Meeting Minutes Resource Subcommittee January 27-28, 2016 Tucson Electric Power 88 East Broadway Boulevard Tucson, Arizona Administrative A meeting of the Resources Subcommittee (RS) was held on January 27–28, 2016 in Tucson, Arizona. The agenda and attendance list are attached as Exhibits A and B, respectively. Resources Subcommittee Chair Troy Blalock presided and Larry Kezele announced that a quorum was present. Mr. Kezele read the applicable Notice of Public Meeting and acknowledged the NERC Antitrust Compliance Guidelines. The subcommittee reviewed and revised the RS Organization and Assignments, the RS Roster and the RS Survey Contacts. Resolution of Appreciation – Gerry Beckerle Whereas, Gerry Beckerle has served as the Resources Subcommittee (RS) Chair for the past two years and formerly as the Vice Chair. Whereas, Gerry Beckerle has led the NERC Resource Subcommittee in its efforts of improving primary frequency response, the creation of Guidelines related to the Loss of Communication and Primary Frequency Response and other efforts in support of improving the reliability of the Interconnections. Whereas, Gerry Beckerle has represented the NERC RS diligently, effectively and admirably at NERC Operating Committee meetings. Resolved, that the RS thanks Gerry for his leadership, vision, and contribution to the Reliability of the North American Bulk Electric System and expresses our appreciation to him and Ameren for his service. By unanimous consent, the RS approved the Resolution of Appreciation. October 27–28, 2015 Meeting Minutes The subcommittee approved the October 27–28, 2015 meeting minutes. Resources Subcommittee Action Item List The RS reviewed, revised and updated the action item list, which is affixed as Exhibit C. Resources Subcommittee Confidentiality Agreement Larry Kezele reviewed the list of those individuals that have signed the RS confidentiality agreement. Resources Subcommittee Email List Servers The RS reviewed and revised the RS, the RS Plus, the FrequencyWG, the ReservesWG and the IIWG list servers. Chair Blalock asked that this topic be placed on the agenda for its April 2016 meeting.
Transcript
Meeting Minutes Resource Subcommittee January 27-28, 2016 Tucson Electric Power 88 East Broadway Boulevard Tucson, Arizona Administrative A meeting of the Resources Subcommittee (RS) was held on January 27–28, 2016 in Tucson, Arizona. The agenda and attendance list are attached as Exhibits A and B, respectively.
Resources Subcommittee Chair Troy Blalock presided and Larry Kezele announced that a quorum was present. Mr. Kezele read the applicable Notice of Public Meeting and acknowledged the NERC Antitrust Compliance Guidelines. The subcommittee reviewed and revised the RS Organization and Assignments, the RS Roster and the RS Survey Contacts. Resolution of Appreciation – Gerry Beckerle
Whereas, Gerry Beckerle has served as the Resources Subcommittee (RS) Chair for the past two years and formerly as the Vice Chair.
Whereas, Gerry Beckerle has led the NERC Resource Subcommittee in its efforts of improving primary frequency response, the creation of Guidelines related to the Loss of Communication and Primary Frequency Response and other efforts in support of improving the reliability of the Interconnections.
Whereas, Gerry Beckerle has represented the NERC RS diligently, effectively and admirably at NERC Operating Committee meetings.
Resolved, that the RS thanks Gerry for his leadership, vision, and contribution to the Reliability of the North American Bulk Electric System and expresses our appreciation to him and Ameren for his service.
By unanimous consent, the RS approved the Resolution of Appreciation.
October 27–28, 2015 Meeting Minutes The subcommittee approved the October 27–28, 2015 meeting minutes. Resources Subcommittee Action Item List The RS reviewed, revised and updated the action item list, which is affixed as Exhibit C. Resources Subcommittee Confidentiality Agreement Larry Kezele reviewed the list of those individuals that have signed the RS confidentiality agreement. Resources Subcommittee Email List Servers The RS reviewed and revised the RS, the RS Plus, the FrequencyWG, the ReservesWG and the IIWG list servers. Chair Blalock asked that this topic be placed on the agenda for its April 2016 meeting.
Working Group and Task Force Reports
1. Frequency Working Group Chair Sydney Niemeyer reported that the FWG met on January 27, 2016. The FWG selected ALR1-12 and BAL-003-1 frequency events for December 2015 for the Quebec, Western, Eastern and ERCOT Interconnections. Bob Cummings reviewed proposed changes to the ALR1-12, now called M-4, candidate event selection criteria. He also discussed the events selected for the 2016 State of Reliability Report and the event screening process. Mr. Cummings reported that NERC has formed an internal Frequency Response team. Terry Bilke reported on his work with UTK to develop a Rate of Change Metric for reporting in conjunction with Fnet messages (Exhibit D). Mr. Bilke is also working with UTK to incorporate loss of unit MW data in the ROC Metric.
Mr. Niemeyer reported that, given his impending retirement, he asked the RS to consider finding a volunteer to replace him.
