reliability assessments subcommittee (ras) report highlights an… · web viewmethods to model...

AgendaPlanning Committee Meeting

December 7, 2010 | 1–5 p.m. (EST)December 8, 2010 | 8 a.m.–noon (EST)

Tampa Marriott Westshore1001 N. Westshore Blvd.Tampa, FL 33607 (813) 287-2555

1. Administrative Matters *a. Welcome and introductions - Tom Burgess

*b. Arrangements – John Seelke*c. Parliamentary procedures – John Seelke d. Announcement of quorum – John Seelke*e. NERC Antitrust Compliance Guidelines – John Seelke f. Approve agenda – Tom Burgess

*g. Future meetings – John Seelke*2. Consent Agenda

*a. Approve September 14–15, 2010 draft PC meeting minutes as final minutes*b. Approve the November 8, 2010 draft joint OC and PC Web meeting minutes as final minutes*c. Approve changes to the PC three-year work plan

3. Chairman’s Remarks a. Report on the November 3–4, 2010 Member Representative Committee and Board of Trustees

meetings4. Information Only

*a. Generator Model Validation for Dynamics Simulation – Dmitry Kosterev, Bonneville Power Administration, on behalf of the North American SynchroPhasor Initiative

*b. Upcoming Planning Committee Special Election – 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 the scopes of the Severe Impact Resilience Task Force (SIRTF) and the

Cyber Attack Task Force (CATF); status report of the Critical Infrastructure Strategic Initiatives Action Plan – Mark Lauby, Director, Reliability Assessment and Performance Analysis, NERC

*b. Status report on Frequency Response Initiative – Bob Cummings, Director, System Analysis and Reliability Initiatives, NERC

*c. Status report on System Modeling Initiative – Bob Cummings, Director, System Analysis and Reliability Initiatives, NERC

*d. Provide feedback by January 14, 2011 on a draft report review and approval process– John Seelke on behalf of the Planning Committee’s Executive Committee

*e. Discuss NERC strategic issues from the Planning Committee’s perspective – Tom Burgess*f. Discuss how the technical committees, in advance of NERC alerts, can contribute to review/advise

on the content of such alerts in the future – Tom Burgess*g. Provide feedback by December 31, 2010 on a concept document addressing technical

considerations for a common NERC-wide definition of the Bulk Electric System – Peter Heidrich, Manager of Reliability Standards, FRCC, on behalf of an ad hoc SAR team

6. Subgroup Reports PC Action*a. Reliability Assessment

SubcommitteeProvide feedback on 2011 scenario assessment proposals by January 14, 2011.Approve the RAS proposal for reporting market areas for reliability assessments.Provide feedback on proposed changes to the post-seasonal assessments by January 8, 2011.

*1. Load Forecasting Working Group

None – status report.

*b. Reliability Metrics Working Group

Approve RMWG scope change. Provide feedback by January 8, 2011on refinement to the Severity Risk IndexApprove Metric ALR6-16 – Transmission System Unavailability.

*c. G&T Reliability Planning Models Task Force

Approve:1. The revised the Metrics and Methodology document. The

previous version was approved at the September 2010 meeting.

2. Disbanding the G&T Reliability Models Task Force.*d. Integration of Variable

Generation Task ForceApprove the report Potential Reliability Impacts of Emerging Flexible Resources by IVGTF Team 1-5.Provide feedback by January 30, 2010 on the report Methods to Model and Calculate Capacity Contributions of Variable Generation for Resource Adequacy Planning by IVGTF Team 1-2.


Planning Committee Meeting Agenda 2December 7-8, 2010

6. Subgroup Reports PC Action*e. Geomagnetic Disturbance Task

ForceNone – status report.

*f. Resource Issues Subcommittee None – status report.*1. Loss-of-Load Expectation

Working GroupNone – status report.

*2. Generating Availability Data System Task Force


*g. Transmission Issues Subcommittee


*1. Model Validation Task Force

Approve the Power System Model Validation White Paper, including its associated work plan (Appendix C in the white paper).

*h. System Protection and Control Subcommittee

Approve:1. Posting a reliability guideline, Transmission System Phase

Backup Protection, for industry comment.2. A report to the Planning Committee, NERC SPCS

Technical Review of UVLS-Related Standards: PRC-010-0, PRC-020-1, PRC-021-1, and PRC-022-1.

3. A report to the Planning Committee, Reliability Fundamentals of System Protection

*i. Data Coordination Subcommittee


*1. Transmission Availability Data Systems Working Group

Approve the TADSWG recommendation to change the TADS Event Type Number data collection beginning with calendar year 2012 data, as detailed in the TADSWG letter to the PC dated November 12, 2010.

*2. Demand Response Data Task Force


*3. Data Coordination Working Group


*4. Spare Equipment Database Task Force

Approve revised SEDTF scope.

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 revised SGTF scope.*l. Events Analysis Working Group None – status report.


Planning Committee Meeting Agenda 3December 7-8, 2010

Agenda Item 1.aPlanning Committee Meeting

December 7–8, 2010

Welcome 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.gPlanning Committee Meeting


Future Meetings


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 LocationMarch1, 2011 Joint OC/PC/CIPC Web meetingMarch 8–9, 2011 Phoenix, AZ (confirmed)

Agenda Item 2Planning Committee Meeting


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 will defer discussion on the item until later in the meeting.

Each item has an attachment or a link to the referenced documents.

Agenda Item 2.a – Approve September 14–15, 2010 draft PC meeting minutes as final minutes (attached as Agenda Item 2.a)

Agenda Item 2.b – Approve the November 8, 2010 draft joint OC and PC Web meeting minutes as final minutes (attached as Agenda Item 2.b).

Agenda Item 2.c – Approve proposed PC three-year work plan changes:

1. The Resource Issues Subcommittee proposes new activity # 89 related to the coordination of the probabilistic metric reports by MRAs and deferring activity #82 (developing a method for defining "zones" (within an RTO or a region) and associated zonal data that will be used for more granular analysis of reliability (such as load pockets) for NERC's various reliability assessments) until 2012 or later when probabilistic reports are due per activity #89.

2. The 2010 activity status of three Integration of Variable Generation Task Force activities was changed to “completed”:

a. #141 – “Team 1.1: Make recommendations and identify changes needed to NERC’s MOD Standards.”

b. #142.2 – “Team 1.4: Resource planning processes should be adjusted to ensure that the designed system includes resources that provide the desired flexibility”; and “Produce a set of metrics based on the functions of the tasks on resource adequacy and transmission planning approach.”

c. #147.11 – “Team 2.1: Study variable resource-forecast tool requirements suitable for large amounts of variable generation and identify any gaps”; and “Report outlining the requirements of variable fuel (wind, solar, etc.) forecasting needed to maintain bulk power system reliability. In addition, the report will investigate current state-of-the-art forecasting tools and, thereby, identify gaps between the requirements and the current available technology.”

