Balancing Authority Operating Committee April 3, 2018 Minutes No. 15 Antitrust: SPP strictly prohibits use of participation in SPP activities as a forum for engaging in practices or communications that violate the antitrust laws. Please avoid discussion of topics or behavior that would result in anti- competitive behavior, including but not limited to, agreements between or among competitors regarding prices, bid and offer practices, availability of service, product design, terms of sale, division of markets, allocation of customers or any other activity that might unreasonably restrain competition. 1 SOUTHWEST POWER POOL, INC. Balancing Authority Operating Committee (BAOC) April 3, 2018 Tulsa, Oklahoma • MINUTES • Agenda Item 1 – Call to Order, Attendance, and Agenda Approval The meeting was called to order by Chairman Bryan Taggart at 9:00 AM. Attendance was taken. (See Attachment 1 – Attendance List). The agenda was approved with no modifications; Gary Plummer, INDN, moved to approve the Agenda and Kyle McMenamin, Xcel Energy, seconded. Agenda Item 2 – Approval of Minutes for January 23, 2018 The Minutes were approved with no modification. Bryn Wilson, OGE, moved to approve the minutes and Ron Gunderson, NPPD, seconded. There were no ‘nay’ votes and no abstentions. Agenda Item 3 – Staff Update SPP Mountain West Update – Scott Aclin, SPP, provided an update on the integration of Mountain West into SPP which is currently scheduled for September 2019. As noted in the presentation: • On March 13, the SPP BOD approved the next phase to integrate Mountain West into the RTO membership. • The BOD approved a set of policies defining the terms and conditions of Mountain West potential membership. • A public webinar was held March 22 and the new policies were discussed. • SPP anticipates that integration of the Mountain West entities as RTO members will take approximately two years, though it plans to implement Reliability Coordination services sooner, in late 2019. • Mountain West's membership stands to increase SPP's footprint by 165,000 square miles, add 16,000 miles of transmission lines to its network and add 21 gigawatts of generating capacity to its portfolio. • Mountain West and SPP based their agreed upon terms and conditions on input from a wide range of stakeholders, state commissioners, company executives, and customers. These provisions include: • East and west balancing authority areas • East and west planning regions that will follow the same transmission planning processes • Cost allocation of transmission expansion specific to each planning region
Transcript
Balancing Authority Operating Committee April 3, 2018
Minutes No. 15
Antitrust: SPP strictly prohibits use of participation in SPP activities as a forum for engaging in practices or communications that violate the antitrust laws. Please avoid discussion of topics or behavior that would result in anti-competitive behavior, including but not limited to, agreements between or among competitors regarding prices, bid and offer practices, availability of service, product design, terms of sale, division of markets, allocation of customers or any other activity that might unreasonably restrain competition.
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SOUTHWEST POWER POOL, INC.
Balancing Authority Operating Committee (BAOC) April 3, 2018
Tulsa, Oklahoma
• MINUTES • Agenda Item 1 – Call to Order, Attendance, and Agenda Approval The meeting was called to order by Chairman Bryan Taggart at 9:00 AM. Attendance was taken. (See Attachment 1 – Attendance List). The agenda was approved with no modifications; Gary Plummer, INDN, moved to approve the Agenda and Kyle McMenamin, Xcel Energy, seconded. Agenda Item 2 – Approval of Minutes for January 23, 2018
The Minutes were approved with no modification. Bryn Wilson, OGE, moved to approve the minutes and Ron Gunderson, NPPD, seconded. There were no ‘nay’ votes and no abstentions. Agenda Item 3 – Staff Update
SPP Mountain West Update – Scott Aclin, SPP, provided an update on the integration of Mountain West into SPP which is currently scheduled for September 2019. As noted in the presentation:
• On March 13, the SPP BOD approved the next phase to integrate Mountain West into the RTO membership.
• The BOD approved a set of policies defining the terms and conditions of Mountain West potential membership.
• A public webinar was held March 22 and the new policies were discussed. • SPP anticipates that integration of the Mountain West entities as RTO members will take
approximately two years, though it plans to implement Reliability Coordination services sooner, in late 2019.
• Mountain West's membership stands to increase SPP's footprint by 165,000 square miles, add 16,000 miles of transmission lines to its network and add 21 gigawatts of generating capacity to its portfolio.
• Mountain West and SPP based their agreed upon terms and conditions on input from a wide range of stakeholders, state commissioners, company executives, and customers. These provisions include:
• East and west balancing authority areas • East and west planning regions that will follow the same transmission planning processes • Cost allocation of transmission expansion specific to each planning region
Balancing Authority Operating Committee April 3, 2018
Minutes No. 15
Antitrust: SPP strictly prohibits use of participation in SPP activities as a forum for engaging in practices or communications that violate the antitrust laws. Please avoid discussion of topics or behavior that would result in anti-competitive behavior, including but not limited to, agreements between or among competitors regarding prices, bid and offer practices, availability of service, product design, terms of sale, division of markets, allocation of customers or any other activity that might unreasonably restrain competition.
