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Meeting Agenda Reliability Advisory Council (RAC)

August 25, 2020 9:00 a.m. – 3:00 p.m. Central

Via Webex

Meeting Agenda – Reliability Advisory Council – August 25, 2020

VIDEO AND AUDIO RECORDING

Please note that Midwest Reliability Organization (MRO) may make a video and/or an audio recording of this organizational group meeting for the purposes of making this information available to board members, members, stakeholders and the general public who are unable to attend the meeting in person.

By attending this meeting, I grant MRO:

1. Permission to video and/or audio record the meeting including me; and 2. The right to edit, use, and publish the video and/or audio recording. 3. I understand that neither I nor my employer has any right to be compensated in connection with the

video and/or audio recording or the granting of this consent.


MRO ORGANIZATIONAL GROUP GUIDING PRINCIPLES

These MRO Organizational Group Guiding Principles complement charters. When the Principles are employed by members, they will support the overall purpose of the organizational groups.

Organizational Group Members should:

1. Make every attempt to attend all meetings in person or via webinar.

2. Be responsive to requests, action items, and deadlines.

3. Be active and involved in all organizational group meetings by reviewing all pre-meeting materials and being focused and engaged during the meeting.

4. Be self-motivating, focusing on outcomes during meetings and implementing work plans to benefit MRO and MRO’s registered entities.

5. Ensure that the organizational group supports MRO strategic initiatives in current and planned tasks.

6. Be supportive of Highly Effective Reliability Organization (HEROTM) principles.

7 Be supportive of proactive initiatives that improve effectiveness and efficiency for MRO and MRO’s registered entities.


MEETING AGENDA

Agenda Item

1 Call to Order and Determination of Quorum Ron Gunderson, Reliability Advisory Council Chair

a. Determination of Quorum and Introductions b. Standards of Conduct and Anti-Trust Guidelines c. Robert’s Rules of Order

2 Chair’s Remarks Ron Gunderson, Reliability Advisory Council Chair

3 Consent Agenda Ron Gunderson, Reliability Advisory Council Chair

a. Approve June 3, 2020 RAC meeting minutes b. Approve June 18, 2020 RAC LTRA meeting minutes c. Approve PRS Charter

4 MRO Board of Directors OGOC Update Bryan Clark, Director, Reliability Assessment and Performance Analysis

a. HERO Award

5 RSTC Update John Stephens, Reliability Advisory Council Vice Chair

6 Update 2020 Work Plan Ron Gunderson, Reliability Advisory Council Chair

a. Review Action Items b. Reliability Risk Matrix c. Pandemic Operational Impacts Webinar d. Reliability Conference

7 AEP (SWEPCO) Outage in Texas Category 2 Event David Ball, Managing Director of Transmission Operations, AEP

8 Regional Risk Assessment Process John Seidel, Principal Technical Advisor

Break – 12:00 p.m.

9 Reliability Coordinator Summer Updates a. MISO – Durgesh Manjure b. SPC – Binod Shrestha c. SPP – CJ Brown

10 NERC Committee Representative Written Reports Bryan Clark, Director, Reliability Assessment and Performance Analysis

a. NERC Electric Gas Working Group (EGWG) - Jaimin Patel b. NERC Inverter Based Resource Performance Task Force (IRPTF) - David Brauch c. NERC System Planning Impacts from DER Working Group (SPIDERWG) - Sunny Raheem d. NERC Operations Reliability Subcommittee (ORS) - Steve Sanders e. NERC System Analysis and Modeling Subcommittee (SAMS) - Amanda Schiro


Agenda Item f. NERC System Protection and Control Subcommittee (SPCS) - Mark Gutzmann

11 NERC Reliability Assessments a. Long Term Reliability Assessment Salva Andiappan, Principal Reliability Assessment Engineer b. State of Reliability Report

John Seidel, Principal Technical Advisor

12 Special Protection System Working Group (SPSWG) Update a. Update John Seidel, Principal Technical Advisor b. SPSWG Dissolution Ron Gunderson, Reliability Advisory Council Chai

13 Protective Relay Subgroup (PRS) Update Mike Bocovich, PRS Technical Liaison

14 Upcoming Meetings and Review 2020 meeting calendar Ron Gunderson, Reliability Advisory Council Chair

a. Expiring Terms b. Election Process Review

15 RAC Member Roundtable Reliability Advisory Council Members

16 Other Business and Adjourn Ron Gunderson, Reliability Advisory Council Chair


AGENDA 1 Call to Order and Determination of Quorum

a. Determination of Quorum and Introductions - Roster Ron Gunderson, Reliability Advisory Council Chair

Name Role Company Term

Ron Gunderson Chair Nebraska Public Power District 12/31/2020

John Stephens Vice Chair City Utilities of Springfield, Missouri 12/31/2020

Allen Klassen Member Westar Energy, an Evergy Company 12/31/2021

Antoine Lucas Member Southwest Power Pool, Inc. 12/31/2021

Binod Shrestha Member Saskatchewan Power Company 12/31/2022

CJ Brown Member Southwest Power Pool, Inc. 12/31/2020

Dallas Rowley Member Oklahoma Gas and Electric 12/31/2022

Dean Schiro Member Xcel Energy 12/31/2020

Dick Pursley Member Great River Energy 12/31/2022

Dwayne Stradford Member American Electric Power 12/31/2021

Gayle Nansel Member Western Area Power Administration 12/31/2022

Jason Weiers Member Otter Tail Power Company 12/31/2021

Durgesh Manjure Member MISO 12/31/2020

Nandaka Jayasekara Member Manitoba Hydro 12/31/2022

Nicholas Giffin Member American Transmission Company 12/31/2021


AGENDA 1 Call to Order and Introductions

b. Standards of Conduct and Anti-Trust Guidelines Ron Gunderson, Reliability Advisory Council Chair

Standards of Conduct Reminder: Standards of Conduct prohibit MRO staff, committee, subcommittee, and task force members from sharing non-public transmission sensitive information with anyone who is either an affiliate merchant or could be a conduit of information to an affiliate merchant.

Anti-trust Reminder: Participants in Midwest Reliability Organization meeting activities must refrain from the following when acting in their capacity as participants in Midwest Reliability Organization activities (i.e. meetings, conference calls, and informal discussions):

• Discussions involving pricing information; and • Discussions of a participants marketing strategies; and • Discussions regarding how customers and geographical areas are to be divided among

competitors; and • Discussions concerning the exclusion of competitors from markets; and • Discussions concerning boycotting or group refusals to deal with competitors, vendors, or suppliers.


AGENDA 1 Determination of Quorum c. Robert’s Rules of Order

Ron Gunderson, Reliability Advisory Council Chair

Parliamentary Procedures. Based on Robert’s Rules of Order, Newly Revised, Tenth Edition

Establishing a Quorum. In order to make efficient use of time at MRO organizational group meetings, once a quorum is established, the meeting will continue, however, no votes will be taken unless a quorum is present at the time any vote is taken.

Motions. Unless noted otherwise, all procedures require a “second” to enable discussion.

When you want to… Procedure Debatable Comments Raise an issue for discussion

Move Yes The main action that begins a debate.

Revise a Motion currently under discussion

Amend Yes Takes precedence over discussion of main motion. Motions to amend an amendment are allowed, but not any further. The amendment must be germane to the main motion, and cannot reverse the intent of the main motion.

Reconsider a Motion already resolved

Reconsider Yes Allowed only by member who voted on the prevailing side of the original motion. Second by anyone.

End debate Call for the Question or End Debate

No If the Chair senses that the committee is ready to vote, he may say “if there are no objections, we will now vote on the Motion.” Otherwise, this motion is not debatable and subject to majority approval.

Record each member’s vote on a Motion

Request a Roll Call Vote

No Takes precedence over main motion. No debate allowed, but the members must approve by majority.

Postpone discussion until later in the meeting

Lay on the Table Yes Takes precedence over main motion. Used only to postpone discussion until later in the meeting.

Postpone discussion until a future date

Postpone until Yes Takes precedence over main motion. Debatable only regarding the date (and time) at which to bring the Motion back for further discussion.


Remove the motion for any further consideration

Postpone indefinitely Yes Takes precedence over main motion. Debate can extend to the discussion of the main motion. If approved, it effectively “kills” the motion. Useful for disposing of a badly chosen motion that cannot be adopted or rejected without undesirable consequences.

Request a review of procedure

Point of order No Second not required. The Chair or secretary shall review the parliamentary procedure used during the discussion of the Motion.

Notes on Motions Seconds. A Motion must have a second to ensure that at least two members wish to discuss the issue. The “seconder” is not required to be recorded in the minutes. Neither are motions that do not receive a second.

