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AgendaPlanning Committee Meeting
September 14, 2010 | 1–5 p.m. (MDT)September 15, 2010 | 8 a.m.–noon (MDT)
Crowne Plaza Denver International Airport15500 E. 40th AvenueDenver, CO 80239(303) 371-9494
1. Administrative Matters *a. Welcome and introductions - Tom Burgess *b. Planning Committee membership changes – John Seelke *c. Arrangements – John Seelke*d. Parliamentary procedures – John Seelke e. Announcement of quorum – John Seelke*f. NERC Antitrust Compliance Guidelines – John Seelke g. Approve agenda – Tom Burgess
*h. Future meetings – John Seelke*2. Consent Agenda
*a. Approve June 15-16, 2010 draft PC meeting minutes as final minutes*b. Approve changes to the PC three-year work plan
3. Chairman’s Remarks a. Report on the August 4-5, 2010 Member Representative Committee and Board of Trustees
meetings4. Information Only
*a. Reliability Standards Development Plan Comment Period – John Seelke
*Background material included
116-390 Village Blvd.Princeton, NJ 08540
609.452.8060 | www.nerc.com
5. Committee Matters*a. Provide feedback on ERO Event Analysis Process draft documents by September 28, 2010 –
David Hilt, Vice President and Director of Operations and Engineering, NERC *b. Critical Infrastructure Strategic Initiatives: Coordinated Action Plan Report – Mark Lauby,
Director, Reliability Assessment and Performance Analysis, NERCApprove:1. Approve the direction of the draft Critical Infrastructure Strategic Initiatives Coordinated
Action Plan formulated to address: The proposals for action presented in the “High-Impact, Low-Frequency Event Risk to
the North American Bulk Power System”1 report The direction provided by the Chair of NERC’s Board of Trustees Alignment with the strategic initiatives identified in the Electricity Sub-Sector
Coordinating Council’s Critical Infrastructure Strategic Roadmap.2 Seek comments on the Action Plan by PC-OC-CIPC by September 24, 2010 to [email protected].
2. Approve the authorization of the technical committee officers to consider the comments in formulating the final Action Plan for presentation to the NERC Board of Trustees at their November 4, 2010 meeting.
3. Approve the scope for the Spare Equipment Database Task Force. 4. Approve the scope for the Geomagnetic Disturbance Task Force.
*c. Provide feedback on draft Frequency Response Initiative Terminology by September 22, 2010 and on draft Frequency Response Initiative Work Plan by September 30, 2010 – Bob Cummings, Director, System Analysis and Reliability Initiatives NERC
6. Subgroup Reports PC Action*a. Reliability Assessment
SubcommitteeApprove:1. 2010 Scenario Reliability Assessment Report: Potential
Impacts of Environmental Regulations: Early Fossil-Fired Unit Retirements; Phase I: Impact on Planning Reserve Margins
2. 2009/2010 Post-Winter Operational Reliability Assessment
3. 2010 Long-Term Reliability Assessment*1. Load Forecasting Working
GroupNone – status report
*b. Reliability Metrics Working Group
Approve:1. White paper Integrated Bulk Power Risk Assessment
Concepts2. Nine 2010 Reliability Metric ProposalsProvide feedback by September 30, 2010 on the use of metrics for assessing Bulk Power System performance
*Background material included
1 HILF report http://www.nerc.com/docs/hilf/HILF_Event_Risk_to_BPS.pdf2 See Agenda Item 2 of http://www.nerc.com/docs/escc/ESCC_30Aug10_agenda.pdf Planning Committee Meeting Agenda 2September 14-15, 2010
6. Subgroup Reports PC Action*c. G&T Reliability Planning Models
Task ForceApprove the Methodology and Metrics document and the implementation plan in the GTRPMTF Report on Methodology and Metrics.
*d. Reliability Impacts of Climate Initiative Changes Task Force
Approve disbanding the Reliability Impacts of Climate Initiative Changes Task Force
*e. Integration of Variable Generation Task Force
Approve the report Flexibility Requirements and Metrics for Variable Generation and their Implications on Planning StudiesProvide feedback by September 30, 2010 on the report Potential Reliability Impacts of Emerging Flexible Resources
*f. Resource Issues Subcommittee None – status report*1. Loss-of-Load Expectation
Working GroupNone – status report will include the LOLEWG’s required annual report to the PC
*2. Generating Availability Data System Task Force
None – status report
*g. Transmission Issues Subcommittee None – status report*1. Model Validation Task Force None – status report
*h. System Protection and Control Subcommittee
Approve development of a white paper on Issues Related to Protection System Response to Power Swings.Provide feedback on:1. The role or function of technical reference
documents and how specific issues with reference documents should be addressed ; and
2. Comments that were not addressed during the e-mail vote to approve the technical reference document Power Plant and Transmission System Protection Coordination.
*i. Data Coordination Subcommittee Provide feedback to questions in Review of DCS White Paper Key Issues by October 8, 2010
*1. Transmission Availability Data Systems Working Group
None – status report
*2. Demand Response Data Task Force
None – status report
*3. Data Coordination Working Group
None – status report
j. Reliability Fundamentals Working Group
None – the RFWG is suspended until the March 2011 meeting when its status will be re-evaluated
*k. Smart Grid Task Force Approve the report Reliability Consideration from Integration of Smart Grid
*l. Events Analysis Working Group Approve proceeding with a field test of the elements of the Event Analysis Process
*Background material included
Planning Committee Meeting Agenda 3September 14-15, 2010
Agenda Item 1.aPlanning Committee Meeting
September 14–15, 2010Welcome and Introductions
Action RequiredNone – information only
BackgroundPlease see the following:1. Attachment 1 – the Planning Committee’s summary roster.2. Attachment 2 – the Planning Committee’s full roster with contact information.3. Attachment 3 – the Planning Committee’s organizational chart showing all PC subgroups.