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• Joint dispatch of electricity via SPP's wholesale market under a single set of rules • An expansion of SPP's Regional State Committee to include state commissioners from the
Mountain West region • Staged approach with RC services going live before the BA and Market. • Additional information available at https://www.spp.org/mountain-west/
When asked, Mr. Aclin noted that as of now, there are no plans to share regulation over the DC ties. There is also an effort underway to review and revise drafts of the SPP governing documents by May 2018. These documents include, but are not limited to, the SPP Tariff and Market Protocols. The process of adding new members to the Board and various working groups is now being discussed at the Board and Corporate Governance Committee level. Additional updates will be provided at the next meeting of the BAOC. EI Frequency Excursion – Daniel Baker, SPP, shared information with the group regarding an Eastern Interconnect frequency excursion, which occurred on March 14, 2018, due to the loss of a 2000 MW unit in the North Eastern area of the United States. NERC has been leading efforts to track and improve frequency response, including a Generator Operator Survey which was sent in November 2017. The results of this survey should be available later this year. Although SPP’s response to this event was favorable, SPP could benefit from stronger language in its Criteria regarding governor response. Mr. Baker reviewed the impacts to and response from the SPP Balancing Authority during this event. Before the event, our ACE was +350 and dipped to -50 after the event. He also provided data on the overall response of SPP’s fleet by fuel type.
NERC Standards Update - Shannon Mickens, SPP, presented comments on the following:
BAL-002-3 - A 45-day formal comment period for BAL-002-3 - Disturbance Control Performance (DCS), Contingency Reserve for Recovery from a Balancing Contingency Event is open through 8 p.m. Eastern, Monday, May 7, 2018. Ballot pools are being formed through 8 p.m. Eastern, Friday, April 20, 2018. An initial ballot for the standard and a non-binding poll of the associated Violation Risk Factors and Violation Severity Levels will be conducted April 27 - May 7, 2018.
With regard to FERC’s directed modifications to BAL-002-2, the order stated: “Accordingly, we direct NERC to develop modifications to Reliability Standard BAL-002-2, Requirement R1 to require Balancing Authorities (BA) or Reserve Sharing Groups (RSG): (1) to notify the reliability coordinator of the conditions set forth in Requirement R1, Part 1.3.1 preventing it from complying with the 15-minute ACE recovery period; and (2) to provide the reliability coordinator with its ACE recovery plan, including a target recovery time. NERC may also propose an equally efficient and effective alternative.”
BAL-003-1.1 - A 30-day formal comment period for Project 2017-01 Modifications to BAL-003-1.1 Standards Authorization Request (SAR), is open through 8 p.m. Eastern, Tuesday, July 18, 2017.
Balancing Authority Operating Committee April 3, 2018
Minutes No. 15
Antitrust: SPP strictly prohibits use of participation in SPP activities as a forum for engaging in practices or communications that violate the antitrust laws. Please avoid discussion of topics or behavior that would result in anti-competitive behavior, including but not limited to, agreements between or among competitors regarding prices, bid and offer practices, availability of service, product design, terms of sale, division of markets, allocation of customers or any other activity that might unreasonably restrain competition.
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However, this project could be postponed until the Standards Efficiency Review (SER) activities are completed.
Function Model Review – The Functional Model Advisory Group (FMAG) met February 28, 2018 and is inquiring of the industry if the Model is still relevant and if areas of the Model need to be revised. Mr. Mickens requested that everyone review the Model and provide feedback on whether or not any portion of it needs to be revised.
Additional information regarding the NERC Standards can be found in the attached NERC Notes. See Attachment 2 – NERC Notes.
Load Shed Test Update – Margaret Adams, SPP, informed the group that there was excellent response to the updated schedule (tests moved to every 11 weeks on Wednesdays). The test held in January showed continued improvement in participation and response. She provided an updated on the open action item to add a test that contained errors. Ms. Adams mentioned that she was working with the Shift Engineers and others to conduct a test with those requirements later this fall. She also mentioned that other tests for a partial restore and adding to an original load shed request is being developed.
Agenda Item 4 – AGC Control Modes for Units Supplying Regulation
Mark Eastwood (CUS) discussed his concerns with routine plant maintenance affecting regulation capability of resources. The Protocols were reviewed regarding the selection of regulating resources at 20 minutes prior to each Operating Hour and the expectations of these resources to be prepared to provide that regulation for that hour. Reliability issues regarding resources not able to perform this regulation when selected were discussed. Also, for routine maintenance, suggestions and best practices were shared, including contacting the SPP real-time desk to provide a heads up, performing shorter maintenance items during hours when not selected for regulation, communicating with day-ahead staff regarding offers and regulation selection in order to plan for and accommodate routine maintenance.
Agenda Item 5 – Open Discussion
The committee provided updates and comments on issues impacting their locations such as mergers, audits and EMS upgrades.
Several members requested that the PowerPoint presentation be included in the posted meeting material prior to the meeting. Kim Gorter agreed to post a ‘draft’ copy of the PowerPoint presentation with the meeting material if a final version is not available.
Balancing Authority Operating Committee April 3, 2018
Minutes No. 15
Antitrust: SPP strictly prohibits use of participation in SPP activities as a forum for engaging in practices or communications that violate the antitrust laws. Please avoid discussion of topics or behavior that would result in anti-competitive behavior, including but not limited to, agreements between or among competitors regarding prices, bid and offer practices, availability of service, product design, terms of sale, division of markets, allocation of customers or any other activity that might unreasonably restrain competition.
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Agenda Item 6 – Review of Action Items
The following action was taken:
• Action Item #16 – this task was closed.