2. Inadvertent Interchange Working Group Chair Tabitha Hernandez reported that the IIWG met on January 27, 2016. The IIWG discussed the Regional Administrator Roles and Responsibilities document, which Ms. Hernandez finalized and will now distribute to the Regional Survey Contacts and the RS. The IIWG did complete its task of determining the on-peak and off-peak inadvertent interchange balances as of January 1, 2015 for the Eastern Interconnection. The IIWG discussed options for distributing the balances among the balancing authorities in the Eastern Interconnection. Options included: 1) dissolving the imbalance with the system by system override in the Inadvertent Interchange tool, 2) pro-rata assignment based on the bias of the balancing authority, or 3) balancing authorities volunteer to take a portion of outstanding balance. The IIWG agreed to recommend to the RS the pursuit of Option 1. At the RS meeting, Ms. Tabitha moved that the RS create in the NERC Inadvertent Interchange Tool a pseudo BA to hold the accumulated inadvertent imbalance. This will take the NERC Inadvertent Interchange Tool to a zero inadvertent balance and a zero carry forward balance. The Inadvertent imbalance is: on peak (46768 MWHr) and off peak (-97849 MWHr), which totals to -51081 MWHr. The pseudo BA would be created with equal and opposite values. The RS approved the motion. Following the subcommittee’s approval, Don Badley noted that he would be developing a minority opinion (Exhibit E). The RS motion will be presented to the Operating Committee.
The IIWG also discussed the total inadvertent interchange disputes between NYISO/PJM and between MISO/PJM that have been ongoing since October 2015. The IIWG will continue to monitor these disputes.
3. Reserve Working Group Chair Bob Klueber reported that the RWG met twice by conference call since the last RS meeting. The RWG is drafting a Frequency Response Sharing Group White Paper. Chair Blalock asked that the RWG share the draft white paper with the RS. Chair Klueber also noted that the RWG is reviewing the format of the current Disturbance Control Standard report.
NERC Related Activity
1. Development of Reliability Guidelines Chair Blalock reported that the Project 2010-14.2.2 Standard Drafting Team asked the Operating Committee, at its December 2015 meeting, for the Resources Subcommittee’s input in the development of an Inadvertent Interchange Reliability Guideline and a Reporting ACE Reliability
Guideline. The RS expressed some concern as to the need to define more exactly what the deliverables are from the SDT.
2. Eastern Interconnection Frequency Response Initiative Chair Blalock reported NERC is developing an action plan to address the issues uncovered during the course of the Eastern Interconnection Frequency Response Initiative. NERC is expected to present its action plan to the Operating Committee at its March 2016 meeting. Some Regional Entities are beginning to address frequency response concerns with their existing generation fleet.
3. Reliability Guideline: Primary Frequency Control Chair Blalock reported that the Operating Committee approved the Reliability Guideline: Primary Frequency Control at its December 2015 meeting. The guideline is posted at Reliability Guidelines.
4. Modifications to Large and Small Generator Interconnection Agreements Chair Blalock noted that the RS approved a motion to support the efforts of NERC and FERC staff to modify the LGIA and SGIA pro forma tariffs to incorporate primary frequency response according to the draft Reliability Guideline: Primary Frequency Control at its October 2015 meeting. FERC is also addressing this topic on its own volition.
5. Essential Reliability Services Task Force Pooja Shah reported that the NERC Board of Trustees approved the ERSTF Framework Report and the ERSTF Abstract Document at its December 7, 2015 conference call meeting (Presentation 1). The Board of Trustees requested continuation of ERS efforts, therefore, the ERSTF has been elevated to the ERS Working Group. The ERSWG will 1) define and develop sufficiency guidelines for each measure and 2) focus on distributed energy resources. As a result of the second ERSWG task a DER Task Force will be formed. Deliverables for 2016 include 1) a white paper on the methodology for ERS measures sufficiency guidelines and 2) a final report from the DERTF. Ms. Shah noted that Measures 1 – 4 are currently being assigned to the RS and its FWG. There is a need for continued data collection and calculation of measures on both the balancing authority and Interconnection levels.
6. Position Paper Frequency Response Bob Cummings provided a summary of NERC’s internal efforts to address frequency response. A position paper will be presented to the Operating Committee at its March 2016 meeting.
7. IEEE 1547 Eddy Lim provided an overview of IEEC P1547 (Subgroup III) – Clause 4.2 (F3) (Presentation 2). IEEE 1547 is the Standard for Interconnecting Distributed Resources with Electric Power Systems. The primary focus of IEEE 1547 is voltage ride through, frequency droop and frequency/power. Following Mr. Lim’s presentation, the RS recommended that he carry the following message regarding proposed changes to IEEE 1547 back to IEEE: That generator governor settings should be at 5% droop, with a 16 mHz deadband and a linear ramp into the deadband.
NERC Reliability Standards and Reliability Related Documents
1. Project 2007-12 (Frequency Response and Frequency Bias Setting) Implementation BAL-003-1 (Frequency Response and Frequency Bias Setting) was approved by FERC on January 16, 2014.