3. The recently-formed Spare Equipment Database Task Force proposes to add its first activity (#151).

4. The Generating Availability Data Systems Task Force proposes to extend the schedule on activity #201 – “Review and recommend whether Generation Owners on the NERC Compliance Registry should report GADS data on a mandatory basis” – to allow for further refinement of its draft report, with PC approval aimed for the March 2011 meeting.

These were the only changes. The proposed work plan (with the proposed changes in red font) is posted at http://www.nerc.com/filez/pcmin.html along with the December 7–8, 2010 PC meeting material.

http://www.nerc.com/filez/pcmin.html


December 7-8, 2010

Generator Model Validation for Dynamic Simulations


BackgroundA presentation for this item will be posted in a .zip file with other presentations on November 30 at http://www.nerc.com/filez/pcmin.html along with the December 7–8, 2010 PC meeting material.


Agenda Item 4.bPlanning Committee Meeting


Upcoming Planning Committee Special Election


BackgroundPC member Dick Kafka will be retiring at the end of this year, vacating his position in the investor-owned utility sector. A special election will be announced in late December 2010 for the remaining term on that position, which runs through the June 2012 meeting, as well as other committee vacancies in two sectors: electricity marketer sector (two vacancies) and large end-use customer sector (two vacancies).



Critical Infrastructure Strategic Initiatives Coordinated Action Plan Report

Action RequiredProvide feedback on: 1. Severe Impact Resilience Task Force scope (Attachment 1)2. Cyber Attack Task Force (Attachment 2)

Background1. The purpose of the Severe Impact Resilience Task Force (SIRTF) is to contribute to efforts to

enhance the ability of the bulk power system to withstand and recover from three severe-impact events as described in the Coordinated Action Plan. The SIRTF will report to the Operating Committee, who will approve its scope.

2. The purpose of the Cyber Attack Task Force (CATF) is to consider the impact of a coordinated cyber attack on the reliable operation of the bulk power system, and identify opportunities to enhance existing protection, resilience, and recovery capabilities. The CATF will report to the Critical Infrastructure Protection Committee, who will approve its scope.

Status Report1. The Joint Steering Group, comprised of NERC staff and the chairs and vice chairs of the

Planning, Operating, and Critical Infrastructure Protection Committees, held three conference calls to finalize the Coordinated Action Plan for Board of Trustees approval and provide guidance on the work plan activities and how they should be organized.

2. On November 4, 2010, NERC’s Board of Trustees approved the Critical Infrastructure Strategic Roadmap and the Critical Infrastructure Strategic Initiatives Coordinated Action Plan.1

3. The Joint Steering Group is coordinating efforts to establish the required task forces to meet the objectives of the Coordinated Action Plan, consistent with direction from the NERC Board of Trustees. The Joint Steering Group will engage with and monitor the progress of each task force, report progress to the Electricity Sub-Sector Coordinating Council (ESCC), and provide further guidance as necessary.

4. The Smart Grid Task Force efforts include the development of cyber security and risk metrics. This activity also supports the Coordinated Action Plan.

5. In the future, once these task forces are established, the Joint Steering Group will provide a consolidated status report for all task force efforts under the Coordinated Action Plan to help ensure that the NERC technical committees are well coordinated.

1 http://www.nerc.com/docs/ciscap/Critical_Infrastructure_Strategic_Initiatives_Coordinated_Action_Plan_BOT_Apprd_11-2010.pdf

http://www.nerc.com/docs/ciscap/Critical_Infrastructure_Strategic_Initiatives_Coordinated_Action_Plan_BOT_Apprd_11-2010.pdf

http://www.nerc.com/docs/ciscap/Critical_Infrastructure_Strategic_Initiatives_Coordinated_Action_Plan_BOT_Apprd_11-2010.pdf

6. Individual status reports for other task forces under this initiative (the Spare Equipment Database Task Force (SEDTF), portions of the Smart Grid Task Force (SGTF), and the Geomagnetic Disturbance Task Force (GMDTF)) are provided separately.

a. Separate work plans for the SEDTF and the SGTF are in the PC three-year work plan.



Frequency Response Initiative Status Report


BackgroundThe Frequency Response Initiative has multiple objectives:

Coordinate all NERC standards development and performance analysis activities related to frequency response and control

Identify specific frequency-related reliability factors Identify root causes of changes in frequency response Identify practices and methods to address root causes Consider impacts of integration of new generation technologies (such as wind, solar, and

significant nuclear expansion) Develop metrics and benchmarks to improve frequency response performance tracking Share lessons learned with the industry via outreach, alerts, and Webinars Determine if performance-based frequency response standards are warranted

Attachment 1 provides an update of activities under this initiative.

Agenda Item 5.cPlanning Committee Meeting


System Modeling Initiative Status Report


BackgroundAttachment 1 contains the background material.

Agenda Item 5.dPlanning Committee Meeting


Planning Committee Report Review and Approval Process

Action RequiredProvide feedback by January 14, 2011 on a draft report review and approval process.

BackgroundAt the September 2010 meeting, the System Protection and Control Subcommittee (SPCS) categorized reports into separate categories for Planning Committee approval. The discussion widened into a discussion of PC-approved reports in general. Chair Burgess asked that the SPCS provide any additional recommendations on this topic to Secretary John Seelke, and tasked the PC Executive Committee to consider the SPCS’s comments as well as those of the Executive Committee to recommend a PC process for approving and updating reports.

The Executive Committee convened a conference call on October 27 to discuss the issue. It received no additional recommendations from the SPCS, but considered their categorization as a starting point. Several Executive Committee members noted that the PC is asked to approve reports that are first made available to PC members two weeks prior to the meeting. Some of these reports are quite lengthy and technical and may require a PC member to obtain input from subject matter experts within his/her company. Therefore, a report approval process should provide members with adequate time to review reports prior to approval. Review time may be shortened if the need to approve a report is dictated by a deadline set by others outside of the PC, such as need to respond to a regulatory agency or the NERC Board of Trustee request or to assist another NERC committee or NERC staff.

The Executive Committee developed the draft process shown on the next page for report review and approval, and seeks comments on that draft process be provided to John Seelke ([email protected]) by January 14, 2011. The Executive Committee will review those comments and propose a final report review and approval process for approval by the PC at its March 2011 meeting. To facilitate comments, a Word version of the draft process may be downloaded at is posted at http://www.nerc.com/filez/pcmin.html along with the December 7–8, 2010 PC meeting material.


mailto:[email protected]

Draft Process for Planning Committee Approval of Reports

Report Category Review and Approval process

1. Reliability guidelines The review and approval process found in Appendix 4 of the Planning Committee Charter will be followed.

