Vice Chair Independent Electricity System Operator Vice Chair. New York Independent System Operator Central Maine Power Company

Transcription

1 NORTHEAST POWER COORDINATING COUNCIL MINUTES of the meeting of the Reliability Coordinating Committee, held at the Crowne Plaza Hotel, Albany, New York on Tuesday November 28 and Wednesday November 29, Officers of the NPCC Reliability Coordinating Committee William Longhi, Consolidated Edison Company of New York, Inc. Chair Colin Anderson, Ontario Power Generation, Inc. Vice Chair Derek Cowbourne, Independent Electricity System Operator Vice Chair Transmission Providers Michel Armstrong David Boguslawski Richard Bolbrock Michael Calimano Brian Conroy Curt Dahl Thomas Duffy Michael Forte Jean-Marie Gagnon Don Gates Mark Graham Steve DeCarlo Henry Masti Robert Pelligrini Paul Renaud Mike Sampson (via phone) Brian Scott Transmission Customers John Bonner, PE (via proxy) Hugo Sansoucy representing, André Cauchon Glen McCartney (via proxy) Lou Oberski (via proxy) Public Interest Diane Barney Paul Fraser Roy Hrab Howard Tarler Hydro-Québec TransÉnergie Northeast Utilities Long Island Power Authority New York Independent System Operator Central Maine Power Company Long Island Power Authority Central Hudson Gas & Electric Company Consolidated Edison Company of New York, Inc. Hydro-Québec TransÉnergie ISO New England Inc. Hydro One Networks, Inc. New York Power Authority New York State Electric & Gas Corporation The United Illuminating Company National Grid USA Nova Scotia Power, Inc. New Brunswick Power Transmission Corporation Entergy Nuclear Northeast, Inc. Hydro-Québec Production Constellation Energy Commodities, Inc. Dominion Energy Marketing, Inc. New York State Department of Public Service Ontario Energy Board Ontario Energy Board New York State Department of Public Service 2

2 NPCC Jennifer Budd Charles J. Durkin, Jr. Philip Fedora Donal Kidney Stanley Kopman Quoc Le Catherine P. McCarthy, Esq. John G. Mosier, Jr. Andrianne S. Payson, Esq. Paul Roman Edward A. Schwerdt Guy Zito Guests John Adams Greg Campoli Dave Conroy Steve Corey Bob Creighton ( via phone) Pat Doran John Ferraro Michael Henderson William McEvoy Paul Metsa Thimn Nguyen John Pade Ralph Rufrano Carol Sediwitz Phil Tatro Director, Strategic Planning/Treasurer Chairman Director, Regulatory Affairs, Market Reliability Senior Engineer Director, Planning & Compliance Manager, Compliance Secretary Director, Operations Assistant secretary Manager, Operations Planning Executive Director Manager, Planning New York Independent System Operator New York Independent System Operator Chair, Task Force on System Studies New York Independent System Operator Nova Scotia Power, Inc. Chair, Task Force on Coordination of Operation Chair, Task Force on System Protection Chair, Task Force on Coordination of Planning Chair, Task Force Infrastructure Security and Technology Hydro-Québec TransÉnergie New York Independent System Operator New York Independent System Operator New York Power Authority National Grid National Grid 3

3 Antitrust Guidelines for NPCC Meetings The NPCC Reliability Coordinating Committee was informed that the current antitrust laws require that all meeting participants avoid discussion of topics that could result in charges of anti-competitive behavior, including restraint of trade and conspiracies to monopolize, unfair or deceptive business acts or practices, price discrimination, division of markets, allocation of production, imposition of boycotts and exclusive dealing arrangements. Accordingly the meeting attendees were advised that, during the meeting or during any breaks, they should not enter into conversation involving the following topics: The prices for products or services, or the prices charged by competitors, should not be discussed. Costs, discounts, terms of sale, profit margins or anything else that might affect prices should not be discussed. The resale prices customers charge for products sold should not be discussed. The allocation of markets, customers, territories or products with competitors should not be discussed. The limiting of production should not be discussed. The decision to deal, or not to deal, with any company should not be discussed. Any competitively sensitive information concerning a company or a competitor should not be discussed. Administrative Matters/ Items for Affirmation of the Meeting of September 6, 2006 The Draft for Approval of the minutes of the Reliability Coordinating Committee meeting of September 6, 2006 was approved as revised at the meeting. Roster Changes The NPCC Reliability Coordinating Committee approved the following changes to Task Force and Working Group memberships: Task Force on Coordination of Operation Effective, January 1, 2007, Mr. Daniel Soulier of TransÉnergie Hydro Québec will succeed Mr. Pat Doran of the Independent Electricity System Operator as the Chairman. Mr. Alden Briggs of the New Brunswick System Operator will succeed Mr. Daniel Soulier of TransÉnergie Hydro Québec as the Vice Chairman. Task Force on System Protection Mr. Serge Bernard succeeds Mr. Robert Lecavalier as a member, both of TransÉnergie Hydro Québec 4

