2010 FERC order regarding a three-year ERO performance assessment. It includes a directive requiring NERC to submit an informational filing six months after the order to update the Commission on its progress.
The North American Electric Reliability Corporation ("NERC") submits this Notice of Filing of Informational Filing as required by the Federal Energy Regulatory Commission's ("FERC") Order issued September 16, 2010 concerning NERC's "Three-...
AI summary NERC submits a Notice of Filing of Informational Filing in response to FERC's Order from September 16, 2010, concerning NERC's Three-Year Electric Reliability Organization Performance Assessment Report.
A. Three-Year ERO Performance Assessment NERC submitted the Assessment on December 17, 2009. The Assessment consisted of the following documents: - Three-Year Electric Reliability Organization Performance Assessment Report Overview ("Asses...
AI summary NERC submitted a Three-Year ERO Performance Assessment to FERC in 2009, detailing its compliance with reliability standards, stakeholder feedback, and actions to improve operations. The assessment included evaluations of regional entities and stakeholder survey results, with FERC issuing an order in 2010 affirming NERC's role in maintaining bulk power system reliability.
B. FERC Acceptance of NERC Filing and Request for Informational Filing In its September 16, 2010 Order, P 54, FERC found that NERC continued to satisfy the criteria in Federal Power Act Section 215 and FERC's regulations for certification...
AI summary FERC accepted NERC's certification as the Electric Reliability Organization (ERO) under the Federal Power Act Section 215, reaffirming compliance by Regional Entities. The September 16, 2010 Order directed NERC to submit an informational filing addressing specific directives within six months, including updates on activities related to FERC's additional guidance.
1. Specific Directives, Other Actions, and Additional Guidance NERC's response to each specific directive or other action in the September 16, 2010 Order is identified as " NERC Response to Commission's Directive – P XX " or " NERC Respons...
AI summary The document outlines NERC's responses to specific directives and actions from the September 16, 2010 FERC Order, including supplemental comments on FERC's conclusions and guidance. Responses are labeled as 'NERC Response to Commission's Directive – P XX' or 'NERC Response to Commission's Other Action – P YY' within the informational filing.
A. Response to FERC Discussion of Opportunities for Improvement in Each Program Area In its September 16, 2010 Order, P 12, FERC stated: "The Commission believes that the July 6 Conference provided a useful, high level discussion of topics...
AI summary FERC plans to hold a second Commissioner-led technical conference in 2011 to discuss reliability monitoring, enforcement, compliance, and policy issues related to NERC Reliability Standards. The Commission emphasizes public dialogue to clarify expectations for standard development and will collaborate with NERC and international regulators on agenda development.
NERC Response to FERC's Other Actions – PP 12 and 13 NERC participated in the November 2010 and February 2011 high-level technical conferences along with a number of other stakeholders. NERC believes those conferences were extremely benefi...
AI summary NERC participated in technical conferences with FERC and stakeholders, advocating for annual high-level dialogues on bulk power system reliability and Canadian stakeholder inclusion. FERC's Order P 57 (2010) affirmed satisfaction with NERC's Rules of Procedure, noting their fairness and encouraging continued international recognition efforts.
NERC Response to FERC's Other Action – P 57 In connection with and following the 3-Year Assessment, NERC and the Regional Entities conducted an extensive review of the NERC Rules of Procedure. Revisions to the Rules of Procedure were filed...
AI summary Following a 3-Year Assessment, NERC revised its Rules of Procedure, including sections on compliance monitoring, sanction guidelines, and organization registration. These revisions were submitted to and approved by FERC in 2010, focusing on updates to compliance processes and standard procedures.
eminate information regarding regional reliability standards. As such, the RSG will consider the practices identified by FERC in P 76 for use in the Regional Entities' standards development processes. NERC agrees with FERC's suggestion to...
AI summary NERC agrees with FERC's proposal to post proposed regional reliability standards for stakeholder comment while allowing final determinations through regional entities. NERC will follow its procedures for concurrent posting during development and a second posting after regional entity processes are complete, alongside submitting technical comments. A dedicated staff member was added in 2011 to support this activity.
Prioritization of Reliability Standards Development In its September 16, 2010 Order, P 105, FERC stated: "We believe that improved prioritization of the Reliability Standards development process will alleviate some of the burdens discussed...