Agenda Item 1.bPlanning Committee Meeting
September 14–15, 2010
Planning Committee Membership Changes
Action RequiredNone – information only
BackgroundElections were held in June 2010. The following were elected for two-year terms and confirmed by the Board of Trustees in August 2010:
Sector Re-elected or new member Elected Member
1. Investor-owned utility R Dick Kafka, Pepco Holdings2. State/municipal utility R Stuart Nelson, Lower Colorado River Authority3. Cooperative utility R Jay Farrington, PowerSouth Energy Cooperative4. Federal or provincial
utility/Federal Power Marketing Administration
NR
Christian Deguire, Hydro Québec TransÉnergieRon Mazur, Manitoba Hydro
5. Transmission dependent utility N Kevin Koloini, American Municipal Power6. Merchant electricity generator R Scott Helyer, Tenaska, Inc.7. Small end-use electricity
customerN Stacia Harper, Ohio Partners for Affordable Energy
8. Independent system operator/ regional transmission organization
N Dan Rochester, IESO
Special elections were held in August 2010 to fill remaining vacancies. The following were elected for one-year and two-year terms and will serve pending confirmation by the Board of Trustees in November 2010:
Sector Re-elected or new member Elected Member/Term
12. State government N
N
Christine Ericson, Illinois Commerce Commission (2 years)Jeff Kaman, Iowa Utilities Board (1 year)
Two sectors (electricity marketer and large end-use electricity customer) remain vacant.
Agenda Item 1.hPlanning Committee Meeting
September 14–15, 2010
Future Meetings
Action RequiredNone – information only
BackgroundThe future joint meetings of the Operating Committee, Planning Committee, and Critical Infrastructure Protection Committee and the Planning Committee’s future meetings are scheduled as follows:
Date LocationDecember 1, 2010 Joint OC/PC/CIPC Web meetingDecember 7–8, 2010 Tampa, FL (confirmed)
March1, 2011 Joint OC/PC/CIPC Web meetingMarch 8–9, 2011 Phoenix, AZ (unconfirmed)
Agenda Item 2Planning Committee Meeting
September 14–15, 2010
Consent Agenda
Action RequiredApprove each of the items on the Consent Agenda.
BackgroundThe following items are for Planning Committee approval without discussion. However, if a member requests discussion on any item, the chair may defer discussion on the item until later in the meeting.
Each item has an attachment or a link to the referenced documents.
Item 2.a – Approve June 15–16, 2010 draft PC meeting minutes as final minutes (attached as Agenda Item 2.a)
Item 2.b - Approve PC three-year work plan changes
1. The Load Forecasting Working Group proposes to suspend activity #14 – “Provide Reliability Concepts document input” until the Reliability Fundamentals Working Group’s status is clarified (presently slated for a decision at the March 2011 meeting).
2. The Transmission Issues Subcommittee proposes to modify the 2010 tasks/deliverables/milestones for activity #22 – “Modeling improvements initiative” with the addition of this sentence: “Created the Model Validation Task Force (MVTF) and its associated work plan and scope.”
3. The Data Coordination Subcommittee proposes to modify the 2010 tasks/deliverables/milestones for activity #41 – “Develop white paper describing data collection vision and strategy” from a completion date of June 2010 to one of December 2010.
4. The Transmission Availability Data Systems Task Force proposes to modify the 2010–12 tasks/deliverables/milestones for activity #51 – “TADS” to reflect additional coordination with the RMWG and the EAWG.
5. The System and Protection and Control Subcommittee proposes to drop activity # 103.5 – “Complete ‘Beyond Zone 3’ report” given that PRC-023 was approved which addresses transmission relay loadability.
6. The Generating Availability Data Systems Task Force proposes to add new activity #201 – “Review and recommend whether Generation Owners on the NERC Compliance Registry should report GADS data on a mandatory basis.”
These were the only changes. The proposed work plan (with the proposed changes highlighted) is posted at http://www.nerc.com/filez/pcmin.html along with the September 14–15, 2010 PC meeting material.
Agenda Item 4.aPlanning Committee Meeting
September 14-15, 2010
Reliability Standards Development Plan Comment Period
Action RequiredNone – information only
BackgroundA comment period for the Reliability Standards Development Plan is open through September 16. See the announcement in Attachment 1.
Agenda Item 5.aPlanning Committee Meeting
September 14–15, 2010
ERO Event Analysis Process
Action RequiredProvide feedback on ERO Event Analysis Process draft documents by September 28, 2010.
BackgroundThe members of the Event Analysis Working Group (EAWG), Planning and Operating Committee chairs, Regional Entity Executives, and NERC staff have been working to develop a new consensus approach to the ERO Event Analysis Process, as described in the plan and timetable shared with the committees in mid-June.Comments are requested on two documents, described below, that are posted in Word at http://www.nerc.com/filez/pcmin.html along with the September 14–15, 2010 PC meeting material. In addition to comments provided at the meeting, committee members are encouraged to submit further written comments by September 28, 2010, to Dave Nevius, NERC senior vice president, who is facilitating this effort, at [email protected].
1. A working draft (Attachment 1), dated August 31, 2010, is being provided to the committees for input at their September 14, 2010 Joint Session.In particular, the participants working on the process document would value the committees’ inputs on the following:1. Does the document provide a clear and concise framework for the identification,
reporting, and analysis of events so their causes can be identified and corrected and important recommendations and lessons learned shared with the industry?
2. Does the document adequately describe a defined, repeatable process for identifying bulk power system events that warrant prompt reporting and the level of analysis required?
3. Does the document establish clear roles, responsibilities and expectations for registered entities, Regional Entities, and NERC regarding analysis of events?
4. Will the document promote consistency, comparability, flexibility and timeliness in the event analysis process?
5. What specific changes would improve the document and its ability to satisfy its objectives?
2. After considering the committee inputs, the process document will be revised and shared with industry stakeholders through a series of webinars and workshops, following which final changes will be made to the process document for field testing. NERC anticipates the field testing process to begin in mid to late October 2010 with improvements made as the field test progresses. A suggested approach for the field test is also attached (Attachment 2), and committee member comments and suggestions are welcome.
Following the field test and evaluation of all feedback received, the process document will be finalized for regular use. The EAWG and NERC staff will develop the changes needed to the ERO Rules of Procedure to accommodate this new process, which will be processed for board approval through the procedure specified for that purpose.
Agenda Item 5.bPlanning Committee Meeting
September 14–15, 2010
Critical Infrastructure Strategic Initiatives: Coordinated Action Plan Report
Action Required1. Approve the direction of the draft Critical Infrastructure Strategic Initiatives Coordinated
Action Plan formulated to address: The proposals for action presented in the High-Impact, Low-Frequency Event Risk to the
North American Bulk Power System3 report The direction provided by the Chair of NERC’s Board of Trustees Alignment with the strategic initiatives identified in the Electricity Sub-Sector
Coordinating Council’s Critical Infrastructure Strategic Roadmap.4 Seek comments on the Action Plan by PC-OC-CIPC by September 24, 2010 to [email protected]
2. Approve the authorization of the technical committee officers to consider the comments in formulating the final Action Plan for presentation to the NERC Board of Trustees at their November 4, 2010 meeting.