Technical Considerations of Implementing BAL-003-1 a. Balancing Authority Submittal Site (BASS) Status Report – Bob Cummings reported that BASS
will be used as a repository for balancing authority Form 1 and Form 2 data. All balancing authorities have users that have been vetted into BASS. He also reported that NERC conducted a webinar on October 21, 2015 to provide the industry with an overview of the implementation of Standard BAL-003-1 – Frequency Response and Frequency Bias Setting.
b. Uploading Multiple Files to BASS – Antonio Franco reported that he could not determine how to upload multiple files to BASS. Therefore, he had to upload many individual files. Miguel Yanes demonstrated how to accomplish uploading multiple files in one step.
c. 2016 CPS Bounds Report – Bob Cummings reported that he expects to see little change, other than formatting, in the 2016 CPS Bounds Report and expects the 2016 bias data to be implemented on or about April 1, 2016.
d. Handling of Frequency Response Sharing Groups – Bob Klueber reported that the RWG is developing a white paper that addresses this topic.
2. BAL-001-2 Field Trial Status Report Tom Pruitt reported that the SDT is meeting during the week of February 1, 2016. The drafting team will consider the status of changing the BAAL equation to match that in BAL-001-2.
3. Project 2010-14.1 Phase 1 of Balancing Authority Reliability-based Controls: Reserves Status – A final ballot for BAL-002-2 – Disturbance Control Standard – Contingency Reserve for Recovery from a Balancing Contingency Event concluded on October 8, 2015. The standard was submitted to and approved by the Board of Trustees for adoption. Note: BAL-002-2 was filed with FERC on January 29, 2016.
4. Project 2010-14.2.1 Phase 2 of Balancing Authority Reliability-based Controls – BAL-005, BAL-006 and FAC-001 Status – A formal comment period and initial ballot for BAL-005-1 – Balancing Authority Control, and FAC-001-3 – Facility Interconnection Requirements and the recommended retirement of BAL-006-2 – Inadvertent Interchange was open through January 11, 2016. An additional ballot for the three standards and a non-binding poll of the associated Violation Risk Factors and Violation Severity Levels for BAL-005-1 and FAC-001-3 was conducted December 31, 2015 through January 11, 2016. A non-binding poll will not be conducted for BAL-006-2 due to its recommended retirement. The standards received sufficient affirmative votes for approval. The SDT will consider all comments received during the formal comment period and determine the next steps of the project.
5. Project 2010-14.2.2 Phase 2 of Balancing Authority Reliability-based Controls - BAL-004-2 Status – A final ballot for the recommended retirement of BAL-004-0 – Time Error Correction concluded on December 17, 2015. The standard will be submitted to the Board of Trustees for adoption and then filed with the appropriate regulatory authorities.
Discussion of Time Error Correction and Reliability White Paper Terry Bilke provided an overview of a document titled Resources Subcommittee Recommendations to Support BAL-004 Retirement (Exhibit F). The paper suggested that the following recommendations should be implemented prior to the halting of manual TECs:
1. Perform similar analysis for the other Interconnections.
2. Post live time error for all Interconnections on a common website for transparency and to assist BES users.
3. Post daily average frequency.
4. Implement RC notification on:
a. Daily average frequency outlier.
b. 5 consecutive days of high or low average frequency (3% chance of this happening at random).
5. Provide information to the RCs via the NERC Operating Reliability Subcommittee (ORS).
6. It is recommended not to retire the associated NAESB business practice at this time. Leaving it in place will have no impact as there will be no TECs requested. Retiring the NAESB business practice would make reversion more difficult should it be found there were unanticipated impacts by stopping manual TECs.
The RS decided to table further discussion of Mr. Bilke’s paper to the April 2016 meeting. For the record, Mr. Bilke offered his Minority Opinion on the Elimination of Manual TECs (Exhibit G). Discussion of RS 2016 Work Plan Chair Blalock stated that Operating Committee Chair Jim Case has invited all subcommittee leadership and the Executive Committee to a meeting on February 2, 2016 to develop an OC Work Plan. The RS Work Plan will be a portion of the OC Work Plan. The RS Work Plan will include:
1. IIWG – Identify and train the RAs and development of a guideline to address disputes pending the resolution of BAL-006. In addition, the IIWG will resolve the Eastern Interconnection Inadvertent Interchange imbalance.
2. RWG – Develop a FRSG white paper and to review the format of DCS reports.
3. FWG – Support the ERS Measures 1 through 4 as much as practicably possible and the full implementation of BAL-003-1. Develop a FAQ related to implementation of BAL-003-1.
4. The RS and its Working Groups will also review its training documents, Reference Documents and Reliability Guidelines.
