8-1-2017 oc agenda packet - midwest reliability organization 1, 2017 oc... · august 1, 2017 8:00...

CLARITY ▪ ASSURANCE ▪ RESULTS

380 St. Peter Street #800 Saint Paul, MN 55102 P. 651.855.1760 F. 651.855.1712 W. MidwestReliability.org

MEETING AGENDA

August 1, 2017 8:00 a.m. – 3:00 p.m.

MRO Corporate Offices, King Conference Center St. Paul, MN 55102

MRO Operating Committee


VIDEO AND AUDIO RECORDING


VIDEO AND AUDIO RECORDING

Please note that Midwest Reliability Organization (MRO) may make a video and/or an audio

recording of this Operating Committee 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.

Agenda MRO Operating Committee


MEETING AGENDA MRO Operating Committee

August 1, 2017 8:00 a.m.-3:00 p.m. MRO Corporate Offices, King Conference Center, St. Paul, MN

AGENDA ITEM BOARD ACTION

1 Call to Order and Introductions Dean Schiro, Chair

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

Information

2 Consent Agenda Dean Schiro, Chair

a. Approve May 23, 2017 Meeting Minutes

Action Item

3 Chair’s Report Dean Schiro

Discussion

4 Review of Event Analysis a. Review of Events Since Last Meeting – MRO Staff b. Recommendations and Lessons Learned – Bill Kunkel and Dick Pursley c. MRO Metrics Review - John Seidel d. Solar invertor issue addressed in recent NERC alert

Discussion

5 Reliability Coordinator Reports – Summer 2017 Conditions to Date MISO – Tony Rowan SPP-RTO – Terry Oxendale SaskPower- Cordell Wrishko

Information and

Discussion

6 Fall Reliability Conference- finalize topics – All Discussion Item

Lunch

7 MRO Protective Relay Subcommittee Report - Richard Quest and John Seidel a. Protective Relay Subcommittee Activities

Information

8 SPS Review Progress and Schedule - Richard Quest and John Seidel Information

9 Protection Misoperations a. 2017 Q1 Misoperation Results - Rich Quest

Information

10 NERC Committee Reports a. Operating Committee – Dick Pursley b. Operations Reliability Subcommittee – Steve Sanders c. Resources Subcommittee – Terry Bilke/Bill Kunkel d. System Protection and Control Subcommittee – Rich Quest/Mark Gutzmann e. Personnel Subcommittee – Neil Lindgren f. Reliability Assessment Subcommittee – Bill Kunkel

a. Summer Assessment Update g. Transmission Availability Data System Working Group – Rich Quest h. Event Analysis Subcommittee – Dick Pursley i. Performance Analysis Subcommittee (PAS)- Jamin Patel

Information

Agenda MRO Operating Committee


j. Updated terms for MRO Representatives on NERC Committees- Dan Schoenecker

11 Other Business a. Review Operating Committee Charter b. Review Operating Committee Terms c. Regional Risk Assessment (RRA) review and discussion- Ben Lewiski d. CMEP/COP/IRA Status and Activities update- Ben Lewiski

Information &

Discussion

12 Adjourn Action

AGENDA 1-Call to Order and Introductions


AGENDA 1

Call to Order and Introductions Operating Committee Roster

Name Role Sector Company Term End

Dean Schiro Chair Investor Owned Utility Xcel Energy 12/31/2019Ron Gunderson Vice Chair Cooperative Utility Nebraska Public Power

District 12/31/2017

Abubaker Elteriefi Member Transmission System Operator

ITC Midwest 12/31/2019

Nicholas Giffin Member Transmission System Operator

American Transmission Company

12/31/2019

Cordell Wrishko Member Canadian Utility Saskatchewan Power 12/31/2017Thomas Hrdlicka Member Investor Owned Utility Otter Tail Power Company 12/31/2017Dick Pursley Member Cooperative Utility Great River Energy 12/31/2018Lloyd Linke Member Federal Power Marketing

Agency Western Area Power Administration

12/31/2018

Dennis Florom Member Municipal Utility Lincoln Electric System 12/31/2018Tim Nissen At-Large At-Large incumbent Omaha Public Power

District

Open Member Municipal Utility 12/31/2019Anthony Rowan Member Transmission System

Operator Midcontinent ISO 12/31/2017

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 1b. Review of Robert’s Rules of Order


AGENDA 1

Consent Agenda 1b. Review of Robert’s Rules of Order

Parliamentary Procedures Based on Robert’s Rules of Order, Newly Revised, 10th Edition Establishing a Quorum In order to make efficient use of time at MRO Committee meetings, once a quorum is established, the quorum will be considered to be in effect until the meeting is adjourned. 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

(Recommendations from EFC, not necessarily Mr. Robert)

Abstentions. When a member abstains, he is not voting on the Motion, and his 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. The results of the vote (other than Unanimous Consent) are determined by dividing the votes in favor by the total votes cast. Abstentions are not counted in the vote and shall not be assumed to be on either side. For any votes on motions taken during the meeting, the motion shall be considered passed with 2/3 affirmative vote of the parties casting votes. For any votes on motions taken via e-mail or an electronic meeting, the motion shall be considered passed with 2/3 affirmative vote of the parties casting votes



“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. Robert’s Rules use a simple majority (one more than half) as the default for most motions. MRO does also.

Agenda 2 Approve May 23, 2017 Meeting Minutes


AGENDA 2

Consent Agenda 2 Approve May 23, 2017 Meeting Minutes

Dean Schiro, Chair

MIDWEST RELIABILITY ORGANIZATION DRAFT Meeting Minutes of the

MRO Operating Committee May 23, 2017

Call to Order Chair Dean Schiro called the meeting to order at 8:00 a.m.

Determination of Quorum and Standards of Conduct and Anti-Trust Guidelines Chair Schiro asked for introductions from the committee members and guests and determined that a quorum of the MRO Operating Committee was present. A complete list of attendees is included as Exhibit A. MRO’s Standards of Conduct and Anti-Trust Guidelines were provided in the meeting agenda for review. Chair Schiro asked the members if there were any additions to the agenda:

Upon motion duly made by and seconded, the MRO Operating Committee

unanimously approved the Operating Committee agenda as presented. Consent Agenda

a. Introductions Approve Meeting Minutes from February 7, 2017 Chair Schiro asked the members if there were any requests for changes to the meeting minutes. Minutes page 4 change to “provided” under Rich Quest.

Upon motion duly made and seconded, the MRO Operating Committee unanimously

approved the February 7, 2017 Operating Committee meeting minutes with the change as noted.

Chairman’s Report Chair Schiro gave his chairman’s brief report based on the most recent Board meeting. Review of Event Analysis

a. Review of Events Since Last Meeting Mr. John Seidel summarized the events that have occurred since the last meeting and provided follow up on previously reported events.



b. Recommendations and Lessons Learned- Dick Pursley Mr. Dick Pursley reviewed the latest NERC Lessons Learned report with the group. The group discussed how best to disseminate Lessons Learned (LL). NERC sends out LL as they are approved to industry via their ALL exploder. The group agreed that it is best for the companies themselves to disseminate the LL within their company. MRO will point out particular LL in MRO newsletters when they especially pertain to the MRO Region. The latest NERC LL are listed in each MRO newsletter under the Tips and Lessons Learned section.