2. Long-term and seasonal reliability assessments

The PC will continue to separately approve the schedule for receiving and approving these documents. Seasonal assessments, which require approval between committee meetings, are being handled by Web meetings, with documents made available for review and comment about 10 days prior to the meeting.

3. Reports with deadlines set outside on the Planning Committee

The PC will approve a schedule for report review and approval that is consistent with the required deadline.

4. A report that accompanies a Section 1600 request for data or information

Section 1600 of NERC’s Rules of Procedure defines a process for requesting data or information from registered entities. The process requires a description of the data to be requested and why the data is needed, which is often documented in an initial supporting report prepared by a subgroup. An initial supporting report requires posting for public comment per Section 1600. A final supporting report contains the subgroup’s response to comments received and any modifications to the data request. The PC must approve both reports.

5. All other reports developed by a PC subgroup which will be posted on NERC’s Website when completed. This includes technical documents, white papers, special assessments, etc.

A draft report will be submitted at one meeting, with the opportunity to provide comments both during and after the meeting. Unless directed by the PC in its review of the draft report, there is no specific requirement for public posting and comment since the PC agenda that contains the draft report is publically noticed. A final report may be considered for approval no earlier than the next meeting. The final report will include a separate document that describes the comments received for the draft report and how they were addressed in the final report.

Except for reliability guidelines, the Executive Committee recognizes the need for flexibility for in the proposed review and approval process defined above. Therefore, it proposes that exceptions be brought to the PC at its regular meetings for members to approve, or to the Executive Committee if the exception cannot wait for a PC meeting.

Agenda Item 5.ePlanning Committee Meeting


NERC Strategic Issues from the Planning Committee’s Perspective



Agenda Item 5.fPlanning Committee Meeting


Potential Technical Committee Contributions to NERC Alerts





Technical Considerations for a NERC-Wide Definition of “Bulk Electric System”

Action RequiredProvide feedback by December 31, 2010 on a concept document addressing technical considerations for a common NERC-wide definition of the term “Bulk Electric System” (BES).

Background The background on this item is partially contained in three regulatory filings:

1. The Federal Energy Regulatory Commission (FERC) issued a Notice of Proposed Rulemaking (NOPR) on this subject on March 18, 2010 (http://www.nerc.com/files/NOPR_Re_Revision_ERO_DefinitionBES_31510.pdf ).

2. NERC responded to the NOPR on May 10, 2010, stating that any revision to the BES definition would need to be developed through its Reliability Standards Process (http://www.nerc.com/files/Final_Final_BES_NOPR_Comments.pdf).

3. FERC issued a final rule (Order 743) on November 18, 2010 (http://www.ferc.gov/whats-new/comm-meet/2010/111810/E-2.pdf). FERC’s news release (Attachment 1) and FERC Chairman Jon Wellinghoff’s statement (Attachment 2) describe this order.

Prior to the issuance of Order 743, an ad hoc team comprised of staff from NPCC, FRCC, and WECC was formed to develop a Standard Authorization Request (SAR) for a common BES definition. The initial team issued a letter on October 21 to the regions, informing them of their efforts, inviting the participation of additional regions, and describing their work plan. See Attachment 3. The present team has expanded to include members of NERC staff and RFC staff.

The team developed a concept paper addressing technical considerations for a common NERC-wide definition of BES. A Word version of concept paper is posted at http://www.nerc.com/filez/pcmin.html along with the December 7–8, 2010 PC meeting material. Comments on the concept document should be sent to [email protected] by December 31, 2010.



http://www.ferc.gov/whats-new/comm-meet/2010/111810/E-2.pdf

http://www.ferc.gov/whats-new/comm-meet/2010/111810/E-2.pdf

http://www.nerc.com/files/Final_Final_BES_NOPR_Comments.pdf

http://www.nerc.com/files/NOPR_Re_Revision_ERO_DefinitionBES_31510.pdf



Reliability Assessments Subcommittee (RAS) Report

Action RequiredProvide feedback on 2011 scenario assessment proposals by January 14, 2011.Approve the RAS proposal for reporting market areas for reliability assessments.Provide feedback on proposed changes to the post-seasonal assessments by January 8, 2011.

Background1. 2011 scenario assessment proposals.

The RAS has identified three potential scenario assessments to conduct for 2011. The RAS is requesting the PC consider each of these three proposals and identify those they would like to pursue:

i. Changing Fuel Mix Reliability Considerations

ii. Reliability Assessment on EPA Combined Rules, Phase II

iii. Dependence on Natural Gas

A description of the scenarios is provided in Attachment 1. Provide feedback by January 14, 2011 to [email protected].

2. RAS proposal for reporting market areas for reliability assessments.

a. One key to delivering credible and meaningful assessments of the bulk power system reliability is the establishment of suitable capacity/load regions/subregions. To improve NERC’s reliability assessments, RAS desired to provide increased granular data and analysis of the capacity/load conditions, which fairly and correctly represent the current and future conditions, regardless of regional membership boundaries. Increased subregional granularity was recommended in the approved Reliability Assessments Improvement Report from 2008.2

b. Capacity/load regions/subregions, for purposes of reliability assessment, should reflect the planning process used to identify resources needed to serve demand, thereby promoting increased granularity, clarity and accuracy. Creation of suitable capacity/load regions/subregions does not necessarily mean they must reside within Regional Entity boundaries.

c. Given the unique nature of ISOs/RTOs specific to organized markets and the Regional Entity membership boundary issue, for the 2011 reliability assessments, RAS recommends:

i. ISO/RTOs should provide resource/demand projections and self-assessments to NERC for Seasonal/Long-Term Reliability Assessments, regardless of whether they span multiple Regional Entities, with suitable vetting and peer review by affected Regional Entities.

2 http://www.nerc.com/files/Reliability%20Improvement%20Report%20RAITF%20100208.pdf

http://www.nerc.com/files/Reliability%20Improvement%20Report%20RAITF%20100208.pdf


ii. For those portions of a Regional Entity where an ISO/RTO does not exist, capacity/demand projections and self-assessments should be provided using logical capacity/load subareas within a Regional Entity’s boundaries.

d. The RAS requests approval of this approach in order to send applicable data requests to the Regional Entities in December. The proposed method (Attachment 2) serves as a guide for enhanced subregional reporting.

3. Proposed changes to the post-seasonal assessments.

a. 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.

b. Based on feedback at the NERC Board of Trustees meeting, the RAS is proposing changes to the structure of the post-season reports:

i. The report will be shortened (one page per Region\Reliability Coordinator).

ii. There will be a stronger focus on lessons learned.

iii. Data requirements will be lessened.

c. PC feedback on proposed changes to the post-seasonal assessments is requested to be sent to [email protected] by January 8, 2011.