AI summary FERC emphasized in Order P 105 (2010) the need for improved prioritization of reliability standards development to reduce burdens while maintaining quality. NERC agreed, proposing a prioritization tool to balance Commission directives, industry inputs, and reliability performance feedback, focusing on high-impact projects for the Bulk-Power System.
Results-Based Standards In its September 16, 2010 Order, P 106, FERC stated: "Now that NERC has obtained some experience with developing and enforcing mandatory Reliability Standards, it is appropriate for it to assess whether the number a...
AI summary FERC's 2010 Order P 106 directed NERC to assess reliability standards' effectiveness in meeting national goals, emphasizing alignment with prior orders (693, 706) and minimizing administrative burdens. The Commission stressed that revised standards must ensure reliability while streamlining requirements.
4. Compliance Registry In its September 16, 2010 Order, P 162, FERC stated: "While NERC indicates that it will consider whether to raise the thresholds set forth in the Registry Criteria, NERC also observes that the registration process is...
AI summary FERC's 2010 Order emphasizes that NERC must justify threshold changes to the Compliance Registry from a reliability perspective. NERC acknowledges the current process works well but is refining registration requirements in alignment with Bulk Electric System definitions and the Ad Hoc Generator Owner/Transmission Owner Report. Revisions to Section 500 and Appendix 5A of the Rules of Procedure were approved by FERC.
NERC Response to FERC's Directive – P 169 NERC has established criteria for prioritizing events by risk and significance for the purpose of reporting and determining the level of analysis needed for each category. The threshold criteria ar...
AI summary NERC has established event categorization criteria based on risk and significance, with five categories. A field trial from October 2010 to January 2011 led to process improvements, with plans for a second revision by April 2011 and updates to Rules of Procedure for the NERC Board of Trustees in November 2011.
b. Informal Comment Periods i. Permit standard drafting teams to use "informal" comment periods for feedback on concepts or information used to develop reliability standards requirements (but not for comments on proposed requirements) wher...
AI summary The text outlines the use of informal comment periods for feedback on concepts in developing reliability standards, excluding proposed requirements, with no obligation to respond. Changes to Section 300 of the NERC ROP are referenced.
. If a new or modified standard is developed, approved by its ballot pool, and subsequently adopted by the NERC Board through the expedited process, one of the following three actions must then occur: - If the standard is to be made perman...
AI summary The text outlines mandatory post-adoption actions for standards developed via NERC's expedited process, including submitting a SAR, revising/replacing standards, or withdrawing them within two years. These steps ensure compliance with ANSI accreditation requirements, which prohibit abbreviated comment periods or ballot windows.
9. Change the timing of the budget process. The schedule for the preparation of the annual business plan and budget process is posted annually, with minor improvements each year as deemed necessary. Extensive changes to the timing of the b...
AI summary The annual budget process timing is constrained by regulatory requirements mandating submission to the Commission by August 22. Minor adjustments are permitted annually, but extensive changes are not feasible due to this deadline, as outlined in 18 C.F.R. §39.4(b).
Alberta: The Alberta Transmission Regulation (Reg 288/2009 as amended) outlines the framework for Reliability Standards in Alberta. The North American Electric Reliability Corporation (NERC) Reliability Standards apply in Alberta to the ex...
AI summary Alberta's Transmission Regulation (2009) integrates NERC Reliability Standards through AESO consultation and Alberta Commission oversight. The Minister of Energy recognized NERC as the ERO in 2007, and the 2009 Electricity Statutes Amendment Act formalized enforcement by the Alberta Commission and MSA, with penalties for non-compliance.
s on which the latter two requirements are to be met, based on stakeholder approaches to the BCUC. The NERC Functional Model and NERC Glossary of Terms Used in Reliability Standards were also adopted. In late February 2010 BCTC (now BC Hyd...
AI summary The BCUC approved new and revised reliability standards, with WECC designated as CMEP administrator. NERC's functional model was rescinded, and the Act grants BCUC authority over reliability standards. Legislative amendments aim to enhance BCUC's enforcement powers, while BCTC (now BC Hydro) noted NERC's limited role in enforcement.