Dick Pursley/Bill Kunkel’s presentation slides will be sent out to the OC. c. MRO Metrics Review- John Seidel and Rich Quest Mr. John Seidel reviewed regional metrics and provided an overview of event trending of MRO system events. Rich Quest discussed the 2016 Q4 reported misoperations.

Reliability Coordinator Reports The three Reliability Coordinators within MRO were requested to provide a brief summary of winter 2016/2017 preparation and expected system conditions.

d. MISO: Mr. Anthony Rowan gave a verbal update to the committee on summer

weather readiness. NOAA forecasts warmer than normal temps in the upper Midwest. There has been some severe weather in MISO south already. The summer peak load forecast is slightly below last summer’s forecast. Gas supply is sufficient and MISO has daily calls with pipeline companies to receive daily updates. There have been no new transmission-related issues and no new IROLs.

SPP-RTO: There was no report from SPP-RTO.

SaskPower: Mr. Cordell Wrishko gave a verbal report to the committee. SPC is expecting

normal weather for summer and a peak load forecast of 3500 MW. No concerns or problems are anticipated for this summer. There are no gas supply concerns anticipated. Reservoirs are above average at this point with recent rainfall. Hydro capacity is currently 855 MW installed.

Review of upcoming Spring Reliability Conference - All Mr. John Seidel summarized the upcoming spring reliability conference presentations and pointed to some of the highlights. MRO Protective Relay Subcommittee (PRS) Report- Rich Quest

a. PRS Activities Mr. Rich Quest provided a brief summary of recent PRS activities. The PRS met May 4-5, 2017 to finalize the Misoperations White Paper.



b. Status Update of PRS Phase II Misoperations Paper Mr. Rich Quest gave an update on the status of the Misoperations Phase II White Paper. Sections include:

Breaker Failure Schemes Differential Schemes Differential Commissioning Practices

Upon motion duly made by and seconded, the MRO Operating Committee unanimously endorsed the PRS Phase II Misoperations Whitepaper.

c. PRS Nomination Approval

The PRS members endorsed the PRS nominee Terry Fett, CIPCo, to fill the open Iowa position. PRS is now requesting approval from the Operating Committee and final approval from the board will be requested at the June 22 meeting.

Upon motion duly made by and seconded, the MRO Operating Committee unanimously approved the PRS Nomination.

PRS Nomination will go on the June 22 Board Meeting agenda.

d. PRS Membership Term Balancing

The PRS membership three year terms needed to be balanced over a three-year period, with approximately one third of the terms ending per year. Two of the fourteen PRS members (Mike Weir and Wayne Miller) volunteered to have their term end date shifted from 12/31/2019 to 12/31/2018 to balance out the subcommittee.

New terms will be included in the June 22 Board report.

SPS Review Progress and Schedule Rich Quest gave an update on the SPS review.

NERC Committee Reports The OC briefly discussed several of the below NERC reports. MRO staff recommends that the OC members review the reports and provide any follow-up questions or comments to MRO staff.

a. Operating Committee- Dick Pursley

Joint OC/PC Meetings have been added to the agendas before the regular OC meetings.

b. Operations Reliability Subcommittee- written report submitted by Steve Sanders c. Resources subcommittee- written report submitted by Terry Bilke System Protection and Control Subcommittee- Rich Quest/Mark Gutzman



Rich Quest discussed the group’s recent activities which focused on the PRC-023 transformer requirements for loadability.

d. Personnel Subcommittee- Neil Lundgren provided a verbal report to the group. SOCCED- Continuing Education Program roll out has been delayed until at least mid-August 2018. Upcoming PS Workshops:

July 11-12 NERC Aug 8-9 CAISO

e. Reliability Assessment Subcommittee- No report f. Transmission Availability (TADS)- Verbal report by Rich Quest. g. Event Analysis Subcommittee- Dick Pursley reviewed his report.

(Situational awareness conference 10/3-4, 2017) h. NERC Performance Analysis Subcommittee (PAS)- Reviewed Jamin Patel’s

written report. i. Terms for MRO Representatives on NERC Groups- Dan Schoenecker

MRO will provide proposed term dates for NERC Committee members and send out to the OC group for review.

Other Business

j. Regional Risk Assessment (RRA) update- Ben Lewiski Information can be found here. Send out previous year report and topics for discussion before our next meeting (August 1, 2017)

and (October 26, 2017) and put on the agendas for OC/PC discussion.

k. GMD Discussion: What tools have your organization found to establish the Geomagnetic Latitude of your footprint? – facilitated by Jeff Norman

Adjourn The meeting was adjourned at 2:55 p.m.

Upon motion duly made and seconded, the MRO Operating Committee adjourned the meeting.

Agenda b. Approve May 23, 2017 Meeting Minutes


Exhibit A – Meeting Attendees Committee Members Present Dean Schiro Xcel Energy, Chair Ron Gunderson Nebraska Public Power District Vice Chair Abubaker Elteriefi ITC Midwest Dennis Florom Lincoln Electric System Nicholas Giffin American Transmission Company Anthony Rowan MISO Dick Pursley Great River Energy Tom Hrdlicka Otter Tail Power Company Lloyd Linke Western Area Power Administration Cordell Wrishko Saskatchewan Power (via teleconference) Aaron Smith Omaha Public Power District (proxy for Tim Nissen) Committee Members Not Present Tim Nissen Omaha Public Power District (At-Large) MRO Staff Dan Schoenecker Vice President Operations Lisa Stellmaker Operations Administrator and Office Manager John Seidel Sr. Manager of Operations and Reliability Rich Quest Principal Systems Protection Engineer Salva Andiappan Mgr. Reliability Assessments and Performance Analysis, Assessments Jeff Norman MRO Ben Lewiski MRO Guests Neal Faltys OPPD (via teleconference) Neil Lindgren NERC PS (via teleconference)

Agenda 4b. Recommendations and Lessons Learned


AGENDA 4

4b. Recommendations and Lessons Learned

Bill Kunkel Date: August 1, 2017 To: MRO Operating Committee From: Bill Kunkel Subject: Recommendations and Lessons Learned Action: Information and Discussion

OPERATING COMMITTEEM I D W E S T R E L I A B I L I T Y O R G A N I Z AT I O N

Promoting RELIABILITY and Mitigating RISKS to the Bulk Power System

LESSONS LEARNEDSUMMARY

Lessons Learned Published in June and July 2017

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OPERATING COMMITTEEM I D W E S T R E L I A B I L I T Y O R G A N I Z A T I O N

The MRO Operating Committee is an industry stakeholder committee which includes subject matter experts from MRO member organizations in various technical areas. Any materials, guidance, and views from stakeholder committees are meant to be helpful to industry participants; but should not be

considered approved or endorsed by MRO staff or its board of directors unless specified.