4 Task Force on System Studies Mr. Daniel Taft succeeds Mr. Michael Forte as a member, both of Consolidated Edison Company of New York, Inc. Mr. Ibrahim El Nahas succeeds Mr. John Ciufo as a member, both of Hydro One Networks, Inc. Task Force on Infrastructure Security and Technology Mr. Martin Ferland succeeds Mr. Jean-Guy Ouimet as a member, both of TransÉnergie Hydro Québec. Mr. Jacques Chevalier succeeds Ms. Sophie Sylvestrie as an alternate, both of TransÉnergie Hydro Québec. Task Force on Coordination of Planning John Adams succeeds Mike Henderson as chairman on January 1, SS-38 Working Group Ms. Alessia Dawes of Hydro One Networks, Inc. succeeds Mr. Alain Elen, formally of Hydro One Networks, Inc., as a member. Mr. Peter Huang as the alternate Hydro One Networks, Inc. member. SS-37 Working Group Mr. Peter Huang is the Hydro One Networks member. Ms. Alessia Dawes as the alternate Hydro One Networks, Inc member. CP-10 Working Group Mr. Dieter Wagner is the Hydro One Networks member. In addition the following memberships have been designated: Reliability Coordinating Committee Mr. Mike Sampson succeeds Mr. Mark Savory as a member, both of Nova Scotia Power Inc. Mr. Derek Cowbourne succeeds Mr. Paul Murphy as a member, both of Independent Electricity System Operator. Mr. Dana Walters succeeds Mr. Paul Renaud as a member, both of National Grid USA. Compliance Monitoring and Assessment Subcommittee Mr. T. M. (Trey) Kirkpatrick succeeds Mr. Elliot Barnett as a member, both of Northeast Utilities. 5

5 New England Area Interim Review of Resource Adequacy In accordance with the Guidelines for NPCC Reviews of Resource Adequacy (B-8), the ISO-NE has presented a draft New England 2006 Interim Review of Resource Adequacy report to the Task Force on Coordination of Planning (TFCP). TFCP reviewed the report and concurred with its main conclusion, that New England meets the NPCC resource adequacy criterion, as planned for years 2006 through 2010, and will be in conformance with the NPCC Basic Criteria for Design and Operation of Interconnected Power Systems (A-2). The RCC approved the report. Scope and Schedule for CP Summer Multi-Area Probabilistic Assessment Working Group The TFCP CP8 working group proposed draft scope and schedule for the subject assessment was provided to the RCC. The CP8 working group will be using the G.E. Multi-Area Reliability Simulation (MARS) program, to review NPCC Area reliability resulting from the anticipated resources and transmission transfer capability reported for the year 2007 under Base Case and Severe Case assumptions. The report will summarize the range of results for the summer and shoulder season months (the period from May to September). The RCC approved the scope and schedule as presented. Terms of Reference for NPCC Blackout Study Task 5 Evaluation of Other Potential Preventive Mitigation Measures This study will evaluate various possible mitigation measures to improve the ability of the NPCC member systems to withstand a major system disturbance originating from a wide range of initiating conditions. Possible mitigation measures will include: a. Improved coordination of the UFLS program, transmission system protections, and generator protections, b. Improved coordination of system protection and system control functions, c. Supplementing existing transmission line protection schemes to enable reliable formation of islands containing coherent generation groups (e.g. out of step tripping or blocking) with consideration to minimizing the complexity of system restoration, d. Implementation of Under-Voltage Load Shedding (UVLS) with due consideration to the November 2005 NPCC Assessment of the Feasibility of Under-Voltage Load-Shedding. The RCC approved the terms of reference NPCC Working Group Industry Support Budget Summary Re: 2007 NPCC Working Group Industry Support Budget Summary At its July 25, 2006 meeting, the NPCC Executive Committee approved a recommendation that the NPCC Inc. (RRO) and the NPCC CBRE (RSA & RDA) 2007 budgets include $122,500 and $297,500 respectively for a total of $420,000 in Account 6