3. Approve the scope for the Spare Equipment Database Task Force. 4. Approve the scope for the Geomagnetic Disturbance Task Force.
Background1. On May 17, 2010, NERC’s Board of Trustees approved the report, entitled High Impact, Low
Frequency (HILF) Event Risk to the North American Bulk Power System. Subsequently, a series of efforts were undertaken leading to the development of a draft Action Plan, including the following: The officers of the PC-OC-CIPC and NERC staff formulated an initial approach to
addressing the proposals for action identified in the HILF Report, including initial proposals for scenarios for coordinated physical attack, coordinated cyber attack, and geomagnetic disturbance (GMD) events.
The Chair of NERC’s Board of Trustees issued a letter to the technical committees requesting development of an action plan to address the proposals for actions
The Electricity Sub-sector Coordinating Council (ESCC) was formed, and conducted a strategic planning session which led to development of a draft Critical Infrastructure Strategic Roadmap” that is in alignment with the scenario priorities, the technical committee initial approach, and identifies technical committee support functions.
The principle strategic objectives being to provide demonstrated deliberate progress toward addressing the HILF proposals for action and thereby enhancing the reliability, resiliency, mitigation, recovery, and security of the bulk power system, while enhancing government-industry communications.
These efforts led to the development of a draft Action Plan. In tandem with the Action Plan, a communications plan is under development that would articulate actions planned consistent with the above. The draft Action Plan (download at http://www.nerc.com/docs/hilf/CIP_Coordinated_Action_Plan_083110_V5.pdf)
3 HILF report http://www.nerc.com/docs/hilf/HILF_Event_Risk_to_BPS.pdf4 See Agenda Item 2 of http://www.nerc.com/docs/escc/ESCC_30Aug10_agenda.pdf
identifies priorities, milestones, and ‘lead’ technical committees to formulate proposed improvements and provides indicated deliverables.
The technical committee chairs/vice-chairs request concurrence/comments from the membership by September 24, 2010 on the directionality of this Action Plan, and specific comments on the contents. The technical committee leadership further requests a strategic view of aligning or adjusting overall priorities within the existing work plan.
2. The technical committee chairs/vice-chairs request authorization from the members to consider their comments and formulate the final Action Plan in time for the upcoming Board meetings in early November.
3. The purpose of the Spare Equipment Database Task Force (SEDTF) is to develop a whitepaper with recommendations/conclusions on spare equipment availability requirements, along with database specifications. Ultimately, this database should be populated through a NERC Data Authorization request (Rule 1600 of the Rules of Procedure)5 with spare equipment vital to the recovery process of the bulk power system from physical attacks and GMD (Attachment 1). This task force will support the Action Plan, work plan items: 1) G - Critical Spares, and 2) P- GMD – Restore the Bulk power System.
4. Severe-impact geomagnetic disturbance events present risks and vulnerabilities that may not be fully addressed for HILF events in conventional bulk power system planning, design, and operating processes. The Geomagnetic Disturbance Task Force (GMDTF) will develop a technical white paper describing the evaluation of scenarios of potential GMD impact, identifying key bulk power system parameters under those scenario conditions, and evaluating potential reliability implications of these incidents. Based on these technical foundation elements, identify potential mitigation, recovery, planning, and operational approaches that mitigate this risk (Attachment 2). This activity supports the Action Plan (Scenario 3, Items M, N, O, and P).
Status Report1. NERC staff and technical committee leadership held one face-to-face meeting and three
conference calls to develop, prioritize, and rank the Action Plan activities. 2. The technical committee leadership and NERC staff are continuing to formulate effective
approaches to remain in alignment with ESCC Strategic Roadmap and the Board of Trustees guidance.
3. The Action Plan represents a long-term deliberate approach to address the HILF risks to the bulk power system and once finalized will be integrated within the multi-year work plan for each technical committee.
5 http://www.nerc.com/files/NERC_Rules_of_Procedure_EFFECTIVE_20100610.pdf
Agenda Item 5.cPlanning Committee Meeting
September 14–15, 2010
Frequency Response Initiative
Action RequiredProvide feedback on:1. Draft Frequency Response Initiative Terminology to [email protected] by September
22, 2010.2. Draft Frequency Response Initiative Work Plan draft to [email protected] by
September 22, 2010.
BackgroundAttachment 1 has proposed draft Frequency Response Initiative Terminology. A Word version is posted at http://www.nerc.com/filez/pcmin.html along with the September 14-15, 2010 PC meeting material. Attachment 2 has proposed draft Frequency Response Initiative Work Plan. A PowerPoint version is posted at http://www.nerc.com/filez/pcmin.html along with the September 14-15, 2010 PC meeting material.
Agenda Item 6.aPlanning Committee Meeting
September 14–15, 2010
Reliability Assessments Subcommittee (RAS) Report
Action RequiredApprove:1. 2010 Scenario Reliability Assessment Report: Potential Impacts of Environmental
Regulations: Early Fossil-Fired Unit Retirements; Phase I: Impact on Planning Reserve Margins
2. 2009/2010 Post-Winter Operational Reliability Assessment3. 2010 Long-Term Reliability AssessmentAs these reports are embargoed, instructions for downloading will be sent by e-mail to the “pc_plus” and “oc_plus” Lyris lists by September 2, 2010 for items 2 and 3, and by September 6, 2010 for item 1. For all items, comment instructions will be included. Comments are to be provided by September 9 for items 2 and 3 and September 13 for item 1.
Background1. 2010 Scenario Reliability Assessment Report: Potential Impacts of Environmental
Regulations: Early Fossil-Fired Unit Retirements; Phase I: Impact on Planning Reserve Margins. a. Phase I of this study assesses the impacts on planning reserve margins due to four
proposed regulations by the U.S. Environmental Protection Agency for the years 2009-2017.i. Coal Combustion Residuals Surface Impoundments with high Hazard Potential
Ratings Rule (CCR)ii. Clean Air Transport Rule (CATR), formerly Clean Air Interstate Rule (CAIR)
iii. Maximum Achievable Control Technology (MACT)iv. Clean Water Act Enhancement Rule 316b – Cooling-Water Intake Structures
b. This scenario is designed to assess the impact of each rule on planning reserve margins from these proposed environmental regulations and all four in composite, which may result in accelerated retirements of power plants due to the cost of compliance.