NERC Interconnections 2015 Frequency Events Traces and 2011 to 2015 Events’ Parameters Trends Carlos Martinez, CERTS, provided an overview of 2015 frequency event traces and 2011 to 2015 frequency event parameter trends (Presentation 3). More specifically, Mr. Martinez discussed:
1. NERC Interconnections 2015 Candidate Events Traces Using Frequency of the Same 1-Second Median
2. NERC Interconnections 2011 to 2015 Candidate Events Parameters Trends and Comparisons
3. NERC interconnections Candidate Events with Minimum Frequencies During the Period 2011 to 2015
4. NERC Interconnections 2011 to 2015 Candidate Events Parameters, Comparisons and 5-year Regression Coefficients
5. Observations and Conclusions Summary Table Governor Deadband Analysis for ERCOT using Mike Potishnak’s “Pinto Tool” Sandip Sharma presented the results of an analysis that covered the period post implementation of BAL-TRE-001 Regional Standard where Generators within ERCOT had to operate within a tighter deadband (Presentation 4). The analysis shows significant improvement in frequency response after March 2015 following implementation of BAL-TRE-001. Comparison of Generator Governor Dead-band Settings ERCOT 2008 to 2015 Sydney Niemeyer noted that prior to November 2008 most ERCOT generators utilized a maximum governor dead-band setting of +/- 0.036 Hz (Presentation 5). Beginning on April 1, 2015, half of the generators at facilities that had more than one generator were required to implement a maximum dead-band of +/- 0.017 Hz and provide proportional response from the dead-band. In December 2010, wind generation resources were required to install or activate governor devices and provide primary frequency control. NERC Regional Standard BAL-001-TRE-1 included performance measures of each generator during identified frequency excursions. These measures began April 1 and October 1 of 2015 on various generators. The minimum performance standards improved the number of generators performing correctly during frequency excursions. Following Mr. Niemeyer’s introductory remarks, he provided the results of statistical analysis using data from 2008 through 2015.
1. ERCOT Frequency Profile using One-Minute Average Frequency from Two-Second Data
2. Primary Frequency Control Actions of Generator Governors
3. Comparison of Same Generator with the Same Governor Settings
4. Comparison of Same Generator with Different Governor Settings Mr. Niemeyer summarized his presentation and analysis by noting the following:
1. The lower governor dead-band and proportional droop curve improved frequency control while reducing generator governor control action from 2008 to 2015.
2. Wind Generator Primary Frequency Control provides excellent frequency control for high frequency excursions.
3. Generators with large governor dead-bands have a clear competitive advantage.
4. Requiring similar type generators to have the same governor settings improves the frequency profile while reducing the burden on each generator.
5. Performance requirements ensures proper implementation and control action. Evaluating Interconnections 2013 to 2015 Historical Frequency Response Demands and Assessing Reliability Issues – Ongoing Costs and Concerns Mike Potishnak provided an overview of the project objectives of a NERC staff, RS, and DOE-CERTS project to assess ongoing costs and concerns in the provision of frequency response to support reliability – initial
installation costs are excluded from this study (Presentation 6). Other project objectives include 1) produce metrics, statistics and graphs on the demands for frequency response and trends on an Interconnection basis for any deadband-droop pair, using 2013 to 2015 frequency data archived at 1-second resolution, 2) share frequency response demand information with resource owner/operators, market developers, NERC Staff, and Resources Subcommittee so that costs and concerns can be addressed having the insight of useful empirical data, 3) receive feedback from resource owners/operators and market developers on the utility of the data and metrics provided and how the information can be presented most effectively, 4) address the following concerns when frequency response is provided based on the typical demands for frequency response: changes in efficiency or energy production costs; increased wear and tear; greater emissions; renewable resources adequacy; violation of failure to follow dispatch rules where applicable; and any other recurring concern, and 5) present knowledge gained from (1) and (4) above to market developers to see if it is useful for guiding frequency response market development. Mr. Potishnak discussed each of the above project objectives in more detail, provided a project timeline and discussed project deliverables. Resources Subcommittee Software Applications Song Xue, representing Electric Power Group (EPG), provided a status report of CERTS/NERC applications (Presentation 7 (slides 1-5)). Ms. Xue noted that in September 2015 the Intelligent Alarms application was migrated to a new server and new operating system. There is a compatibility issue that is preventing the creation of the Summary Report emailed to users registered for Short-Term and Long-Term alarms. EPG is upgrading the Intelligent Alarms to make it compatible with the new operating system. In the mean-time, users will receive the email notice without the summary report. Ms. Xue also noted that the Area Interchange Error (AIE) application was retired at the end of 2015. Frequency and Control Performance and Time Error
1. Frequency Performance, Trends and Events and Time Error a. Fourth Quarter Frequency and Time Error Performance Reports – Song Xue, EPG, reviewed the
preliminary Western, Eastern, ERCOT and Quebec Interconnection frequency control performance reports (Presentation 7 (slides 6-33)). Time error correction performance reports were available from the ERCOT, Eastern and Western Interconnections.
b. Quebec Interconnection Frequency Performance and Time Error Francis Monette reviewed the fourth quarter Quebec Interconnection frequency and time error report. Since the report is marked confidential, it is not included as part of these meeting minutes.