• Action Item #17 – In progress. RE: Load Shed Testing. The BAOC suggested SPP consider adding a procedure for Load Shed Test errors and testing the error process once developed.
Agenda Item 7 – Next Meetings
• June 5, 2018 – Teleconference, 1:00-3:00 PM
• October 2, 2018 - Face-to-Face, Little Rock – 8:00 AM to Noon (CPT) followed by 2018 EOP Winter Preparedness Workshop, 1:00 – 5:00 PM
Adjournment
With no further business, the meeting was adjourned by Chairman Taggart at 11:45 AM. Respectfully submitted, Kim Gorter Staff Secretary, BAOC
Attended First Name Last Name Committee Position Companyx Bryan Taggart Chair Westar Energy
Allen Klassen Alternate Westar Energy
x Bryn Wilson Vice Chair Oklahoma Gas and Electric Co.x Kevin Ma Alternate Oklahoma Gas and Electric Co.
Mike Anderson Member American Electric PowerProxy Chris Shaffer Alternate American Electric Power
x Laurie Gregg Member Lincoln Electric SystemLee Anderson Alternate Lincoln Electric System
x Mark Eastwood Member City Utilities of SpringfieldJohn Stephens Alternate City Utilities of Springfield
x Kyle McMenamin Member Xcel EnergyMike Harrison Alternate Xcel Energy
x Andrew Ridley Member Grand River Dam Authorityx Jeff Wells Alternate Grand River Dam Authority
x Ron Gunderson Member Nebraska Public Power DistrictJake Burger Alternate Nebraska Public Power District
x Joel Robles Member Omaha Public Power DistrictLuke Haner Alternate Omaha Public Power District
x Gary Plummer Member City of IndependenceJohn Mason Alternate City of Independence
x David Pham Member Empire District Electric CompanyFred Myer Alternate Empire District Electric Company
x Chance Myers Member Western FarmersJosh Kirby Alternate Western Farmers
x Jerry McVey Member Sunflower Electric Power Corporation
Bill Nolte Alternate Sunflower Electric Power Corporation
x Josef Perez Member Board of Public Utilities (Kansas City, KS)
Jerin Purtee Alternate Board of Public Utilities (Kansas City, KS)
John Carlson Member Kansas City Power & Light CompanyDavid Adamczyk Alternate Kansas City Power & Light Company
Chris Bridges Member Kansas City Power & Light Company (GMO)Dave Millam Alternate Kansas City Power & Light Company (GMO)
x Craig Speidel Member Western Area Uppper Eastx Chris Bultsma Alternate Western Area Uppper East
x Margaret Adams SPP Staff SPP BA Adminx Shannon Mickens SPP Staff SPP Compliancex Kim Gorter SPP Staff BAOC Staff Secretaryx Scott Aclin SPP Staff SPP BA Adminx Allen George Sunflower Electric Power Companyx Daniel Baker SPP Staffx Jason Tanner SPP Staffx Melissa Rhinehart SPP Staffx Neil Robertson SPP Staffx Ryan Kirk AEPx Tom Mayhan OPPDx Mason Favazza SPP Staff
NERC Reliability Standard Activities Update – April 3, 2018 Ballot Periods: Project 2015-10 – Single Points of Failure (Initial Ballot) - 04/13/18 to 04/23/18 Project 2016-02 Modifications to CIP Standards (CIP-002-6, Control Center Definition and Implementation Plan, CIP-012-1) – 4/20/18 to 4/30/18
Drafting Team Vacancies: Nomination period open for Guidelines and Technical Basis Review Team-4/27/18. Cyber Security – CIP Operations & Data Exchange – BAL, INT, IRO, TOP Personnel & Emergency Planning – COM, EOP, PER Modeling & Long-term Planning – FAC, MOD, NUC, TPL System Performance – PRC, VAR Webinars: Inverter-Based Resource Webinar Series: Distributed Energy Resource Impacts – 2:00–4:00 p.m. Eastern, April 5, 2018 Inverter-Based Resource Webinar Series: Inverter-Based Resources Connected to the Bulk Power System – 2:00–4:00 p.m. Eastern, May 2, 2018 Inverter-Based Resource Webinar Series: Inverter Modeling for Protection, Harmonics, EMT Studies, and Review of Real-World VER-Related Events – 2:00–4:00 p.m. Eastern, May 17, 2018 Inverter-Based Resource Webinar Series: Recommended Performance for Inverter-Based Resources Connected to the Bulk Power System – NERC Reliability Guideline – 2:00–4:00 p.m. Eastern, June 13, 2018 Workshops and Conferences 2018 Power System Modeling Conference – June 20–21, 2018, New Albany, Ohio 2018 NERC Standards and Compliance Workshop – July 24–25, 2018, Columbus, Ohio
Currently Posted for Comment:
Project Applicability Comment
Period Ends
SPP Review
Project 2015-10 Single Points of Failure TPL-001 The SPCS and the SAMS conducted an assessment of protection system single points of failure in response to FERC Order No. 754, including analysis of data from the NERC Section 1600 Request for Data or Information. The assessment confirms the existence of a reliability risk associated with single points of failure in protection systems that warrants further action. Additionally, the two directives from FERC Order No. 786 (p. 40 and p. 89) and updates to the MOD reference in Requirement R1, Measure M1 and the Violation Severity Levels sections have been added to the scope of the project.