2. 2009/2010 Post-Winter Operational Reliability Assessment Review a. This report is focused on a post-seasonal assessment, rather than traditional assessment of
forecasted conditions traditionally produced by the RAS. The goal of this report is to assess planned operating /mitigation strategy implementation, document new strategies developed during the season, document actual operational experiences, and share lessons learned through the 2009/2010 winter season in North America.
b. Data collection and self-assessment narratives have been completed by the Regional Entities and Reliability Coordinators which provide an assessment of the performance during the 2009/2010 season.
c. Highlights of this report:
Agenda Item 6.aPlanning Committee Meeting
September 14–15, 2010i. All Regions/Sub-Regions/Reliability Coordinators met required operating reserve
margin requirements to support and maintain reliability.
ii. Colder than expected temperatures in northwest and southeast (including Texas, Florida, and the southeastern portions of SERC) resulted in actual peak demands greater than 110 percent of the seasonal forecasts. Operational procedures and mitigationstrategies were implemented successfully and ensured reliability through the winter season.
3. 2010 Long-Term Reliability Assessment (LTRA) a. This report is NERC’s annual ten-year reliability outlook and provides an independent
view of the reliability of the system, identifying trends, emerging issues, and potential concerns. All projections within this assessment are based on a bottom-up approach, collecting data and perspectives from grid operators, electric utilities, and other users, owners, and operators of the bulk power system.
Status Report1. The RAS met in August 2010 to discuss the aforementioned action items and upcoming
reliability assessment documents.2. 2010 LTRA– Emerging Issue Topic Review
a. Each year, the Emerging Issues section of the LTRA highlights issues adopted by the RAS, RIS, and TIS that could pose an immediate or long-term threat to the reliability of the bulk power system. NERC asked RAS Committee members for help this year due to their extensive knowledge and expertise in this area of electric system operation and planning.
3. A draft version of the 2010 LTRA was provided to the RAS on August 25 for a seven-day comment period on the document.
4. 2010 Post-Summer Operational Reliability Assessment Plan a. The goal of this report is to assess planned operating / mitigation strategy implement,
document new strategies developed during the season, document actual operational experiences, and share lessons learned through the 2010 summer season in North America.
b. The RAS decided that unlike the 2009/2010 Post-Winter Operational Reliability Assessment which focused on collecting operating data for the entire winter season, the Post Summer assessment will look to collect data only on Peak operating days and Extraordinary operating days (i.e. days where an Energy Emergency Alert was issued).
5. A separate meeting was scheduled on September 1st to discuss the re-alignment of Regional Operational boundaries for the purpose of developing reliability assessments.
6. The RAS is on schedule with all three-year work-plan items.
Agenda Item 6.a.1Planning Committee Meeting
September 14–15, 2010
Load Forecasting Working Group (LFWG) Report
Action RequiredNone – see status report below
Status Report1. The LFWG reviewed the 2010 LTRA demand and energy data. In August 2010, the demand
and energy uncertainty bandwidths for the 2010 LTRA forecasts were prepared and incorporated into the report.a. As an improvement to annual uncertainty bandwidth calculations, the LFWG is using
three (summer, winter, energy) ratios instead of only summer peak ratios for data reconstruction. The group acknowledged that the 2009 work to reconstruct the bandwidths based on summer peak ratios by NERC staff was an important improvement, but identified the use of three ratios for the affected Regional data as the next improvement step for the 2010LTRA.
b. The Peak Demand and Energy Projection Bandwidths Methodology report is currently being developed for RAS approval in October.
2. The LFWG will hold a meeting its next meeting in Vancouver in September 2010.3. The Vice Chair position is still vacant.4. Future activities include:
a. Identify improvements for demand forecasting to improve reliability assessments;b. Evaluate energy forecasting techniques; andc. Monitor the economic trends to evaluate impacts on demand of any economic recovery.
5. The LFWG is on schedule with all three-year work plan items and no material changes are needed to the 2010 work plan.
Agenda Item 6.bPlanning Committee Meeting
September 14–15, 2010
Reliability Metrics Working Group (RMWG) Report
Action RequiredApprove:1. White paper Integrated Bulk Power Risk Assessment Concepts2. Nine 2010 Reliability Metric Proposals
Provide feedback by September 30, 2010 on the use of metrics for assessing Bulk Power System (BPS) performance.
BackgroundThe RMWG recommends OC and PC approval:1. The Integrated Bulk Power Risk Assessment Concepts paper was submitted to the OC and PC
for feedback in June 2010. Ten sets of comments were received from stakeholders and incorporated in the latest version of the paper, available at http://www.nerc.com/docs/pc/rmwg/Integrated_Bulk_Power_System_Risk_Assessment_Concepts_Final.pdf2.
2. Nine metric proposals were presented to the OC and PC for feedback in June 2010. Detailed comments and suggestions were received from the System Protection and Control Subcommittee (SPCS), and the Transmission Availability Data System Working Group (TADSWG). The RMWG has considered and incorporated the comments. The updated descriptions and sample charts of the nine metrics summarized in the following table can be found at page 26 of the report located at http://www.nerc.com/docs/pc/rmwg/2010_Metrics_Final.pdf.
ALR 1-5 System Voltage Performance
ALR 1-12 Interconnection Frequency Response
ALR 2-3 Activation of Under Frequency Load Shedding (UFLS)
ALR 6-11 Automatic AC Transmission Outages Initiated by Failed Protection System Equipment
ALR 6-12 Automatic AC Transmission Outages Initiated by Human Errors
ALR 6-13 Automatic AC Transmission Outages Initiated by Failed AC Substation Equipment
ALR 6-14 Automatic AC Transmission Outages Initiated by Failed AC Circuit Equipment
ALR 6-15 Element Availability Percentage (APC)
ALR 6-16 Transmission System Unavailability due to Automatic Outages
The RMWG requests OC and PC feedback on:3. Continuing the discussion from the OC and PC meeting in June 2010, RMWG needs
guidance to answer the following question: “Should the RMWG’s future annual reports provide a high-level assessment of BPS performance?” Please send your feedback to [email protected] by September 30, 2010. The current RMWG scope includes:
a. Develop reliability metrics measuring characteristics of ALRb. Define data collection and reporting guidelinesc. Risk assessmentd. Publish quarterly update and annual report
Status Report1. The group finalized the paper Integrated Bulk Power Risk Assessment Concepts and nine
metric proposals; further collaborated with SPCS and TADSWG in July and August. 2. Nine conference calls were held from mid-June to the end of August. 3. Future activities include a webinar in September and a face-to-face meeting on November 3–
4. 4. No changes required to the work plan.