Nova Scotia: The Nova Scotia Utility and Review Board (NSUARB) exercises general supervision over all electric utilities operating as public utilities within the Province of Nova Scotia, pursuant to the Nova Scotia Public Utilities Act. In...
AI summary The Nova Scotia Utility and Review Board (NSUARB) oversees electric utilities under the Nova Scotia Public Utilities Act, ensuring compliance with reliability standards. An MOU with NERC allows NSUARB to adopt or remand reliability standards, making compliance mandatory in Nova Scotia. NSPI, part of NPCC, adheres to NERC standards, with NSUARB proposing mandatory adoption by mid-2011.
Ontario: The Electricity Act, 1998 (Ontario) established the Independent Electricity System Operator (IESO). The IESO is responsible for managing Ontario's bulk electric system and operating the wholesale electricity market. A 2004 amendme...
AI summary Ontario's Electricity Act established the IESO and Ontario Power Authority. NERC Reliability Standards are enforced via IESO market rules, with compliance tied to licenses from the Ontario Energy Board. Bill 44 (2008) allows the Board to review NERC standards post-May 2008, limiting applicability to standards approved by the NERC Board of Trustees.
07810Quarterly Application for Approval of Reliability Standards of the North American Electric Reliability Corporation - September 2, 2011 9/6/2011
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BEFORE THE NOVA SCOTIA UTILITY AND REVIEW BOARD OF THE PROVINCE OF NOVA SCOTIA NORTH AMERICAN ELECTRIC ) RELIABILITY CORPORATION ) QUARTERLY APPLICATION FOR APPROVAL OF RELIABILITY STANDARDS OF THE NORTH AMERICAN ELECTRIC RELIABILITY CORPO...
AI summary The document is a quarterly application for the approval of reliability standards by the North American Electric Reliability Corporation before the Nova Scotia Utility and Review Board.
The North American Electric Reliability Corporation ("NERC") 1 hereby submits to the Nova Scotia Utility and Review Board ("NSUARB") a quarterly application for approval of the NERC Reliability Standards and an updated NERC Glossary of Ter...
AI summary NERC submits a quarterly application to the NSUARB for approval of updated NERC Reliability Standards and Glossary of Terms. NERC requests these standards be made mandatory for bulk power system users in Nova Scotia. Supporting documents include exhibits with updated standards, implementation plans, and risk factors.
A. NERC Quarterly Filing of Proposed Reliability Standards On July 20, 2011, NSUARB issued a decision approving the Reliability Standards and NERC Glossary of Terms that NERC submitted to NSUARB on June 30, 2010, and accepted as guidance t...
AI summary NSUARB approved NERC's Reliability Standards in 2011, with NERC seeking subsequent approval for standards finalized by FERC since June 2010. NERC, certified as the U.S. ERO under the Federal Power Act, has mandatory standards in several Canadian provinces.
В. Overview of Reliability Standards Development Process NERC Reliability Standards define the requirements for reliably planning and operating the North American bulk power system. These standards are developed by & lt;sup>10 NSUARB Decis...
AI summary NERC's reliability standards are developed by industry stakeholders through a balanced, open process managed by the NERC Standards Committee, with approval from stakeholders and the NERC Board of Trustees. The process is governed by NERC's Rules of Procedure and has been endorsed by ANSI.
& lt;sup>16 Reliability Standards marked with an asterisk are not yet mandatorily effective, but have been approved by FERC and have a future mandatory effective date. Critical Infrastructure Protection (CIP) Standards CIP-001-1a - Sabotag...
AI summary The document lists various reliability standards, including Critical Infrastructure Protection (CIP) and Emergency Preparedness and Operations (EOP) standards, along with their effective dates. Some standards are not yet mandatorily effective but have been approved by FERC and have a future mandatory effective date.
IV. CONCLUSION By this filing, NERC requests that the NSUARB approve the Reliability Standards and NERC Glossary of Terms used in Reliability Standards, as set out in Exhibit B. Respectfully submitted, Gerald W. Cauley President and Chief...
AI summary NERC requests the NSUARB to approve Reliability Standards and a Glossary of Terms, as detailed in Exhibit B. The filing is signed by NERC's executives and legal counsel, emphasizing the need for regulatory approval of these documents.