One NERC Lesson Learned was published in June 2017

LL20170601 – Generator Trip While Performing Frequency Response

One NERC Lesson Learned were published in July 2017

LL20170701 – Loss of Wind Turbines Due to Transient Voltage Disturbance

June and July 2017 Lessons Learned

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Two generating units were responding to a large frequency excursion when they tripped off‐line on low boiler furnace pressure.

Generator Trip While Performing Frequency Response

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Two units (units 1 and 3) of a three‐unit coal plant were operating at about half load when 1500 MW of generation tripped off elsewhere.

The interconnection frequency dropped to 59.79 Hz.

In response to the dip in frequency, both operating coal units rapidly increased their output.

Unit 1 responded with a 205 MW/minute ramp rate while unit 3 responded with a 169 MW/minute ramp rate.

Generator Trip While Performing Frequency Response - Detail

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The induced draft (ID) and forced draft (FD) fans did not respond in an appropriately coordinated manner with the increased load demand, resulting in low furnace pressure.

In less than 15 seconds after the frequency dip, both of these units tripped offline due to low boiler furnace pressure.


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Investigation of the unit trips with the original design engineer and distributed control system (DCS) vendor, it was determined that the accumulation of plant modifications and incremental tuning (addressing many isolated issues over time) changes during the past fifteen years had altered plant response.

The DCS was no longer “in tune” with the physical plant.


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The stroke times on FD and ID fans were captured. It was found that their control curves needed to be modified to align with the physical system changes that had occurred over time to improve stability.

The GO worked with the DCS vendor to schedule load ramps and testing to further tune control curves for the fans and other equipment. This was similar to performing an initial control system commissioning.

Generator Trip While Performing Frequency Response – Corrective Actions

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Accumulated effects of plant modifications and incremental tuning changes may significantly alter plant response over time.

Eventually, the digital model in a DCS may no longer correspond to physical reality or system requirements.

It is cost effective to obtain unit load data and perform baseline “re‐tuning” every 5‐10 years (depending on frequency of modifications) or as part of any major modification project.

Generator Trip While Performing Frequency Response – Lesson Learned

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Voltage disturbance events on the transmission system in Australia and Texas have highlighted concerns with voltage ride through and in some wind turbine control system parameters.

Loss of Wind Turbines due to Transient Voltage Disturbances on the Bulk Transmission System

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Six events were reviewed:South Australia Blackout – September 28, 2016ERCOT Events:• Event 1: A 138 kV multiphase bus fault resulted in seven voltage

disturbances within a ten‐minute period. Investigations showed a total reduction of 475 MW of wind generation across nine wind plants.

• Event 2: A 138 kV line fault caused a low‐voltage excursion, resulting in the loss of 342 MW of wind generation across seven wind plants

Loss of Wind Turbines due to Transient Voltage Disturbances on the Bulk Transmission System - Detail

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• Event 3: A 345 kV line fault caused a single‐phase low voltage excursion resulting in the loss of 343 MW of wind generation across seven wind plants.

• Event 4: A 69 kV bus fault caused a low‐voltage excursion, resulting in the loss of 230 MW of wind generation across seven wind plants.

• Event 5: A 138 kV line fault caused a low voltage excursion, resulting in the loss of 404 MW of wind generation across six wind plants

Loss of Wind Turbines due to Transient Voltage Disturbances on the Bulk Transmission System - Detail

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Of the 13 wind plants that were on‐line, nine did not ride through the six voltage disturbances during the event. The simultaneous trip of these wind plants was reclassified as a credible contingency.

The transmission operator worked with the wind plants to identify and document their ride through capability.

As wind plants reconfigured the ride through controls they were removed from the credible contingency.

Subsequently the modified wind plants all rode through a similar event on March 3, 2017.

Loss of Wind Turbines due to Transient Voltage Disturbances on the Bulk Transmission System – Corrective Actions Australia

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During Event 1, wind plant owners noted that 130 turbines tripped due to the repeated voltage fluctuations during a particular event. The turbines tripped due to voltage ride‐through parameters that were set to disconnect or reduce turbine output when a specified number of voltage excursions were detected within a given time frame.

One wind plant owner noted that 11 turbines tripped due to failed crowbar components in the wind turbine during Event 2

Loss of Wind Turbines due to Transient Voltage Disturbances on the Bulk Transmission System – Corrective Actions ERCOT

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During Event 2, one wind plant owner noted that 12 turbines tripped due to the failure of the wind turbine auxiliary uninterruptible power supplies (UPS) devices. The owner is investigating the cause of these particular UPS failures.

During Event 4, multiple wind plant owners indicated that the voltage ride‐through tolerance for their turbines was insufficient for the magnitude of the voltage disturbance. Those ride‐through capabilities ranged from:

Less than 0.80 per‐unit for 0.08 to 0.2 seconds

Between 0.80 and 0.90 per‐unit for up to 60 seconds

Loss of Wind Turbines due to Transient Voltage Disturbances on the Bulk Transmission System – Corrective Actions ERCOT

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Wind generation owners should review and verify the voltage ride‐through capabilities of their equipment, clearly communicate those capabilities to their BA and connected TOPs, and ensure that the models provided to the BA and TOPs correctly reflect those capabilities.

If BAs and TOPs are notified by the wind generation owners that units lack ride through capability, BAs and TOPs should communicate to their RC and BAs, TOPs, and RC should consider in their daily resource plan the potential for the loss of these resources during transmission faults on the power system. BAs, TOPs, and RCs should take appropriate mitigating measures.

Loss of Wind Turbines due to Transient Voltage Disturbances on the Bulk Transmission System – Lesson Learned

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Wind generation owners should review and verify that UPS and “Smart Crowbar” systems within the wind turbines are maintained and functioning properly.

High speed PMU data is critical for visibility into the magnitude of voltage disturbances related to the loss of wind turbines (or grid resources of any type).

Loss of Wind Turbines due to Transient Voltage Disturbances on the Bulk Transmission System – Lesson Learned

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NERC’s goal with publishing lessons learned is to provide industry with technical and understandable information that assists them with maintaining the reliability of the bulk power system.

NERC requests that industry provide input on lessons learned by taking the short survey. A link is provided in the PDF version of each Lesson Learned.

Lessons Learned Survey Link

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Agenda 5a. Reliability Coordinator Report


AGENDA 5

5a. Reliability Coordinator Report

Tony Rowan Date: August 1, 2017 To: MRO Operating Committee From: Tony Rowan, MISO Subject: Reliability Coordinator Report- MISO Action: Information and Discussion

MRO OCMISO RC ReportAugust 1, 2017

2017 Summer Performance

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• No unusual summer performance issues to date.• Mostly normal summer storms with a few instances of outages, but

nothing that would be classified as unusual or very challenging.

• Tropical Storm Cindy made landfall between Cameron, Louisiana and Port Arthur, Texas on June 20th, it weakened as it moved inland.• Storm brought heavy rain with some flooding.

• One 230kV, one 138kV and one 115kV lines were forced OOS but quickly we put back in service.

• Conservative Operations and Severe Weather Alerts were issued for the storm.