Announcement by the Chair. The chair should announce the Motion before debate begins. This ensures that the wording is understood by the membership. Once the Motion is announced and seconded, the Committee “owns” the motion, and must deal with it according to parliamentary procedure.

Voting Voting Method When Used How Recorded in Minutes

When the Chair senses that the Committee is substantially in agreement, and the Motion needed little or no debate. No actual vote is taken.

The minutes show “by unanimous consent.”

Vote by Voice The standard practice. The minutes show Approved or Not Approved (or Failed).

Vote by Show of Hands (tally)

To record the number of votes on each side when an issue has engendered substantial debate or appears to be divisive. Also used when a Voice Vote is inconclusive. (The Chair should ask for a Vote by Show of Hands when requested by a member).

The minutes show both vote totals, and then Approved or Not Approved (or Failed).

Vote by Roll Call To record each member’s vote. Each member is called upon by the Secretary, and the member indicates either

“Yes,” “No,” or “Present” if abstaining.

The minutes will include the list of members, how each voted or abstained, and the vote totals. Those members for which a “Yes,” “No,” or “Present” is not shown are considered absent for the vote.


Notes on Voting. Abstentions. When a member abstains, he/she is not voting on the Motion, and his/her abstention is not counted in determining the results of the vote. The Chair should not ask for a tally of those who abstained.

Determining the results. A simple majority of the votes cast is required to approve an organizational group recommendations or decision.

“Unanimous Approval.” Can only be determined by a Roll Call vote because the other methods do not determine whether every member attending the meeting was actually present when the vote was taken, or whether there were abstentions.

Electronic Votes – For an e-mail vote to pass, the requirement is a simple majority of the votes cast during the time-period of the vote as established by the Committee Chair.

Majorities. Per Robert’s Rules, as well as MRO Policy and Procedure 3, a simple majority (one more than half) is required to pass motions.


AGENDA 2 Chair’s Remarks


Action Information

Report Chair Gunderson will provide an oral report during the meeting.

.


AGENDA 3 Consent Agenda

a. Approve June 3, 2020 RAC Meeting Minutes Ron Gunderson, Reliability Advisory Council Chair

Action Vote to approve June 3, 2020 RAC Meeting Minutes as written.

Report Chair Gunderson will ask for any changes or additions to the agenda during the meeting and approval of the June 3, 2020 RAC Meeting Minutes.

Draft Minutes of the Reliability Advisory Council (RAC) Meeting Via Webex

June 3, 2020 9:00 a.m. – 3:00 p.m. Central 1. Call to Order, Determination of Quorum, Standards of Conduct, and Anti-Trust Guidelines

Chair Gunderson called the meeting to order at 9:03 a.m. He extended a warm welcome to all attendees, roll call was taken and introductions were made. Chair Gunderson determined that a quorum was present. A complete list of attendees is included as Exhibit A. Pursuant to Policy and Procedure 4, MRO’s Standards of Conduct, Conflict of Interest and Anti-Trust Guidelines were presented Bryan Clark provided an overview of the Standards of Conduct and Anti-Trust Guidelines.

2. Chair’s Remarks Chair Gunderson mentioned we are in a different time during the COVID-19 pandemic from a reliability perspective and asked attendees to watch for any delays in maintenance and rescheduling outages on generating units and to note how we forecast load in the new normal when industry starts the reopening phases.

3. Consent Agenda Chair Gunderson provided a brief overview and asked if there were any objections to the April 1, 2020 RAC meeting minutes as presented.

Upon a motion duly made and seconded, the RAC unanimously approved the minutes from April 1, 2020, RAC meeting, as drafted.

4. RSTC Update Vice Chair Stephens provided an update on the NERC RSTC.


5. 2020 Reliability Conference Webinar Bryan Clark mentioned the good group of topics and speakers on the Reliability Conference Agenda and further noted the speakers’ credentials. Clark mentioned that even though there is not a lot of DERS in the region it is important to gain knowledge on the topic. He pointed out there are a couple storage projects on the agenda as it is a relevant and important topic. The Inverter Based Resource group is accomplishing good work and the RAC wants to bring attention to that work. Clark noted the time of the conference was shortened due to being held WebEx and noted the dry run is tentatively scheduled for August 24, depending on speakers’ schedules

A Chairman from the Missouri PSC is scheduled to speak and he is open to discussion topics. Clark mentioned he may present his own topics provided they are related to the other Agenda topics. Council Member Weiers will provide the information to MRO Staff after this meeting.

A suggestion was made to share the agenda with the keynote speaker so he can craft his remarks specific to his role in Missouri that align with the agenda topics. The reliability conference agenda was shared with the group and a brief overview was provided.

6. Update RAC 2020 Work Plan a. Chair Gunderson led the discussion regarding the 2020 work plan presented. A review of Action

Items was performed, and discussion ensued.

Bryan Clark noted that the primary focus of the work plan is topics for outreach. MRO is looking for any type of risk or any awareness that can be communicated to the region on generation mix, transmission systems, load curves, and other topics that may be unique to the region. Perhaps there are special projects council members are working on at their respective companies that others can benefit from. Clark mentioned that RAC newsletter articles have been contributed but we also need to utilize the webinar function to reach others. The webinars are 45 minutes to one hour in duration and MRO staff will complete the majority of the leg work, Clark emphasized that MRO is requesting the topic and a speaker. It was suggested that a lessons learned webinar be held regarding operating under COVID-19. This webinar could be held with three topics or in three phases; 1. The impact to actual system operators and changes noted; 2. The training impacts of training and operating virtually; 3. The impact on Asset Owners; and 4. Organizational responses - testing during quarantine. It was noted that the working from home perspective has been taken care of. Additional topics for outreach noted below:

• One entity’s current COVID plan, has sequestered healthy individuals verses sick, with a novel

approach to housing employees at a hotel. The RAC member asked if a lesson learned from this sequestering would be a good topic, and mentioned Darrel Yonk as a potential author.

• Operator certification or qualification have been changed to virtual only or canceled and

operators are looking for opportunities to get the training hours that may be less achievable.


• Expectation of impacts in the planning perspective that would be worthy of noting, load shapes?

• Maintenance outages.

• Impact of the presidential executive order for electrical equipment that comes from adversaries.

If we have to replace a lot of BES transformers, what will that look like? It was noted that additional guidance is forthcoming.

• A presentation on a Category 2 event from last year is being prepared for the Q3 RAC meeting

with the entity slated to provide an overview of the event and a lessons learned.

Bryan Clark asked for Newsletter articles to complete the work plan, noting that the deadline is July. Discussion ensued. Action items of the work plan were reviewed and updated.

The council recessed for break at 10:06 a.m. and reconvened at 10:21 a.m.

7. Chair and Vice Chair Terms Bryan Clark, Director, Reliability Assessment and Performance Analysis provided an update on the status of Chair and Vice Chair Terms for the MRO councils, noting the timeline of the member nomination process for the past year. He further noted the OGOC is seeking more efficient ways to accomplish the annual election approval process. Clark provided logistics on the terms and noted that the solutions pending now are: 1. Allowing each council to appoint their Char and Vice Chair rather than the OGOC, as the OGOC has already approved the members; and 2. Adjusting the terms of the Chair and Vice Chair to two years, noting that a membership term expiring before a leadership term could be an issue. Clark noted that the OGOC meets June 24, 2020 and more information could be forthcoming, hopefully by the end of the year the council will be able to appoint their own leadership.

To accommodate scheduling conflicts, Chair Gunderson moved the Reliability Risk Matrix Agenda Item 6b ahead on the agenda. These minutes reflect the order in which the reports were provided.

6. Update RAC 2020 Work Plan a. Reliability Risk Matrix

Dallas Rowley provided an overview of the Reliability Risk Matrix and noted the changes that were made to the matrix form the previous meeting; such as removing assessment from the title and realigning the consequence levels for better flow of the chart. Rowley questioned whether negligible is that the best word to use in the chart and that perhaps using inconsequential or insignificant would be better Bryan Clark walked through an example that occurred regarding copper theft to illustrate how the chart can be utilized. Clark further noted that if there are no standards in place, it heightens the likelihood of risk.


Gratitude was extended to RAC Member Rowley, discussion ensued and changes to the matrix were agreed upon. It was further noted that once this living document is put into practice it will be a good plan to update and tweak as it is utilized.

8. Pandemic Discussion a. Regional Pandemic Impacts

Bryan Clark, Director, Reliability Assessment and Performance Analysis led the discussion on plans regarding returning to work. Some highlights from various members: • Most employees are back to work, with restricted access to operators only in areas,

temperature checks to anyone entering that space and encouraging social distance guidelines. • Possible return to work in July • The option for some to continue to work from home with some working from home until the end

of the year (fear level is being considered). Various start times for critical and non-critical employees.