- 1) NERC Reliability Standards Applicable to Nova Scotia Approved by FERC Since June 30, 2010 Filing - 2) PDF copies of Reliability Standards being filed for Approval
AI summary The document outlines NERC reliability standards applicable to Nova Scotia, approved by FERC since June 30, 2010, and includes PDF copies of these standards being filed for approval.
- 3) Updated NERC Glossary of Terms 1.) NERC Reliability Standards Applicable to Nova Scotia Approved by FERC Since June 30, 2010 Filing PRC-023-1 - Transmission Relay Loadability (new standard) 7/1/2010 Transmission Operations (TOP) Stand...
AI summary The document outlines updated NERC reliability standards applicable to Nova Scotia, including new and revised standards approved by FERC since June 30, 2010. These standards cover transmission operations, voltage and reactive control, and include specific dates for their implementation.
4. Applicability: - 4.1. Balancing Authorities - 4.2. Reserve Sharing Groups (Balancing Authorities may meet the requirements of Standard 002 through participation in a Reserve Sharing Group.) - 4.3. Regional Reliability Organizations - 5....
AI summary Section 4 outlines applicability of standards to Balancing Authorities, Reserve Sharing Groups, and Regional Reliability Organizations. Section 5 sets the effective date as one year after regulatory approval or Board of Trustees' adoption, depending on jurisdictional requirements.
Version History Version Date Action Change Tracking 0 April 1, 2005 Effective Date New 0 August 8, 2005 Removed "Proposed" from Effective Date Errata 0 February 14, 2006 Revised graph on page 3, "10 min." to "Recovery time." Removed fourth...
AI summary The document outlines the version history of a regulatory proceeding, detailing changes and revisions over time, including effective dates, errata, and modifications in response to regulatory orders.
2. Violation Severity Levels R# Lower VSL Moderate VSL High VSL Severe VSL R4.1.1. N/A N/A N/A The Balancing Authority, by the end of the next business day, failed to agree with its Adjacent Balancing Authorities to the hourly values of Ne...
AI summary This section outlines the Violation Severity Levels (VSL) for various regulatory requirements related to Balancing Authorities. It specifies the actions required for each severity level, focusing on failures to agree on interchange values and correct accounting data.
Version History Version Date Action Change Tracking 0 April 1, 2005 Effective Date New 0 August 8, 2005 Removed "Proposed" from Effective Date Errata 1 April 6, 2006 Added following to "Effective Date:" This standard will expire for one ye...
AI summary The document outlines the version history of a regulatory standard, detailing changes and approvals over time, including effective dates, errata, and revisions. It also includes information about approvals by various regulatory bodies.
4. Applicability - 4.1. Reliability Coordinators. - 4.2. Balancing Authorities. - 4.3. Transmission Operators. - 4.4. Generator Operators. - 4.5. Load Serving Entities. - 5. Effective Date: Immediately after approval of applicable regulato...
AI summary Section 4 outlines the applicability of regulations to entities including Reliability Coordinators, Balancing Authorities, and Transmission Operators. The effective date is tied to approval by regulatory authorities, indicating immediate implementation post-approval.
4. Applicability: - 4.1. Within the text of Standard CIP-002-3, "Responsible Entity" shall mean: - 4.1.1 Reliability Coordinator. - 4.1.2 Balancing Authority. - 4.1.3 Interchange Authority. - 4.1.4 Transmission Service Provider. - 4.1.5 Tr...
AI summary Section 4 defines 'Responsible Entity' under CIP-002-3 to include roles like Reliability Coordinators, Balancing Authorities, and Transmission Providers, while exempting nuclear-regulated facilities and certain cyber assets. The effective date depends on regulatory approvals or BOT adoption.
4. Applicability - 4.1. Balancing Authorities. - 4.2. Reliability Coordinators. - 4.3. Load-Serving Entities. - 5. (Proposed) Effective Date: First day of the first calendar quarter six months following applicable regulatory approval; or,...