6 #65400 (Industry Support). Consultant services will be funded through Account #65000, consistent with the NERC system of Accounts being adopted January 1, The RCC approved the proposed Industry Support budget. RCC Actions Review and Approval of Proposed Clarification to Document A-3, Emergency Operation Criteria for Member re-ballot [Action Deferred] The latest version of A-3 was posted for comment and then put to ballot for member approval. It was subsequently identified that there is an issue with the interpretation of a revised section of the document. In early 2007, A-3 will be further revised and reposted for comment in conjunction with the posting of A-12 (Restoration of NPCC Areas Following a System Collapse). The changes to clarify the section requiring interpretation will be completed at that time. If no substantive comments are received, A-3 will be presented to the RCC for approval at the March meeting. Review of Revised Document A-5, Bulk Power System Protection Criteria [Action Deferred] The Task Force on System Protection (TFSP) had originally planned to submit the revised A-5 for approval at this meeting, but due to the comments received at the last minute, additional time will be required to address these comments. TFSP also needs to complete the development of the new draft B-5 which contains the language taken from A-5. To ensure that there will be no gaps between the new A-5 and the existing A-5, TFSP plans to request approval of both A-5 and B-5 at the March 2007 RCC meeting when the development of B-5 is expected to be complete. Review and Approval of New Document B-25, NPCC Guide to Time Synchronization of Substation Equipment [Action Required] It was reported that the draft document was posted in the NPCC Open Process Review for a forty-five-day comment period. All comments received have been addressed by the TFSP. As presented at the September 6, 2006 RCC meeting, this document is intended as guidance for meeting the requirement of Bulk Power System Protection Criteria, Document A-5, Section 2.7.3, which states Event and fault recording equipment shall be time synchronized to Universal Coordinated Time with a time source accurate to within one millisecond. The time zone shall be clearly identified as either universal time zone or local time zone. and for meeting the complementary requirement of the NPCC Basic Criteria for Design and Operation of Interconnected Power Systems, Document A-2, Section 2.3, which states Areas shall install dynamic recording devices These devices should be time synchronized and should have sufficient data storage to permit a few minutes of data to be collected. This guide covers time synchronization of substation equipment such as DFRs, DSRs, SERs, Protective Relay IEDs, RTUs, and generally any substation equipment capable of accepting external synchronization. The document was approved by the RCC. 7

7 Review and Approval of the New York Comprehensive Area Transmission Review [Action Required] In accordance with the Guidelines for NPCC Area Transmission Reviews (B-4), the New York ISO presented a draft of the New York 2005 Comprehensive Transmission Review report to the Task Force on Coordination of Planning (TFCP). TFCP reviewed the report and concurred with its main conclusion, that the New York bulk power transmission system, as planned through the year 2010, is judged to be in conformance with the NPCC Basic Criteria for Design and Operation of Interconnected Power Systems (A-2).). The assessment evaluates conformance with A-2 design criteria, extreme contingencies and extreme system conditions. The report concluded that the New York State Bulk Power System as planned through 2010 is in conformance with the NPCC and NYSRC reliability criteria and rules. The RCC requested that the executive summary be revised to reflect changes discussed regarding the impact of extreme contingencies. The wording in the executive summary implied that the extreme contingencies analyzed could cause cascading outages outside of NY. The revised report was brought to the RCC for approval at the second day of the meeting. The conclusions/impact from the report regarding extreme contingency analysis was included in the executive summary and the report was reworded to indicate that the extreme contingencies studied do not have serious consequences in other areas. In addition, the conclusions in the executive summary include a statement that the NYISO is in compliance with applicable NERC standards. The RCC suggested that in the in future, the TFCP, when recommending an assessment for approval, should provide their assessment of the report and discussion of the mitigating actions. The revised report was approved by the RCC. Review and Approval of the New York Comprehensive Area Review of Resource Adequacy [Action Required] New York ISO presented a draft 2006 Comprehensive Review of New York Resource Adequacy report to the Task Force on Coordination of Planning (TFCP). TFCP reviewed the report and concurred with its main conclusion, that New York meets the NPCC resource adequacy criterion, as planned for years 2007 through 2011, and will be in conformance with the NPCC Basic Criteria for Design and Operation of Interconnected Power Systems (A-2). The New York Control Area (NYCA) Comprehensive Triennial Review of Resource Adequacy, conducted by the New York Independent System Operator (NYISO), supplants the 2005 Review that was approved by Northeast Power Coordinating Council s (NPCC) Joint Coordinating Committees in March,