• A few instances of high temperatures that resulted in Hot Weather Alerts for the North and Central Regions (6/10 – 6/13)

• No fuel or capacity issues

2017 Summer Performance

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• 2017 peak load on July 20th, at 120,644 MW

• 2017 forecasted peak load was 125,002 MW.

• We have hit 96.5% of our forecasted seasonal peak.

• Experienced normal congestion.

• Summer wind peak on June 10th, at 13,112 MW

• MISO registered wind is 16,147 MW, so we hit 81% of the nameplate.

• All time wind peak is 13,731 MW which occurred on 12/07/16.

AGENDA 5

b. Reliability Coordinator Reports

Terry Oxendale

Date: August 1, 2017

To: MRO Operating Committee

From: Terry Oxendale, Planning Coordinator, SPP RTO

Subject: Reliability Coordinator Report- Summer 2017 Conditions to Date-SPP RTO

Action: Information and Discussion

The actual peak load realized so far and the 100% peak forecast as a comparison. o So far, our peak realized load was 50.7 GW o Projected 2017 RC area peak load is expected to be 51.6 GW o We’ve realized 98% of our forecasted summer peak load forecast

Any unusual or unanticipated congestion that occurred, including any critical forced outages.

o No significantly challenging, or unanticipated congestion concerns or observations thus far.

Max simultaneous wind output vs. nameplate and whether this was a new high output. o Max simultaneous wind output thus far is 16.4 GW back in April, but we nearly

matched that again in June. This is the second year in which an appreciable amount of summer wind continued past the normal spring season. This output is roughly 75% of nameplate rating for wind in our area.

Any weather related outages to the BES that required mitigation or congestion management.

o We’ve only had a single “summer” storm system that was extremely localized in the KCPL area, but transmission congestion was not a result. Other storm outages within our system have been easily mitigated with current resource dispatching. The lingering concern would be a perfect storm of high N-S flows through our system (internal flows as well as parallel loop flows from external impacts), DC tie maxed export to ERCOT, and target outages in the southeastern most portion of our system. We have good experiential knowledge of how to prepare and mitigate this situation, so this is only an awareness, but not necessarily a concern.

MRO OCSPP RC ReportTerry Oxandale

August 1, 2017

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BES performance Summer 2017

• No unusual summer performance issues as yet Early season storm systems resulted in some forced transmission

outages, but none that resulted in any unusually challenging congestion management events.

No capacity or fuel issues Normal, to relatively mild summer temperatures, with one period in

which the north experienced a short high-heat period, while southern portion was cooler. Combined with high wind injection and high south-north flows, resulted

in an unusual, but easily managed congestion management event in the Oklahoma/Missouri area of our footprint.

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BES performance Summer 2017• 2017 peak load set July 20th, at ~50.7 GW. 2017 Forecast peak load ~ 51.6 GW. So far, we’ve hit ~ 98% of our forecast seasonal peak. No reliability (transfer or capacity) issues on this day.

• Aside from the short high-temp period in the northern portion of our footprint, no unusual or unanticipated congestion this.

• For this summer, peak wind output was set June 12th, at ~13.1 GW This was 80% of nameplate ratings of ~16.4 GW. Was not a new wind peak (2017 peak set Feb 9th, at ~13.3 GW)

• No weather related outages that resulted in extraordinary congestion management activities. Have has instances of weather related forced outages, but none of

significant consequence.

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SaskPower RC Report for MRO OC MeetingAug 1, 2017

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Summary

• No unusual operating conditions to date.

• Load• Projected peak is 3505 MW.

• Our peak load to date is 3419 MW (July 27) which is highest summer peak ever.

• Had ~69 GWHr of consumption for that new peak load.

• Generation• No maintenance or other issues expected as all sources expected to be

available for the remainder of the summer.

• Fuel• Coal and Gas supply is normal for the summer and there are no issues.

• Hydro lake levels are below median levels for this time of year.

• Wind we have seen around 200 MW with our installed capacity of 221 MW (91%

of nameplate).

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Summary (continued)

• Transmission• No congestion or critical forced outages to date due to less storm

activity in the province.

• Weather• Very dry and very hot (parts of the province have not had rain

since June) while locations in the NorthWest have seen localized

flooding.

• Interchange• There have been no restrictions or forced or even planned outages

that have affected reliability.

I T T A K E S P O W E R T O G R O W

Are there any questions?

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Agenda 6a. Fall Reliability Conference- Finalize Topics


AGENDA 6

6a. Fall Reliability Conference- Finalize Topics All

Date: August 1, 2017 To: MRO Operating Committee From: MRO Staff Subject: Fall Reliability Conference –Finalize Topics Action: Information and Discussion

The Fall MRO Reliability Conference is scheduled for October 25, 2017. Changing resource mix is being considered for the focus of the conference. Some topics suggested for the conference include:

Synthetic or artificial inertia from wind turbine generation. Discuss the pros and cons. How does it work. How much of contribution it can provide during a frequency event and reliability of the device (failing to operate)?

New Technology Modeling data from IPP’s. How data is collected and validated? Interconnection

agreement requirements. Frequency response, stability and small signal studies conducted on large scale of

renewables Power inverters Energy storage. Storage potential of batteries for renewals and for providing primary

frequency response. Power system modeling risks. What are the risks associated with erroneous data? MOD-

025-2 has an implementation plan that spans for 5-year. What efforts are in place to ensure existing data is accurate until the generator testing is complete?

GMD/TPL-007-1 Standard. What are the latest activities and study work being conducted by NERC and ISO/RTOs? What are MRO entities doing, what is being done in other Regions.

Mackinac HVDC system. How was it built and contributed to the recent Upper Peninsula event?

Review August 21st total solar eclipse event, preventive measures and lessons learned Update on Essential Reliability Services – metrics and adequacy determination efforts State regulatory perspectives Utility scale Solar development and experiences in the Upper Midwest

Agenda 6a. Fall Reliability Conference- Finalize Topics


Transmission expansion plans (from anyone planning and currently building new facilities)

AGENDA Item 7.a

Standing Committee Reports Special Protection System Working Group Report

Dave Kempf, GRE, Chair Date: July 26, 2017 To: MRO Operating Committee From: Dave Kempf, GRE, Chair Subject: Special Protection System Working Group (SPSWG) Report Action: None - Information and Discussion Operating Committee (OC) Members: Following is a summary of the activities of the SPSWG for 2017 year to date: New RAS Reviews: The SPSWG met once via teleconference/webex on June 9, 2017 to discuss a new Remedial Action Scheme being proposed in the Buffalo, ND area. The SPSWG provided feedback to the RAS owner (OTP) and these suggestions/additions have been added to the report for clarity. The SPSWG will hold a follow-up call with OTP in early August to finalize the review of the new Buffalo scheme. The scheme is expected to be placed in service this fall of 2017. Status of 2017 Existing RAS Reviews:

Manitoba Hydro - Northern Cross Tripping The SPSWG review was completed on June 7, 2017. The SPSWG had requested several clarification be made to the report to provide clarity. These enhancements were added to the RAS documentation by MHEB staff. Rich Quest (MRO) sent out a notification to MHEB staff informing them that the review is complete and meets the MRO documentation and procedure requirements of RAS reviews.