Status Report1. The RAS met on October 13–14, 2010 to discuss the aforementioned action items and

upcoming reliability assessment documents.

2. 2010/2011 Winter Reliability Assessment.

a. A peer review was performed on the Regional self-assessments.

b. Key findings were discussed and incorporated into the final report.

c. A draft version of the 2010/2011 Winter Reliability Assessment was provided to the PC and OC on October 29 and approved on November 8.

3. A separate meeting is scheduled on November 23 to discuss the re-alignment of Regional Operational boundaries for the purpose of developing reliability assessments and coordinate Regional responsibilities and processes.

4. The RAS is on schedule with all three-year work-plan items.


Agenda Item 6.a.1Planning Committee Meeting


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 September 2010, the

updated 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 2010 LTRA.

2. A meeting was held in Vancouver on September 20–21.

a. Historical demand data reconstruction methods were discussed.

b. 2010 LFWG Bandwidth Report was reviewed.

3. The LFWG will hold its next meeting in Austin, TX in February 2011.

4. The vice chair position is still vacant.5. 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.

6. The LFWG is on schedule with all three-year work plan items and no material changes are needed to the 2011 work plan.



Reliability Metrics Working Group (RMWG) Report

Action RequiredApprove RMWG scope change. Provide feedback by January 8, 2010 on refinement to the Severity Risk Index. Approve metric ALR6-16 – Transmission System Unavailability.

Background1. The RMWG recommends the following two scope changes (redlined version – Attachment

1 and clean version – Attachment 2):a. Develop a methodology that will provide an integrated reliability assessment of the bulk

power system performance utilizing metric information and trends; andb. Publish quarterly Web site updates, an annual report, yearly Webinars, and high-level

performance on bulk power system reliability metrics assessment. The development of an integrated reliability assessment aims to inform, increase transparency, and assess the 17 metrics that were approved. The goal is to provide the industry meaningful trends of the bulk system performance and guidance on how they can improve reliability through an annual report, Web site updates, yearly Webinars, and high-level assessments.

2. The RMWG requests feedback on the refinement to the Severity Risk Index (Attachment 3).

With the OC/PC approval of risk assessment framework and concepts (available at http://www.nerc.com/docs/pc/rmwg/Integrated_Bulk_Power_System_Risk_Assessment_Concepts_Final.pdf) at the September meeting, RMWG applied the concepts and conducted preliminary sensitivity studies to evaluate risk factor selections and quantify their relative rankings. The RMWG recommends initially only considering transmission, generation and load losses to develop severity risk curves aggregated at NERC and interconnection level. Other risk factors (e.g., equipment damage) will be reviewed and updated periodically as a part of on-going open improvement process. The RMWG plans to coordinate with the EAWG to further refine the risk assessment approach. Please send feedback to Bill Adams ([email protected]) and Jessica Bian ([email protected]) by January 8, 2011.

3. The RMWG recommends the reliability metric ALR6-16 – Transmission System Unavailability (Attachment 4).

The RMWG has incorporated the comments and suggestions received at the September PC meeting. The RMWG proposes to pilot this metric for three to five years to assess whether it provides useful information for determining the performance of the bulk power system. Between October and November, the RMWG had three conference calls specifically to discuss input and needed changes; two of them were with those who commented.



http://www.nerc.com/docs/pc/rmwg/Integrated_Bulk_Power_System_Risk_Assessment_Concepts_Final.pdf

Status Report1. The RMWG held one face-to-face meeting on November 3–4, and six conference calls from

September to November 2010, completing the following work plan activities:

a. Worked with the ERO-RAPA (Reliability Assessment and Performance Assessment) regional group to pilot the approved metric ALR6-1 Transmission Constraint Mitigation;

b. Worked with the Reliability Coordinator Working Group (RCWG) to pilot the approved metric ALR1-5 System Voltage Performance;

c. Worked with the System Protection and Control Subcommittee (SPCS) and the ERO-RAPA to make the protection system misoperation reporting consistent across the eight Regions, including categories and cause codes (the reporting template is expected to be finalized by December 10, 2010); and

d. Received eight sets of voluntary submittals of the ALR3-5 IROL/SOL Exceedance from 15 Reliability Coordinators for the 2010 third quarter period.

Agenda Item 6.cPlanning Committee Meeting


G&T Reliability Planning Models Task Force (GTRPMTF) Report

Action RequiredApprove:1. The revised the Metrics and Methodology document. The previous version was approved at

the September 2010 meeting.2. Disbanding the G&T Reliability Models Task Force.

Background1. At the September 2010 meeting, the PC approved the recommendations in the G&TRPMTF

Final Report on Methodology and Metrics, posted at http://www.nerc.com/docs/pc/gtrpmtf/GTRPMTF%20Meth%20&%20Metrics%20Report%20final%20w.%20PC%20approvals,%20revisions.pdf. By its approval of the recommendations, the PC approved the Methodology and Metrics document in Appendix 3 of that report. The PC also required the GTRPMTF to prepare a report outline for use by individual metrics reporting areas. The recommended report outline for use by individual metrics reporting areas has been appended to the revised Methodology and Metrics document as Table 3. As a result of developing the report outline, the task force recommends minor changes to the Metrics and Methodology document that add clarity and consistency. Attachment 1 is a redline of the previously approved Methodology and Metrics document with the report outline and recommended changes, and Attachment 2 is a clean version. The report outline was reviewed with the Resource Issues Subcommittee (RIS), who made minor changes that were generally agreeable to the task force. The RIS has responsibility for coordinating most aspects of the implementation plan described in the aforementioned report. The report outline will first be used by areas that volunteer for the 2011 pilot reporting prior to 2012 mandatory reporting.

If the revised Methodology and Metrics document is approved, the G&TRPMTF Final Report on Methodology and Metrics that has the previously approved document in Appendix 3 will be replaced and the report updated to reflect decisions from this PC meeting.

2. Having completed the tasks defined in its scope, the G&T Reliability Planning Models Task Force respectively requests that the PC disband it.

Status Report1. A conference call was held on October 22, 2010 to discuss a draft report outline and

comments received by members. Subsequently a revised report outline and redlined Methodology and Metrics document was circulated for comment by task force members. No comments were received. That version was provided to the RIS for their comment.