AI summary Sections 4.1 to 4.3 outline applicability to Balancing Authorities, Reliability Coordinators, and Load-Serving Entities. Section 5 sets the effective date based on regulatory approval or Board of Trustees adoption.
r>len da da la in to te as p ca r s w u y do in g so T he Tr iss io Op fa i le d to to an sm n er a r i de f he i ie i de i f ie d tw t t t t p ro v o o en s n in i d io la i h ts to t t ap p ro ve re s ra n p n w de ip io f a ha he ir t t...
AI summary The text discusses violations within the Bulk Electric System (BES) and the roles of the Transmission Operator (TO) and Reliability Coordinator (RC) in addressing these violations. It references the need for approval of reliability-related actions and mentions the importance of information disclosure and procedural compliance.
2. Violation Severity Levels: R# Lower VSL Moderate VSL High VSL Severe VSL R1 There shall be a separate Lower VSL, if either of the following conditions exists: One instance of entering a schedule into its ACE equation without confirming...
AI summary The document outlines four violation severity levels (VSL) based on the frequency of specific violations related to entering schedules into the ACE equation and coordinating with the HVDC tie transmission operator. Each level corresponds to a different number of violations, ranging from one instance for Lower VSL to four or more instances for Severe VSL.
Timing Requirements for WECC Α В С D If Arranged Interchange (RFI) 3 is Submitted IA Assigned Time Classification IA Makes Initial Distribution of Arranged Interchange BA and TSP Conduct Reliability Assessments IA Compiles and Distributes...
AI summary The document outlines timing requirements for the Western Electricity Coordinating Council (WECC) related to arranged interchange submissions, including classifications (ATF, Late, On-time), response times for entities, and deadlines for confirmed interchange implementation based on submission timing relative to ramp start.
Example of Timing Requirements for WECC
AI summary The document provides an example of timing requirements related to the Western Electricity Coordinating Council (WECC), though the specific content is not detailed in the provided text. The example likely outlines procedural timelines for compliance or reporting under WECC standards, which are critical for grid reliability and coordination.
5. Proposed Effective Date: In those jurisdictions where no regulatory approval is required, the standard shall become effective on the latter of either April 1, 2009 or the first day of the first calendar quarter, three months after Board...
AI summary The standard's effective date depends on regulatory approval requirements. In jurisdictions without approval, it becomes effective on the later of April 1, 2009, or three months after Board of Trustees adoption. For jurisdictions requiring approval, the effective date is the later of April 1, 2009, or three months after regulatory approval.
2. Violation Severity Levels: Requirement Lower Moderate High Severe Requirement Lower Moderate High Severe
AI summary This section outlines the violation severity levels for different requirements, categorizing them into Lower, Moderate, High, and Severe levels. It provides a framework for assessing the severity of violations in a regulatory or operational context.
5. Effective Date: In those jurisdictions where no regulatory approval is required, the standard shall become effective on the latter of either April 1, 2009 or the first day of the first calendar quarter, three months after BOT adoption....
AI summary The effective date of the standard depends on regulatory requirements. In jurisdictions without regulatory approval, it becomes effective on the later of April 1, 2009, or three months after BOT adoption. In jurisdictions requiring regulatory approval, it becomes effective on the later of April 1, 2009, or three months after approval.
G. Version History Version Date Action Change Tracking 0 April 1, 2005 Effective Date New 0 August 8, 2005 Removed "Proposed" from Effective Date Errata 1 August 8, 2005 Revised Attachment 1 Revision 3 February 26, 2007 Revised Purpose and...
AI summary This section outlines the version history of a regulatory standard, detailing key revisions and approvals over time, including changes related to NERC/NAESB split and FERC orders.
G. Revision History Version Date Action Tracking 1 Creation of new standard, incorporating concepts from IRO-006-4 Attachment; elimination of Regional Differences, as the standard allows the use of Market Flow New 1 April 21, 2011 FERC Ord...
AI summary This section outlines the revision history of a standard, including the creation of a new standard incorporating concepts from IRO-006-4 and the elimination of Regional Differences. It also references a FERC Order issued on April 21, 2011, approving IRO-006-EAST.
2. Violation Severity Levels R # Lower VSL Moderate VSL High VSL Severe VSL R4. The Transmission Service Provider notified one or more of the parties specified in R4 of a new or modified ATCID after, but not more than 30 calendar days afte...
