DRAFT MINUTES Regional State Committee Meeting

DRAFT MINUTES

Regional State Committee Meeting April 26, 2021 -Net Conference

12:30 p.m. CT ADMINISTRATIVE ITEMS

The following members participated: Jeff Byrd, New Mexico Public Regulation Commission (NMPRC)

Randy Christmann, North Dakota Public Service Commission (NDPSC) Kristie Fiegen, South Dakota Public Utilities Commission (SDPUC) Mike Francis, Louisiana Public Service Commission (LPSC) Andrew French, Kansas Corporation Commission (KCC) Dennis Grennan, Nebraska Power Review Board (NPRB) Geri Huser, Iowa Utilities Board (IUB) Dana Murphy, Oklahoma Corporation Commission (OCC) Ted Thomas, Arkansas Public Service Commission (APSC) Scott Rupp, Missouri Public Service Commission (MoPSC)

President Kristie Fiegen called the Regional State Committee (RSC) Business Meeting to order at 12:30 p.m. by way of participant list via Webex and a quorum was declared. There were 158 participants (Attendance & Proxies). The first item of business was the adoption of minutes from 01/25/2021 and 02/12/2021 as presented. (RSC Minutes 01/25/2021 & 02/12/2021). Commissioner Dana Murphy moved to approve the minutes; Commissioner Ted Thomas seconded. The motion was approved unanimously. Ms. Kandi Hughes (SPP staff) reviewed the ongoing action items and, later, the new action items with the RSC. (RSC Action Items) UPDATE SPP Report Ms. Barbara Sugg (SPP President and CEO) provided the SPP Report. She began her report by looking back at her first year as President as of April 1, 2021, and how it was an unprecedented year with the Polar Vortex, pandemic, loss of a board member, and the social unrest of our country. A comprehensive review of the winter event is underway with five main areas being reviewed: Communications, Financial, Operational, Market Monitoring, and the Regional State Committee. Ms. Sugg discussed the ongoing Strategic Planning efforts with a goal for approval in August 2021. Ms. Sugg discussed the ongoing process between the SPP and MISO coordination and joint study; wind records in the first quarter; the RSC 15-year History; and the pandemic. RSC Quarterly Financial Report Mr. Paul Suskie (SPP Staff) provided the RSC financial report for the first quarter of 2021 (RSC 2021 Q1 Financials). Due to the pandemic, there were zero dollars of expenses in the first quarter, so the RSC continues to be under budget due to travel expenses.

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Regional State Committee April 26, 2021

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BUSINESS ITEMS

Nominating Committee Report Commissioner Dana Murphy discussed the Nominating Committee report and the nomination for the RSC Secretary and Treasurer for the remaining calendar year.

NPR Board Member Dennis Grennan moved to approve the Nominating Committee’s nomination of Commissioner Geri Huser as the RSC Secretary/Treasurer; Commissioner Randy Christmann seconded. The motion was approved unanimously.

2021 and Beyond Operational Objectives Commissioner Dana Murphy discussed the 2021 and Beyond Operational Objectives. (Attachment – 2021 SPP RSC Operating Objectives)

Commissioner Dana Murphy moved to approve 2021 and Beyond Operational Objectives; Commissioner Andrew French seconded. The motion was approved unanimously.

SPP RSC/OMS SEAMS LIAISON COMMITTEE REPORT

Commissioner Dana Murphy presented the RSC/OMS Seams Liaison Committee (SLC) report. She mentioned the SLC meetings will move to quarterly meetings, the next meeting will be July. As part of the RSC/OMS SLC recommendations, RSC/OMS and SPP/MISO stakeholder volunteers were requested to participate ina working group to look at the rate pancaking issue. The working group would be comprised of RSC/OMS commissioners and an equal number of stakeholders from SPP and MISO with the first meeting to occur in May. Commissioners Thomas and Murphy volunteered for the RSC, but all RSC commissioners are able to access the meetings. Commissioner Murphy advised that an email to the RSC would follow from her to include the names of volunteers and seek input as needed from the RSC. In the event, additional SPP stakeholders are needed, President Fiegen would seek and select additional stakeholders.