8 The 2006 Comprehensive Triennial Review demonstrates that the number of firm load disconnections range from to days/year for the base load forecast and to for the high load forecasts. For the period 2007 through 2011, the New York Control Area (NYCA) is in compliance and has sufficient existing resource capacity and planned resource capacity additions to meet the NPCC resource adequacy criterion. The RCC had a discussion regarding the need to assure that the assumptions made in the area review are consistent among all areas. It was reported that the CP-8 Working Group does this on behalf of the TFCP. TFCP will review their work scope to ensure that this activity is clearly identified. The RCC approved the review. Review and Approval of the Ontario Comprehensive Area Review of Resource Adequacy [Action Required] In accordance with the Guidelines for NPCC Reviews of Resource Adequacy (B-8), the IESO has presented a draft 2006 Comprehensive Review of Ontario Resource Adequacy report to the Task Force on Coordination of Planning (TFCP). TFCP reviewed the report and concurred with its main conclusion, that Ontario meets the NPCC resource adequacy criterion, as planned for years 2007 through 2011, and will be in conformance with the NPCC Basic Criteria for Design and Operation of Interconnected Power Systems (A-2). This report supersedes the review conducted in The IESO determined Ontario s level of reliability using the Multi-Area Reliability Simulation (MARS) program. Since the last comprehensive review in 2003, about 3,500 MW of incremental generation capacity has been added in Ontario, and 1,150 MW of capacity has been retired. Capacity additions include about 1,900 MW of additional nuclear capacity and about 750 MW of additional gas fired capacity. This year s comprehensive review demonstrates that Ontario is expected to meet the NPCC overall resource adequacy criterion. New generation that is expected to come into service will increase the reliability of the Ontario power system. In 2007 additional resources (imports) of up to 1200MW are required to meet the LOLE requirements for median and high load growth scenarios. The RCC approved the Ontario comprehensive review. Review and Approval of the NPCC Interregional Long Range Adequacy Overview [Action Required] The TFCP s CP8 Working Group presented the final report of its NPCC Interregional Long Range Adequacy Overview. 9

9 This study evaluated, on a consistent basis, the long range adequacy of NPCC and neighboring Region s plans to meet their Loss of Load Expectation (LOLE) planning criteria through a multi-area probabilistic assessment. The RCC approved the report contingent upon revisions discussed at the meeting. Winter 2006/07 Pre-Seasonal Assessments Review and Approval of the NPCC Multi-Area Probabilistic Reliability Assessment for Winter 2006/07 [Action Required] The TFCP s CP8 Working Group presented the subject assessment. This study estimated the use of NPCC Area Operating Procedures designed to mitigate resource shortages for the winter of 2006/07 (November 2006 through March 2007). The CP-8 Working Group closely coordinated its efforts with those of the CO-12 Working Group s study, "NPCC Reliability Assessment for Winter 2006/07", November General Electric s (GE) Multi-Area Reliability Simulation (MARS) program was selected for the analysis. GE Energy was retained by the Working Group to conduct the simulations. Use of operating procedures designed to mitigate resource shortages (specifically, reducing 30-minute reserve, voltage reduction, reducing 10-minute reserve, and public appeals) is not expected for Québec, New England, and New York, during the 2006/07 winter period for both the expected and extreme load level under the assumed Base and Severe Case conditions. The expected load level results were based on the probability weighted average of the seven load levels simulated. The extreme load level conditions represents the second to highest load level, having approximately a 6% chance of being exceeded. For the Maritimes Area there is an expectation for reducing 30-minute reserves in response to a capacity deficiency this winter for the expected load level. This expectation increases to nine times for the extreme load level conditions, coupled with an expectation of also needing to call on interruptible loads three times. For Ontario, use of operating procedures designed to mitigate resource shortages (specifically, reducing 30-minute reserve, voltage reduction, reducing 10-minute reserve, and public appeals) is not expected during the 2006/07 winter period for the expected load level under Base Case conditions. However, there is an expectation for reducing 30- minute reserves in response to a capacity deficiency this winter under the Severe Case, extreme load level conditions. CP-8 will also consider ways of providing the NERC RAS with the benefit of their analysis. Based on the changes discussed, the RCC approved the review. 10