Agenda Item 6.cPlanning Committee Meeting
September 14–15, 2010
G&T Reliability Planning Models Task Force (GTRPMTF) Report
Action RequiredApprove the Methodology and Metrics document and the implementation plan in the GTRPMTF Report on Methodology and Metrics.
BackgroundAt the June 2010 meeting, the PC approved the posting of a draft document that described a methodology for the calculation of probabilistic resource adequacy metrics. Six sets of comments were received. The task force subsequently revised the Methodology and Metrics document and included the revised document as well as an implementation plan in the report GTRPMTF Report on Methodology and Metrics. That report is available at http://www.nerc.com/docs/pc/gtrpmtf/GTRPMTF%20Meth%20&%20Metrics%20Report%20final%20for%20PC%208-28-10.pdf.
Status Report1. A Web meeting was held on July 15 to clarify the posted draft Methodology and Metrics
document. 2. The GTRPMTF has held numerous conference calls and one meeting on August 24–25, 2010
to finalize its material for the September 2010 PC meeting.
Agenda Item 6.dPlanning Committee Meeting
September 14–15, 2010
Reliability Impacts of Climate Change Initiatives Task Force (RICCITF) Report
Action RequiredApprove disbanding the Reliability Impacts of Climate Change Initiatives Task Force
BackgroundThe task force has completed its activities with the approval of the report entitled Reliability Impacts of Climate Change Initiatives, Technology Assessment and Scenario Development. The report is posted at http://www.nerc.com/files/RICCI_2010.pdf. Therefore, the Chair, Mr. Ben Crisp, requests that the Planning and Operating Committees discharge the task force members from their duties.
Status Report1. The report was approved by NERC’s Board of Trustees in July 2010 and subsequently
released.2. The work plan is complete, no further work is proposed.
Agenda Item 6.ePlanning Committee Meeting
September 14–15, 2010
Integration of Variable Generation Task Force (IVGTF) Report
Action RequiredApprove the report Flexibility Requirements and Metrics for Variable Generation and Their Implications on Planning Studies. (IVGTF1-4).
Provide feedback on Potential Reliability Impacts of Emerging Flexible Resources by September 30, 2010 (IVGTF1-5).
Background1. The report Flexibility Requirements and Metrics for Variable Generation and Their
Implications on Planning Studies was submitted for review in May to the Planning Committee. This version incorporates the comments received. The report addresses findings on increasing penetration of variable resources and recommendation of approaches on how transmission and generation can accommodate variability. Further information on applications and methods used to reduce demand, reduce load, and planning approaches for generation and transmission for system flexibility is introduced in the report located athttp://www.nerc.com/docs/pc/ivgtf/IVGTF_Task_1_4_Final.pdf.
2. The report Potential Reliability Impacts of Emerging Flexible Resources addresses the integration of large amounts of plug-in hybrid electric vehicles, storage, and demand response programs which may provide additional resource flexibility and influence bulk power system reliability and should be considered in planning studies. The report is available at http://www.nerc.com/docs/pc/ivgtf/IVGTF_Task_1_5_Final.pdf. Send your feedback to [email protected], copy [email protected] by September 30, 2010.
Status Report1. IVGTF1-4: Team Lead John Adams (NYISO) submitted the draft for review for PC and OC
in May, this draft incorporates the comments received, and the task force’s final meeting took place on August 23, 2010.
2. IVGTF1-5: Team lead Daniel Brooks (EPRI) held numerous conference calls and a meeting in Portland in March to prepare the draft report. The report was reviewed by the IVGTF leadership and the received comments are incorporated in this version.
Agenda Item 6.fPlanning Committee Meeting
September 14–15, 2010
Resource Issues Subcommittee (RIS) Report
Action RequiredNone – see status report below
Status ReportThe RIS held a Web meeting on July 27, 2010 and reviewed its work plan and the activities of several PC subgroups: the Data Coordination Subcommittee, the G&T Reliability Planning Models Task Force, and the Generating Availability Data System Task Force.
Agenda Item 6.f.1Planning Committee Meeting
September 14–15, 2010
Loss-of-Load Expectation Working Group (LOLEWG) Report
Action RequiredNone – see status report below
Status Report1. The LOLEWG had no meetings or conference calls. 2. Chair Andy Ford developed the first annual report to the PC, which is required by the
LOLEWG scope (Attachment 1).
Agenda Item 6.f.2Planning Committee Meeting
September 14–15, 2010
Generating Availability Data System Task Force (GADSTF) Report
Action RequiredNone – see status report below
Status ReportOn June 16, 2010, the NERC Planning Committee approved the creation of the Generating Availability Data System Task Force (GADSTF). GADSTF will review and recommend whether Generation Owners on the NERC Compliance Registry should report GADS data on a mandatory basis (http://www.nerc.com/docs/pc/gadstf/GADSTF_Scope_Approved_061610.pdf)
The GADSTF is targeting its recommendations for the Planning Committee at its December 2010 meeting. The following activities have occurred since this approval:
1. Mr. Benjamin Crisp of Progress Energy (Florida) has agreed to chair the task force.2. A Purposes and Goals document (http://www.nerc.com/docs/pc/gadstf/GADSTF_Kick-
Off_Purpose_and_Goals.pdf) has been created. It outlines the approach to meeting the PC goals outlined in the GADSTF scope. It also outlines the timeline to meet the December 2010 report to the PC.
3. Nearly 50 members have agreed to support GADSTF (1 Chair, 18 appointed by the regions, 4 NERC staff, and 24 observers).
4. GADSTF kick-off conference call with all GADSTF members was held on August 11, 2010.5. Leaders, assistant leaders, and secretaries for each of four sub-groups (Design, Event,
Performance, and Wind reporting) are now engaged.6. All sub-group leadership members were contacted and asked to create work scopes. The sub-
group scopes were approved by the GADSTF Chair.7. Conference calls by the sub-group leaders to their members have started. Work is progressing
to meet the goals set.8. A GADSTF face-to-face meeting is set for September 30-October 1 in Atlanta to bring the
four sub-groups together and prepare the draft of the GADSTF report for the PC.9. The PC three-year work plan has been updated.
Agenda Item 6.gPlanning Committee Meeting
September 14–15, 2010
Transmission Issues Subcommittee (TIS) Report
Action RequiredNone – see status report below
Status Report1. Fault-Induced Delayed Voltage Recovery
a. Collaborating with Department of Energy effort.b. Initiating discussion with air-conditioner industry trade group regarding design.