2. Chair Paul Kure, who is also a RIS member, discussed the report format and the revised Methodology and Metrics document at the November 16, 2010 RIS meeting. RIS comments were incorporated. RIS comments were discussed in a November 18 GTRPMTF call and incorporated with minor modifications.

http://www.nerc.com/docs/pc/gtrpmtf/GTRPMTF%20Meth%20&%20Metrics%20Report%20final%20w.%20PC%20approvals,%20revisions.pdf

http://www.nerc.com/docs/pc/gtrpmtf/GTRPMTF%20Meth%20&%20Metrics%20Report%20final%20w.%20PC%20approvals,%20revisions.pdf

Agenda Item 6.dPlanning Committee Meeting


Integration of Variable Generation Task Force (IVGTF) Report

Action Required1. Approve the report Potential Reliability Impacts of Emerging Flexible Resources (IVGTF1-

5); and2. Provide feedback on Methods to Model and Calculate Capacity Contributions of Variable

Generation for Resource Adequacy Planning by January 30, 2010.

Background1. 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 that 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 .

2. The report Methods to Model and Calculate Capacity Contributions of Variable Generation for Resource Adequacy Planning contributes to the overall reliability by providing current methods and practices of calculating capacity contributions derived from analysis of methods from different regions. The report recommended continued analysis of related metrics on resource adequacy, alternative approach from other forms of variable generation, and future coordination with other groups in developing transparency on the topics of resource adequacy. The report is available at http://www.nerc.com/docs/pc/ivgtf/IVGTF1-2_DRAFT_11.22.pdf. Provide feedback by January 30, 2010 to [email protected] (IVGTF1-2).

Status Report1. IVGTF1-5: Team lead Daniel Brooks (EPRI) submitted and completed the PC review in

September 2010. The report incorporates all comments received from the IVGTF leadership and NERC staffs.

2. IVGTF1-2: Team lead Michael Milligan conducted biweekly meetings and coordinated discussions with industry experts on adequacy. The report will be presented to the members of the Resource Issue Subcommittee (RIS) for additional comment. The IVGTF1-2 consists of 13 members representing the regions ERCOT, PJM, Ontario IESO, CAISO, and WECC. This report incorporates the feedback received from the IVGTF chairs and team leads.

3. All remaining subgroups are now developing and preparing their reports and recommendations.

4. The work plan has been enhanced to reflect changes to schedules.


http://www.nerc.com/docs/pc/ivgtf/IVGTF1-2_DRAFT_11.22.pdf

http://www.nerc.com/docs/pc/ivgtf/IVGTF1-2_DRAFT_11.22.pdf

http://www.nerc.com/docs/pc/ivgtf/IVGTF_Task_1_5_Final.pdf

Agenda Item 6.ePlanning Committee Meeting


Geomagnetic Disturbance Task Force (GMDTF) Report

Action RequiredNone - see status report

Status Report1. The GMDTF does not have a chair or vice chair and urges industry support.

Agenda Item 6.fPlanning Committee Meeting


Resource Issues Subcommittee (RIS) Report


Status ReportThe RIS held a meeting in Baltimore, MD on November 16, 2010. The major topics and conclusions/actions are described below:

1. The RIS conducted a survey of the metrics reporting areas (MRAs) as defined the G&T Reliability Planning Models Task Force’s (GTRPMTF’s) Methodology and Metrics document to determine their readiness to perform probabilistic resource adequacy metrics calculations that incorporate transmission constraints. The RIS was assigned the coordination of this effort at the September 2010 PC meeting. Attachment 1 is Table 1 from that document and it defines the MRAs. A blank survey and the survey results are available at http://www.nerc.com/filez/ris.html. The survey was sent to 57 entities and 34 responded. Although WECC will be doing the analysis for its eight MRAs, it asked that the survey be sent to the individual entities. SERC, who will also be performing the analysis for the all of its four reporting MRAs, provided one response. The readiness status of each MRA is provided in the table below. Overall, most MRAs appear ready to develop the requested probabilistic metrics defined by the GTRPMTF.

Region Readiness StatusMulti-region RTOs Each of these MRAs (PJM, MISO, and SPP RTO) is prepared to

develop the required analysis metrics. ERCOT Although ERCOT (MRA #4) did not respond, we believe ERCOT is

prepared to do this analysis based upon previous discussions, but need to confirm.

FRCC FRCC (MRA#5) is prepared to do the analysis. Their present modeling approach does not include transmission constraints because they are not deemed significant.

MRO MRA # 6 (MRO (US) less MISO and SPP RTO areas in MRO (US)) is the Mid-Continent Area Power Pool. They ceased doing this type of analysis in 2009; however, they will be discussing this with their members. We need to ensure that they do not include any members that are included in MISO.MRA #7 (MRO (Canada)) included Manitoba Hydro and SaskPower. Manitoba Hydro is prepared but prefers to be its own MRA and not be combined with SaskPower. SaskPower did not respond.

NPCC NPCC will perform the analysis for its five MRAs since it now produces the requested metrics in the NPCC long-range resource adequacy overview.

RFC RFC will have no reporting MRAs since they are included within MISO or RFC.

http://www.nerc.com/filez/ris.html

Region Readiness StatusSERC SERC will be performing the analysis for it four reporting MRAs.

The Gateway MRA in SERC will not be reporting since it is included in MISO.

SPP The SPP RTO will include MRA #20 (entities in the SPP RE that are not in the SPP RTO) in their analysis and break out their metrics separately.

WECC WECC will be performing the analysis for all eight of its MRAs.

2. The RIS discussed the draft MRA report outline prepared by the GTRPMTF and made several comments on that document as well as the Methodology and Metrics document for consideration by the GTRPMTF.

3. The RIS reviewed a draft GADSTF report with several NERC staff members who had participated in its development. The draft report recommended mandatory GADS reporting using Section 1600. While the RIS is generally supportive of mandatory GADS reporting, it felt that the case for mandatory reporting had not been adequately made. Follow-up activities are described in the GADSTF report.

4. The RIS reviewed the status of the metric, Expected Reserve Margin, which had been submitted to the Reliability Metrics Working Group in April 2010. Attachment 2 has a description of the metric. The RIS discussed including this metric in reliability assessments since the only missing data to do the calculation of expected capacity on forced outage at time of system peak – that could be easily developed by reporting areas since they will need to use unit forced outage rates in calculating probabilistic resource adequacy metrics. RIS will be following up with the Reliability Assessment Subgroup on including this metric in the 2012 LTRA. There was considerable debate on the name of the metric. This may require changing before implementation.

5. On its work plan, the RIS added activity # 89 related to the coordination of the probabilistic metric reports by MRAs and deferred activity #82 (developing a method for defining "zones" (within an RTO or a region) and associated zonal data that will be used for more granular analysis of reliability (such as load pockets) for NERC's various reliability assessments) until 2012 or later when probabilistic reports are due per activity #89.

a.

Agenda Item 6.f.1Planning Committee Meeting


Loss-of-Load Expectation Working Group (LOLEWG) Report


Status Report1. The LOLEWG had no meetings or conference calls.

2. A meeting is being planned for January 20–21, 2011 in Atlanta, and a call for presenters on topics of interest identified from the last meeting has been sent to members and observers.