COST ALLOCATION WORKING GROUP REPORT

Mr. Greg Rislov provided the Cost Allocation Working Group report (CAWG Report – Attachment). Mr. Rislov discussed the Holistic Integrated Tariff Team (HITT) initiatives C1 Decouple Schedule 9 & 11 Transmission Pricing Zones; C2 Establish Byway Facility Cost Allocation Review process; C4 Study Cost Allocation Transmission Storage Devices. David Schmitt, the CAWG staff member who was heading the CAWG processing of C4 is leaving his position at the Iowa Utilities Board. CAWG staff member Lane Sisung from Louisiana has agreed to replace David. During the April CAWG meeting CAWG approved an action item to suspend HITT initiative C1 from the monthly CAWG agenda pending further action by SPP staff on information requested by the CAWG. This item was placed before the RSC and there were no objections to the suspension of the C1 initiative. Greg also discussed other presentations from the 2021 Winter Weather event ad hoc committee, Strategic and Creative Re-engineering of Integrated Planning Team (SCRIPT); Order 2222 Distributed Energy Resources, Seams Liaison Committee Priorities and the Joint Studies timeline and update.

Mr. John Krajewski provided the CAWG Cold Weather Event Ad Hoc Task Force update. Mr. Krajewski provided a brief overview of activities since the last RSC meeting and planned activities to complete current work. Commissioner Fiegen encouraged RSC members to contact CAWG Ad Hoc Chairman Krajewski if they would like to participate in the next ad hoc meeting on May 3, 2021. The Task Force has reviewed data and had presentations from SPP staff and the Market Monitoring Unit. The Task Force has centered on issues related to resource adequacy, which are an area where the RSC has primary oversight responsibility. The Task Force is working toward completion of its report for inclusion in the Comprehensive Review Steering Committee final report to the Board of Directors.

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Regional State Committee April 26, 2021

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OTHER RSC MATTERS Commissioner Dana Murphy requested the RSC recognize Commissioner DeAnn Walker. Commissioner Fiegen acknowledged this request and noted that the RSC is planning to recognize two past members at the July RSC Business meeting. Mr. Ben Bright will contact the RSC Ad-hoc Cold Weather Communications group for a meeting within the next two weeks. With no further business, the meeting adjourned at 1:45p.m. Respectfully Submitted, Paul Suskie

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Amber Greb [email protected] Schieffer [email protected] McKinnie [email protected] Tamimi [email protected] Myers [email protected] Lachowsky [email protected] French [email protected] Hyatt [email protected] Lucas [email protected] Sugg [email protected] Warren GridLiance [email protected] Bright [email protected] Grant [email protected] LaFave [email protected] Leopold [email protected] Johnson [email protected] Rounds [email protected] Drumm [email protected] Runion [email protected] Bastone [email protected] Rew [email protected] Daniels (WFEC) [email protected] Cathey [email protected] Huslig [email protected] Jones [email protected] Aarnes [email protected] Elliott [email protected] Ireland [email protected] carr [email protected] Murphy [email protected] Shelton [email protected] Hall [email protected] Solomon [email protected] Ortiz [email protected] Prince [email protected] Hudson [email protected] Mindham [email protected] Kelley [email protected] Osburn [email protected] Currie [email protected] Martin [email protected] Buffington [email protected] grennan [email protected] Florom [email protected] Reed [email protected] Wingfield [email protected] Frerking-SPP [email protected]

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Elizabeth Moore [email protected] Nielsen [email protected] Rahimi [email protected] Freier [email protected] huser [email protected] Edwards [email protected] Rislov [email protected] Basaran (PUCT) [email protected] Starnes [email protected]. Maddock [email protected] Madden [email protected] Fortik [email protected] Chaplin [email protected] Mazigian [email protected] Caspary [email protected] Byrd [email protected] Severson [email protected] Jacoby (AEP) [email protected] Krajecki [email protected] Bladow [email protected] O'Dell [email protected] Krajewski [email protected] Stephens [email protected] WILLIAMS [email protected] Sunneberg [email protected] THURBER [email protected] Lang [email protected] Norton [email protected] martin [email protected] Phillips [email protected] Brix [email protected] Hinton [email protected] Hughes [email protected] Fornstrom [email protected] Micek [email protected] Southworth [email protected] McCarty [email protected] Farris [email protected] Collins (MMU) [email protected] Carney [email protected] Bates [email protected] Hall [email protected] Fiegen [email protected] Luke-Fry [email protected] McNabb [email protected] Sisung [email protected] Nickell [email protected]