PC, TP 4/23/18 4/16/18
Project 2016-02 Modification to CIP Standards (three formal comment periods) CIP-002-6 - Cyber Security - BES Cyber System Categorization CIP-012-1 – Cyber Security – Communications between Control Centers Project 2016-02 Modifications to NERC Glossary of Terms Used in Reliability Standards – Control Center
RC, BA, TOP, TO, GOP, GO,
DP 4/30/18 TBD
Project 2017-06 Modifications to BAL-002-3 The primary goal of this SAR is to allow the standard drafting team (SDT) for Project 2017-06, Disturbance Control to modify
BA, RSG 5/7/18 TBD
standard BAL-002-2 to address the directives of the January 19, 2017 FERC Order, and to ensure consistency within the NERC body of Reliability Standards.
Recent Activity (Comments already filed):
Project Applicability Comment Period Ends SPP Review
N/A Notes: Standard Drafting Team Meetings
Long-Term Planning Standards Efficiency Review Team Conference Call – 9:30–11:30 a.m. Eastern, April 3, 2018 Real-Time Operations Standards Efficiency Review Team Conference Call – 11:00 a.m.–1:00 p.m. Eastern, April 4, 2018 Operations Planning Standards Efficiency Review Team Conference Call – 10:00 a.m.–Noon Eastern, April 16, 2018 Long-Term Planning Standards Efficiency Review Team Conference Call – 9:30–11:30 a.m. Eastern, April 17, 2018 Real-Time Operations Standards Efficiency Review Team Conference Call – 11:00 a.m.–1:00 p.m. Eastern, April 18, 2018 Project 2016-02 – Modifications to CIP Standards Drafting Team Meeting – April 17–19, 2018, Location TBD Project 2017-01 – Modifications to BAL-003-1.1 Drafting Team Meeting – April 23–24, 2018 Operations Planning Standards Efficiency Review Team Conference Call – 10:00 a.m.–Noon Eastern, April 30, 2018 Long-Term Planning Standards Efficiency Review Team Conference Call – 9:30–11:30 a.m. Eastern, May 1, 2018
Real-Time Operations Standards Efficiency Review Team Conference Call – 11:00 a.m.–1:00 p.m. Eastern, May 2, 2018 Operations Planning Standards Efficiency Review Team Conference Call – 10:00 a.m.–Noon Eastern, May 14, 2018 Long-Term Planning Standards Efficiency Review Team Conference Call – 9:30–11:30 a.m. Eastern, May 15, 2018 Real-Time Operations Standards Efficiency Review Team Conference Call – 11:00 a.m.–1:00 p.m. Eastern, May 26, 2018 Project 2016-02 – Modifications to CIP Standards Drafting Team Meeting – May 22–24, 2018, Location TBD
Standing Committee Meetings and Conference Calls
Member Representatives Committee Pre-Meeting Conference Call and Informational Webinar – 1:00–2:00 p.m. Eastern, April 10, 2018 Board of Trustees, Member Representatives Committee, and Board Committees Meetings – May 9–10, 2018, Arlington, VA
STANDARDS SUBJECT TO FUTURE ENFORCEMENT
#Date
OriginatedAction Item Owner Update Summary Due Date
Status(Not Started, In Progress, Closure Pending, On Hold,
Closed)
17 01/22/18
RE: Load Shed Tests: BAOC suggested SPP consider adding a procedure for load shed test errors and testing the error process once developed.
Margaret Adams
In progress
18
BAOC Working Group Action Items
CLOSED Action Items
#Date
OriginatedAction Item Owner Update Summary Due Date
Status(Not Started, In
Progress, Closure Pending, On Hold,
Closed)1 11/20/14 Capture and incorporate revisions to
the Emergency Operations Plan (EOP) from other working groups and/or stakeholders.
2/17/15: BAOC discussed the overall process, including the endorsement process for the BAOC (Action Item #2).
Closed
2 12/02/14 Determine an appropriate method for the BAOC to provide their endorsement of and/or agreement with future iterations of the EOP.
SPP Staff 1/13/15 - Draft document sent to SPP staff for review.2/17/15: BAOC approved language to add to the EOP update process to provide a formal mechanism for BAOC endorsement of EOP updates.
Closed
3 12/18/14 Develop Voltage Reduction methodology if deemed necessary by the committee
Assigned by ORWG2/17/15: No further action was deemed necessary by the BAOC membership on this topic. The current SPP method of identifying those entities who have such a plan is sufficient to identify and call up up any such plans in the SPP BA Area.
Closed
4 02/05/15 NERC's Generator Response Survey - Provide updated contacts in order to send the survey to resource owning entities who can accurately provide the necessary data.
2/17/15: Carl Stelly to send sample of the survey to BAOC members so they can provide the best contact to receive the survey. SPP hopes to send the survey out before the end of March and needs to report back results to NERC before June.2/19/15: Sample survey emailed to BAOC. 5/13/15: Survey to be returned to SPP by 5/22/15
5/22/2015 Closed
CLOSED Action Items
#Date
OriginatedAction Item Owner Update Summary Due Date
Status(Not Started, In
Progress, Closure Pending, On Hold,
Closed)5 09/02/15 SPP staff to determine the potential to
enhance the Load Shed drills:• Include web-based Self Studies and Net Conferences • Include it in other training such as Restoration and REOPs. • Discuss with the Training team the option of using the Satellite phones and Blast Calls to alert participants to the arrival of the load shed email.