3. The capability for LOLEWG members to have a private Web location is being implemented by NERC staff to post such items as draft documents before public posting.

Agenda Item 6.f.2Planning Committee Meeting


Generating Availability Data System Task Force (GADSTF) Report


Status ReportOn June 16, 2010, the NERC Planning Committee approved the creation of the Generating Availability Data System Task Force (GADSTF). The GADSTF was asked to review and recommend whether Generation Owners on the NERC Compliance Registry should report GADS data on a mandatory basis. See the task force scope. (http://www.nerc.com/docs/pc/gadstf/GADSTF_Scope_Approved_061610.pdf)

The following activities have occurred since the September 2010 PC meeting:

1. Forty-nine GADSTF members have been involved in the discussions and subgroup reports to the general GADSTF body (one chair, 20 appointed by the Regions, 24 observers, and four NERC staff).

2. The GADSTF was divided into four subgroups for review of GADS major parts: design, event, performance and renewable unit records. Each subgroup conducted a series of conference calls to assess whether GADS (generally) should become mandatory and what parts of their assigned area should be required/voluntary reporting.

3. The subgroups conducted 18 conference calls and one face-to-face meeting. More than 600 hours have been dedicated to discussions and writing reports.

4. Leaders, assistant leaders, and secretaries for each of the four subgroups presided over the calls and subgroup breakout sessions at the face-to-face meeting.

5. Each subgroup reported on their activities and posted their recommendations on the NERC Web site at http://www.nerc.com/filez/gadstf.html.

6. From the subgroup recommendation reports, NERC staff compiled data and drafted a report for review and approval by the Resource Issues Subcommittee (RIS).

7. After review, the RIS felt the GADSTF report needed more justifications for several of the recommendations. NERC staff is now reviewing and revising the GADSTF report, to be resubmitted to the RIS. The next RIS review will be in mid-January 2010, after the next PC meeting.

8. The three-year work plan has been updated.

http://www.nerc.com/filez/gadstf.html

http://www.nerc.com/docs/pc/gadstf/GADSTF_Scope_Approved_061610.pdf



Transmission Issues Subcommittee (TIS) Report


Status ReportSee Attachment 1.

Agenda Item 6.g.1Planning Committee Meeting


Model Validation Task Force (MVTF) Report

Action RequiredApprove the Power System Model Validation White Paper, including its associated work plan (Appendix C in the white paper).

BackgroundThe MVTF presented a similar draft white paper at the June 2010 PC meeting. At the meeting, the committee agreed to acknowledge the situational assessment content of the white paper; approved proceeding with recommendation 53 consistent with the standards development plan; and directed the MVTF to come back with an updated whitepaper in September 2010 for PC approval with refined recommendations (e.g., more specificity, what is short-term and long-term, who should undertake, etc.) and an associated implementation plan.

The PC’s directives are addressed in this new draft, which is posted at http://www.nerc.com/filez/pcmin.html along with other December 7–8, 2010 PC meeting material.

Status Report 1. The inaugural meeting was held on November 11, 2010 at ERCOT facilities in Taylor,

Texas. The group began work on Task 1.1 (Development of a procedure for power system powerflow model validation) and Task 1.2 (Development of a procedure for power system dynamics model validation). An outline was constructed for each procedure.

2. A second meeting will be hosted by FRCC on December 6, 2010 in Tampa, FL

3 Recommendation 5 stated “The Planning Committee should assign the TIS or MVTF to develop a list of suggested improvements for a Standard Authorization Request (SAR).”


Agenda Item 6.hPlanning Committee Meeting


System Protection and Control Subcommittee (SPCS) Report

Action RequiredApprove:1. Posting a reliability guideline, Transmission System Phase Backup Protection, for industry

comment.2. A report to the Planning Committee, NERC SPCS Technical Review of UVLS-Related

Standards: PRC-010-0, PRC-020-1, PRC-021-1, and PRC-022-1.3. A report to the Planning Committee, Reliability Fundamentals of System Protection

These documents are posted at http://www.nerc.com/filez/pcmin.html along with other December 7–8, 2010 PC meeting material.

Background1. The SPCS has developed a reliability guideline, Transmission System Phase Distance

Backup Protection, in response to a number significant system disturbance reports since the 2003 Northeast Blackout that have recommended evaluating specific applications of adding backup and/or redundant protection The most significant of these is the FRCC report from the February 26, 2008 system disturbance which recommends that “NERC should assign the System Protection and Control Task Force to produce a technical paper describing the issue and application of backup protection for autotransformers.” The SPCS has classified its report as a Reliability Guideline because it includes a recommendation to industry regarding application of backup protection on large autotransformers. In accordance with Appendix 4 of the Planning Committee charter, the SPCS requests Planning Committee approval to post the document for industry comment.

2. The SPCS has developed a report to the Planning Committee on its assessment of the existing standards relating to developing, documenting, and evaluating performance of UVLS programs. The report recommends a number of modifications to these standards including consolidation into one standard. The report also recommends development of a Transmission Issues Subcommittee (TIS) paper on coordination of certain Protection Systems through assessments of system performance. The second recommendation has been coordinated with the TIS.

a. The SPCS recommends that the SAR for Project 2008-02 – Undervoltage Load Shedding, should be modified to include addressing the recommendations presented in this report. Project 2008-02 is not one of the 17 High Priority Projects Under Development (it is on the list of Additional Projects to be Initiated in Order of Priority). Since work on this project has not commenced, there is adequate time to amend the SAR for this project.

b. The SPCS recommends that the NERC Transmission Issues Subcommittee, with support from the SPCS and other groups as necessary, develop a paper on the subject of coordinating the design and operation of UVLS programs with transmission system protection, generator protection and control, UFLS programs, and other UVLS programs. The SPCS notes that the issue of coordinating Protection Systems that respond to different quantities such as voltage, frequency, apparent impedance, and excitation, is not traditional relay-to-relay coordination. Coordination must be


addressed in assessments of system performance to compare the response of protections responding to different quantities, and to account for time-based and location-based variations in these quantities. This paper can be used to support the Project 2008-02 Standard Drafting Team and should include consideration of modifications to the Modeling (MOD) Reliability Standards to ensure that data is provided and proper modeling is included as necessary to support coordination through assessments of system performance.

3. The SPCS was charged with developing a section for the Reliability Fundamentals Working Group (RFWG) Reliability Concepts document, addressing reliability fundamentals associated with system protection. Although work on expanding the Reliability Concepts document has ceased, the SPCS believes there is value in publishing this work as a stand-alone report describing basic fundamental reliability concepts associated with system protection in basic terms. Should work resume on the NERC Reliability Concepts document in the future, this information could easily be reformatted and incorporated into the document.