10 Review and Approval of the TFCO 2006/07 Winter Seasonal Assessment [Action Required] This Operations Planning Working Group (CO-12) report focuses on the assessment of reliability within NPCC for the Winter Operating Period of Portions of this report are based on work previously done for the NPCC Reliability Assessment for the 2006 Summer Operating Period. For example, many of the Operational Readiness items discussed in the NPCC Reliability Assessment for Summer 2006 remain applicable for the Winter Operating Period except where noted in the report. The findings are based on forecasted projections of load requirements, resource configurations and transmission configurations. This report identifies NPCC and the associated Areas ability to deal with the differing resources and transmission configurations plus the actions needed to reasonably ensure that NPCC and the associated Areas are prepared to deal with possible uncertainties identified in this report. The report stated the following: The forecasted capacity outlook for NPCC during the peak week (week beginning January 14, 2007) indicates a net capacity margin of approximately 12,970 MW. This equates to a net capacity margin of 11.2 % in terms of the 115,591 MW forecasted peak load. The net margins for the Winter Operating Period are generally lower than what had been forecasted for the previous winter. However, most are not very different when a year to year comparison is done. The overall difference is reflected in the purchases outside NPCC. The margin reflected in this assessment is lower than last year s as a result of fewer purchases from outside NPCC in this year s assessment. During each Area s forecasted peak week, the forecasted net capacity margin ranges from a margin of approximately 4.1 % margin in Québec to a 25.0 % margin in New York. There is approximately 1,350 MW of forecasted new installed capacity for this operating period compared to last year. Québec has 1,080 MW of new capacity. Most of this capacity is already in service, so that any delays to the rest of the capacity additions should not materially impact the overall spare capacity projections for NPCC. The Resource and Transmission Assessments used in this report are mere snapshots in time and base case studies. Changes to the base case assumptions can alter this report s findings. The CO-12 Working Group believes that these preparations remain valid for dealing with the various operating scenarios expected during the Winter Operating Period. Maritimes and Québec, which are winter peaking areas, have additional preparation as a function of these conditions. The report was approved by the RCC. 11

11 Review and Approval TFCO 2006 Post- Seasonal Assessment [Action Required] The results of the post-seasonal assessment, done by the CO-12 Working Group, were presented. The study focuses mainly on the operational aspects within NPCC for the summer 2006 peak, which occurred on August 1, at 16h00 EDT. The CP-8 Working Group has conducted a review of the actual use of Operating Procedures for the summer 2006 operating season. Their report was published on September 21, 2006: Review of Actual 2006 Summer Use of Operating Procedures. The CO-12 working group conducted a Load and Capacity analysis similar to the one usually conducted in the winter and summer Reliability Assessments. Overall, the forecast resources, demand, transfer capability and net margin in the NPCC CO Summer Reliability Assessment Report were very close to the actual values seen on August 1. Generator performance in some of the load pockets that were potential concerns was also good, so problems were not experienced. The analysis of conditions did show bottling of resources within the Québec and Maritimes Areas at the actual peak, which is very similar to what had been projected in the Summer Assessment. At the time of the peak remaining transfer capability to provide further assistance from Québec and Maritimes was very limited (only about 400 MW). The RCC approved the report. Review and Approval of Regional Reserve Sharing and Recommended Changes [Action Required] The Reliability Coordinating Committee, at the June 1, 2005 meeting, unanimously approved a NPCC program of up to 100 MW of regional reserve sharing, but in which each Area may reduce its operating reserve commitment by no more than 50 MW. The provision to reduce the operating reserve requirement by only 50 MW was imposed by the Reliability Coordinating Committee pending a review, by the Task Force on Coordination of Operation, of the effectiveness of the program after six months. Regional reserve sharing was implemented in January of The Control Performance Working Group (CO-1) of the TFCO prepared a report on Regional Reserve Sharing. Although there is limited participation in Regional Reserve Sharing at this time, the report concludes that: The NPCC regional reserve sharing program in its present form has been successful in promoting reliability and should be continued. Consideration should be given to allowing regional reserve sharing energy to count towards ten-minute synchronized reserve requirements in the future. Based on the conclusions of the CO-1 report, the TFCO requested that the Reliability Coordinating Committee approve the following changes to the regional reserve sharing program: 12