Xcel Energy - NOB-GR SPS (Nobles Co - Lakefield Junction area)

The SPSWG review was completed on April 10, 2017. The SPSWG had provided several comments and clarification requests to the RAS owner (NSP) to assure that the report was coordinated with the other entities involved (GRE and ITC). All comments and clarifications have been included in the report documentation by NSP staff. Note: This RAS will be retired upon the commissioning of the 345 kV Lakefield Junction-Huntley line scheduled for late 2017. The effectiveness of this reinforcement has already been included in the 4/10/17 RAS study documentation. NSP will notify MRO of the effective date of the retirement.

Ottertail Power Co. – Big Stone RAS Retirement

On June 30, 2017, OTP provide documentation that supports the retirement of the Big Stone RAS. The RAS was originally installed to open all 230 kV breakers at the Big Stone substation during certain breaker failure contingencies at that substation to prevent potential thermal overloads and stability issues in the area. Several significant reinforcements have occurred in the area that have increased the outlet capabilities of the Big Stone generator. This retirement study will be reviewed at the same August conf call that is scheduled for the Buffalo RAS review.

Saskatchewan Power - Boundary Dam Phase Shifting (pending)

Xcel Energy - Mankato Energy Center (pending)

American Transmission Co. - Port Edwards (pending)

RAS Criteria per PRC-012-2: At the June 9, 2017 SPSWG conf call, the SPSWG reviewed the NERC BOT-approved PRC-012-2 standard that is awaiting FERC approval, regarding limited impact RASs. Requirement 4.1.5 basically states that a limited impact RAS does not require redundancy to cover a single point of failure. A limited impact RAS is defined as: A RAS designated as limited impact cannot, by inadvertent operation or failure to operate, cause or contribute to BES Cascading, uncontrolled separation, angular instability, voltage instability, voltage collapse, or unacceptably damped oscillations. Using this NERC-approved Standard assumes that the FERC will approve the Standard as is or with slight modifications. The Buffalo RAS is a limited impact RAS. If the FERC modifies the redundancy requirement for limited impact RASs, it will not affect the Buffalo SPS since it has redundancy, but we will need to consider any potential Commission revisions during future RAS reviews.

Agenda 10 a. NERC Operating Committee Reports


AGENDA 10

10 a. NERC Operating Committee Reports Dick Pursley

Date: June 6-7, 2017 – San Diego, CA To: Midwest Reliability Organization Operating Committee From: Dan Schoenecker, VP Operations; Proxy for Dick Pursley, MRO Representative Subject: NERC Operating Committee (NERC OC) Report The NERC Operating Committee (NERC OC) met on June 6-7 in San Diego, CA. The agenda for this meeting includes the following items for discussion and/or action and is posted here: The next meeting of the NERC OC will be held on September 12-13 in Quebec City, QC. The following topics were covered in a joint session of the NERC Planning, Operating and Critical Infrastructure Protection Committees

BPS Reliability Perspectives Inverter Disconnects Task Force Report Solar Eclipse, and 2017 State of Reliability Report.

More detail on these presentations will be provided in the NERC Planning Committee (PC) Report. Inverter Based Resource Performance Task Force A presentation was made to both the NERC OC and PC on the proposed creation of an inverter based resource performance task force, which would report to both the OC and PC. More detail on these presentations will be provided in the NERC PC Report. NERC will be preparing an Alert to ensure broad distribution of lessons learned about inverter resources as a result of recent events. Essential Reliability Services Working Group (ERSWG) 2017 Work Plans Work plans include development of sufficiency assessment methods for Essential Reliability Services (ERS), refinement of processes for analysis of trends of ERS, development of tools and processes for predictive analysis of ERS measures and trends, and identification of groups within the OC and PC to ensure ongoing trending and analysis of ERS. Resource Subcommittee (RS) Reliability Guidelines The RS is reviewing a number of reliability guidelines, including Area Control Error Diversity Interchange Process, Operating Reserve Management, and Inadvertent Interchange. The OC approved these guidelines to be posted for a 45-day comment period.

The Event Analysis Subcommittee updated the Generating Unit Winter Weather Readiness

Agenda 10 a. NERC Operating Committee Reports


Guideline and the OC approved its posting for a 45-day comment period. The Operating Reliability Subcommittee developed a new Guideline titled “Gas and Electrical Operational Coordination Considerations.” It will be posted for OC review for two weeks and then for 45 days for industry comments.

Additional Items

The OC heard reports from both the North American Transmission Forum and the North American Generator Forum as the groups continue to look for opportunities to collaborate.

The OC elected new officers for the next two years, Lloyd Linke (WAPA) as chair and David Zwergel (MISO) as vice chair.

NERC Committee Report

Terry Bilke, MRO Rep on NERC Resources Subcommittee

Date: July 28, 2017

To: Midwest Reliability Organization Operating Committee

From: Terry Bilke, MISO

Subject: NERC Resources Subcommittee Report

Action: No

The North American Electric Reliability Corporation (NERC) Resources Subcommittee (RS)

met July 25-27 at BC Hydro offices in Vancouver, BC. The complete meeting package is posted

on the RS website. The following are highlights:

The Frequency Working Group (FWG) selected events from the previous quarter to be used

for the BAL-003-1 (Frequency Response). The events will be posted on the Balancing

Authority Submittal Site (BASS). Information on the site can be found here.

The FWG approved the next revision of its events selection guide.

The FWG discussed errors induced in the calculation of Interconnection Frequency Response

(M-4 in State of Reliability Report) by sometimes capturing gross output and other times net.

The group is looking at creating a job-aid to collect better data.

The RS approved a proposal by the Reserves Working Group (RWG) on data-collection on

DCS events. With the new BAL-002 standard, only non-compliant events are reported.

Besides the number of events and % of events compliant, another key piece of information

needed for the State of Reliability Report is the number of events > Most Severe Single

Contingency (MSSC). The recommendation is to request BAs voluntarily submit their CR

Form 1 (the forms used for calculating DCS compliance) each quarter. Target date to begin

concurrent with the effective date of the new standard (i.e. 1/1/2018).

The Inadvertent Interchange Working Group (IIWG) reviewed the trend in Inadvertent

Interchange balance size. NERC has an obligation to report to FERC in 2018 the impact of

BAL-001-2 on inadvertent balances. The analysis not only looked at current balance, but if

the BA has been trending in the right direction over time. The IIWG will reach out to the

BAs trending in the wrong direction as well as those with large balances that are not drawing

them down. Balances are generally declining in the East.

NERC RS website was updated and reorganized generally around the different balancing

standards.

The RS is updating its Primary Frequency Response Guideline to address BES-connected

inverter based resources.

The RS approved updates to the Frequency Event Selection Process Document. Terry

suggested that the RS use the framework in the document to automate event selection for

http://www.nerc.com/comm/OC/Pages/Resources-Subcommittee-(RS)-2013.aspx

http://www.nerc.com/comm/OC/Related%20Files%20DL/BASS_User_Manual_v1.0_October_2015.pdf

http://www.nerc.com/comm/OC/Pages/Resources-Subcommittee.aspx

BAL-003 and M-4. There is presently too much human intervention in the event selection

process, which can lead to sampling bias.