SPP Staff The Load Shed Test Job Aid will be posted the week of 1/5/16 ORWG meeting materials in response to the member request for some type of self-study and/or net conference. Should have received an exploder email with this information.
With respect to the Satellite phone and Blast Calls – the “draft” process currently uses the Blast Call tool. Satellite phone will be used if necessary.
No update on including in Restoration and REOPS.
closed
7 09/02/15 Inform the ORWG of the need develop a Revision Request to define the specific MW amounts for derates in CROW
Casey Cathey
RR134 . Update provided at ORWG meeting on January 6, 2016 call.
closed
9 01/21/16Gather update information for BA Operating Protocols
SPP Staff Asked for returned templates by by April 1. 4/1/2016 Closed
6 09/02/15
SPP staff to begin reviewing the EOP to determine the impact of replacing the term ‘Market Participants’ with the NERC-defined entity names.
SPP Staff Assigned to SPP Staff to review. 4/1/2016 Closed
8 09/02/15 Begin cleanup of Attachment AN. SPP Staff Assigned to SPP Staff. 4/1/2016 closed
10 04/07/16Gather contact information for the Public Appeals process
SPP Staff Assigned to SPP Staff. 5/1/2016 Closed
CLOSED Action Items
#Date
OriginatedAction Item Owner Update Summary Due Date
Status(Not Started, In
Progress, Closure Pending, On Hold,
Closed)
11 08/31/16
Provide updated version of the load shed process to the ORWG/BAOC members for them to disseminate to their real-time staff
SPP Staff Updated load shed Job Aid provided to members. Closed
12 03/07/17
Discuss with Compliance the need to continue the annual verification of the frequency meters via the BA Operating protocols spreadsheet
SPP Staff SPP Operations and SPP Compliance agreed to discontinue the use of the frequency meter spreadsheets
5/2/2017 Closed
13 05/02/17SPP Staff to develop proposal for Seasonal Preparedness approach.
SPP Staff Staff developed recommendations for seasonal preparedness and included them in the Emergency Operating Plan v 6.0
7/11/2017 closed
14 10/03/17Forward recommendation to CGC for nomination of Bryan Taggart as BAOC Chair
Kim Gorter Nomination forwarded to required staff on 10/09/17. Awaiting feedback.
1/1/2018 Closed
15 10/03/17Send request for nomination for BAOC Vice Chair
Kim Gorter Request for BAOC Vice Chair sent to committee on 10/10/2017.
1/1/2018 Closed
16 10/03/17Inform requester of 30 day EOP Review time period that BAOC voted to retain 14 day review process
Scott Aclin Requestor was informed of BAOC committee decision to retain the 14 day review process. No additional comments at this time.
Closed
CLOSED Action Items
CLOSED Action Items
CLOSED Action Items
Balancing Authority Operating Committee (BAOC)
Bryan Taggart, (WR), ChairmanApril 3, 2018Tulsa, OK
1
Call to Order, Attendance, and Agenda Approval
2
Bryan Taggart
3
Agenda1. BAOC Call to Order, Attendance, and Agenda Approval…….Bryan Taggart
2. Approval of Minutes for January 23, 2018……………………………………All
3. Staff Update• SPP Mountain West Update – Scott Aclin• SPP Response to Frequency Excursion – Daniel Baker• NERC Standard Update – Shannon Mickens• Load Shed Testing Update – Margaret Adams
4. AGC Control Modes for Units Supplying Regulation….................Mark Eastwood, Margaret Adams
5. Open Discussion
6. Review of Action Items…………………………………………….…Kim Gorter
7. Next Meetings• June 5, 2018 – Teleconference, 1:00 PM to 3:00PM• October 2, 2018 – Face–to-Face, Little Rock, AR, 9:00 AM – Noon followed
by the EOP Winter Preparedness Workshop, 1:00 PM to 5:00 PM
• On March 13, the SPP BOD approved the next phase to integrate Mountain West into the RTO membership.
• The BOD approved a set of policies defining the terms and conditions of Mountain West potential membership.
• A public webinar was held March 22 and the new policies were discussed.
• SPP anticipates that integration of the Mountain West entities as RTO members will take approximately two years, though it plans to implement Reliability Coordination services sooner, in late 2019.
• Mountain West's membership stands to increase SPP's footprint by 165,000 square miles, add 16,000 miles of transmission lines to its network and add 21 gigawatts of generating capacity to its portfolio.
SPP Mountain West Update – cont’d
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Mountain West and SPP based their agreed upon terms and conditions on input from a wide range of stakeholders, state commissioners, company executives, and customers. These provisions include:
• East and west balancing authority areas
• East and west planning regions that will follow the same transmission planning processes
• Cost allocation of transmission expansion specific to each planning region
• Joint dispatch of electricity via SPP's wholesale market under a single set of rules
• An expansion of SPP's Regional State Committee to include state commissioners from the Mountain West region
• Staged approach with RC services going live before the BA and Market.
• Eastern Interconnect lost 2000 MW in the North East and frequency dipped 0.065 Hz in our area measured through ICCP. (4-10 sec samples)
• PMU data shows a frequency dip of 0.115 Hz closer to the location of event.
• This corresponds with 0.0575 mHz/MW inertia response of Eastern Interconnect.