2. VAR-001-2; VAR-002-2 Standardsa. TIS involvement through SAR origination and cross membership.b. The Standard Drafting Team has been formed – Bill Harm of TIS is Vice Chairc. First meeting Sept. 21–23 in Salt Lake Cityd. Monitoring and participating needed
3. Data Coordination Subcommittee – participating in white paper development4. LTRA Emerging Issues Development
a. Increased imports without sufficient var supportb. Impact of resource mix changes on system stability and frequency response
5. The TIS has scheduled the following meetings in 2010–2011.
October 13 – 14, 2010 Portland, OR (host: BPA)
Tues Full DayWed Half Day
January 19 – 20, 2011 Tampa, FL Wed Full DayThurs Half Day
May 11 – 12, 2011 Albuquerque, NM Wed Full DayThurs Half Day
Agenda Item 6.g.1Planning Committee Meeting
September 14–15, 2010
Model Validation Task Force (MVTF) Report
Action RequiredNone – see status report below
Status Report 1. Jose Conto of ERCOT was named the Chair of the MVTF. 2. The MVTF roster and scope is posted to MVTF site at http://www.nerc.com/filez/mvtf.html. 3. The MVTF reviewed the PC’s comments from the June 2010 meeting regarding its white
paper Power System Model Validation and is revising it and developing an associated work plan.
Agenda Item 6.hPlanning Committee Meeting
September 14–15, 2010
System Protection and Control Subcommittee (SPCS) Report
Action RequiredApprove development of a white paper on Issues Related to Protection System Response to Power Swings.Provide feedback on:1. The role or function of technical reference documents and how specific issues with reference
documents should be addressed; and2. Comments that were not addressed during the e-mail vote to approve the technical reference
document Power Plant and Transmission System Protection Coordination.
Background1. In its Order No. 733, FERC directed development of a new Reliability Standard that prevents
protective relays from operating unnecessarily due to stable power swings by requiring the use of protective relay systems that can differentiate between faults and stable power swings and, when necessary, phases-out relays that cannot meet this requirement. The NERC Standards Committee has approved posting of a Standards Authorization Request for Project 2010-13 – Order 733 Relay Loadability Modifications. Phase III of this project, scheduled to commence in April 2011, will address development of this new Reliability Standard. The SPCS believes a white paper on this subject is timely to promote understanding of this subject and has developed an outline for a white paper to be developed with support from the Transmission Issues Subcommittee. Attachment 1 has a draft outline of the proposed white paper.
2. There were several comments during the e-mail vote to approve the technical reference document Power Plant and Transmission System Protection Coordination on the process of approving and updating technical reference documents. One approach for PC consideration is whether future technical reference documents should be issued as “reliability guidelines.” Attachment 2 has Appendix 4 from the Planning Committee Charter, and it defines reliability guidelines as “documents that suggest approaches or behavior in a given technical area for the purpose of improving reliability.” Each technical committee (OC, PC, and CIPC) has the same approval and review process in their charters for issuing and updating reliability guidelines.
3. Attachment 3 responds to comments raised during aforementioned e-mail vote.
Status Report1. Modifications to the Power Plant and Transmission System Protection Coordination
Documenta. SPCS has completed responses to comments submitted by PC members during the recent
ballot.b. SPCS has discussed the role of technical reference documents and how specific issues
with reference documents should be addressed. The SPCS is developing a position for PC consideration at the September meeting. More information will be available in the SPCS presentation to be included in the second mailing prior to the meeting.
2. Knowledge Transfer of the Power Plant and Transmission System Protection Coordination Document to Industrya. SPCS has completed the series of seven Web presentations. The sessions were presented
over a seven week period from May 26 to July 15. Attendance was high (average 150-200 web connections) and feedback was very positive.
b. The presentations are available at the NERC Resource Center in PDF format as well as streaming video under the “2010 Webinars” tab.
3. Reliability Fundamentals a. Assignment: Develop a Protection Chapter for the NERC Reliability Concepts
document.b. Status: A SPCS Sub-Team has been assembled to lead the SPCS in the development of
this work. Members are: Phil Tatro (Lead), Joe Spencer, Eric Udren, Baj Agrawal, Charlie Rogers, and John Ciufo. Although work on expanding the Reliability Concepts document has ceased, the SPCS believes there is value in publishing this work as a stand-alone white paper describing fundamental reliability concepts associated with system protection in basic terms. Should work resume on the NERC Reliability Fundamentals document in the future, this information could easily be reformatted and incorporated into the document.
c. It is the intent of the SPCS to present a white paper for PC approval at their December 2010 meeting.
4. Backup Protection Technical Reference Document Based on the Florida Event team recommendations regarding autotransformer backup protection, and further to the work on the development of the redundancy white paper, the PC has authorized the SPCS to develop a backup protection technical reference document. A SPCS sub-team was formed to lead the SPCS in the development of this document. The sub-team members are Bill Miller (lead), Rich Quest, Phil Winston, Hank Miller, Tom Wiedman and Jon Sykes. A third draft was presented at the SPCS’s July meeting and this work continues. The SPCS plans to present this white paper for PC approval at their December 2010 meeting.
5. Power Plant Controls CoordinationSPCS will be working on the development of a scope of work for this project and it is expected to be completed by the end of September. Once completed, a sub-team including industry experts on power plant controls will commence developing the technical reference document.
6. Assessment of Existing PRC StandardsInterpretation of PRC-004 and PRC-005 for Y-W Electric and Tri-State G&TSPCS has drafted responses to comments submitted during the most recent ballot and decided not to make any changes to the draft interpretation. SPCS is waiting for the recirculation ballot to be conducted.
7. Proposals for New Standards and SARSa. Project: 2009-07 Reliability of Protection Systems
The SPCS is continuing to provide support to the SAR drafting team.
b. Project: 2008-2 Undervoltage Load Shedding A sub-team has been assigned that is tasked to lead the assessment: Phil Tatro (Lead), Baj Agrawal, John Ciufo. This assessment should be completed for the December PC meeting
8. Status of SPCS-Related Standards Activitiesa. PRC-001 – Protection System Coordination. The Standard Drafting Team will be
submitting a revised draft for posting. A supplemental Standards Authorization Request (SAR) has been submitted to extend applicability to protection systems within an entity’s footprint in addition to those located at interfaces between entities.
b. PRC-002 – Disturbance Monitoring Equipment. The Standard Drafting Team will be submitting a revised draft for posting. The draft will contain Requirements only; development of Measures and compliance elements will occur for the subsequent posting.
c. PRC-005 – Protection System Maintenance and Testing. The Standard Drafting Team is revising the standard based on comments from the recent ballot.
d. PRC-006 – Automatic Underfrequency Load Shedding. The Standard Drafting Team is working on a revised draft to be posted for balloting in September.
e. PRC-023 – Transmission Relay Loadability. The Standard Drafting Team is revising the approved standard to incorporate modifications directed in Order No. 733.
f. PRC-024 – Generator Performance during Frequency and Voltage Excursions. The Standard Drafting Team is working on a revised draft for a second posting.