Status Report1. Backup Protection Technical Reference Document

a. Assignment : The PC has authorized the SPCS to develop a backup 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.

b. Status : The SPCS sub-team has completed this document and the full SPCS has reviewed and approved submitting the document for Planning Committee approval to post the document for industry comment as a Reliability Guideline.

2. Reliability Fundamentals a. Assignment : Develop a Protection Chapter for the NERC Reliability Concepts document.b. Status : The SPCS sub-team has completed this document and the full SPCS has reviewed

and approved submitting the document for Planning Committee approval.

3. Assessment of Existing PRC Standardsa. Project: 2008-2 Undervoltage Load Shedding

The SPCS sub-team has completed this document and the full SPCS has reviewed and approved submitting the document for Planning Committee approval.

4. SPCS/TIS Document on Response of Protective Relays to Power Swingsa. Assignment : Develop a white paper, with support from TIS, on the subject of the

response of protective relays to power swings. This paper will support development of a standard on this subject, as directed in FERC Order No. 733.

b. Status : The SPCS has completed a first draft of its sections of the document. The SPCS has met with the TIS-team supporting this effort to discuss methods for assessing performance in system studies. The present schedule calls for submitting a document to the Planning Committee for consideration at its March 2011 meeting.

5. Power Plant Controls CoordinationWork on this project has been deferred. A draft scope will be considered by the SPCS at its February 2011 meeting. Once completed, a sub-team including industry experts on power plant controls will commence developing the technical reference document.

6. AURORA Industry AlertThe SPCS discussed this Alert and provided feedback on potential solutions to NERC Staff.

7. 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. Posting the documents for comment will be dependent on availability of NERC staff to perform a Quality Review.

c. PRC-005 – Protection System Maintenance and Testing : The revised definition of Protection System was approved by industry and has been submitted for NERC Board of Trustees approval at its November 19 meeting. The revised standard has been posted through December 17 for another 30-day formal comment period with a successive ballot to be conducted during the final 10 days of the comment period.

d. PRC-006 – Automatic Underfrequency Load Shedding. This standard was approved by the NERC Board of Trustees on November 4, 2010. NERC Staff is working on the filing.

e. PRC-023 – Transmission Relay Loadability : The standard has been revised to address FERC directives in Order No. 733. The revised standard was posted for a 30-day informal comment period and has been revised based on industry comments. The revised standard has been posted through December 16 for a 45-day formal comment period with an initial ballot to be conducted during the final 10 days of the comment period.The Standards Committee has approved formation of a drafting team for Phase II of this project to develop the FERC directed standard on generator relay loadability.

f. PRC-024 – Generator Performance during Frequency and Voltage Excursions : The Standard Drafting Team is working on a revised draft for a second posting.

g. Interpretation of PRC-004 and PRC-005 for Y-W Electric and Tri-State G&T : The SPCS has drafted responses to comments submitted during the most recent ballot and decided not to make any changes to the draft interpretation. The interpretation has been posted for a recirculation ballot through December 3.

8. Alerts and Disturbances SPCS continues to provide protection and control support for studied disturbances.

9. Meeting Schedule. The SPCS has scheduled the following meetings in 2011.

February 1–3 Ft. Worth, TX (Oncor hosted)

Tues Full DayWed Full DayThurs Half Day

April 26–28 Charlotte, NC (SERC hosted)


June 28–30 San Francisco, CA (PG&E hosted)


September 28–30 Minneapolis, MN (Xcel hosted)


November 8–10 Location TBD Tues Full DayWed Full DayThurs Half Day

Agenda Item 6.iPlanning Committee Meeting


Data Coordination Subcommittee (DCS) Report

Action RequiredNone – status report only

Status Report1. The DCS held a Web meeting on November 1, 2010, to address the issue of system modeling

below 100 kV. The material for this meeting is posted at http://www.nerc.com/docs/pc/dcs/System%20Modeling%20Below%20100%20kV%2011.01.10%20with%20notes.pdf. The registered attendance totaled 88 participants.

2. There was not a consensus that all network facilities, a term defined in the presentation for discussion purposes only, need to be modeled explicitly for steady-state and dynamic models. Several participants noted that distribution voltage level facilities may be networked with the bulk power system, and that network equivalents could be used instead of explicit modeling, depending upon the issue being analyzed. The use of equivalents made a wide-area analysis easier to solve from a computer perspective. But for a small-area analysis that is focused on local alternatives, explicit modeling is probably appropriate. Another participant stated that the need for data below 100 kV should be left to the discretion of the Transmission Planner.

3. The DCS will be meeting on December 7 prior to the PC meeting to continue the discussion of this and other issues.

http://www.nerc.com/docs/pc/dcs/System%20Modeling%20Below%20100%20kV%2011.01.10%20with%20notes.pdf

http://www.nerc.com/docs/pc/dcs/System%20Modeling%20Below%20100%20kV%2011.01.10%20with%20notes.pdf

Agenda Item 6.i.1Planning Committee Meeting


Transmission Availability Data Systems Working Group (TADSWG)Report

Action RequiredApprove the TADSWG recommendation to change the TADS Event Type Number data collection beginning with calendar year 2012 data, as detailed in the TADSWG letter to the PC dated November 12, 2010 and which is posted at http://www.nerc.com/filez/pcmin.html along with other December 7–8, 2010 PC meeting material.

BackgroundAs stated in the original TADS Phase I report “…we believe that the greatest use of TADS data will be for outage cause analysis and outage event analysis.” If we delay changing the proposed Event Type Numbers for several more years, approximately one-quarter of the TADS event characteristics will continue to be unidentified on a NERC-wide basis. The proposed Event Type Number categories will aid in the determination of credible contingencies and will result in a better understanding of the “Other” events. The increased granularity of the data will increase the understanding of actual NERC-wide events that could allow for improved system analysis by bridging gaps between the operating environment and planning assumptions, and may therefore influence the development of future NERC planning and operating standards.

The recommendation followed the NERC Rules of Procedure Section 1600, including advance notice to FERC, NERC posting of the proposed changes for a 45-day public comment period ending August 23, 2010, and evaluation of the comments by the TADSWG for final recommendation. The TADSWG recommendation was reviewed and approved by the Data Coordination Subcommittee. After the above NERC PC action is taken, NERC will send the recommendation to the NERC Board of Trustees for final approval.

Status Report1. EIA notified NERC that “… on October 5, 2010, the Office of Management and Budget

(OMB) notified the U.S. Energy Information Administration of its approval of the Electricity 2011 forms, including Form EIA-411, Coordinated Bulk Power Supply Program Report. We greatly appreciate the extensive contributions made by NERC and the electric industry representatives on the Data Coordination Working Group and the Transmission Availability Data System Working Group to enhance the EIA-411 survey. We also look forward to continued cooperation between NERC and EIA.” This latest version of Schedule 7 has a three-year effective date from January 1, 2011 to December 31, 2013, and would affect reporting of calendar year data for 2010 to 2012. Future versions of Schedule 7 could have a two-year effective date, thus accelerating any NERC efforts required by the revised forms.