• Our ACE was such that our AGC (RTGEN) didn’t adjust setpoints because of low ACE, so the Generation response measured for our BA between 20 and 52 sec in event should result in prime mover governor response. (speed droop). Our generation increased with 50-55 MW as result of prime mover response.
Frequency Control
• Primary – Actions provides to arrest and stabilize frequency. (governor response, load response)
• Secondary – Balancing Authority actions to return frequency to schedule. (AGC, Reserve Sharing Group Deployments)
• Tertiary Control – Balancing Authority or Market Dispatch instructions
Eastern Interconnection Concern
• The EI has experienced problems where Resource FR is “withdrawn” by outer loop controls attempting to maintain AGC setpoint
• NERC has been leading several efforts to track and improve Frequency Response
2012 NERC FRI report highlighted this decline in response
NERC BAL-003 Measurements(Also related M4 reliability metric)
Where 𝐴𝐴𝑃𝑃𝑃𝑃𝑃𝑃𝐴𝐴𝐴𝐴𝐴𝐴 is the Adjusted Actual Primary Frequency Response of the resource and 𝐸𝐸𝑃𝑃𝑃𝑃𝑃𝑃𝐹𝐹𝐹𝐹𝐹𝐹𝐹𝐹𝐹𝐹 is the Final Expected Primary Frequency Response of the resource.Actual Primary Frequency Response Calculation
Where the 𝑀𝑀𝑀𝑀𝑇𝑇−4 − 𝑀𝑀𝑀𝑀𝑇𝑇−60 in the 𝑃𝑃𝑅𝑅𝑅𝑅𝑅𝑅𝑀𝑀𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝐹𝐹𝐹𝐹𝐹𝐹𝑝𝑝𝐹𝐹𝐹𝐹𝐹𝐹 equation represents the MW ramp of the generator resource for a full minute prior to the event. The factor 0.59 adjusts this full minute ramp to represent the ramp that should have been achieved during the post‐perturbation measurement period.
Expected Primary Frequency Response Calculation
𝐸𝐸𝑃𝑃𝑃𝑃𝑃𝑃𝐹𝐹𝐴𝐴𝑅𝑅𝐹𝐹𝐹𝐹 = 𝐸𝐸𝑃𝑃𝑃𝑃𝑃𝑃𝑝𝑝𝑅𝑅𝑅𝑅𝑝𝑝−𝑝𝑝𝑅𝑅𝑅𝑅𝑝𝑝𝑅𝑅𝑅𝑅𝑝𝑝𝐹𝐹𝑝𝑝𝐹𝐹𝑅𝑅𝐹𝐹 − 𝐸𝐸𝑃𝑃𝑃𝑃𝑃𝑃𝑝𝑝𝑅𝑅𝑅𝑅−𝑝𝑝𝑅𝑅𝑅𝑅𝑝𝑝𝑅𝑅𝑅𝑅𝑝𝑝𝐹𝐹𝑝𝑝𝐹𝐹𝑅𝑅𝐹𝐹Where 𝐸𝐸𝑃𝑃𝑃𝑃𝑃𝑃𝐹𝐹𝐴𝐴𝑅𝑅𝐹𝐹𝐹𝐹 is the ideal Expected Primary Frequency Response without any specific resource technology adjustments (i.e. steam turbine throttle pressure, air mass flow rate in CT/CC’s). 𝐸𝐸𝑃𝑃𝑃𝑃𝑃𝑃𝑝𝑝𝑅𝑅𝑅𝑅𝑝𝑝−𝑝𝑝𝑅𝑅𝑅𝑅𝑝𝑝𝑅𝑅𝑅𝑅𝑝𝑝𝐹𝐹𝑝𝑝𝐹𝐹𝑅𝑅𝐹𝐹 and 𝐸𝐸𝑃𝑃𝑃𝑃𝑃𝑃𝑝𝑝𝑅𝑅𝑅𝑅−𝑝𝑝𝑅𝑅𝑅𝑅𝑝𝑝𝑅𝑅𝑅𝑅𝑝𝑝𝐹𝐹𝑝𝑝𝐹𝐹𝑅𝑅𝐹𝐹 are the Expected Primary Frequency Response during the post and pre-perturbation periods, respectively.If 𝐻𝐻𝐻𝐻𝑝𝑝𝑅𝑅𝑅𝑅−𝑝𝑝𝑅𝑅𝑅𝑅𝑝𝑝𝑅𝑅𝑅𝑅𝑝𝑝𝐹𝐹𝑝𝑝𝐹𝐹𝑅𝑅𝐹𝐹 > 60 + 𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑑𝑑𝑅𝑅𝑅𝑅𝑅𝑅 then:
And 𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑑𝑑𝑅𝑅𝑅𝑅𝑅𝑅 is the current governor deadband setting of the resource and 𝑅𝑅𝑑𝑑𝑜𝑜𝑜𝑜𝑅𝑅 is the current governor droop setting of the resource.
𝐸𝐸𝑃𝑃𝑃𝑃𝑃𝑃𝑓𝑓𝐹𝐹𝐹𝐹𝐹𝐹𝐹𝐹 = 𝐸𝐸𝑃𝑃𝑃𝑃𝑃𝑃𝐹𝐹𝐴𝐴𝑅𝑅𝐹𝐹𝐹𝐹 + 𝑋𝑋Where 𝐸𝐸𝑃𝑃𝑃𝑃𝑃𝑃𝑓𝑓𝐹𝐹𝐹𝐹𝐹𝐹𝐹𝐹 is the final Expected primary Frequency Response number used for evaluation and 𝑋𝑋 is an adjustment factor for any specific resource technologies.