• Staged approaches and changes in the way traffic is routed in • Facility plans are being developed for most to implement returning to work. Several counties

are behind the state which adds an extra layer to the plans. • The building that houses the control room will continue to be off limits for non-essential

employees will work from a different building as the control room. In response to a question on maintenance outages for RTOs, RAC Member Manjure mentioned fairly low loads and does not foresee any issues yet, although this could change as summer progresses. It was noted that the return to work plan is one of the biggest challenges of this pandemic. A few major storm events have been navigated with the current challenges positively, so valuable lessons are occurring as well.

b. NERC Pandemic Document Bryan Clark, Director, Reliability Assessment and Performance Analysis provided an update and presented on the NERC Pandemic Document released to the ERO on April 23, 2020. Clark pointed out some review of the document was done by MRO Staff prior to publication. The document highlighted different system conditions, lower demands, sequestering Operators, and work force interruptions. Long term potential changes and their impacts were also highlighted. NERC issued a region-wide Level 2 alert March 10, 2020 with the following numbers noted; 166 of 203 REs reported they have emergency pandemic plans in place. 192 of 203 have reviewed their staffing and critical roles, 164 of 203 could assist in mutual aid to others, and 174 out of 203 reported they have reviewed supply chain goods for critical services. There is risk around loss of critical staff operating and maintaining the BPS, are there enough people to get the job done. The guidance for control room continuity was noted. A bi-weekly call with the RCs is being held with NERC, Clark mentioned that maybe one of our RCs can touch on that in their update. The security aspect was also highlighted from the E-ISAC and actions taken maintaining situational awareness. The conclusion is NERC is commending industry on the steps taken during this pandemic.


9. NERC Committee Representative Written Reports Bryan Clark, Director, Reliability Assessment and Performance Analysis provided an overview of the following reports provided in the Agenda packet.

a. NERC Electric Gas Working Group (EGWG) - Jaimin Patel

b. NERC Inverter Based Resource Performance Task Force (IRPTF) - David Brauch

c. NERC System Planning Impacts from Distributed Energy Resources Working Group (SPIDERWG) - Sunny Raheem

Sunny Raheem commented on the reliability guidelines and modeling verification studies that the SPIDERWG completed. He also referenced the DER Modeling Practices Survey located in the agenda packet that the subgroup recently published. The ones that seem to have lower penetrations of DER do not have rules written yet, and this information will be parsed at the next DER meeting. The coordination group is looking at ways to define DER and terminology and definitions for consideration for a NER definition that would help industry in direction to go with DERs.

Regarding the release of the TPL whitepaper he responded they are working on the review process and next few months it will be issued for public comments. Requirement in the standard preclude or limit DER is being reviewed in the standard. Coordination subgroup and SPIDER is doing coordination with MOD-032 SAR and TPL whitepaper.

d. NERC Operations Reliability Subcommittee (ORS) - Steve Sanders

e. NERC System Analysis and Modeling Subcommittee (SAMS) - Amanda Schiro

Amanda Schiro provided a brief update – there was a specific request for transient voltage discussion requesting volunteers for the effort depending on work from home situation. Question was asked whether the EMT study user panel presentation material is shared in NERC SAMS website.

f. NERC System Protection and Control Subcommittee (SPCS) - Mark Gutzmann

The council recessed for lunch at 11:57 p.m. and reconvened at 12:45 p.m.

Council member Dick Pursley left the meeting at 11:57 p.m.

10. Reliability Coordinator Update a. MISO – Durgesh Manjure.

RAC Member Manjure presented on the expectations for the upcoming summer and upcoming trends. Highlighting spring operations, and severe weather alerts. COVID-19 related impacts contributed to change in load shape and energy load deviation from forecast and could influence the summer forecast. Planned generator outages have dropped due to COVID-19 and are well below other years. They see no issue with outages in the fall. Summer outage situation does not appear to be any different due to scheduled outages. Adequate resources are expected to be available to meet demand for summer 2020.


b. SPC – Binod Shrestha Binod provided an overview of his presentation highlighting COVID-19 impacts on load by decrease in consumption, decrease in instantaneous peak, adjustment to the load forecast and a change in time of daily peak load. Shrestha also noted the planned outages and the 2020 summer outlook and a look back to last season.

c. SPP – CJ Brown RAC Member Brown presented on the COVID-19 impact on generation outages which is very similar to MISO’s. He added that last year was the largest outage season for SPP so a more stringent process of outages was implemented. Brown noted that a Generation Outage Task Force was stood up and is assisting with outages and they are trying hard to prepare for the worst. Regional Dispatch Transfer and Load Trends based on legacy BAs were also highlighted. Brown noted it is an Interesting time for the shift engineers responsible for load forecasting due to the current conditions. Brown mentioned that wind curtailed is up, and a new peak was reached in April. He is looking forward to the study coming from task group and they are looking at implementing ramping products to make the process more efficient.

11. Special Protection System Working Group (SPSWG) Update John Seidel, MRO Principal Technical Advisor provided an update noting that the SPSWG is getting closer to sun setting. He commented on the positive process of the RAS reviews since the last meeting and noted there are just a few more on the schedule before December 31, 2020 which is the date the group will sunset. Seidel commented that handoff is going well as SPP RTO and MISO have groups set up to take ownership in August and the end of the year respectively. SPC has already taken ownership of the process and MH plans to take over when the standard is effective on January 1, 2021. There will be two more reports to come from this group before it disbands.

12. Protective Relay Subgroup Update John Seidel, MRO Principal Technical Advisor provided an update highlighting MRO staff and a subgroup of the PRS is finishing a white paper addressing the SF 6 breakers. He mentioned the criteria of the data request regarding the white paper. Seidel noted that a lessons learned will be submitted to NERC and potentially a broadcast by NERC.

The subgroup is meeting once again before the paper is finalized and will be sent to the RAC for review and comments.

Seidel commented that there is an existing whitepaper prepared in 2017, posted on the MRO website, which consisted of increasing breaker failure schemes and identified ways to improve best practices for commissioning system protection equipment. The goal is to recycle this information into a webinar hopefully in late June or early July. Seidel noted several PRS agreed to assist with the webinar.

Seidel stated if any entity had a large impact event, or perhaps any interesting misops that the entity would like to share as a discussion topic at the PRS meetings, they are all welcomed. Xcel energy’s presentation on CT failure protection schemes was mentioned as a good discussion topic and it will be discussed further.


Seidel further commented that PRS Staff Liaison Bocovich has been looking at scheme types with more misops than others and the directional comparison blocking scheme is one, with the goal of making sure the frequency per population is accounted for accurately. A data request will be sent.

Seidel commented on two Lessons learned submitted by PRS; one on mixing technologies and blocking schemes, and one on lockout relay failure, both have been reviewed by NERC staff and have been well-received and both are being submitted.

The PRC-002 application guide will be voted for recommendation to the OGOC at the CMEPAC meeting on June 4, 2020. The topic of TPL-001-5 was brought up at the PRS meeting and it was noted that this will require a lot of cooperation to determine single points of failure. The Chisago CT failure will be discussed at the next PRS meeting again.

13. Compliance Monitoring and Enforcement Program Advisory Council (CMEPAC) Meeting Agenda Review

Bryan Clark, Director, Reliability Assessment and Performance Analysis presented the Agenda of the CMEPAC’s June 4, 2020 meeting and invited anyone who would like to attend to please do so and highlighted items of interest to the RAC. Bryan asked Terri Pyle, the Vice Chair of the CMEPAC, if she had anything to add. Pyle is excited to have the opportunity to share and collaborate with the RAC to make sure the work is seamless and the CMEPAC is aware of what the other councils are doing.

14. NERC Summer Reliability Assessment (SRA) Update Salva Andiappan, Principal Reliability Assessment Engineer presented and highlighted the 2020 NERC SRA with emphasis on the MRO region. MW peak generation by fuel type, forecasted net internal demand, and COVID – 19 operational impacts were a few of the focus areas.

15. Upcoming Meetings and Review 2020 Meeting Calendar Chair Gunderson provided an overview of the next meetings, noting that November 18 meeting is still scheduled to be F2F, and notification will be provided if this changes.

16. RAC Member Roundtable Chair Gunderson provided an opportunity for all RAC members to discuss anything that they wanted to discuss that was not already covered in this meeting. Discussion ensued.