As noted in September’s status update to the PC, the TADSWG is continuing its evaluation of EIA’s intention to”…migrate the 411 form towards a 100 kV lower limit for all transmission data.” This is an issue since TADS reporting currently begins at ≥200 kV for all reported Elements. If this is required in the next version of Schedule 7, it would affect how the 2013 calendar year data is collected.


2. Issuance of the TADS data validation questionnaire as detailed in the June and September 2010 status reports to the PC has been delayed as NERC staff and the TADSWG review effective detailed processes, yet to be determined, for coordinating this review effort through the Regional Entities.

3. The TADSWG is making good progress on the format changes for the 2010 calendar year reports. These reports will be the first to include both Automatic and Non-Automatic Outage data and are 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 which may cause a delay to the third quarter.

4. NERC staff, with the assistance of Open Access Technologies International, Inc. (OATI), has conducted four Webinar training sessions on how/why/when TADS data is reported to the webTADS program operated by OATI. The sessions train those new to TADS/webTADS and provide updated training for existing reporters/users. Remaining training for 2010 includes: an OATI webTADS software class on December 9 and a Data Instruction class on December 14.

5. The TADSWG is working with the RMWG in revising metric ALR6-16 to better align with TADS since it was not approved by the PC as originally proposed.

6. Beginning December 1, 2010, Transmission Owners (TOs) 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 ensure all registered TOs are ready for the new calendar year.



Demand Response Data Task Force (DRDTF) Report


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.

3. The group has not met since the last PC meeting.

4. NERC staff is currently in negotiations with a vendor for a Web application to support the mandatory data reporting requirements of DADS Phase II.

5. Future actions include:

a. The DRDTF will process and disseminate data received during data collection process.

b. Mandatory reporting is scheduled for December 2011.

6. The DRDTF chair position is currently open. NERC staff is soliciting recommendations for a new chair of the DRDTF.

7. The three-year work plan activities are on schedule

http://www.nerc.com/filez/drdtf.html



Data Coordination Working Group (DCWG) Report

Action RequiredNone– see status report below

Status Report1. A DCWG meeting was held on October 20 to discuss the data collection for the 2010/2011

Winter Reliability Assessment and enhancements to the 2011 data collection.

2. The DCWG submitted the final 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.

3. 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.

4. 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.

5. The DCWG continues to work with EIA to support future data needs and resolve data collection issues for the new version of the Form EIA-411. EIA has indicated that they are proposing shortening the EIA form development cycle from a three-year cycle to a two-year cycle. This most notably affects DCWG as a new Form EIA-411 may be implemented by 2013. The DCWG does not expect this to cause any issues.

6. A meeting has not been held since the last PC meeting.

7. 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 of 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.

8. The three-year work plan activities for the DCWG are on schedule.



Spare Equipment Database Task Force (SEDTF) Report

Action RequiredApprove a revised SEDTF scope.

BackgroundThe initial SEDTF scope was approved at the PC meeting in September 2010 and is included as Attachment 1. The scope was later reviewed and suggestions were offered from the PC, OC and CIPC as well as SEDTF leadership to improve upon the scope. A clean version of this revised scope is included as Attachment 2 and a redline comparing the two scopes is included as Attachment 3. The following high-level enhancements were made:

A greater emphasis on reviewing processes for identification of spare equipment to respond to HILF situations has been added;

Activities and milestones have been expanded; and

The task force will now report to the PC.

Status Report1. PC members Dale Burmester of ATC and Mark Westendorf of MISO are the SEDTF chair

and vice chair, respectively. Thus far, the request for nominees resulted in 19 members and ten observers. Additionally, seven members from NERC will be kept advised of the work for its possible effects on other NERC programs. Several regional membership slots remain open and nominees for these slots are welcomed. A table showing the membership slots and the number of members and observers on SEDTF is noted below:

SEDTF Scope Member ObserverOfficers 2 (chair, vice chair) ─

FRCC (2) ─ ─MRO (2) 2 ─NPCC (2) 3 ─RFC (2) 6 ─

SERC (2) 4 ─SPP (2) ─ ─TRE (2) 2 ─

WECC (2) 1 ─Canada (2) (1 see MRO) ─

Industry Experts 1 2Industry Associations 1 4Government Agencies ─ 6

NERC Staff ─ 7

2. The SEDTF held its initial Web meeting on November 9 to review the scope, discuss the deliverables and proposed time schedule, and to divide the work among the two focus subgroups. One subgroup will review potential SED long-lead time equipment and its design

criteria. The second subgroup will review the operational, software and management issues associated with collecting, storing, distributing, and essentially managing SED data. Collectively, the SEDTF will review the SED policies and procedures and how they might complement existing industry spares programs and interact with the other NERC efforts.

3. Face-to face and Web meetings are being scheduled. A face-to-face meeting will be held in Tampa immediately following the PC meeting. To accomplish the activities identified for the next year, the SEDTF will schedule quarterly face-to-face meetings and hold Web meetings on the first and third Tuesday of each month beginning in January 2011.

Agenda Item 6.kPlanning Committee Meeting


Smart Grid Task Force (SGTF) Report

Action RequiredApprove a revised SGTF scope – see Attachment 1 (redline) and Attachment 2 (clean).

BackgroundThe PC approved the Reliability Considerations from the Integration of Smart Grid report at its September 2010 meeting. Four tasks were identified in the work plan outlined in the report, which are now incorporated into the revised scope:

1. Integration of smart grid devices/systems requires development of new planning/operating tools, models and analysis techniques.

2. Integration of smart grid devices/systems will change the character of the distribution system, potentially affecting bulk power system reliability.

3. Engage Standard Development Organizations in the U.S. and Canada to increase coordination and harmonization in standard development.

4. Develop risk metrics that measure current and future system physical and cyber vulnerabilities from smart grid integration.

Status Report1. The report was sent to NERC’s Board of Trustees for their review and approval, which is

slated for November 19, 2010.

2. Work plan status: No change until the Planning Committee approves the new task force scope.

Agenda Item 6.lPlanning Committee Meeting


Event Analysis Working Group (EAWG) Report

Action RequiredNone– see status report below

Status ReportAttachment 1, which describes the status of the ongoing event analysis field trial, is excerpted from the Joint OC/PC/CIPC November 30 presentation of Mr. Tom Galloway, senior vice president and chief reliability officer.

reliability assessments subcommittee (ras) report highlights an… · web viewmethods to model...

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