12 Areas participating in regional reserve sharing are allowed to reduce the synchronized reserve component of their ten minute reserve by 100MW (increased from 50 MW and ten minute non-synchronized reserve only). The changes to the Regional Reserve Sharing Program as recommended by TFCO were approved. Approval of CMAS Compliance Report [Action Required] The CMAS Compliance Report for the period beginning August 21, 2006 and ending November 20, 2006 was presented. As detailed in the report, ISO New England reported one Level 4 violation to NERC Standard IRO-006, Reliability Coordination Transmission Loading Relief and one 345 kv transmission outage due to contact with vegetation that will result in a Level 3 violation if there are no further category 1 vegetation contacts through the end of the calendar year for NERC Standard FAC-003-1, Transmission Vegetation Management Program. CMAS have also conducted a review of probable violations submitted by NERC to NPCC following a NERC Readiness Audit and identified non-compliance with three requirements of the NERC Standard BAL-005-0, Automatic Generation Control, in the Maritimes Area. NERC requested CMAS to follow up on the finding of probable violations from a readiness audit in the Maritime Area. CMAS has completed the compliance review and identified non-compliance with three requirements of the NERC Standard BAL-005-0, Automatic Generation Control. This is not a part of the RCEP requirements. CMAS will follow-up with a letter to the Area in an effort to confirm these violations before NERC will be informed of the result of the CMAS review. The CMAS report was approved by the RCC. Approval of Work Plans [Action Required] The Work Plans for the Compliance Monitoring and Assessment Subcommittee, Task Force on Coordination of Operation, Task Force on Coordination of Planning, Task Force on Information Systems and Technology, Task Force on System Protection and the Task Force on System Studies were approved by the RCC with revisions as discussed. Status Reports Development of Document A-10, Classification of Bulk Power System Elements The document was revised based on comments from TFSS and CP-11. The changes relate to testing requirements and should result in a list of BPS elements that is similar to the existing list. The document is posted for comment through the NPCC Open Process. 13

13 Development of Document A-12, System Restoration Criteria This new document was posted for comment through the NPCC Open Process. The comment period closed on November 27, 2006 and enough comments were received to result in revisions to the document. A revised version will be reposted for comment once and the intent is to present the revised document to the RCC for approval at their March meeting. Development of Document A-13, Verification of Generator Gross and Net Real Power Capability Criteria This new document was posted for comment through the NPCC Open Process. The comment period closed on November 27, 2006 and enough comments were received to result in revisions to the document. A revised version will be reposted for comment once and the intent is to present the revised document to the RCC for approval at their March meeting. Blackout Study Recommendations TFSS recommendations from the Blackout study follow-up include the following: TFSS should investigate whether separating Ontario from Michigan for conditions similar to those experienced during the blackout would improve reliability for other conditions and would not degrade reliability, under most circumstances for both NPCC and other Regions. If so, they should propose a dependable means of detecting the necessary conditions and effecting the separation. Transmission owners should investigate changes that could be made to improve the security of protection operation of the Homer City 345 kv transmission lines to Watercure and Stolle Road and recommend any proposed changes to TFSS and TFSP. TFSP has forwarded information from NYSEG on July 29. First Energy will investigate changes in The RCC believed that the improvements should be completed prior to 2008 and actioned NPCC staff to pursue an earlier resolution through Reliability First Corporation and First Energy. SS-38 needs to have all proposed changes at both ends of line to do a complete assessment. TFSP recommendations from the Blackout study follow-up include the following: Review of improvements to the Loss of 3001 SPS should be considered.. NB Power will replace this SPS with proposed Maritimes Islanding SPS (approved in May) in TFSS Underfrequency Load Shedding Program Review The latest status of the study was presented. Analysis is complete to identify the islands being studied using the experience from August 14, Some new islands were identified. The analysis will be completed by December 15, 2006, sensitivity analysis by January 16, 2007 and the final report to the RCC by March, If deficiencies are identified, then additional work will be required to identify appropriate modifications. 14

14 JWG-3 - Working Group Reviewing March 29, 2006 NYPA Incident The WG met by conference call last week. The WG will review the three existing reports and the TFCP report when completed. A list of actions and recommendations for future testing will be completed by December 8, The final report should be available for the March RCC meeting. TFIST Cyber Security Survey Summary The objective of the survey was to determine how the NPCC Members compare to the NERC Implementation Plans in regards to the following areas: Progress against NERC Implementation Plans Comparison of preliminary CIP-002 Requirement (1) results amongst like companies within NPCC Determine the next burning question(s) in regards to the CIP standards so TFIST can adjust future work plans In addition, the survey was meant to continue to raise the awareness and drive towards a Regional Risk Methodology Guideline to promote consistency within NPCC. The key findings of the survey were: Majority at the Begin Work (BW) phase Majority know their o Critical Assets (CA) o Critical Cyber Assets (CCA) Challenges are o CIP-004 (Personnel & Training) o CIP-007 (Systems Security Management) Has helped raise awareness on Regional Risk Methodology Guideline Update on RFC - NPCC Activities and Report on ERAG The Eastern Interconnection Reliability Assessment Group (ERAG) met two weeks ago to determine how to oversee the Inter-Regional studies. The MEN and VEM studies were completed this year under the ERAG. The NERC MMWG may also come under the ERAG however this would be difficult to govern. The JIRC is now disbanded. NPCC Reliability Assessment Program (NRAP) Status Report The NPCC Reliability Assessment Program Summary Report has been updated and shows that the projects are within the approved budgets. The full updated NRAP Status Report will be posted in Adobe format in the Current Year NRAP folder on the NPCC Home Page. The URL is: TFCP Working Group CP-9, NPCC Review of NERC Reliability Standards CP-9 will meet to discuss the FERC NOPR. They are also continuing to provide comments on NERC standards. 15