17. RAC Charter Chair Gunderson presented on the redline charter submitted by RAC Member and noted the comment regarding articulating objectives. He suggested agreeing on the changes made with the comments on objectives added as an action item. Clark highlighted removing the bullet regarding Participate in and support the ERAG efforts in Section III. Discussion ensued.

Upon a motion duly made and seconded, the RAC unanimously approved recommendation to the OGOC for approval of the Charter with the changes outlined in the charter redline attached.


18. Other Business and Adjourn Chair Gunderson asked if there was any other business to discuss. Having no further business to discuss, the meeting was adjourned at 2:47 p.m.

Upon a motion duly made and seconded, the RAC unanimously agreed to adjourn the meeting.

Prepared by: Dana Klem, RAPA Administrator.

Reviewed and Submitted by: Bryan Clark, Director, Reliability Assessment and Performance Analysis

Exhibit A – Meeting Attendees

Reliability Advisory Council Members Present

Name Organization

Ron Gunderson, Chair Nebraska Public Power District

John Stephens, Vice Chair City Utilities of Springfield Missouri

Allen Klassen Evergy, Inc.

Antoine Lucas Southwest Power Pool, Inc.

Binod Shrestha Saskatchewan Power Company

CJ Brown Southwest Power Pool, Inc.

Dallas Rowley Oklahoma Gas and Electric

Dean Schiro Xcel Energy

Dick Pursley Great River Energy

Durgesh Manjure MISO

Dwayne Stradford American Electric Power

Gayle Nansel Western Area Power Administration

Jason Weiers Otter Tail Power Company

Nandaka Jayasekara Manitoba Hydro

Nicholas Giffin American Transmission Company

Members Not Present



MRO Staff Present

Name Title

Bryan Clark Director of Reliability Assessment and Performance Analysis

Dana Klem RCS and RAPA Administrator

Dianlong Wong Senior Power Systems Engineer

Estee Kolles Security Administrator

Jake Bernhagen Senior Systems Protection Engineer

John Seidel Principal Technical Advisor

Lisa Stellmaker Executive Administrator and Office Manager

Max Desruisseaux Senior Power Systems Engineer

Salva Andiappan Principal Reliability Assessment Engineer

Guests

Name Organization

Amanda Schiro MISO

Bryan Wilson Oklahoma Gas and Electric

David Bautista PUC Texas

David Brauch MISO

Don Hargrove Oklahoma Gas and Electric

Jeremy Severson Basin Electric Power

John Hare Oklahoma Gas and Electric

Mary Agnes Nimis FERC

Rich Heidorn RTO Insider

Sunny Raheem Southwest Power Pool, Inc.

Sing Tay Oklahoma Gas and Electric

Terri Pyle Oklahoma Gas and Electric

Terry Volkmann Consultant



b. Approve June 18, 2020 RAC LTRA Meeting Minutes Ron Gunderson, Reliability Advisory Council Chair

Action Vote to approve June 18, 2020 RAC LTRA Meeting Minutes as written.

Report Chair Gunderson will ask for any changes or additions to the agenda during the meeting and approval of the June 18, 2020 RAC LTRA Meeting Minutes.

DRAFT MINUTES OF THE RELIABILITY ADVISORY COUNCIL MEETING WebEx

Thursday, June 18, 2020 – 9:00 a.m. to 11:00 a.m. 1. Call to Order and Introductions

Council Chair Gunderson called the meeting to order at 9:00 a.m. Gunderson extended a warm welcome to all attendees, roll call was taken and introductions were made.

2. Determination of Quorum, Standards of Conduct, and Anti-Trust Guidelines The meeting secretary Salva Andiappan determined that a quorum was present. A complete list of attendees is included as Exhibit A. Pursuant to Policy and Procedure 4, MRO’s Standards of Conduct, Conflict of Interest and Anti-Trust Guidelines were presented.

3. Review Initial 2020 Long-term Reliability Assessment (LTRA) Narratives Chair Gunderson opened the floor for the first speaker. a. Manitoba Hydro (MH). Kelly Hunter provided an overview of MH’s LTRA. Some highlights from that

presentation include; no significant methodology changes since the last assessment, as of June 1, the new 500kv line from Winnipeg to Duluth MN is operational, and that the Keeyask hydroelectric generating station is under construction. He provided explanation of the Assessment Process, noting the anticipated reserve margin does not fall below the reference margin level of 12%, and calling out the three portions of demand; residential, commercial market and top consumers. Mr. Hunter provided an overview of Demand, Energy Efficiency and Conservation, Net Peak Hour Demand Forecast among others. He mentioned MH is slowly evolving and that the Selkirk thermal


gas plant may be retired by replacing with the new Keeyask hydro capacity to reduce carbon emissions. Wind capacity accreditation is at 16.6%, and Solar PV has less favorable economics further north mainly due to snow remaining on solar panels. It was noted that the loss of Selkirk natural gas generation plant is not devastating to MH BES. The extreme event that occurred in October 2019 resulted in one-third of customers without power and additional crews from US and SaskPower managed to have power restored in two weeks. He reiterated that reliability issues are always being monitored for extreme cold and severe drought conditions for MH. Mr. Hunter, in response to a question regarding any EEA event occurred for the October 2019 event will respond back to MRO.

b. MISO. Stuart Hansen provided an overview of the LTRA noting the retirement of traditional units are being replaced with wind and also additions of hybrid (renewables pairing with batteries) and the large shift to solar. He noted that overall energy consumption amounts and patterns have changed due to the COVID impact but are slowly rebounding as portions of the US reopen. Long term impacts of the COVID pandemic remain to be seen. Mr. Hansen highlighted among others, the planning reserve margin, generation fleet change composition, and MISO local resource zones. Regarding LTRA changes, the focus for MISO is on summer months as they are a summer peaking entity and over half of the generation interconnection queue is made of solar. For inverter based systems the fleet is changing and they are working on determining how to accredit these resources and how they will perform, he directed everyone to the Resource Availability and Need whitepaper link in his presentation. Regarding the Planning Reserve Margin, Mr. Hansen noted members’ responses were evaluated, from LOLE analysis to determine ICAP PRM increase. The Load Forecast did increase but not drastically, they do not forecast load they collect data from load serving entities monthly for two years. In response to a question regarding changing the six month unit retirement impact study requirement to longer review period, Mr. Hansen noted that the MISO survey conducted is voluntary but it shows x amount of capacity loss in any given zone and indicates potential retirement which is shared with stakeholders. The stakeholder’s survey did not show any need to extend the minimum review period. MISO is not responsible for resource planning but there is a lot of discussion around it at MISO OMS In response to a question regarding RDT limits to see a possible resource shortage, Mr. Hansen responded that MISO looks at transfer limits from North to South – they do have excess generation in the south that is not deliverable to the north, they determine what the overall capacity is in the south, load plus reserve margin and contract path are adjusted to determine transmission limitation. A single BA planning reserve margin for any generation in the south would not be included in the total generation.


c. SaskPower. Suman Thapa provided an overview of the LTRA presentation. Some highlights included an overview of their capacity, and noting that the generation mix is changing in the next five years and will see retirement of coal and an increase in natural gas, and the LTRA comparison from last year shows minimal changes. Mr. Thapa further noted the assessment process uses periodic reliability studies and resource adequacy assessments, including a 10-year supply plan, and that generation methods and assumptions are determined by looking at peak times. The perspective planning reserve margins ranges from 11% to 42% because of coal units being retired in 2030, and Mr. Thapa further noted that a joint study was done to determine SaskPower’s import of power from MH. The Demand Summary comparison was provided however Mr. Thapa noted that the impact of COVID is unable to be addressed at this time. Mr. Thapa also provided an overview of SPC’s transmission studies conducted, reliability impacts, new transmission facilities and extreme events. No changes to the assessment area footprint have occurred or are expected to occur for the next 10-years.

d. SPP. Chris Haley provided an overview of the LTRA highlighting an increase in wind penetration in

the footprint and the coordination plan between SPP and ERCOT for switchable generation during the summer time. He further highlighted reserve margins, coal and gas retirements and the generation interconnection queue resource mix for SPP is predominately wind, solar and battery storage. To address the demand to further align the NERC LTRA with market operations and seasonal assessments, SPP wants to align individual member non-coincident demand with a coincident peak for BA consideration. Mr. Haley also touched on Demand-Side, Existing-Certain and Net Firm Transfers and a Reserve Margin chart was illustrated. He commented that reliability Issues are not anticipated at this time. In response to a question regarding the switchable generation agreement and what SPP receives from ERCOT, Mr. Haley noted there are resources in ERCOT that SPP has firm access to and are in place, but SPP is not looking at any imports from ERCOT at this time. A further question was raised regarding how often ERCOT is reaching out to SPP during summer peaks with regard to accessing these switchable generation. Mr. Haley responded that SPP had one event last year for which they had to call some resources back from ERCOT, but no others were recalled. It was important to note that the conversation regarding resource availability has occurred between SPP and ERCOT so the communication exists in anticipation of any necessary transfers. In response to the question if SPP is in discussion to try and increase demand response with regard to some other RTOs having hefty load resources, Mr. Haley responded that it is being discussed and steps are being taken but as far as the build out inside the market that will probably not occur.