2. CPS1 and CPS2 Data Trends In closed session the RS reviewed the fourth quarter CPS1 and CPS2 data.
3. DCS Data Trends In closed session the RS reviewed the fourth quarter DCS data.
Wednesday, April 20, 2016 (FWG) Wednesday, April 20, 2016 (IIWG) Wednesday, April 20, 2016 (RWG) Wednesday, April 20, 2016 (RS) Thursday, April 21, 2016 (RS)
Wednesday, July 27, 2016 (FWG) Wednesday, July 27, 2016 (IIWG) Wednesday, July 27, 2016 (RWG) Wednesday, July 27, 2016 (RS) Thursday, July 28, 2016 (RS)
San Francisco, CA: WECC RS Members (hosted by OATI)
Wednesday, October 26, 2016 (FWG) Wednesday, October 26, 2016 (IIWG) Wednesday, October 26, 2016 (RWG) Wednesday, October 26, 2016 (RS) Thursday, October 27, 2016 (RS)
NERC Antitrust Compliance Guidelines and Public Announcement
Agenda Items
1. Administrative
a. Membership and Guests — Chair Blalock
i. Resource Subcommittee (RS) Organization and Assignments*
ii. RS Roster*
iii. RS Survey Contacts*
b. Arrangements — Vice Chair John Tolo
c. Parliamentary Procedures* — Larry Kezele
d. Approve — Meeting Agenda — Chair Blalock
e. Approve — October 27–28, 2015 Meeting Minutes* — Chair Blalock
f. Resources Subcommittee Action Items List*— Chair Blalock
g. NERC–RS Confidentiality Agreement* — Chair Blalock
h. RS List Servers
i. RS List Server*
ii. RS Plus List Server*
iii. Frequency Working Group List Server*
iv. Reserves Working Group List Server*
v. Inadvertent Interchange Working Group List Server*
Exhibit A
Agenda – Resources Subcommittee Meeting – January 27-28, 2016 2
2. Working Groups and Task Force Reports
a. Frequency Work Group — Sydney Niemeyer
b. Inadvertent Interchange Work Group — Tabitha Hernandez
c. Reserve Work Group — Bob Klueber
3. NERC Related Activities
a. NERC Operating Committee Action Items Assigned to RS — Chair Blalock
i. Development of Inadvertent Interchange Reliability Guideline
ii. Development of a Reporting ACE Reliability Guideline
b. Eastern Interconnection Frequency Initiative — Chair Blalock
i. Status Report – NERC Survey Data Repository
ii. Status Report – Interconnection Frequency Response Initiative
c. Reliability Guideline: Primary Frequency Control — Chair Blalock
d. Modifications to Large and Small Generator Interconnection Agreements to Address Frequency Response — Chair Blalock
e. Essential Reliability Services Task Force — Larry Kezele
4. NERC Reliability Standards and Reliability Related Documents
a. Project 2007-12 (Frequency Response) — Chair Blalock
Background – BAL-003-1 (Frequency Response and Frequency Bias Setting) was adopted by the NERC Board of Trustees on February 7, 2013 and was filed at FERC on March 29, 2013. On July 18, 2013, FERC issued a notice of proposed rulemaking wherein FERC proposed to approve Reliability Standard BAL-003-1. On January 16, 2014, FERC approved BAL-003-1.
Technical Considerations:
i. Balancing Authority Submittal Site Status Report – Bob Cummings
ii. Uploading Multiple Files to BASS – Antonio Franco
iii. 2016 CPS Bounds Report – Chair Blalock
iv. Handling of Frequency Response Sharing Groups – Bob Klueber
b. BAL-001-2 Field Trial Status Report – Darrel Richardson and Glenn Stephens
i. Status of Changing the BAAL Equation to Match that in BAL-001-2
c. Project 2010-14.1 Phase 1 of Balancing Authority Reliability-based Controls: Reserves
Status – A final ballot for BAL-002-2 – Disturbance Control Standard – Contingency Reserve for Recovery from a Balancing Contingency Event concluded on October 8, 2015. The standard was adopted by the Board of Trustees on November 5, 2015 and will be filed with the appropriate regulatory authorities.
Agenda – Resources Subcommittee Meeting – January 27-28, 2016 3
Purpose/Industry Need – The purpose of this project is to ensure that Balancing Authorities take actions to maintain interconnection frequency with each Balancing Authority contributing its fair share to frequency control. This project is intended to address the following:
i. FERC Final Rule “Mandatory Reliability Standards for the Bulk-Power System, FERC Order 693” on the NERC standards BAL-002.
ii. Issues raised by stakeholders and compliance teams related to BAL-001-0.1a Real Power Balancing Control Performance and BAL-002-1 Disturbance Control Performance.
iii. To ensure that when finalized, the standards associated with this project conforms to the latest versions of NERC’s Reliability Standards Development Procedure.
d. Project 2010-14.2.1 Phase 2 of Balancing Authority Reliability-based Controls – BAL-005, BAL-006 and FAC-001
Status – A formal comment period and initial ballot for BAL-005-1 – Balancing Authority Control, and FAC-001-3 – Facility Interconnection Requirements and the recommended retirement of BAL-006-2 – Inadvertent Interchange was open through January 11, 2016. An additional ballot for the three standards and a non-binding poll of the associated Violation Risk Factors and Violation Severity Levels for BAL-005-1 and FAC-001-3 will be conducted December 31, 2015 through January 11, 2016. A non-binding poll will not be conducted for BAL-006-2 due to its recommended retirement. The standards received sufficient affirmative votes for approval. The SDT will consider all comments received during the formal comment period and determine the next steps of the project.