AI summary This section outlines the violation severity levels (VSL) for the Transmission Service Provider (TSP) based on the timing of notifications regarding new or modified ATCID. Four levels—Lower, Moderate, High, and Severe—are defined according to the number of days after implementation that the notification occurs.
R6.2. Be allocated as follows: - For ATC Paths, based on the expected import paths or source regions provided by Load-Serving Entities or Resource Planners - For Flowgates, based on the expected import paths or source regions provided by L...
AI summary The text outlines requirements (R6.2–R12) for allocating and managing Capacity Benefit Margin (CBM), including notification timelines, data sharing obligations, and procedures for importing energy during NERC Energy Emergency Alerts (EEA 2 or higher). It emphasizes operational planning, reliability, and compliance with CBM allocation rules.
T he C B M in in in ta m a g iss io Se ic i de 's Tr Pr an sm n rv e ov r C B M I D do d dr f t a es n o es s o ne o he b ire t ts su re q u m en O R T he C B M in in in ta m a g Tr iss io Se ic Pr i de 's an sm n rv e ov r C B M I D do d...
AI summary The document discusses the Capacity Benefit Margin (CBM) and its implementation, referencing the CBM Implementation Document (CBMID) and the Transmission Service Provider (TSP) in the context of modeling standards and regulatory procedures.
5. Proposed Effective Date for Regulatory Approvals: - 5.1. In those jurisdictions where regulatory approval is required, Requirement R1 and Requirement R2 shall become effective on the first day of the first calendar quarter, 24 months af...
AI summary The section outlines the effective dates for regulatory requirements (R1, R2, R3, and R3.1) based on whether regulatory approval is required. Requirements become effective 24 or 36 months after approval or Board of Trustees adoption, depending on jurisdiction.
r tt nc e se g s ly it h c ite ia in R 1. 1 co mp w r r ho h 1. 1 3 e ist bu i de is t t e ug x s, v nc e inc let inc fo ct om p e o r or re r o ne or f t he br ire nt mo re o su eq u me s. lay in do ly it h Re tt t c se g s no om p w f t...
AI summary The text discusses violation severity levels, referencing standards and requirements related to transmission and generation protection system misoperations within the Bulk Electric System. It mentions PRC-004-2, NERC, IEEE, and specific requirements such as R1, R2, and R3.
Version History Version Date Action Change Tracking 1 February 12, 2008 Approved by Board of Trustees New 1 March 19, 2008 Corrected typo in last sentence of Severe VSL for Requirement 3 — "then" should be "than." Errata 1 March 18, 2010 A...
AI summary The document provides a version history of a regulatory proceeding, including approvals by the Board of Trustees and FERC, and a correction to a typo in a requirement related to Severe VSL.
5. Proposed Effective Date: In those jurisdictions where no regulatory approval is required, the standard shall become effective on the latter of either April 1, 2009 or the first day of the first calendar quarter, three months after BOT a...
AI summary The standard's effective date is set to the later of April 1, 2009, or three months after BOT adoption (if no regulatory approval is needed). If regulatory approval is required, it becomes effective three months after such approval, whichever is later.
A. Introduction 1. Title: Monitoring System Conditions 2. Number: TOP-006-2 3. Purpose: To ensure critical reliability parameters are monitored in real-time. 4. Applicability 4.1. Transmission Operators. - 4.2. Balancing Authorities. - 4.3...
AI summary The standard TOP-006-2 aims to monitor critical reliability parameters in real-time, applicable to Transmission Operators, Balancing Authorities, Generator Operators, and Reliability Coordinators. It becomes effective after regulatory approval or on April 1, 2009, depending on jurisdiction.
2. Violation Severity Levels: R# Lower Moderate High Severe R4 N/A N/A The responsible entity has either weather forecasts or past load patterns, available to predict the system's near-term load pattern, but not both. The responsible entit...
AI summary This section outlines violation severity levels for different regulatory rules (R4, R5, R6) related to load prediction, monitoring equipment use, and metering adequacy. Each rule defines the conditions under which violations are categorized as high or severe based on the lack of resources or actions taken by the responsible entity.
Introduction: This Glossary lists each term that was defined for use in one or more of NERC's continent-wide or Regional Reliability Standards and adopted by the NERC Board of Trustees from February 8, 2005 through August 4, 2011. This ref...