Actual Sustained Primary Frequency Response Calculation
Where the 𝑀𝑀𝑀𝑀𝑇𝑇−4 − 𝑀𝑀𝑀𝑀𝑇𝑇−60 in the 𝑃𝑃𝑅𝑅𝑅𝑅𝑅𝑅𝑀𝑀𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑝𝑝𝐹𝐹𝐹𝐹𝐹𝐹𝑅𝑅𝐴𝐴 equation represents the MW ramp of the generator resource for a full minute prior to the event. The factor 0.821 adjusts this full minute ramp to represent the ramp that should have been achieved by 𝑇𝑇 + 46. 𝑀𝑀𝑀𝑀𝑀𝑀𝐹𝐹𝑚𝑚𝑅𝑅𝑅𝑅𝑅𝑅𝑝𝑝𝑅𝑅𝐹𝐹𝑅𝑅𝑅𝑅 is the maximum MW value obtained be the resource between 𝑇𝑇 + 46 and 𝑇𝑇 + 60 for low frequency events and the minimum MW value obtained be the resource between 𝑇𝑇 + 46 and 𝑇𝑇 + 60 for high frequency events.
𝐸𝐸𝑆𝑆𝑃𝑃𝑃𝑃𝑃𝑃𝐹𝐹𝐴𝐴𝑅𝑅𝐹𝐹𝐹𝐹 = 𝐸𝐸𝑆𝑆𝑃𝑃𝑃𝑃𝑃𝑃𝑇𝑇+46 − 𝐸𝐸𝑃𝑃𝑃𝑃𝑃𝑃𝑝𝑝𝑅𝑅𝑅𝑅−𝑝𝑝𝑅𝑅𝑅𝑅𝑝𝑝𝑅𝑅𝑅𝑅𝑝𝑝𝐹𝐹𝑝𝑝𝐹𝐹𝑅𝑅𝐹𝐹Where 𝐸𝐸𝑆𝑆𝑃𝑃𝑃𝑃𝑃𝑃𝐹𝐹𝐴𝐴𝑅𝑅𝐹𝐹𝐹𝐹 is the ideal Expected Sustained Primary Frequency Response without any specific resource technology adjustments. 𝐸𝐸𝑆𝑆𝑃𝑃𝑃𝑃𝑃𝑃𝑇𝑇+46and 𝐸𝐸𝑃𝑃𝑃𝑃𝑃𝑃𝑝𝑝𝑅𝑅𝑅𝑅−𝑝𝑝𝑅𝑅𝑅𝑅𝑝𝑝𝑅𝑅𝑅𝑅𝑝𝑝𝐹𝐹𝑝𝑝𝐹𝐹𝑅𝑅𝐹𝐹 are the Expected Primary Frequency Response at 𝑇𝑇 + 46 and during the pre-perturbation periods, respectively.If 𝐻𝐻𝐻𝐻𝑇𝑇+46 > 60 + 𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑅𝑑𝑑𝑅𝑅𝑅𝑅𝑅𝑅 then:
End IfWhere 𝐻𝐻𝐻𝐻𝑇𝑇+46 is the frequency at 𝑇𝑇 + 46.
𝐸𝐸𝑆𝑆𝑃𝑃𝑃𝑃𝑃𝑃𝑓𝑓𝐹𝐹𝐹𝐹𝐹𝐹𝐹𝐹 = 𝐸𝐸𝑆𝑆𝑃𝑃𝑃𝑃𝑃𝑃𝐹𝐹𝐴𝐴𝑅𝑅𝐹𝐹𝐹𝐹 + 𝑋𝑋Where 𝐸𝐸𝑆𝑆𝑃𝑃𝑃𝑃𝑃𝑃𝑓𝑓𝐹𝐹𝐹𝐹𝐹𝐹𝐹𝐹 is the final Expected primary Frequency Response number used for evaluation and 𝑋𝑋 is an adjustment factor for any specific resource technologies.
Improvements to Frequency Response
2017 GO Survey• 20 November 2017 selected
to gauge the response of all Resources in the EI.
• This survey has also been done in other interconnects.
• Results will be available later this year.