Note: See RS Agenda Items 3.a.i and 3.a.ii above.
e. Project 2010-14.2.2 Phase 2 of Balancing Authority Reliability-based Controls - BAL-004-2
Status – A final ballot for the recommended retirement of BAL-004-0 – Time Error Correction concluded on December 17, 2015. The standard will be submitted to the Board of Trustees for adoption and then filed with the appropriate regulatory authorities.
5. Discussion of Time Error Correction and Reliability White Paper — Terry Bilke
6. Discussion of RS 2016 Work Plan — Chair Blalock
7. NERC Interconnections 2015 Frequency Events Traces and 2013 to 2015 Events’ Parameters Trends — Carlos Martinez
8. Scope for Evaluating Interconnections 2013 to 2015 Frequency Response Historical Demands and Assessing Reliability Issues – Ongoing Costs and Concerns — Mike Potishnak
9. Comparison of Generator Governor Dead-band Settings ERCOT 2008 to 2015 — Sydney Niemeyer
10. Governor Deadband Analysis for ERCOT using Mike Potishnak’s “Pinto Tool.” (Note: The analysis will cover period post implementation of BAL-TRE-001 Regional Standard where Generators within ERCOT had to operate with the tighter deadband.) — Sandip Sharma
11. RS Software Applications — Frank Carrera
12. Frequency and Control Performance and Time Error
Agenda – Resources Subcommittee Meeting – January 27-28, 2016 4
a. Fourth Quarter 2015 Frequency Performance Report for all Four Interconnections — Song Xue
b. Frequency Performance, Trends, and Events and Time Error
vi. Québec Interconnection — Francis Monette
CLOSED SESSION (NDA required)
c. CPS1, CPS2, BAAL Data Trends — Chair Blalock
d. DCS Data Trends — Chair Blalock
END CLOSED SESSION
13. Future Meetings
a. April 20–21, 2016 – Austin, Texas
b. July 27–28, 2016 – San Francisco, CA or Vancouver, BC
c. Schedule future meetings *Background materials included.
Resources Subcommittee Meeting Attendance January 27-28, 2016 Tucson Electric Power Tucson, Arizona Attendance: Name Attendance Troy Blalock, Chair Y John Tolo, Vice Chair Y Gerry Beckerle Y Sydney Niemeyer Y Bill Henson Y Bob Klueber Y Tabitha Hernandez Y Francis Monette Y Tony Nguyen Y Tom Pruitt Y Bill Kunkel Y Larry Kezele Y Antonio Franco Y Song Xue Y Danielle Croop Y Carlos Martinez Y Miguel Yanes Y Eddy Lim Y David Kimmel Y (Speakerphone) Terry Bilke Y (Speakerphone) Sandip Sharma Y David Deerman Y Pooja Shah Y (Speakerphone) Bob Cummings Y Allen Schriver Y Warren Wu Y (Speakerphone) Lloyd Linke Y Mike Potishnak Y Don Badley Y Tim Reynolds Y Ali Miremadi Y (Speakerphone)
Exhibit B
Robert Blohm Y (Speakerphone)
Document Title 2
Resources Subcommittee January 27–28, 2016 Meeting
Open Action Items List
Action Figure
Subject Action Item/Assignment Due Date Completion Date
Tabitha Hernandez
Inadvertent Interchange Balances Determination
102914 Suggest notifying BAs on verifying their accumulated inadvertent balances. Additional discussions will take place at April 2015 meeting.
012815 Deferred to the April 2015 IIWG meeting.
042215 Deferred to the July 2015 IIWG meeting.
102715 OC Letter issued. Responses due November 6, 2015.
012716 Complete
021111 042612
Resources Subcommittee
NERC OC Operating Manual Docs
RS Operating Manual documents are:
Performance Standard Reference Guidelines (PSRG) – John Swez – Note the OC approved the PSRG on June 15, 2010, new PSRG inserted into the NERC Operating Manual
102412 IIWG beginning to address changes required in the Area Interchange Error Survey and Inadvertent Interchange Accounting Training Documents.
072314 AIE Training Document. Tabitha reviewed and concluded that changes are not required. Inadvertent Interchange Accounting Training Document. CERTS is updating the application user guide, which is scheduled to be completed by August 2014.
102914 Application user guide is now scheduled for uploading to the tool on 10/31/14.
012815 Tabitha to review if the user guide was uploaded to the application and will verify that the upload was completed.