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Larry Altenbaumer [email protected] Elliott [email protected] Tao [email protected] Linke [email protected] Ditsch [email protected] Haner [email protected] Berry [email protected] Choate [email protected] Crisson [email protected] Caves (WFEC) [email protected] Moss [email protected] Sever [email protected] Desselle [email protected] WISE [email protected] Spencer [email protected] Francis [email protected] Mathis [email protected] Ross [email protected] Kraft [email protected] Henderson [email protected] Morris(EDE) [email protected] Parker [email protected] Wagner [email protected] Williams [email protected] ghoshal [email protected] Hayes [email protected] Woods [email protected] Clarey [email protected] Suskie [email protected] Fischer [email protected] Christmann [email protected] Bergmeier [email protected] Ross (AEPSC) [email protected] Janssen [email protected] Safuto [email protected] Pick [email protected] Tallman OG&E [email protected] Massman [email protected] Carey [email protected] Ellis [email protected] Loudenslager [email protected] Bents [email protected] Rupp [email protected] Albrecht [email protected] Geil [email protected] Maxey [email protected] Gaw [email protected]

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Steve Johnson [email protected] Lowry [email protected] Certoma [email protected] Smith [email protected] Thomas [email protected] pemberton [email protected] Kentner [email protected] Kent [email protected] Hestermann [email protected] Dunn [email protected] Christensen [email protected] Kleckner [email protected] Turner [email protected] Bujimalla [email protected] Schock [email protected] Cecil [email protected] Pekins [email protected]

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APPOPPDMissouri PSCSepcITC HoldingsArkansas Electric CoopKansas Corporation CommissionIowa Utilities BoardSPPSPPGridLianceSPPSPSNorthWestern EnergyITC Great PlainsAEPAESL ConsultingITCSouthwest Power PoolSPPSouthwest Power Pool, Inc.WFECSouthwest Power PoolGrcCity UtilitiesSunflower Electric Power CorporationIowa Utilities BoardAR PSCwfecOCCLPSCacpaSPPSPP DirectorKansas Municipal Energy AgencySPS/Xcel EnergyEDP RenewablesSPPOMPASouthwest Power PoolSPPEvergy CompaniesNebraska Power Review BoardLincoln Electric SystemMWRC SPP

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SPPSouthwestern power administrationOATISPPIowa Utilities BoardSPPSDPUCPUCTMJMEUCBasin Electric Power CooperativeGDS Associates, Inc.Lincoln Electric SystemOCCBasin Electric Power CooperativeGrid Strategies LLCNMPRCBasin Electric Power CooperativeAEP/PSOCustomized Energy Solutions, LTDTri-State G&TSPPNPRBCity Utilities of SpringfieldMPUANebraska Public Power DistrictSouth Dakota PUCOmaha Public Power DistrictSouthwest Power PoolSPPSouthwest Power PoolSPPSPPSPPSouthwest Power PoolS&P Global PlattsSustainable FERC ProjectSPPSPPSouthwest Power PoolSPPSPP (MMU)Southwest Power PoolSD PUCKansas Corporation CommissionVesta Strategic Solutions, LLCLPSCSouthwest Power Pool

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Southwest Power PoolSouthwest Power PoolSouthwest Power PoolWestern Area Power AdministrationOPPDOmaha Public Power DistrictGolden Spread Electric Cooperative, Inc.SPPSPPWestern Farmers Electric CooperativeCUSSouthwest Power PoolSouthwest Power PoolGolden Spread Electric CooperativeNPPDLPSCContinental ResourcesSPPBasin Electric Power CooperativeGolden Spread Electric Cooperative, Inc.Liberty Utilities / Empire DistrictSPPSPPGridLianceinvenergyLS PowerITC Great Plains, LLCFERCSPPBEPCND PSCSunflower Electric Power CorporationAEP (AEPSC)Dogwood EnergyCustomized Energy SolutionsNPPDOG&EMOPSCSPPSPPSouthwest Power PoolOffice of Consumer Advocate of IowaMO PSCKCCKEPCoSouthwest Power PoolAPA