9. Alerts and Disturbances SPCS continues to provide protection and control support for studied disturbances.
10. Meeting Schedule. The SPCS has scheduled the following meetings in 2010–2011.
September 21–23
Niagara on the Lake (OPG hosted at Sir Adam Beck)
Tues Full DayWed Full DayThurs Half Day
November 9–11 Atlanta, GA (Georgia Power hosted)
Tues Full DayWed Full DayThurs Half Day
February 1–3 Tampa, FL (FRCC hosted – pending confirmation of availability)
Tues Full DayWed Full DayThurs Half Day
April 26–28 Charlotte, NC (SERC hosted)
Tues Full DayWed Full DayThurs Half Day
Agenda Item 6.iPlanning Committee Meeting
September 14–15, 2010
Data Coordination Subcommittee (DCS) Report
Action RequiredProvide feedback to questions in Review of DCS White Paper Key Issues by October 8, 2010.
Background1. The DCS completed a draft white paper, Planning Data Issues and Recommendation, which
addresses numerous planning data topics. At the June 2010 meeting, the PC approved posting the white paper for public comment. Fourteen entities provided comments. The white paper and the comments are posted at http://www.nerc.com/filez/dcs.html.
2. In its review of the comments, the DCS identified four core issues that it needed PC feedback on before it revised the white paper. These issues are posed as questions below. Each of them is discussed in greater detail in Attachment 1 (Review of DCS White Paper Key Issues) along with DCS recommendations.
Issues1. Is facility and load data below 100 kV (the limits of the Bulk Electric System in most regions) essential for
accurate BES results from steady-state and dynamics response modeling?
2. To what extent should data below 100 kV should be required?
3. How can that are interconnected to the Bulk Power System (i.e., “users, owners, or operators”) best be required to provide existing facility and forecasted load data?
4. How should planned (i.e., future) facility data be acquired?
3. The DCS requests PC comments on the questions above which are summarized on the last page of Attachment 1, including recommendations and options. Attachment 1 (Review of DCS White Paper Key Issues) is posted as a separate Word document at http://www.nerc.com/docs/pc/dcs/Review_of_DCS_White_Paper_Key_Issues_Sept_2010_PC_meeting.docx. Send comments to [email protected] by October 8, 2010.
Status Report1. The DCS developed Attachment 1 via e-mail among the members.
Agenda Item 6.i.1Planning Committee Meeting
September 14–15, 2010
Transmission Availability Data Systems Working Group (TADSWG)Report
Action RequiredNone – see status report below
Status Report1. The TADSWG has identified a future issue the Planning Committee (PC) needs to be aware
of concerning an evolving issue with Schedule 7 of EIA-411 – Coordinated Bulk Power Supply and Demand Program Report. TADSWG and NERC staffs have reviewed the issue with EIA and discussions continue. As previously reported to the PC, NERC has been designated as the mandatory respondent for Schedule 7. This mandatory reporting will begin with the calendar year 2010 data that must be reported to EIA by July 15, 2011. As stated in the Schedule 7 reporting instructions, the annual summary data will be provided from the TADS database. This latest version of Schedule 7 has a three-year effective date from January 1, 2011 to December 31, 2013. This request would require the reporting of calendar year data for 2010 to 2012. The Schedule 7 data for 2010 was identified in a draft survey distributed for public comment. NERC, through the TADSWG, DCWG and PC, provided comments on January 15, 2010. On April 8, EIA notified NERC it would update the draft Schedule 7 and ‘…adopted the NERC suggestions…without reservation.’ However, the EIA response included one notable exception and a statement about the (expected) content of the next version of Schedule 7. TADSWG is treating the latter as an indication of what is likely to occur. These are: For calendar year 2010, EIA will require that NERC report Schedule 7
information for ±100-299 kV DC voltage class. This is an issue since TADS DC reporting currently begins at ±200 kV.
In the next version of Schedule 7, slated to begin in 2014, EIA will require reporting of 2013 calendar year data. It is EIA’s intention to‘…migrate the 411 form towards a 100 kV lower limit for all transmission data.’ This is an issue since TADS AC reporting currently begins at ≥200 kV for all reported elements.
TADSWG is continuing discussions with EIA to (1) reconcile the DC circuit reporting gap for the ±100-199 kV voltage class, and, (2) assure the references in Schedule 7 to TADS are consistent with those in the TADS Manual and the data is contained in webTADS. To that second purpose, TADSWG provided additional direction to EIA to assure TADS─EIA compatibility. This included providing EIA a list of edits and a redline of Schedule 7 changes for consistency with TADS, with the exception of collecting ±100-199 kV DC outage data. Concerning ±100-199 kV DC outage data for 2010, unless EIA changes its reporting requirements, NERC will be required to directly contact the involved organization(s) and request the EIA mandated summary data. TADSWG has begun assessing options for gathering 100-199 kV (AC and DC) summary information that would allow NERC to respond to EIA’s future requirements. Further, TADSWG is also assessing how each option might be implemented and the appropriate schedule that would satisfy the implied EIA reporting requirements. Though EIA's 100-199 kV statement is not yet binding, TADSWG is treating the 100-199 kV statement as an
Agenda Item 6.i.1Planning Committee Meeting
September 14–15, 2010indication of a planned change to the 2013 outage data to be reported in the July 2014 Schedule 7 submittal to EIA. TADSWG is discussing options, plans, and schedules. TADSWG will keep the PC advised of its findings as they develop and will provide an update at future PC meetings until this issue is resolved.
2. During third quarter, TADSWG issued a proposed change in the current TADS Event Type Number definitions. Following NERC Rules of Procedure Section 1600, including advance notice to FERC, NERC proceeded to post the proposed changes for a 45-day public comment period. Comments that were accepted through August 23, 2010 are now being evaluated and will be responded to by the TADSWG. TADSWG will keep the PC advised of its findings as they develop and will provide further information at the December PC meeting.
3. The August 1 issuance of the TADS data validation questionnaire as detailed in the June 2010 report has been delayed to October 1 to allow for an additional round of content review by the TADSWG.