Ongoing
Agenda Item 1.f Exhibit C
Action Figure
Subject Action Item/Assignment Due Date Completion Date
042215 Chair Beckerle tasked Larry Kezele with archiving the Frequency Response Training Document on the RS website. He will also post the Frequency Response Standard Background document to the RS website under “Related Files”. Chair Beckerle tasked the RS to review the PSRG for discussion at the next meeting. (Completed April 30, 2015)
102715 Updated the action item to reflect the current status of various Operating Manual documents. The RS decided to close this action item and open a new action to address the Performance Standard Reference Guidelines (PSRG). Chair Beckerle tasked each working group chair with providing L. Kezele documents for which their working group is responsible.
012716 – L. Kezele reviewed where the documents were on the NERC website. Sydney Niemeyer reported that he has reviewed some of the documents in the NERC Operating Manual. However, most of his time will be devoted to BAL-003. Tabitha Hernandez reported that the IIWG documents are up-to-date. Bob Klueber reported that he has not had an opportunity to review the documents assigned to the RWS.
The IIWG to review the Inadvertent Interchange Accounting Training Document and the Area Interchange Error Survey Training Document.
Chair Blalock tasked Vice Chair Tolo, Tom Pruitt, Miguel Yanes and Bob Klueber to review and revise the Dynamic Transfer Reference Guidelines.
Chair Blalock also noted that the Performance Standards Reference Guidelines are in need of review. The RS will engage the SDTs for their input (BAL-001 and BAL-002).
Chair Blalock tasked the Don Badley review the Reliability Guideline: ACE Diversity Interchange.
Chair Blalock noted that the Reliability Guideline: Operating Reserve Management is due for review in October 2016.
Larry Kezele CPS Data 102810, During the CPS data review, it was pointed out that not all Canadian entities are included in the CPS Summary. Tom to visit with Chris Scheetz to include future Canadian entities into the CPS Summary.
102715 BC Hydro is ready to start providing data pending signing of a final agreement. AESO status remains unknown. WECC is receiving AESO and BC Hydro data.
012716 Tony Nguyen reported that NERC and BC Hydro have entered into a NDA which will address this issue. Don Badley will follow up with AESO.
012611
Action Figure
Subject Action Item/Assignment Due Date Completion Date
Larry Kezele EPG Software Application Users
072512. The subcommittee decided to annually review the list of those having access to the Resource Adequacy, Intelligent Alarm, Frequency Analysis and Monitoring, Automatic Reliability Report, and Inadvertent Interchange software applications.
102715 Completed for 2015. Review again at the July 2016 RS meeting.
July 2015 Completed
Tabitha Hernandez
Contact Regional Entity Administrators
072413 Tabitha to contact each Regional Administrator to discuss the locking and unlocking of NERC tool. The plan is for one person to lock the system for the Eastern Interconnect. This will ensure the function is getting completed.
102913 In progress.
012214 In progress. EPG provided the list of names.
042314 In progress.
072314 In progress.
102914 In progress.
012815 In progress.
042215 Defer to the July 2015 meeting.
102715 The Regional Administrator Roles and Responsibilities document will be sent to Regional Survey contacts requesting them to provide a primary and secondary Regional Administrator.
012716 Tabitha will be sending an email to L. Kezele for forwarding to the RS survey contacts.
RS Review RS Email List Servers
012815 Completed. Review again at January 2016 RS meeting.
012716 Completed. Review again at April 2016 RS meeting.
January 2017
RS CPS Bounds Report 102914 Does the CPS Bounds reporting methodology need to change in the future?
012815 To be addressed by Agenda Item 4.a.
042215 To be addressed by Agenda Item 4.a.ii.
102715 To be addressed by Agenda Item 4.a.ii.
012716 To be addressed by Agenda Item 4.a.iii.
January 2015
Re-assigned to the Reserve
Questions related to Frequency Response Sharing Groups
102914 Should FRSGs be NERC registered entities? Should they only contain contiguous BAs?
January 2015
Action Figure
Subject Action Item/Assignment Due Date Completion Date
Working Group
012815 RS subgroup tasked with reviewing the use of FRSGs and reporting back at the next RS meeting.
042215 To be addressed as part of Agenda Item 4.a. The Reserve Working Group will address frequency response sharing groups.
102715 Deferred to January 2016 RS meeting.
012716 RWG is developing a FRSG white paper.
Reserve Working Group
Review format of the DCS event report
102715 Chair Beckerle tasked the RWG with reviewing the format of the DCS report.
012716 Bob Klueber reported that the RWG is tackling this action item.
012716 Chair Blalock reviewed the OC motion related to the development of these two reliability guidelines stemming from the Project 2010-14.2.1 standard drafting team.
UTK Rate of Frequency Change Update
The University of Tennessee-Knoxville (UTK) has been capturing rate of frequency change for different time windows through their event detection toolset. The email messages from this system estimate generation and load loss size based on delta F (point A to C). The estimate has some error, primarily due to:
Starting frequency. If the event starts with the frequency > 60Hz, fewer governors get called upon.