AI summary This glossary compiles terms defined by NERC's Board of Trustees from 2005-2011 for continent-wide and regional reliability standards. It distinguishes between FERC-approved definitions and those pending approval, with color-coded indicators. The document outlines the development process, regional scope (WECC, NPCC, ReliabilityFirst), and provides a contact for comments.
1 See 18 CFR 37.6(b)(1) Continent-wide Term Acronym BOT Approved Date FERC Approved Date Definition Balancing Authority [Archive] BA 2/8/2005 3/16/2007 The responsible entity that integrates resource plans ahead of time, maintains load-int...
AI summary The text provides definitions and approval dates for various terms related to electricity regulation, including Balancing Authority, Balancing Authority Area, Base Load, and Blackstart Capability Plan. These definitions are approved by the Board of Trustees (BOT) and the Federal Energy Regulatory Commission (FERC).
Glossary of Terms Used in NERC Reliability Standards Continent-wide Term Acronym BOT Approved Date FERC Approved Date Definition Operating Voltage [Archive] 2/7/2006 3/16/2007 The voltage level by which an electrical system is designated a...
AI summary This section provides definitions for terms used in NERC Reliability Standards, including Operating Voltage, Operational Planning Analysis, and Outage Transfer Distribution Factor (OTDF), with dates of approval by the Board of Trustees (BOT) and the Federal Energy Regulatory Commission (FERC).
The following definitions were developed for use in NPCC Regional Standards. NPCC Regional Term Acronym BOT Approved Date FERC Approved Date Definition Current Zero Time [Archive] 11/04/2010 The time of the final current zero on the last p...
AI summary The text provides definitions for terms used in NPCC Regional Standards, including 'Current Zero Time' and 'Generating Plant,' along with their approval dates by the Board of Trustees and FERC.
The following definitions were developed for use in WECC Regional Standards. WECC Regional Term Acronym BOT Approved Date FERC Approved Date Definition Qualified Transfer Path Curtailment Event [Archive] 2/10/2009 3/17/2011 Each hour that...
AI summary This document outlines definitions for WECC Regional Standards, including terms such as 'Qualified Transfer Path Curtailment Event' and 'Relief Requirement,' with dates of approval by the Board of Trustees and FERC, and references to attachments for detailed information.
Endnotes August 4, 2011 Page 55 of 55 † FERC approved the WECC Tier One Reliability Standards in the Order Approving Regional Reliability Standards for the Western Interconnection and Directing Modifications, 119 FERC ¶ 61,260 (June 8, 200...
AI summary FERC approved WECC's Tier One Reliability Standards in 2007, directing modifications to align regional definitions with NERC Glossary standards. Replacement standards were filed with FERC in 2009 to address inconsistencies.
Prerequisite Approvals There are no other reliability standards or Standard Authorization Requests (SARs), in progress or approved, that must be implemented before this standard can be implemented.
AI summary The document states there are no pending or approved reliability standards or Standard Authorization Requests (SARs) that must be implemented prior to this standard's implementation, indicating no prerequisites exist for its adoption.
Prior Version Implementation Plan Retirement By December 31, 2009, CIP Version 1's Table 1, 2, and 3 Registered Entities that registered prior to December 31, 2007 will have reached the "Compliant" milestone for all CIP Version 1 Requireme...
AI summary The document outlines the retirement of CIP Version 1's Implementation Plan by December 31, 2010, when Table 3 Registered Entities achieve Auditably Compliant status. Compliance milestones for new entities are covered under CIP Version 2, effective April 1, 2010, with Version 3 milestones pending FERC approval.
Matrix of Violation Risk Factors for Information S d d Nu b ta n a r m e r Re ire t q m e n u Nu b m e r Te f Re ire t o t q m e n x u V io la io R is k t n Fa to c r B A L- 0 0 2- 0 R 3. 1. As in im he Ba la in A ho i Re S ha in G ha l l...
AI summary The document presents a matrix of violation risk factors for information, highlighting a high risk associated with the BAL-002-0 matter. It outlines issues related to balancing authority, reliability, and coordination among groups, as well as concerns about obligations and responsibilities.