4. Adjourn Having no further business to discuss, the meeting was adjourned at 11:09 a.m.

Upon a motion duly made and seconded, the RAC unanimously agreed to adjourn the meeting.


Prepared by: Dana Klem, RCS and RAPA Administrator

Reviewed and Submitted by: Bryan Clark, Director, Reliability Assessment and Performance Analysis

EXHIBIT A – MEETING ATTENDEES

Reliability Advisory Council Members Present

Name Organization

Ron Gunderson, Chair Nebraska Public Power District

John Stephens, Vice Chair City Utilities of Springfield Missouri

Allen Klassen Evergy, Inc.

Antoine Lucas Southwest Power Pool, Inc.

Binod Shrestha Saskatchewan Power Company

CJ Brown Southwest Power Pool, Inc.

Dean Schiro Xcel Energy

Dick Pursley Great River Energy


Gayle Nansel Western Area Power Administration

Nandaka Jayasekara Manitoba Hydro

Nicholas Giffin American Transmission Company

Members Not Present

Dallas Rowley Oklahoma Gas and Electric

Durgesh Manjure MISO

Jason Weiers Otter Tail Power Company

MRO Staff Present

Name Title

Bryan Clark Director of Reliability Assessment and Performance Analysis


Dana Klem RCS and RAPA Administrator

David Kuyper Power Systems Engineer

Dianlong Wong Senior Power Systems Engineer

Jake Bernhagen Senior Systems Protection Engineer

John Seidel Principal Technical Advisor

Max Desruisseaux Senior Power Systems Engineer

Mike Bocovich Principal Systems Protection Engineer

Salva Andiappan Principal Reliability Assessment Engineer

Guests

Name Organization

Stuart Hansen MISO

Chris Haley Southwest Power Pool

Suman Thapa SaskPower

Jeff Toye Manitoba Hydro

Kelly Hunter Manitoba Hydro

Charles Hendrix Southwest Power Pool

Dinesh Dhungana SaskPower

David Jacobson Manitoba Hydro

Bruce Reimer Manitoba Hydro



c. Approve PRS Charter Ron Gunderson, Reliability Advisory Council Chair

Action Vote to approve the PRS Charter for recommendation to the OGOC.

Report Chair Gunderson will ask for approval of the updated Charter as shown in redline.

1

MRO PROTECTIVE RELAY SUBGROUP CHARTER

September 19, 2019 I. Purpose The purpose of the MRO Protective Relay Subgroup (PRS) is to identify, review and discuss system protection and control issues relevant to the reliability of the bulk electric system and to develop and implement regional procedures for applicable NERC PRC standards. The MRO Protective Relay Subgroup (MRO PRS) reports to the Reliability Advisory Council (RAC).

II. Membership Pursuant to Policy and Procedure 3: Establishment, Responsibilities, and Procedures of Organizational Groups and MRO Sponsored Representatives on NERC Organizational Groups (PP3), membership of organizational groups shall be determined based upon experience, expertise and geographic diversity and to the extent practicable, shall include a balanced representation of the sectors. The MRO PRS is comprised of industry experts in the areas of system protection and control. The specific experience and expertise needs of the MRO PRS are determined by the MRO PRS. The subgroup shall be comprised of no more than 19 members, with not more than one member from the same company and membership based on geographic representation as follows:

• Arkansas/Texas/Louisiana/New Mexico – 2 • Canada – 2 • Dakotas – 2 • Iowa – 2 • Kansas/Missouri – 2 • Minnesota – 3 • Nebraska – 2 • Oklahoma – 2 • Wisconsin – 2

If after soliciting membership based on the above geographic representation, one or more seat cannot be filled, then MRO will solicit for members from the entire region and the member will be designated “Regional.” When the term for that seat ends, MRO will again solicit a member from the state(s) which gave rise to the Regional member.

III. Key Objectives • Develop, maintain, and implement regional procedures as needed that address the

requirements of NERC PRC standards. • Annually review the summary of Misoperations (prepared by MRO staff) for the purpose of

identifying Lessons Learned and communicating these lessons with MRO membership. Formatted: Justified

2

• Trend the Event Analysis reports submitted to MRO for the purpose of identifying misoperations that are causing, or increasing the severity of, these events. Through the MRO PRS, work with the Entities involved with these events to assure that the misoperations are effectively identified and mitigated. Assure that any protection-related Lessons Learned of value to the industry are prepared and submitted to NERC Event Analysis staff.

• Prepare as necessary additional reports/whitepapers that identify methods that can reduce the likelihood and/or severity of system events or misoperations that can lead to system events.

• Provide oversight of the Remedial Action Schemes (RAS) review process to ensure that all new and modified RASs are reviewed before they come into service, and that all RASs in the MRO region are reviewed every five years. Review Remedial Action Schemes (RAS) as necessary to verify protection system functionality and/or assess operability.

• Provide technical input related to system protection and control to MRO. • Interface with the NERC groups related to protection and control.

IV. Meetings The MRO PRS will meet quarterly, or as necessary, in person, or via conference call, or web meeting. Meetings of the MRO PRS are open to public attendance; however, an executive session may be called by the chair or vice-chair. Additional meeting requirements related to agendas and minutes, voting and proxy, and rules of conduct are outlined in MRO Policy and Procedure 3, Organizational Groups.

V. Costs Meeting costs incurred by MRO PRS members are reimbursable by MRO according to MRO Policy and Procedure 2, Expense Reimbursement.

VI. Reporting Requirements The chair of the MRO PRS, or delegate, will provide a written and/or oral report describing the activities and actions of the group quarterly to the Reliability Advisory Council (RACRAC). The MRO PRS wi l l shall perform an annual review of this charter and the group’s overall purpose and key objectives to ensure that the group is efficient and effective in its operations and according to its purpose. The chair willshall provide an annual summary report, including a statement of its conclusions, to the RAC.

1


September 19, 2019 I. Purpose The purpose of the MRO Protective Relay Subgroup (PRS) is to identify, review and discuss system protection and control issues relevant to the reliability of the bulk electric system and to develop and implement regional procedures for applicable NERC PRC standards. The PRS reports to the Reliability Advisory Council (RAC).

II. Membership Pursuant to Policy and Procedure 3: Establishment, Responsibilities, and Procedures of Organizational Groups and MRO Sponsored Representatives on NERC Organizational Groups (PP3), membership of organizational groups shall be determined based upon experience, expertise and geographic diversity and to the extent practicable, shall include a balanced representation of the sectors. The PRS is comprised of industry experts in the areas of system protection and control. The specific experience and expertise needs of the PRS are determined by the PRS. The subgroup shall be comprised of no more than 19 members, with not more than one member from the same company and membership based on geographic representation as follows:

• Arkansas/Texas/Louisiana/New Mexico – 2 • Canada – 2 • Dakotas – 2 • Iowa – 2 • Kansas/Missouri – 2 • Minnesota – 3 • Nebraska – 2 • Oklahoma – 2 • Wisconsin – 2

If after soliciting membership based on the above geographic representation, one or more seat cannot be filled, then MRO will solicit for members from the entire region and the member will be designated “Regional.” When the term for that seat ends, MRO will again solicit a member from the state(s) which gave rise to the Regional member.

III. Key Objectives • Develop, maintain, and implement regional procedures as needed that address the

requirements of NERC PRC standards. • Annually review the summary of Misoperations (prepared by MRO staff) for the purpose of

identifying Lessons Learned and communicating these lessons with MRO membership.

2

• Trend the Event Analysis reports submitted to MRO for the purpose of identifying misoperations that are causing, or increasing the severity of, these events. Through the PRS, work with the Entities involved with these events to assure that the misoperations are effectively identified and mitigated. Assure that any protection-related Lessons Learned of value to the industry are prepared and submitted to NERC Event Analysis staff.

• Prepare as necessary additional reports/whitepapers that identify methods that can reduce the likelihood or severity of system events or misoperations that can lead to system events.

• Review Remedial Action Schemes (RAS) as necessary to verify protection system functionality and/or assess operability.

• Provide technical input related to system protection and control to MRO. • Interface with the NERC groups related to protection and control.