15 CMAS and Task Force 2006 Work Plan Review The following is a summary of the CMAS and Task Force Reports on their 2006 Work Plans: TFSP Blackout recommendation re zone 3 loadability Beyond Z3 submission to NPCC by end December for submission to NERC in March A-5 & A-11 available for posting in early 2007 Completed guide re time synchronization of event recording devices TFIST Cyber Security workshop held in Toronto in June Y27K awareness document sent Survey readiness to implement cyber security standards CMAS Summary of RCEP to RCC in March Reviewing document changes required for ERO implementation Participating in readiness assessments and following-up on reportable violations Compliance Workshop held in October TFSS Blackout-study follow-up items all underway A-10 evaluation study plan completed Comment on load as synchronized reserve Governor survey distributed results in January, 2007 UFLS study underway Approved SPS and updated SPS list Posted second semi-annual major projects list TFCP Resource adequacy reviews completed Transmission reviews completed A-10 CP-9 support of NERC standards TFCO New Documents developed o A12 System Restoration o A-13 Generator Capability Document review and clean-up based on a review of compliance requirements and the gap analysis resulting from the mapping of NPCC documents to NERC criteria ATC/TTC methodology whitepaper to be posted for comment White paper on inter-area reserve under development 16

16 Approval for load participation in synchronized reserve document changes underway Review of regional reserve Sharing completed RCC approval of requested changes Facilitated Transaction Checkout implemented in all BA control rooms Seasonal Assessments and Post Seasonal Assessments completed Report on the Implementation of the UFLS Relay Time Delay Conversion The implementation of the change to the under-frequency load shedding relay time delay to the nominal operating time of 0.3 second was to be carried out approximately uniformly distributed within a four year time period beginning on August 31, This is the second year of this implementation in which approximately 50% of the change is expected to have been completed by August 31, A form was developed by TFSP to obtain the data in a consistent format. CMAS was again requested to assist in this effort. The data indicates that the Areas are on schedule in completing this effort. TransEnergie stated that the Quebec Area is fully compliant with the new criteria requirement. Registration of Entities Responsible for Complying with NERC and Regional Reliability Standards NPCC is compiling a registration list with contact information. This will become the responsibility of the CBRE staff. There are approximately 750 entity types registered and the listing will be reviewed through verification surveys identifying the applicable NERC requirements for each of the entities. NPCC will also undertake a review to determine if other entities are required to register. NPCC will determine how to handle multiple TOP registrations in an Area where they have overlapping accountabilities. The next version of the non-binding registration list is to due to NERC by March 2, Informational Items TFCP Action Plan to Increase NPCC Area Study Efficiencies At the March RCC meeting, the RCC requested the Task Force on Coordination of Planning to review the current set of NPCC studies performed to determine if there were any opportunities to combine, condense and increase the study efficiencies. The TFCP has conducted a preliminary review of the individual studies and determined that they are in fact distinct, with different purposes, satisfying different needs. Efficiencies to be gained regarding data gathering are minimal and due to the differing timeframes which the Areas have the final data sets available would make any improvement in this area difficult and yield little benefit. TFCP did discuss the potential that exists for an Area study currently done to satisfy local requirement (not NPCC s) which may be expanded to ensure that all the NPCC requirements are met, allowing the use of that study to meet the local and NPCC 17