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SPPSunflower Electric Power CorporationSPPSouthwest Power PoolArkansas PSCKansas Corporation CommissionSPPNebraska Public Power DistrictSunflower Electric Power CorporationSPPBasin ElectricRTO InsiderOGE EnergyIUBNorth Dakota Public Service CommissionMissouri Public Service CommissionTCEC

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Antitrust: SPP strictly prohibits use of participation in SPP activities as a forum for engaging in practices or communications that violate the antitrust laws. Please avoid discussion of topics or behavior that would result in anti-

competitive behavior, including but not limited to, agreements between or among competitors regarding prices, bid and offer practices, availability of service, product design, terms of sale, division of markets, allocation of customers or any

other activity that might unreasonably restrain competition.

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SOUTHWEST POWER POOL, INC. REGIONAL STATE COMMITTEE BUSINESS MEETING

April 26, 2021

AGENDA

12:30 P.M. – 2:00 P.M. 1. CALL TO ORDER 2. PRELIMINARY MATTERS

a. Commissioners’ Roll Call and Declaration of a Quorum. b. Adoption of Minutes from January 25, 2021 and February 12, 2021. c. Review of Ongoing Action Items.

3. UPDATE a. SPP Report……………………………………………………………………………………………..………Barbara Sugg

b. RSC First Quarter 2021 Financial Report……………………………………...............................Paul Suskie

4. BUSINESS ITEMS

a. Nominating Committee Report………………..…………….……………………………………..Dana Murphy [VOTING ITEM]

b. 2021 and Beyond Operational Objectives……....Dana Murphy, Jason Chaplain, Shari Albrecht [VOTING ITEM]

c. Other Potential Business Items

5. SPP RSC/OMS SEAMS LIAISON COMMITTEE REPORT……..…………….…………………….Dana Murphy

6. CAWG REPORT

a. Cost Allocation Working Group (CAWG) Report…….........................................................Greg Rislov This report will update the RSC on the February, March, and April activities of the CAWG.

b. CAWG Cold Weather Event Ad Hoc Update……………………………………………….John Krajewski This report will update the RSC on the Cold Weather Event.

7. OTHER RSC MATTERS

8. NEW ACTION ITEMS

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Antitrust: SPP strictly prohibits use of participation in SPP activities as a forum for engaging in practices or communications that violate the antitrust laws. Please avoid discussion of topics or behavior that would result in anti-

competitive behavior, including but not limited to, agreements between or among competitors regarding prices, bid and offer practices, availability of service, product design, terms of sale, division of markets, allocation of customers or any

other activity that might unreasonably restrain competition.

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9. SCHEDULE OF NEXT RSC BUSINESS MEETINGS

July 26, 2021 October 25, 2021

10. ADJOURNMENT OF BUSINESS MEETING

RSC/BOD/MC EXECUTIVE SESSION

THE RSC MAY HOLD AN EXECUTIVE SESSION WITH THE SPP BOARD & MEMBERS COMMITTEE. ATTENDANCE IS LIMITED TO THE BOARD OF DIRECTORS, MEMBERS COMMITTEE, OFFICERS, AND

ONE REPRESENTATIVE FROM EACH MEMBER COMPANY. *NOTE: ADDITIONAL INFORMATIONAL MATERIAL ATTACHED. Attached to the RSC’s meeting agenda and background material is additional material that is either for informational or reporting purposes.