IV. Meetings The PRS will meet quarterly, or as necessary, in person, via conference call, or web meeting. Meetings of the PRS are open to public attendance; however, an executive session may be called by the chair or vice-chair. Additional meeting requirements related to agendas and minutes, voting and proxy, and rules of conduct are outlined in MRO Policy and Procedure 3, Organizational Groups.

V. Costs Meeting costs incurred by PRS members are reimbursable by MRO according to MRO Policy and Procedure 2, Expense Reimbursement.

VI. Reporting Requirements The chair of the PRS, or delegate, will provide a written or oral report describing the activities and actions of the group quarterly to the RAC. The PRS wi l l perform an annual review of this charter and the group’s overall purpose and key objectives to ensure that the group is efficient and effective in its operations and according to its purpose. The chair will provide an annual summary report, including a statement of its conclusions, to the RAC.

1


September ___, 2020

I. Purpose

The purpose of the MRO Protective Relay Subgroup (PRS) is to identify, review and discuss system

protection and control issues relevant to the reliability of the bulk electric system and to develop and

implement regional procedures for applicable NERC PRC standards. The PRS reports to the Reliability

Advisory Council (RAC).

II. Membership

Pursuant to Policy and Procedure 3: Establishment, Responsibilities, and Procedures of Organizational

Groups and MRO Sponsored Representatives on NERC Organizational Groups (PP3), membership of

organizational groups shall be determined based upon experience, expertise and geographic diversity and

to the extent practicable, shall include a balanced representation of the sectors. The PRS is comprised of

industry experts in the areas of system protection and control. The specific experience and expertise

needs of the PRS are determined by the PRS. The subgroup shall be comprised of no more than 19

members, with not more than one member from the same company and membership based on geographic

representation as follows:

Arkansas/Texas/Louisiana/New Mexico – 2

Canada – 2

Dakotas – 2

Iowa – 2

Kansas/Missouri – 2

Minnesota – 3

Nebraska – 2

Oklahoma – 2

Wisconsin – 2

If after soliciting membership based on the above geographic representation, one or more seat cannot be

filled, then MRO will solicit for members from the entire region and the member will be designated

“Regional.” When the term for that seat ends, MRO will again solicit a member from the state(s) which

gave rise to the Regional member.

III. Key Objectives

Develop, maintain, and implement regional procedures as needed that address the

requirements of NERC PRC standards.

Annually review the summary of Misoperations (prepared by MRO staff) for the purpose of

identifying Lessons Learned and communicating these lessons with MRO membership.

2

Trend the Event Analysis reports submitted to MRO for the purpose of identifying

misoperations that are causing, or increasing the severity of, these events. Through the MRO

PRS, work with the Entities involved with these events to assure that the misoperations are

effectively identified and mitigated. Assure that any protection-related Lessons Learned of

value to the industry are prepared and submitted to NERC Event Analysis staff.

Prepare as necessary additional reports/whitepapers that identify methods that can reduce the

likelihood or severity of system events or misoperations that can lead to system events.

Provide oversight of the Remedial Action Schemes (RAS) review process to ensure that all

new and modified RASs are reviewed before they come into service, and that all RASs in the

MRO region are reviewed every five years.

Provide technical input related to system protection and control to MRO.

Interface with the NERC groups related to protection and control.

IV. Meetings

The PRS will meet quarterly, or as necessary, in person, via conference call, or web meeting. Meetings

of the PRS are open to public attendance; however, an executive session may be called by the chair

or vice-chair. Additional meeting requirements related to agendas and minutes, voting and proxy, and

rules of conduct are outlined in MRO Policy and Procedure 3, Organizational Groups.

V. Costs

Meeting costs incurred byPRS members are reimbursable by MRO according to MRO Policy and

Procedure 2, Expense Reimbursement.

VI. Reporting Requirements

The chair of the PRS, or delegate, will provide a written or oral report describing the activities and

actions of the group quarterly to the RAC. The PRS shall perform an annual review of this charter and

the group’s overall purpose and key objectives to ensure that the group is efficient and effective in its

operations and according to its purpose. The chair shall provide an annual summary report,

including a statement of its conclusions, to the RAC.

Approved by the Organizational Group Oversight Committee on September ____, 2020


AGENDA 4 MRO Board of Directors OGOC Update

a. HERO Award Bryan Clark, Director, Reliability Assessment and Performance Analysis

Action Information

Report Bryan Clark will provide an oral report during the meeting.


AGENDA 5 RSTC Update

John Stephens, Reliability Advisory Council, Vice Chair

Action Information

Report Vice Chair Stephens will provide an oral report during the meeting.


AGENDA 6 Update RAC 2020 Work Plan

a. Review Action Items b. Reliability Risk Matrix

c. Pandemic Operational Impacts Webinar d. Reliability Conference


Action Discussion

Report Chair Gunderson will lead these discussions during the meeting. The 2020 RAC Work Plan can be found here.

https://www.mro.net/MRODocuments/MRO%20RAC%20Workplan.pdf?Web=1


AGENDA 7 AEP (SWEPCO) Outage in Texas Category 2 Event

David Ball, Managing Director of Transmission Operations, AEP

Action Information

Report David Ball will present on the SWEPCO Load Shed Event at the meeting.

David Ball - Managing Director Transmission

Operations

August 18th, 2019SWEPCO Load Shed

Event

MRO Reliability Advisory Council Meeting

BACKGROUND

01

Summary

On Sunday, 8/18/2019, between 1559 - 1643 CPT, the SWEPCO Pirkey area of AEP experienced multiple forced transmission outages, resulting in power system oscillations and system voltage instability. As a result, 645 MW of firm system load was lost at 1643 CPT. During the event, AEP manually shed 303 MW of firm customer load to resolve system constraints.

Existing Outages

The Diana 138kV CB 12050 was out of service for replacement. Additionally, the Knox Lee plant (138kV) was offline.

Weather

In general, weather conditions that promoted increased vegetation growth were greater than normal for 2019 in this area. Near the time of the event, rain falls were 78” when average annual rainfall for the area is 55”. Coupling the rainfall with warm temperatures, the vegetation in the area grew at an unexpected and increased rate.

Event Conditions: Blue sky day

EVENT SEQUENCE

02

SequenceEvent 11559 CPT: KNOX LEE - PIRKEY (138 kV)Outage Cause: Vegetation Contact

Event 21615 CPT: PIRKEY - WHITNEY (138 kV) Outage Cause: Vegetation Contact

Event 31618 CPT: MARSHALL 138/69 kV TransformerOutage Cause: Overload

Event 41623 CPT: NORTH MARSHALL – WOODLAWN – JEFFERSON 69 kVOutage Cause: Conductor failure

1

23

4

Load Shed

1629 CPT Manual Load Shed: AEP operated the switch at AEP SPRING RIDGE which shed approximately 11MW of ETEC load.

SequenceEvent 51637 CPT: DIANA – PLILER (138 kV)Outage Cause: Vegetation Contact

Event 61637 CPT: LAKE LAMOND 138/69 kV TransformerOutage Cause: Overload

Event 71643 CPT: DIANA - PERDUE (138 kV) Circuit (breakers failed to reclose at Perdue)Outage Cause: Vegetation Contact

Event 81643 CPT: SW SHREVEPORT – ROCKHILL (138kV) (reclosed after approximately 30 seconds)Outage Cause: Line tripped by relay misoperation

56

7

8

Sequence

Event 91643 CPT: Power system oscillations were observed for approximately 9 seconds, causing numerous 69 kV and 138 kV circuits to operate.

Event 9

Additional sustained outages at 1643 CPT

1643 CPT: EASTEX SWITCH – SOUTH TEXAS EASTMAN (138 kV) Circuit

1643 CPT: KNOX LEE - ROCK HILL (138 kV) Circuit

1643 CPT: OVERTON – NW HENDERSON (138 kV) Circuit

1643 CPT: EASTEX COGENERATION

1643 CPT: NW HENDERSON – POYNTER (69 kV) Circuit

1643 CPT: EVENSIDE – POYNTER (69 kV) Circuit

AEP Automatic UFLS Operation

1643 CPT: LEVERETT (12 kV) 5200 & 5700 (setting 59.0 Hz for 15 cycles)

1643 CPT: LAKE LAMOND (12 kV) 6850 & 8570 (setting 59.3 Hz for 15 cycles)

1643 CPT: CLARKSVILLE (12 kV) CB 3660 (setting 58.7 Hz for 15 cycles)

At 1643 CPT, there were multiple stations that did not have a source as a result of the forced/momentary outages. The table below represents the stations that were all or partially de-energized momentarily at 1643 CPT, due to all sources being lost. The source was lost for the time it took the momentary outages to reclose following their 1643 CPT trip.