Staff updates

o Steve Crutchfield (OC liaison) noted Dave Devereaux (IESO) appointed as chair of

the NERC ORS. Lloyd Linke and David Zwergel will be chair and vice chair of

NERC OC. OC working on several reliability guidelines and lessons learned.

o Darrel Richardson discussed the SAR for BAL-002 and the two SARs for BAL-003.

The BAL-003 SAR submitted by NWPP suggesting a generator-level standard was

referred to the NERC OC for opinion. NERC decided that the other BAL-002 and

BAL-003 will be reposted for nominations. Work to begin no earlier than late

September. Those that submitted in the initial period do not need to resubmit

nominations.

o Nicole Segal (ERSWG). ERSWG will be working on forward-looking measures.

Reviewed inertia data captured under ERSWG. No significant observations as yet except

that there appears to be more than sufficient inertia in the East. Goal is to present annual data

and trends. One key piece needed in this effort is the size of the event in each Interconnection

against which inertia needs to protect.

Reviewed the M-4 (frequency response) metrics and submeasures. There is additional

refinement needed on some of the submetrics. In particular, the “C prime” metric gives the

wrong impression for the East. Even though frequency is arrested in the East and stabilized

at the “B value”, there is always going to be variability of frequency, so half the time

following an event, there will be frequency that is seen below B.

Terry Bilke gave an update on the University of Tennessee-Knoxville’s (UTK) Rate of

Change of Frequency (ROCOF) tool in FNet. Primary benefits of this notification are using

the ROCOF for situational awareness (an unusual observation has occurred), trending over

time as a proxy of inertia, and possible input to improve the FNet loss estimate (another

awareness benefit). Beyond the notification of ROCOF, the reports also note if the frequency

excursion is a MOD-027 opportunity. Terry recommended NERC capture Interconnection

load and ROCOF(s) along with events in their M-4 dataset.

Terry presented frequency performance metrics for the Interconnections from 2015 to

present. The uptick in TECs in the East has subsided. Part of this report reviewed “noisy”

frequency days (RMS1 outliers). As a trial, a representative from each of the

Interconnections reviewed 3 recent outlier days. Several lessons were learned. Terry will

work with a team to develop a process to work with the NERC ORS to review RMS1 outliers

as learning opportunities.

ERCOT, HQ, and WECC still plan to perform some type of Time Error Correction upon the

retirement of BAL-004. Terry Bilke is working with the RS chair and the RS members from

the East to reach out to Balancing Authorities on a BAL-004 transition plan for the East. A

webex was held in April with Easter Interconnection BAs to discuss current issues to include

interest in continuing some form of TEC as well as a supplementing Inadvertent Interchange

payback approach intended to reduce the number of TECs. All BAs that responded to the

survey (representing 71% of the East load) wanted to continue TEC in some form or another.

There will be a follow-up webex to present a recommended approach based on survey

results.

Reviewed an RS process document regarding the housekeeping and compliance support tasks

for modification of BA footprints as well as BA startup and retirement. The RS document

was intended to ensure proper CPS limits and RS tools (e.g. ACE monitoring, Inadvertent

Interchange reporting) worked for changes in BAs. The allocation of frequency response is a

new issue that needs to be addressed, to include situations such as the point which pseudo-tie

changes are factored into the process. Bill Kunkel will be on the team to update the

document to address these new issues.

Generator Survey. The NERC OC agreed to allow the RS conduct a series of generator

surveys this year to capture governor response information for specific events. The first

survey in the East will likely be later this year.

Staff gave an update on the Inverter Task Force. This effort was initiated due to loss of large

blocks of solar resources in the West due to transmission faults. Manufacturers are willing to

make necessary changes, but it is important to get the requirements properly stated with

regard to ride-through, normal operating ranges, reconnection logic, etc.

The next RS meeting will be Oct 31–Nov 2, 2017 at Tucson Electric’s headquarters in

Tucson, AZ.

Quiet period during holidays of 2015, process change beginning about week 66 (coincident with

bias setting change), uptick in frequency noise due to prevailing fast time beginning February.

TECs settled out following a webex with Eastern Interconnection BAs.

2015 to Present Daily RMS1 Grouped by Week

131118105927966534027141

0.015

0.014

0.013

0.012

0.011

Sample

Sam

ple

Mean __

X=0.013873

UCL=0.015552

LCL=0.012194

131118105927966534027141

0.0048

0.0036

0.0024

0.0012

0.0000

Sample

Sam

ple

Rang

e

_R=0.000893

UCL=0.002917

LCL=0

11

111

1

11

1111

11

1

1

1111

1

1

Xbar-R Chart of EI RMS1

Tests are performed with unequal sample sizes.

EI BA webex

EI Minimum Bias Reduced

Agenda 10 d. NERC System Protection and Control Subcommittee Report


AGENDA 10

10 d. NERC System Protection and Control Subcommittee Report Rich Quest

Date: July 26-27, 2017 To: Midwest Reliability Organization Operating Committee From: Rich Quest, MRO Subject: NERC System Protection and Control Subcommittee Report

The NERC SPCS met in Toronto on July 26 & 27. A second Canadian representative, a representative from SPP, and an industry expert in generation were added to the roster. The roster has now been culled of extraneous members, has representatives from each region, and added industry representation for currently assigned work. Industry experts are given three year terms, at the end of which continued participation is evaluated by the regional subcommittee members. It was emphasized that regions should put forth representatives based on Protection System expertise. The existing guidance document for PRC-023 was modified to address issues for which it was rejected by the ERO. A guidance document for PRC-024 is in an advanced stage. Technical methods for determining voltage settings have been formalized. During the development of guidance, flaws in the existing standard were revealed. These are associated with the determination of voltage at the “Point of Interconnection”. The guidance proposes use of nominal voltages, while the standard requires the use of voltages determined by the latest location specific Transmission Planner study. This requirement presents a moving target to the Generator Owner with zero response time allowed for changing settings. It also imposes no requirements on the Transmission Planner. The guidance document proposes the use of “Nominal Voltage”, which effectively alters the effect of the standard. Neither approach to determining the POI has any effect on the setting methods proposed, and in either case some revision to the standard would be required. A discussion of proposed changes to PRC-025 was given by a drafting team member. Those changes are currently posted for comment. A web meeting will be held in late August to approve any final changes to the two guidance documents above for presentation to the Planning Committee.