Season. Light loads mean fewer generators on line means a combination of less frequencyresponse and less inertia (I don’t know the proportionality).
The messages and data offer promise as a possible performance-based proxy for Interconnection Inertia. Below is a plot of events from November through January 7, 2016 showing Rate of Change in Frequency in the East (Point A to seven seconds later) vs. estimated event size. While some correlation between event size and Rate of Change would be expected, the linearity is remarkable.
A suggested next step is to populate the data set with actual resource loss and perform a similar regression. The outliers might tell us something.
It would appear tracking the slope of the relationship would be a good annual benchmark of grid performance related to inertia. Additionally, if an observation deviates from the regression, could imply greater or less inertia in near real time.
There would likely be some impact in UTK’s loss estimates if inertia changes, but performing an annual review of the model would stay on top of this.
UTK Rate of Frequency Change Update It also appears that given the relationship between the resource loss estimate and the ROC, that the slope of the event could actually be used to improve the loss estimate. The strength of the variable could be tested using actual loss data. UTK is capturing the rate of change at different time windows (derivative at point A, 3 seconds, 7 seconds, A to C). The point A derivative is heavily influenced by local oscillations coincident with the event. Seven seconds is too long for some ERCOT events. Point C is sometimes not clearly identifiable. Given the correlation below, a suggested approach is to use the A to 3 second rate of change for all Interconnections.
While the derivative at Point A has issues with regard to benchmarking rate of change, there would be value in capturing this metric for another purpose. An outlier of the derivative at point A would be a useful notification for a case meriting a look into PMU data to understand the dynamics of the event.
Minority Opinion
I (Don Badley) do not support the Resources Subcommittee’s recommendation to mask the mismatched On-Peak and Off-Peak accumulations of Inadvertent Interchange currently locked up in the Eastern Interconnection (EI) by assigning opposite signed quantities to a fictitious balancing authority (BA). My reasoning is as follows.
• Currently, accumulations of +46,768 MWh On-Peak and −97,849 MWh Off-PeakInadvertent Interchange reside on the EI without matching offsets. Since the RSrecommendation is to mask these quantities by creating a fictitious BA to counter-balancethese accumulations, the imbalance will continue to be held among the EI BAs forever.The 35 BAs in the EI will continue to try reduce their individual quantities but theycannot reduce the EI total, therefore, they just push it around to other BAs causing moreneedless unit movement and maintenance.
• Continuous unilateral paybacks in one direction will result in a propensity for frequencyto ride high or low.
• The creation of a fictitious BA to hold the imbalances will give the appearance of aproperly balanced system but ignores the reality of the real accounts, which are notbalanced.
https://inadvertent.nerc.net/WebHub/
Exhibit E
Resources Subcommittee Recommendations to Support BAL-004 Retirement
1
The Resources Subcommittee (RS) Scope document outlines several responsibilities directly and indirectly related to Time Error Corrections (TEC):
Reviewing and assisting in the development of generation and load “balancing” standards.Which may include developing any necessary reference documents.
Reviewing and assisting in the development of interconnection balancing standards toassure problems resulting from balancing do not adversely affect reliability.
Providing oversight and guidance to working groups and task forces.
Providing industry leadership and guidance on matters relating to balancing resources anddemand issues as well as resulting issues related to interconnection frequency.
Addressing the reliability aspects of inadvertent interchange creation, accounting, andpayback.
Review balancing authorities’ control performance (e.g., CPS and DCS) on a periodic basis.
Address technical issues on automatic generation control (AGC), time error correction,operating reserve, and frequency response.
Provide oversight and guidance on aspects of interchange scheduling as it applies toimpacts on balancing and inadvertent interchange.
If BAL-004 is retired and the practice of Manual TEC eliminated, the RS should take action such that the
benefits provided by TECs are retained to the extent practical:
TECs anchor average frequency at 60 Hz.
Provide an early warning of a chronic or major error in the Area Control Error (ACE) of a
Balancing Authority.
Keeping average frequency at 60Hz reduces the movement of Inadvertent Interchange due to
frequency variation.
As noted by NIST, customer equipment and processes still rely on grid frequency as a time
reference. The extent of this is unknowable.
As noted, TECs (or more specifically a change in the number and duration of TECs), provide an early
warning of a large or chronic error in net schedules or net interchange that aren’t seen in ACE.
Reliability Coordinators (RCs) will need a different trigger to start investigating if frequency is slightly off
normal and ACE values do not point to the underlying cause.
The graphic below is for the Eastern Interconnection, but could be easily replicated for the others if the
recommendations are approved and supported. The process behavior chart depicts average daily
frequency variation for 2014 and 2015. The upper control limit (UCL) and lower control limit (LCL) are
basically “3 sigma” bounds, beyond which reflect an unusual observation with a likely identifiable cause.
The chart shows that days with an average frequency of 4 mHz off schedule (60Hz in the future) are
unusual and merit inspection for balancing issues. Similarly, long runs (5 or more days) with average
frequency either above or below 60 Hz, should be reviewed.