Load Shed

Additional AEP Manual Load Shed1647 CPT: BRADY SWITCH: Approximately 50MW 1649 CPT: LAKE HAWKINS Approximately 26 MW1659 CPT: GILMER: Approximately 9MW1717 CPT: POYNTER: Approximately 20MW1721 CPT: ROCK HILL Approximately 57MW1803 CPT: WHITNEY: Approximately 17MW1809 CPT: LAKE LAMOND: Approximately 23MW1822 CPT: PLILER: Approximately 45MW1822 CPT: SABINE: Approximately 9MW1840 CPT: KILGORE: Approximately 12MW1840 CPT: LONGVIEW: Approximately 24MW

Load Shed

ETEC Manual Load Shed Per AEP Operating Instruction

1723 CPT: ALTO: Approximately 7.60 MW1716 CPT: PINE GROVE: Approximately 8.06 MW1800 CPT: WALNUT SPRINGS: Approximately 3.6 MW

ETEC= East Texas Electric Cooperative

OUTAGES

03

Customer Outages

AEP identified that approximately 87,000 internal AEP customers were affected as a result. ETEC identified approximately 61,000 ETEC customers affected.

Customer Outages

The Eastex generator outage occurred at 1643 CPT, after a system voltage instability caused momentary outages and sustained forced outages at Eastex Switch station and in the surrounding area. The Eastex generator tripped offline at 1643 CPT after all circuit breakers opened at Eastex Switching station and after a monetary outage occurred on the Eastex Cogen-North Texas Eastman 138 kV circuit which isolated the generator from the transmission system.

Misoperations

16:43:04 CPT: DIANA-PERDUE (138 kV) line tripped at both ends for BC faults 16:43:04 CPT: ROCK HILL-SW SHREVEPORT (138 kV) line tripped by relay misoperation at the SW Shreveport end only (Cause due to improper CT ratio connected, CT ratio was corrected on 8/19/2019)16:43:19 CPT: CARTHAGE CONNECTION (138 kV) CB 13140 operates trip/close by Z1 during restoration of circuit (Logansport-Tenaha 138kV circuit)Note: Ryan Godwin from AEP presented to the MRO Protective Relay Subgroup in February, 2020, Corrective actions for the other two Misoperations are ongoing.

CONCLUSIONS & LESSONS LEARNED

04

Vegetation

AEP Forestry declared “storm mode” following the event and is actively mitigating vegetation concerns on the PIRKEY – KNOX LEE and PIRKEY – WHITNEY circuits.The project was completed at the end of 2019 with a spend of $3.96 M. The original target was 325 miles but the effort surpassed that target and the project completed 393 miles addressing: 97 aerial spray miles 133 aerial saw miles 163 mow/cut miles

Proactive Actions Taken

Valid Real-time Assessment every 30 minutes RTA and EMS worked well

Followed Transmission Operations Emergency Operating Plan to shed load Training and processes proved effective Successful collaboration between the SCC, TDC, DDC, SPP, and COOPs

Restoration Efforts

All customer feeders were re-energized by 2300 CPT on 8/18/2019 The last Transmission circuit was restored at 0158 CPT on 8/19/2019

Questions?


AGENDA 8 Regional Risk Assessment Process

John Seidel, Principal Technical Advisor

Action Information

Report The MRO Reliability Advisory Council (RAC) was instrumental in the development and success of the 2020 Regional Risk Assessment.

Areas of Focus

1. The approach taken last year was to review the risks that were identified in the following ERO reports and then assess their impact within the MRO region:

• 2019 ERO Reliability Issues Steering Committee (RISC) Priorities Report (RISC report)• 2020 ERO Compliance Monitoring and Enforcement Program Implementation Plan (CMEP IP)• 2019 NERC State of Reliability Report (SOR report)• 2019 NERC Long-Term Reliability Assessment (LTRA report)

The documents above that fall under the RAC’s purview are the RISC report, the SOR report, and the LTRA report. The 2019 RISC report is biennial, so remains unchanged for 2020. The 2020 SOR report was completed and posted on July 28, 2020 (to be reviewed under RAC agenda item 11.b). The 2020 LTRA is scheduled to be finalized in Dec, 2020, but we will have the reporting areainformation for the four Planning Coordinators (PCs) within MRO later this fall.

2. The RAC along with MRO staff then worked to identify any additional BPS reliability risks that wereapplicable to the MRO region (using sources such as Event Analysis reports, NERC LessonsLearned, NERC Alerts, actual system performance during peak load periods, etc.) These risk were:

• Overhead Transmission Line Ratings• Reactive Resource Management and Voltage Stability• Reactive Capability of Renewable Generation• Accuracy of Bulk Power Models (Powerflow and Short Circuit)

3. New/Proposed MRO Reliability Risks Identified for 2021 RRA

a. The deployment of accurate and timely Load Modifying Resources (LMRs) of sufficient MWamount can help increase reliability within the MRO region. In 2020, three of the four BalancingAuthorities within MRO experienced a shortage of generation capacity that resulted in eitherenergy emergency alerts or Balancing Authority resource alerts on multiple occasions such thatoperating reserve requirements/limits were being approached. This occurred during loadconditions well below the forecast peak levels. This occurred due to a significant number of

https://www.nerc.com/comm/RISC/Related%20Files%20DL/RISC%20ERO%20Priorities%20Report_Board_Accpeted_November_5_2019.pdf

https://www.nerc.com/pa/comp/Reliability%20Assurance%20Initiative/2020%20ERO%20CMEP%20Implementation%20Plan%20V%201.0.pdf

https://www.nerc.com/pa/comp/Reliability%20Assurance%20Initiative/2020%20ERO%20CMEP%20Implementation%20Plan%20V%201.0.pdf

https://www.nerc.com/pa/RAPA/PA/Performance%20Analysis%20DL/NERC_SOR_2019.pdf

https://www.nerc.com/pa/RAPA/ra/Reliability%20Assessments%20DL/NERC_LTRA_2019.pdf


generation outages that were not accounted for or anticipated in the summer assessment and, at times, when wind generation was below its expected output level used for capacity planning. Deferred generator maintenance and supply chain issues during spring due to the pandemic may have also caused some forced or operational unit outages during the summer season. Note that the 2020 summer anticipated planning reserve margins for these three BAs (per the NERC Summer Reliability Assessment) were well above target reserve margin levels.

MISO: LMRs within the MISO BA amount to about 5% of total summer peak load forecast. However, only a small portion of these reside within MISO-South. Because MISO-South has very limited firm deliverability from MISO-North (1000 MW limit of Regional Directional Transfer limit has been extended) and has limited import capability from SPP and SERC BAs, it is at unidentified additional risk due to single MISO BA analysis practices. This was identified in the January 17, 2018 FERC Inquiry report. Additional LMRs in MISO-South that can be deployed without extensive notification requirements would help to reduce the risk of firm load shed during resource capacity shortages in MISO-South.

SaskPower: LMRs within the SaskPower BA amount to about 1.7% of their summer peak load forecast. SaskPower also has very limited import capability from the Western Interconnection, the US, and MHEB and therefore largely rely on their own generation to serve load. Additional LMRs in SaskPower would help reduce the risk of firm load shed during resource capacity shortages within the province.

SPP-RTO (EI): LMRs within the SPP BA amount to about 1.6% of their summer peak load forecast. The majority of these reside in the northern portion of the RTO footprint. SPP anticipated a 32.8% planning reserve margin for summer 2020, well above the 12% target margin criteria. However, unanticipated generator outages combined with low wind resulted in several resource alerts during 2020, even with demand well below 100% forecast peak. Additional LMRs within the SPP BA, particularly in the southern half of the BA where the majority of the wind generation exists, would help reduce the risk of firm load shed during resource capacity shortages within the BA.

b. Others? (RAC discussion on other risks that may pertain to the MRO region)

MRO staff will also review other regional RRAs to identify any other regional risk that have been identified that may pertain to the MRO region.

As these regional risks are identified and expanded for 2021, MRO staff would like the RAC to help MRO staff assess these risks by using the new MRO risk matrix to determine an internal relative ranking. This may allow us to develop an MRO heat chart (similar to the RISC heat chart for the NERC-wide risks.

Regional Risk Assessment: https://www.mro.net/MRODocuments/2020%20Regional%20Risk%20Assessment%20Final.pdf

https://www.mro.net/MRODocuments/2020%20Regional%20Risk%20Assessment%20Final.pdf


AGENDA 9 Reliability Coordinator Update

a. MISO - Durgesh Manure

Action Information

Report Durgesh Manjure will provide an update during the meeting.



b. SPC - Binod Shrestha

Action Information

Report Binod Shrestha will provide an update during the meeting.



c. CJ - Brown, SPP

Action Information

Report CJ Brown will provide an update during the meeting.