17 requirements. This will require revisions to the B-08 Guidelines for Area Review of Resource Adequacy, and the B-04 Guidelines for NPCC Area Transmission Reviews documents to allow for submission of a non-npcc initiated Area study to meet NPCC s reliability objectives. The TFCP has directed the CP8 working group and requests TFSS to consider the necessary revisions to these documents and suggests the development of a simple template for each that would allow the Area to fill in the blank to ensure all the necessary criteria and requirements of the NPCC study are addressed. This will ease the review process for the NPCC working groups and task forces and ensure that all NPCC Criteria are met. TFCP will continue to review this topic at future meetings. New NPCC Document C-39, Procedure to Collect Major Disturbance Event Sequence Data This document was developed by the Task Force on System Protection and posted in the NPCC Open Process Review for a forty-five-day comment period. All comments received have been addressed. This document will be issued and posted on the NPCC web site on November 30, This procedure document will provide a common format for consistent collection of data across organizational boundaries when piecing together the events following a significant disturbance. The procedure references a set of spreadsheets for use by transmission owners, generation owners and large customers in providing the data. A similar format was used to collect information during the 2003 blackout investigation, and again following the March 29, 2006 St. Lawrence disturbance. NPCC/NERC Activities NPCC, Inc. Board of Directors Meeting Highlights NPCC will be dissolved at the EC meeting and will become NPCC Inc. The first annual meeting of NPCC Inc will be held following the last meeting of NPCC on November 29 th. The RCC will continue to operate under NPCC Inc. NPCC CBRE, Inc. Board of Directors Meeting Highlights The first meeting was held in September and approved the Regional Delegation Agreement. The Board will also approve the separate Canadian Provincial MOUs. Regional Reliability Standards Development Process The NPCC Regional Reliability Standard Process was posted and received comment at both NPCC and NERC. NERC Board of Trustees/Stakeholder Committee Highlights The following are highlights reported to the RCC: NERC has made a Governance and non-governance Compliance Filing with FERC. The BOT sanctioned a new transmission owner s forum. The BOT will not support this group financially however will provide support to the group. 18

18 NERC will send a letter to HQ acknowledging that Quebec is a separate interconnection. The NERC Board established a separate corporation. This entity filed the ERO application. The NERC Council will be dissolved and merged into the NERC Corporation. NPCC presented comments on procedures related to Standards Development and objected to standard changes that did not follow due process. Next meeting in February. Operating Committee Highlights and Agenda Items The next meeting will be held on December 6 & 7. Agenda includes: Approval of Version 3 of the Functional Model and the Regional Reliability Plan Guideline (joint with PC) Input on SAR for back-up control center standard Letter from NYISO regarding frequency excursions requests work to identify causes and mitigating actions OLDTF Planning Committee Highlights and Agenda Items The next meeting will be held on December 6 & 7. Agenda includes: Approval of v3 of the Functional Model and the Regional Reliability Plan Guideline (joint with OC) Transmission availability statistics System Operating Limits follow-up on OLDTF discussion Critical Infrastructure Protection Committee Highlights and Agenda Items The next meeting will be held on December 7 & 8. The agenda includes the following: Indications/alerts/warning working group HSIN update Panel discussion on complying with cyber standards Other Matters As it was Mr. William Longhi s last meeting as RCC Chairman, a Resolution of Appreciation was read by Stanley E. Kopman, NPCC Staff, thanking him for his leadership and wishing him well in his future endeavors. The RCC also acknowledged the many contributions and dedicated service of Mr. Michel Armstrong, Hydro-Québec TransÉnergie, and wished him well on his upcoming retirement. The next Joint Chairs conference call was scheduled for January 25, :00 am to 12:00 pm. Date March 14, 2007 May 23, 2007 Location New York City New York City 19

19 Distribution of Approved NPCC Full Member Representatives and Alternates NPCC Public Interest Representatives and Alternates Members, NPCC Executive Committee Members, NPCC Reliability Coordinating Committee Members, NPCC Public Information Committee Members, NPCC Compliance Monitoring and Assessment Subcommittee Members, NPCC Task Force on Coordination of Operation Members, NPCC Task Force on Coordination of Planning Members, NPCC Task Force on Infrastructure Security and Technology Members, NPCC Task Force on System Protection Members, NPCC Task Force on System Studies Mr. Richard J. Bolbrock Ms. Jennifer H. Budd Andrew J. Fawbush, Esq. Mr. Philip A. Fedora Mr. James H. Hartwell Mr. Brian Hogue Mr. Donal J. Kidney Mr. Stanley E. Kopman Mr. H. Quoc Le Catherine P. McCarthy, Esq. Mr. John G. Mosier, Jr. Andrianne S. Payson, Esq. Mr. Frantz Roc Mr. Paul A. Roman Mr. Edward A. Schwerdt Mr. Guy V. Zito and Federal Energy Regulatory Commission La Régie de L Énergie Maine Public Utilities Commission New England Conference of Public Utilities Commissioners New York State Department of Public Service Ontario Energy Board United States Department of Energy Vermont Department of Public Service 20