Agenda 10 e. NERC Personnel Subcommittee Report


AGENDA 10

10 e. NERC Personnel Subcommittee Report Neil Lindgren

Date: July 25, 2017 To: Midwest Reliability Organization Operating Committee From: Neil Lindgren, Otter Tail Power Company Subject: NERC Personnel Subcommittee (NERC OC) Report Summary of Activity by Personnel Subcommittee (PS)

Last Meeting:

June 20 – 22, 2017 at the NERC office in Atlanta

Future Meetings

October 3-5, 2017 at the NERC office in Atlanta

December 5-7, 2017 at the SPP office in Little Rock, AR

1. Chair Update

a. Operating Committee (OC) Work Plan

The OC has completed the component of their work plan regarding the PS, items were discussed, with the manual update and the SOCCED being the largest of the deliverables for 2017-2018.

b. PS 2017 Work Plan Status

Description Status Due

Begin work on CE Program Manual, v. 4.4 Completed Q2 2018

Support testing and implementation of the updated SOCCED provider interface (dependent upon NERC Staff related work)

In Progress Q2 2017

Implement a multi‐reviewer process for questionable course submissions.

In progress Q3 2017

Work with EAS and ORS to develop a draft situation awareness guideline for System Operators

Completed Q2 2017

Industry Outreach via workshops and webinars On going

Recruiting new members for the CERP On going



External Requests to Group:

Develop examples of Human Performance ILAs that meet the requirements of Appendix A.

In progress Q2 2017

Members of the PS, EAS, and ORS have developed a Situational Awareness guideline. The guideline is at a high level. The final version was presented to the OC in the March 2017 meeting and approved.

c. PS/PCGC Officer Conference Call

Call focused mainly on the SOCCED roll-out issues, and the course submission of non-Appendix “A” courses. Educational efforts will be undertaken in 2017 to reduce the number of submissions not meeting the requirements of the program.

2. Continuing Education Program Update

No Metrics to report to date as the SOCCED Transition this is a manual process. A report will be pulled next month and distributed.

Workshops

A tentative 2017 schedule has been determined:

1. July 11-12 Atlanta 2. August 8 CAISO 3. Aug (?) FRCC – PS member led/ Oct? 4. Presentation to the NATF Aug 31 KC, MO

There is a possibility of one more workshop; however, the location and date will not be confirmed until the end of Q3.

Once availability of venues is confirmed, the schedule and registration links for the 2017 Provider Workshops will be posted to the NERC SOCCCED Help Center Announcements.

a. CE Manual 4.4 was approved as an interim solution to resolve several open items while work on a broader revision is in progress. Version 4.4 is effective July 1, 2017

b. NERC.com postings

The following highlights from Operating Committee meeting were reviewed:

PER-003 and PER-004 comment period

Nomination form and request for members



Industry survey

3. Personnel Subcommittee Governance

The Chair lead a review of the Personnel Subcommittee Scope Document. There were minor editorial changes proposed.

Updated PS Scope document to reflect the No Term Limit of Officers of the Sub-Committee and address the term-limits of the PS Members.

OC Officers are Lloyd Linke, Chair and David Zwergel, Vice-Chair

4. SOCCED Updated

Communications when dates are finalized, but this is a moving target. The PS and PCGC are in constant communication trying to ensure the product once released will meet the needs of the industry.

5. Closed Session

The group discussed membership applications and other sensitive items in the closed session.

6. Task Force Updates

The task forces presented updates on their assignments.

7. Continuing Education Program

The PS conducted a series of “workshop” session centered on the topical areas of the manual. These items were addressed by rotating small groups of the PS Members present. These ideas and criteria to be addressed will be collected and presented to the industry for their input to consider revisions in theV5.0 program criteria.

8. Voting Items a. A vote was carried to approve the Agenda.

b. A vote was carried to approve the minutes from the February 2017 meeting.

c. A vote was carried to adjourn Day One.

d. A vote was carried to adjourn Day Two.

9. Summary of Task Forces and Working Groups

a. New Provider Evaluation: Leslie Sink, Rocky Williamson

b. Membership: Rocky Williamson, Max Colney, and Kelly Blackmer



c. SOCCED Liaison: Christine Econome, Jim Donahue, Neil Lindgren, Rocky Williamson

d. CERP Oversight: Jim Donahue, John Rymer, Leslie Sink, and Neil Lindgren.

e. Course Validation: PS Officers and PCGC Representative(s).

f. Audit Oversight: John Rymer, Art Diaz-Gonzalez, Rocky Williamson

g. Workshop Planning: Diane Laferriere, Chris Econome, Kelly Blackmer

h. Task Force A: Erik Johnson, Leslie Sink, Neil Lindgren, Robert Kapteyn, Maureen Curley, Diane Laferriere, Jim Donahue, Lauri Jones

i. Task Force B: Kelly Blackmer, Art Diaz-Gonzalez, Christine, John Rymer, Max Colney, Rocky Williamson, Lauri Jones

10. Closing Comments and Adjourn – Chair 11:54 AM

Note of Interest

Productive Meeting, we worked in small groups to produce content to the previously constructed outline for V5.0 of the CE Manual. This is by no means completed, but gives a great spring-board to begin the conversations internal, and then bring both the suggested content and meaning/thoughts behind them to the industry through a series of out-reach webinars to gain both education, engagement, and feedback from the industry as to the forthcoming changes to the program to better serve the industry. The October Meeting and the CC Meetings between will be primarily focused on two issues the remainder of the year, first with the SOCCED Deployment, and the CE Program V 5.0 creation and roll-out.

Meeting locations have been severely restricted due to travel budget issues for both NERC and the members, we will no longer “match” the OC’s Meeting Location by default, as the majority of our future meetings will be in Atlanta at the NERC Offices for the foreseeable future.

Agenda NERC Performance Analysis Subcommittee (PAS) Report Report


AGENDA 10i.

NERC Performance Analysis Subcommittee (PAS) Report Report Jaimin Patel, MRO Representative

Date: July 14, 2017 To: MRO Operating Committee From: Jaimin Patel, MRO Representative on NERC PAS Subject: NERC Performance Analysis Subcommittee (PAS) Report Action: None - Information and Discussion Operating Committee Members: Since the last OC meeting, the PAS met on June 20-21, 2017 at Montreal, QC for a face to face meeting. The next meetings of the PAS will be held on August 16-17, 2017 in Atlanta, GA. During its recent meeting, the PAS focused on reviewing the existing State of Reliability (SOR) report elements and performance metrics. Following is a brief summary of the discussion:

1. Compliance Process (CP) 1 and 2 (Chapter 5): It was proposed to remove this chapter from SOR report. However, PAS members believe this chapter should remain in SOR report adding more contexts to associate standard compliance and its impact on reliability.

2. BES Security Metrics (Chapter 7): There was significant discussion and effort by NERC in the development of this chapter. Seeking additional direction from NERC on the development of security metrics for next year SOR.

3. Event Analysis (Chapter 6): Request to submit suggestions for additional Event Analysis metrics using existing data will be made to EAS and PAS. MRO suggested,

Considering new graphs to show more sensitivity with respect to non EMS Displaying the attributes assigned to events during cause coding Reporting Cat 1h EMS events through a tool similar to MIDAS (Misoperations

Information Data Analysis System)

4. SRI (Chapter 3): Momentary and sustained outages are included in current SRI calculation. It was discussed in the meeting to recreate SRI calculation a) excluding momentary outages and b) including DC equipment outages. MRO suggested calculating SRI without momentary outages should be given top priority.