AGENDA 10 NERC Committee Representative Written Reports

a. NERC Electric Gas Working Group (EGWG) Jaimin Patel, EGWG Representative

Action Information

Report Jaimin Patel will provide an update during the meeting.



b. NERC Inverter Based Resource Performance Task Force (IRPTF) David Brauch, IRPTF Representative

Action Information

Report Report on activities of the IRPTF during the June 2, 2020 meeting.

Areas of Focus

1. Inverter-Based Resource Modeling IRPTF had several presentations on the modeling of IBRs from manufacturers, consultants, RTOs, and TOs. The scope of the modeling presentation encompassed highly detailed EMT modeling to positive sequence models. Since most IBRs controllers are software based, some manufacturers suggest using “real code” to model the behavior of their products with a wrapper interface with power system modeling software. Real code offers the benefit of incorporating manufacturer updates to their products faster than dynamic model development, but also is more accurate since the same code is also uploaded to the turbines installed in the field.

2. BES Definition With the increase in IBRs, there was a discussion in the current definitions of Bulk Electric System. The current definition for dispersed resources has resulted in a fair number of plants that are excluded from BES definition. This has resulted in relying on other mechanisms such as market rules and interconnection requirements to address accountability gaps. It should be noted that there is a concern among Generator Owners and Developers on potential unintended consequences and costs with updating the BES definition.

3. IRPTF Priorities Survey IRPTF conducted as survey to prioritize the top ten tasks that need to be addressed in the near term. With over 75 respondents, the top three items identified in the survey had the common theme of modeling of IBRs. 1. Reliability Guideline: BESS and Hybrid Plant Performance, Modeling, and Studies 2. Reliability Guideline: EMT Modeling and Simulation 3. Follow-Up and Tracking: Positive Sequence Modeling Issues

Accomplishments

1. IRPTF conducted a survey of tasks to focus efforts in the near term 2. An introductory training session was held on the basics of using the PSCAD modeling tool that can

be used in EMT studies.


Challenges

1. Resistance to additional reliability requirements for generators that could be reclassified as BES if the definitions were altered.

2. IBR modeling in both positive sequence and EMT model needs more standardization on interface to incorporate real code more seamlessly to existing power flow software tools. Vestas refers to this as the Uniform Modeling Framework (UMF). This could potentially be IEEE or IEC standard development which will take time.

3. Model development timelines for power flow software is on the scale of years whereas manufacturers are updating their real code on a monthly basis. This results in a slow gradual divergence of the effectiveness for positive sequence model to emulate modern turbine technology over time.



c. NERC System Planning Impacts from DER Working Group (SPIDERWG) Sunny Raheem, SPIDERWG Representative

Action Information

Report Sunny Raheem will provide a report at the Quarter 4 meeting.


AGENDA 10 NERC Committee Representative Written Reports d. NERC Operations Reliability Subcommittee (ORS)

Steve Sanders, ORS Representative

Action Information

Report Steve Sanders will provide a report at the Quarter 4 meeting.



e. NERC System Analysis and Modeling Subcommittee (SAMS) Amanda Schiro, SAMS Representative

Action Information

Report Activities at July SAMS Meeting.

Areas of Focus

1. Node Breaker Modeling The Phase III scoping document was approved after member discussion and updates. Key Milestones include establishing the criteria to move from bus-branch to node-breaker modeling, testing and initial findings, and a whitepaper (2021 Q3). Reports on current node-breaker efforts were provided by ISO-NE and SPP. Siemens also provided information on how the PSS/e software has been adjusted to accommodate node-breaker modeling.

2. NERC Whitepaper Load Loss Definition

Hari Singh presented an updated load loss definition to distinguish between the utility side of the meter status – active or inactive – to coordinate with the consequential and non-consequential load loss definitions. A final review of the Whitepaper provided additional updates and clarifications regarding recommended actions. These clarifications were accepted, and the final document approved by the SAMS community. It will be submitted to the RSTC for final approval prior to publicly posting the document.

3. Transient Voltage Criteria Whitepaper A preliminary draft paper was presented outlining the problem statements and background information. This whitepaper will expand on the existing NATF document to address the recommendation to review transient voltage criteria once more realistic dynamic load models are created, leveraging the recent work on the composite load model (CMLD) benchmark activities. A request for SAMS member volunteers to assist with this effort was put forth.

Accomplishments

1. NERC Acceptable Models List update approved. 2. Node-Breaker Modeling Phase III scope for Eastern Interconnection cases approved.

Challenges

None.



f. NERC System Protection and Control Subcommittee (SPCS) Mark Gutzmann, SPCS Representative

Action Information

Report The SPCS activity has been limited in the previous quarter but has had two partial day conference calls. The focus has been on completing a Standard Authorization Request (SAR) to remove Requirement R2 from PRC-023-4 (Transmission Relay Loadability) concerning out-of-step blocking elements and clarifying Attachment A, exclusion 2.3 which is related.

Areas of Focus

1. PRC-023-4 Standard Authorization Request

Requirement R2 concerns out-of-step blocking (OOSB) elements which are utilized on some transmission line protection systems and has caused some confusion for entities leading some entities to unnecessarily disable these elements. Disabling these OOSB elements could lead to instability. Attachment A, exclusion item 2.3 is a related exclusion to Requirement R2. This proposed SAR eliminates or clarifies these two items in PRC-023-4 and directs any needed changes be applied to PRC-026-1 (Relay Performance During Stable Power Swings).

Accomplishments

1. PRC-023-4 SAR approved by the SPCS. SAR delivered to the Standards Committee.

Challenges

Presently no significant challenges.


AGENDA 11 NERC Reliability Assessments

a. Long Term Reliability Assessment Salva Andiappan, Principal Reliability Assessment Engineer

Action Information

Report Salva Andiappan will provide an oral report during the meeting.


AGENDA 11 NERC Reliability Assessments

b. State of Reliability Report John Seidel, Principal Technical Advisor

Action Information

Report John Seidel will provide an oral report during the meeting. State of Reliability Report: https://www.nerc.com/pa/RAPA/PA/Performance%20Analysis%20DL/NERC_SOR_2020.pdf

https://www.nerc.com/pa/RAPA/PA/Performance%20Analysis%20DL/NERC_SOR_2020.pdf


AGENDA 12 Special Protection System Working Group (SPSWG) Update

a. Update John Seidel, Principal Technical Advisor

Action Information

Report John Seidel will provide an update during the meeting.


AGENDA 12 Special Protection System Working Group (SPSWG) Update

b. SPSWG Dissolution Ron Gunderson, Reliability Advisory Council Chair

Action Information

Report Chair Gunderson will lead the discussion on the SPSWG dissolution.


AGENDA 13 Protective Relay Subgroup (PRS) Update

Mike Bocovich, Principal Systems Protection Engineer

Action Information

Report Mike Bocovich will provide an update during the meeting.


AGENDA 14 Upcoming Meetings and Review 2020 Meeting Calendar

a. Expiring Terms Ron Gunderson, Reliability Advisory Council Chair

Action Information

Report Chair Gunderson will provide an update at the meeting.

2021 Nomination Timeline

September•Solicit Nominations for all Organizational Groups

October -November

•Compilation of nominations•Staff recommendations•Subgroups (PRS, NSRF, SACTF) recommend members to Advisory Councils•Advisory Councils recommend members for all Organizational Groups to OGOC

December

•OGOC approves all Organizational Group members•Advisory Councils recommend leaders to the OGOC for approval


AGENDA 14 Upcoming Meetings and Review 2020 Meeting Calendar

b. Election Process Review Ron Gunderson, Reliability Advisory Council Chair

Action Information

Report Chair Gunderson will provide an update at the meeting on the Election Process Review and upcoming meeting dates.

November 18, 2020 Q4 RAC Meeting

Proposed 2021 Meeting Dates

2021 Proposed Council Meeting Dates

Board OGOC SAC CMEPAC RAC

Q1 3/25/2021 3/24/2021 2/10/2021 2/9/2021 3/24/2021

Q2 6/24/2021 6/23/2021 6/23/2021 6/2/2021 6/9/2021

Q3 9/30/2021 9/29/2021 9/23/2021 9/29/2021 9/8/2021

Q4 12/2/2021 12/1/2021 11/3/2021 11/10/2021 11/17/2021

* The Board and OGOC meeting dates are confirmed


AGENDA 15 RAC Member Roundtable

Reliability Advisory Council Members

Action Information

Report Chair Gunderson will lead this discussion.


AGENDA 16 Other Business and Adjourn