4. The work on the TADS supplemental analysis report, detailed in the June 2010 status report, was suspended by the TADSWG during its August 23-25 meeting. It was determined the supplemental analysis report should involve input from a cross-functional team of several NERC working groups that are using the TADS data and not the TADSWG alone. In the interim, TADSWG will be working with the RMWG, EAWG, and other NERC groups who use the TADS data to develop an appropriate report content and formulate analyses that are meaningful to a broader audience.
5. The TADS 2010 calendar year report, which will be the first to include both Automatic and Non-Automatic Outage data, is targeted for completion by June 2011. The TADSWG has begun developing the report content; however, the newly expanded report may require additional data validation, preparation, and publication time. The TADSWG is assessing the schedule and will provide an update at future PC meetings.
6. The TADSWG is working with the RMWG in developing the following metrics that are based on the information collected through TADS: ALR6-11 through ALR6-16.
7. Similar to last year, in late-October through early-December, the TADS staff with the assistance of Open Access Technologies International, Inc. (OATI) will conduct several Webinar training sessions on how/why/when TADS data is reported to the webTADS program operated by OATI. The sessions will not only train those new to the webTADS program, but more importantly, will also provide updated training to existing TADS users.
8. Beginning December 1, 2010, Transmission Owners may begin registering to participate in the calendar-year 2011 reporting to webTADS. Following registration, participants may begin to upload contact and inventory information. Early registration and entry of contact and inventory information is recommended by the TADSWG to assure all registered TOs are ready for the new calendar year.
9. The TADSWG three-year work plan has been updated to include the activities initiated and completed. The updated plan has been submitted to the PC Secretary.
Agenda Item 6.i.2Planning Committee Meeting
September 14–15, 2010
Demand Response Data Task Force (DRDTF) Report
Action RequiredNone – see status report below
Status Report1. On May 17, 2010, the NERC Board of Trustees unanimously approved the Rules of
Procedure: Section 1600-Request for Information or Data: Mandatory Collection of DADS Phase II Data included in the report entitled Demand Response Availability Data System (DADS): Phase I & II Final Report. The report and data collection forms (including definitions, instructions, and data submittal procedures) can be found at: http://www.nerc.com/filez/drdtf.html.
2. Based on recommendations from industry, the DRDTF will no longer be collecting quarterly data. Semi-annual data collection periods will be implemented for the future of DADS. The two annual collection periods will be centered around summer and winter peaks (as shown in the figure below).
3. Future actions include:a. First data submission (voluntary) scheduled for December 2010.b. DRDTF will process and disseminate data received during data collection process.
4. The DRDTF Chair position is currently open. NERC staff is soliciting recommendations for a new Chair of the DRDTF.
5. The work plan activities are on schedule.
DADS
Res
pons
ible
Ent
ities
De
man
d Res
pons
e Dat
a Ta
sk F
orce
April May Jun July Sep Oct Nov Dec Jan FebAug Mar
Reporting Period for Summer
Reporting Period for Winter
Data Gathering Summer
SummerDADS datadue
SummerReport
Published
Summer Winter
Receive Summer
DADS data
Receive Winter
DADS data
DADS Annual Reporting Schedule
Summer DataProcessing
Winter DataProcessing
WinterDADS datadue
Data Gathering Winter
WinterReport
Published
Agenda Item 6.i.3Planning Committee Meeting
September 14–15, 2010
Data Coordination Working Group (DCWG) Report
Action RequiredNone – see status report below
Status Report1. The DCWG submitted the 2010 Long-Term Reliability Assessment data to the Energy
Information Agency (EIA) on behalf of the electric industry as part of the Form EIA-411 filing.
2. Individual unit/plant data was collected for the first time as part of the 2010 Long-Term Reliability Assessment. The DCWG will continue to develop improved methods for gathering and submitting this data with a common and consistent approach.
3. The DCWG will be developing data collection methods for future Post-Seasonal Reliability Assessments based on the results and feedback from the 2009/2010 Post-Winter Reliability Assessment.
4. The DCWG continues to work with EIA to support future data needs and resolve data collection issues for the 2014 version of the Form EIA-411.
5. A meeting has not been held since the last PC meeting.6. Future activities include:
a. DCWG will meet with EIA in the fall 2010 to discuss the current status of EIA-411 changes and future coordination.
b. DCWG will begin development of the data collection forms for the 2011 Summer Reliability Assessment and the 2011 Long-Term Reliability Assessment during the fall 2010.
c. DCWG will incorporate the recommendations from the recently approved RIS report Recommendations for the Treatment of Controllable Capacity Demand Response Programs in Reserve Margin Calculations. Changes must be incorporated in 2011 and future data collections forms in order to fulfill these recommendations.
7. The three-year work plan activities for the DCWG are on schedule.
Agenda Item 6.kPlanning Committee Meeting
September 14–15, 2010
Smart Grid Task Force (SGTF) Report
Action RequiredApprove the report entitled Reliability Considerations from Integration of Smart Grid.
BackgroundThe SGTF presented a draft of this report to the Planning Committee at their June 15–16, 2010 meeting. Comments and enhancements from the Planning Committee members were requested by June 30, 2010. After that date, eight sets of comments were receive and subsequently incorporated into the current draft. Further, the report was reorganized to increase focus on bulk power system planning and operational challenges. Finally, key observations were added and a proposed follow-on work plan developed.
As this report is embargoed, instructions for downloading will be sent by e-mail to the “pc_plus” Lyris list by September 2, 2010.
Status Report1. NERC Staff integrated the eight sets of comments into the report, and enhanced the
Standards evaluation section to focus on how Smart Grid integration can provide additional options to meeting NERC Standards.
2. On August 6, 2010, the SGTF Leadership team met to review the changes, providing insights into the key observations and proposed follow-on work plan.
3. Work plan status: no changes until the Planning Committee approves the report.
Agenda Item 6.lPlanning Committee Meeting
September 14–15, 2010
Event Analysis Working Group (EAWG) Report
Action RequiredApprove proceeding with a field test of the elements of the Event Analysis Process.
BackgroundThe EAWG has been working closely with Dave Nevius in order to incorporate the working group’s ideas and work products into the Electric Reliability Organization Event Analysis Process – Working Draft dated August 31, 2010.
Status Report1. Reviewed and incorporated industry comments on NERC Event Categories and Levels of
Analysis document.2. Worked on reporting template for Event Analysis Report.3. Worked on clarifying roles, responsibilities and expectations for registered entities, Regional
Entities, and NERC for each category of event.