Agenda NERC Performance Analysis Subcommittee (PAS) Report Report


5. TADS (Chapter 3): TADS will be consulted for suggestion to include transmission outage duration into the SRI calculation.

6. TADS/GADS/DADS (Chapter 3) – Individual group will be consulted to determine potential data analysis that would be useful for the SOR report.

7. Other Items: Need for developing new metrics to address emerging issues was discussed. As requested by PC, a survey/questionnaire will be developed to acquire input from PC member on potential improvement to the SOR report.

Agenda 10 i. Updated terms for MRO Representatives on NERC Committees


AGENDA 10

10 i. Updated terms for MRO Representatives on NERC Committees Dan Schoenecker

Date: August 1, 2017 To: MRO Operating Committee From: Dan Schoenecker Subject: Updated terms for MRO Representatives on NERC Committees

Name Title Company Term EndDemand Response

Availability Data System Working

Group (DADSWG)

Sam Zewdie Staff Engineer MRO Sam ZewdiePlanning

Committee

Essential Reliability Services Working Group (ERSWG)

Mick KirwanTransmission Operations & Switching Mgr.

Western Area Power Administration

December 31, 2019Planning

Committee

Dick Pursley Great River Energy

December 31, 2018Dan Schoenecker Bill Kunkel

Dan Schoenecker MRO Bill Kunkel

Generating Availability Data

System Task Force (GADSWG)

Katie Ege Fuel Supply Specialist

Great River Energy

December 31, 2017Bill Kunkel, Rich Quest

Planning Committee

Operating Committee (OC)

Dick Pursley Great River Energy

December 31, 2018Dan

SchoeneckerOperating Committee

Operations Reliability

Subcommittee (ORS)Steve Sanders

Transmission System Planning

Western Area Power Administration

December 31, 2017 OpenOperating Committee

Performance Analysis

Subcommittee (PAS)Jamin Patel

Sask Power

December 31, 2019John Seidel, Bill

KunkelOperating Committee

Personnel Subcommittee (PS)

Neil LindgrenOperations Coordinator

Otter Tail Power Company

December 31, 2018 John Seidel

Compliance Committee and

Operating Committee

Planning Committee (PC)

Dale BurmesterManager, Economic Planning

American Transmission Company LLC

December 31, 2017John Seidel,

Salva Andiappan

Planning Committee

MRO Representatives on NERC Committees and Subgroupsas of June 2017

MRO RepresentativeCommittee

Staff Contact

Reports to (MRO

Committee)

Operating Committee

Event Analysis Subcommittee (EAS)

MRO Representatives on NERC Committees and Subgroupsas of June 2017

MRO RepresentativeCommittee

Staff Contact

Reports to (MRO

Committee)

Reliability Assessment

Subcommittee (RAS)Salva Andiappan

Manager, Reliability Assessment Perf Analysis

MROSalva

Andiappan, Bill Kunkel

Operating & Planning

Committees

Terry Bilke Midwest ISO December 31, 2018

Bill Kunkel MRO

Kerry Marinan ATC, LLC December 31, 2019

Salva Andiappan MRO

Mark Gutzmann

Director, System Protection & Comm. Engineering

Xcel Energy December 31, 2019

Rich Quest MRO

Kurt Weisman, ATC ManagerAmerican Transmission Company LLC

December 31, 2017

Rich Quest MRO

Transmission Availability Data System Working

Group (TADSWG)

Operating & Planning

CommitteesRich Quest

Operating Committee

Bill KunkelResource

Subcommittee (RS)System Analysis and

Modeling Subcommittee

Salva Andiappan, Sam Zewdie

Planning Committee

System Protection and Control

Subcommittee (SPCS)

Rich Quest, John Seidel

Operating Committee

Agenda Other Business


AGENDA 11a.

Other Business MRO Staff Date: August 1, 2017 To: MRO Operating Committee From: MRO Staff Subject: Operating Committee Charter Annual Review Action: Discussion

380 St. Peter Street, Ste. 800, Saint Paul, MN 55102 MidwestReliability.org P.651.855.1760 F.651.855.1712

CLARI TY ■ ASSURAN CE ■ RESULTS

MRO OPERATING COMMITTEE CHARTER

November 3, 2016

I. Purpose

The MRO Operating Committee (OC) provides a forum for discussion and aggregation of bulk power system operational issues and best practices. The OC provides MRO stakeholders and staff with collective and diverse expert opinions on interconnected system operations to help the industry arrive at informed decisions to improve reliability. Areas that the OC and its sub-groups focus on include: system protection, special reliability assessments, event analysis reviews, Bulk Power System mis-operations, frequency response trending, along with NERC and regulatory data requests. The OC reviews and provides comments on proposed Regional and NERC reliability procedures and guidelines.

II. Membership Pursuant to Policy and Procedure 3 (Organizational Groups), 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. As such, the MRO OC is comprised of two members from each sector, providing a balanced representation of the sectors.

III. Key Objectives

• Review and provide comments on reliability assessments prepared by the MISO, SPP-RTO, and MRO Canadian reporting areas from an operational perspective.

• Review any NERC and other reliability assessments from an operational perspective.

• Review event analysis detailed reports and review and approve larger scale detailed event reports (Category 3 and higher) to assure the appropriate analysis is performed and that any lessons learned are identified and shared with the industry.

• Provide input and guidance on system protection and control matters including Standards development, mis-operation reviews, and reviews of special protection schemes.

• Participate in and represent the MRO region in all NERC groups, as required, that report to the NERC Operating Committee.

• Provide regular reports to the MRO Board on matters related to the activities of the OC and its working groups.

380 St. Peter Street, Ste. 800, Saint Paul, MN 55102 MidwestReliability.org P.651.855.1760 F.651.855.1712

CLARI TY ■ ASSURAN CE ■ RESULTS

Provide technical advice and subject matter expert support to the related NERC program areas, and serve as a forum to integrate the outputs of each NERC program area to MRO stakeholders.

• Review the Reliability Coordinator summer and winter preparedness plans as necessary for the Reliability Coordinators that are registered within the MRO region.

• Align with and support MRO strategic objectives.

IV. Meetings

The MRO OC will meet quarterly or as necessary, in person or via conference call and/or web meeting. Meetings of the MRO OC are open to public attendance; however, the meeting may be called into executive session 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 OC members are reimbursable by MRO according to MRO Policy and Procedure 2, Expense Reimbursement.

VI. Reporting Requirements

The chair of the MRO OC, or a designate, will provide a written and/or oral report describing the activities and actions of the committee quarterly to the MRO Board of Directors. Annually each November, the committee shall perform a review of this charter and the committee’s overall purpose and key objectives to ensure that committee is efficient and effective in its operations and according to its purpose. The chair shall provide a summary report, including a statement of its conclusions, to the board at the annual meeting.

Agenda Other Business


AGENDA 11b.

Other Business MRO Staff Date: August 1, 2017 To: MRO Operating Committee From: MRO Staff Subject: Operating Committee Terms Review Action: Discussion

8-1-2017 oc agenda packet - midwest reliability organization 1, 2017 oc... · august 1, 2017 8:00...

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