Unofficial SPP Response for the GO Survey Event
SPP Planning Criteria
Governor Droop
Governor Droop
Frequency
ACE 225 MW ACE drop
0.065 Hz drop (2000 MW contingency: 0.0325 mHz/MW)
0.065 Hz (2000 MW contingency: 0.0325 mHz/MW)
50 MW frequency responsePrimary
Load drop 35 MW resulting from 0.065 Hz frequency drop
0.065 Hz (2000 MW contingency: 0.0325 mHz/MW)
50 MW frequency responseMostly prime mover response
Unit A
Estimated response level
PFR Window
Unit B
Estimated response level
PFR Window
Unit C
Estimated response level
PFR Window
SPP Hydro Response
Estimated response level
PFR Window
SPP Gas Response
Estimated response level
PFR Window
SPP Coal Response
Estimated response level
PFR Window
NERC Standards UpdateShannon Mickens
35
Area of Discussion
• Status update for BAL-002-3 (Standards Committee)
• Status update for BAL-003-1.1 (Standards Committee)
• Status update for the Functional Model (Standards Committee)
36
Status of BAL-002-3 (SC Meeting)
• Requested action was to post for a 45-day formal comment period (approved)
• Comment period 03/22/18 - 05/07/18
37
Status of BAL-002-3 (SC Meeting)• Redline revisions have been made to Requirement 1 subpart 1.3 and
subpart 1.3.1 -- Subpart 1.3 - deploy Contingency Reserve, within system
constraints, to respond to all Reportable Balancing Contingency Events, however, it is not subject to compliance with Requirement R1 part 1.1 if the Responsible Entity
Subpart 1.3.1 - is (i) a Balancing Authority or (ii) a Reserve Sharing Group with at least one member that the Responsible Entity is a Balancing Authority experiencing a Reliability Coordinator
declared Energy Emergency Alert Level or is a Reserve Sharing Group whose member, or members, are experiencing a Reliability Coordinator declared Energy Emergency Alert level, and
has depleted its Contingency Reserve to a level below its Most Severe Single Contingency, and
has, during communications with its Reliability Coordinator in accordance with the Energy Emergency Alert procedures, (i) notified the Reliability Coordinator of the conditions described in the preceding two bullet points preventing the Responsible Entity from complying with Requirement R1 part 1.1, and (ii) provided the Reliability Coordinator with an ACE recovery plan, including target recovery time.
• Reminder: Industry cannot communicate with NERC staff during this time period per the Standards Process Manual (SPM). If those in the industry have questions, contact drafting team members.
39
Status of BAL-003-1.1 (SC Meeting)
• Requested action was to Authorize posting for solicitation of additional nominees for Standard Authorization Request (SAR) drafting team members for Project 2017-01 Modifications to BAL-003-1.1. This posting will seek to add three to four members from the generation segment to the current SAR Drafting Team, which will become the standard drafting team (SDT). Supplemental Nomination period 03/19/18 – 03/28/18
• Project can be possibly postponed until the Standards Efficiency Review (SER) activities are completed.
40
Status for the Functional Model (SC Meeting)
• The Functional Model Advisor Group (FMAG) met February 28, 2018 Discussed the FMAG Membership Reviewed Work Plan Future Meeting - March 22, 2018
• Note: The concept is to develop a redline document of proposed definitions and ask two questions to help determine the direction of the group. Is the Functional Model still relevant? If so, what areas should be revised?
• Questions?
41
Load Shed Test UpdateMargaret Adams
42
Reminder: New Schedule Cycle
• Effective January 31, Load Shed Tests are conducted every eleven (11) weeks on Wednesdays.”
• Will allow more coverage of multiple shifts at each entity
43
Load Shed Test Summary
Date BA MW Shed
Entities Participating
Total Entity MW Shed, if Known
01/31/2018 300 21 324
04/18/2018
44
Action Item Update
45
• In Progress
• Plan to use similar functionality to test cancellation
• Will update internal and external Job Aids accordingly
AGC Control Modes for Units Supplying RegulationMark Eastwood, Margaret Adams
46
4.4.2.1 Managing Regulation Control Status Prior to Operating Hour(3) No later than 20 minutes prior to the Operating Hour (OH), SPP will notify MPs with available qualified regulating Resources as to whether they have or have not been selected to regulate for the upcoming OH;
(a) MPs with selected Resources that are physically capable of providing regulation must submit a Resource Control Status = “Regulating” at least 10 minutes prior to the OH to ensure that the Resources will be available to clear Reg-Up and/or Reg-Down in the first Dispatch Interval of the upcoming OH.
47
4.4.2.2.3 Control Status
• Regulating (2) – Indicates that the Resource is on-line and capable of following a Dispatch Instruction, Contingency Reserve Deployment Instruction, and/or Regulation Deployment.
• Manual (3) – Indicates the Resource is on-line but not capable of following a Dispatch Instruction. (1) Start-up(2) Shut-down(3) Testing(4) Experiencing, or recovering from, a unit trip(5) Generating at an output to which the Resource is not capable of responding to a Dispatch Instruction(6) Condensing(7) Experiencing environmental, control or mechanical issues(8) Qualifying Facility exercising its rights under PURPA to deliver its net output to its host utility.
48
4.4.3.3 Regulation Deployment
• MPs providing Reg-Up and/or Reg-Down Service during the OH have an obligation to report to SPP when their Resources are no longer capable of providing the service due to physical problems with the associated Resources through submission of the applicable Resource Control Status.
• If the problem persists into the next OH, that MP must update its Resource Offer by submitting a Reg-Up Service and Reg-Down Service Dispatch Status as “Not-Qualified”.
49
Best Practices
• Update SPP before xx:40 for the next OH
• Time maintenance, where possible, according to Reg selection timeframes For example, perform a 30 minute maintenance
task from xx:00 through xx:30 during an OH in which the resource was not selected for Reg
• Others?
50
Open DiscussionBryan Taggart
51
Review of Action ItemsKim Gorter
52
53
Action Items
Next MeetingsBryan Taggart
54
55
• June 5, 2018 – Teleconference, 1:00 PM to 3:00 PM
• October 2, 2018 – Face-to-Face, Little Rock, AR, 8:00 AM – Noon followed by the EOP Winter Preparedness Workshop, 1:00 PM to 5:00 PM