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Regional State Committee Special Meeting

February 12, 2021 -Net Conference 1:30 p.m. CT

ADMINISTRATIVE ITEMS

The following members participated: Proxy John Reynolds for Jeff Byrd, New Mexico Public Regulation Commission (NMPRC)


DeAnn T. Walker, Public Utility Commission of Texas (PUCT) President Kristie Fiegen called the Regional State Committee (RSC) Special Business Meeting to order at 1:30 p.m. by way of participant list via Webex and a quorum was declared. There were 75 participants. (Attendance & Proxies). President Fiegen, Mr. Lanny Nickell, Mr. Bruce Rew, and Mr. Paul Suskie from Southwest Power Pool to give an update on the extreme weather event that began on February 9, 2021. SPP RSC/OMS SEAMS LIAISON COMMITTEE REPORT Commissioner DeAnn Walker presented the RSC/OMS Seams Liaison Committee (SLC) report. Commissioner Walker discussed the final recommendations for the SLC issues and the Commissioners Rupp and Fiegen compromised language. Nebraska Power Review (NPR) Board Member Dennis Grennan discussed the need for standing agenda items related to the seams. NPR Board Member Dennis Grennan made a motion that SPP staff include a standing agenda item on the Joint Quarterly Stakeholders Briefing related to inter-regional planning and operations. This quarterly update should provide a report on the status of the Seams Liaison Committee, Joint Study related to generator interconnection queue, and any other study improvement process affecting inter-regional planning and operations. Commissioner Scott Rupp seconded. The motion passed unanimously. Commissioner Walker discussed Recommendation Number 5 - Issue 1: Market-to-Market; Issue 6: Coordinated Transaction Scheduling; and Issue 7: Interface Pricing. The individual members of OMS and SPP-RSC were encouraged to participate in the RTO roadmap ranking processes (i.e., MISO Integrated Roadmap and SPP Strategic Roadmap) and give priority to the following issues: Market-to-Market, Coordinated Transaction Scheduling, and Interface Pricing. MISO and SPP were encouraged to coordinate roadmap items that have interdependencies and consider joint implementation timelines where appropriate. Iowa Utilities Board (IUB) Member Geri Huser made a motion to approve Recommendation Number 5- Issues 1, 6, and 7. Commissioner Randy Christmann seconded. The motion passed unanimously.

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Regional State Committee February 12, 2021

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Commissioner Walker discussed Recommendation Number 4 - Issue 3 Interregional Planning: MISO and SPP shall update the SLC, RSC, or OMS as appropriate as to other interregional planning activities that are going on within their respective long-term planning processes. This includes SPP’s 2022 20-year Assessment Future 4 and MISO’s Long-Range Transmission Planning process. Commissioner Andrew French made a motion to approve Recommendation Number 4 - Issue 3: Interregional Planning. Commissioner Ted Thomas seconded. The motion passed unanimously. Commissioner Walker discussed Recommendation Number 3 - Issue 5 Generator Interconnection: MISO and SPP shall provide updates as needed to the SLC, RSC, or OMS as appropriate on the ongoing joint study focused on interconnection along the seam. The RTOs could highlight possible changes to existing generator interconnection processes that are considered as a result of this process. Commissioner Ted Thomas made a motion to approve Recommendation Number 3 - Issue 5: Generator Interconnection. Commissioner Scott Rupp seconded. The motion passed unanimously. Commissioner Walker discussed Recommendation Number 2 - Issue 4-TMEP: OMS and SPP-RSC shall request that MISO and SPP to submit to the Interregional Planning Stakeholder Advisory Committee a directive to evaluate the need for a TMEP process and to develop such a process if supported by stakeholders. Commissioner Scott Rupp made a motion to approve Recommendation Number 2 - Issue 4: Targeted Market Efficiency Projects. Commissioner Andrew French seconded. The motion passed unanimously. Commissioner Walker discussed recommendation number 1-Issue 2 Rate Pancaking: The SLC recommends the creation of a working group focused on inventorying different types of rate pancaking along the SPP/MISO Seam and requests that MISO and SPP conduct a survey of transmission owners and other stakeholders to measure interest in studying rate pancaking issues. The working group should report to the SLC using existing staff, hold open meetings, and provide updates to the SLC on a quarterly basis. Commissioner Ted Thomas made a motion to approve Recommendation Number 1 - Issue 2: Rate Pancaking. Commissioner Scott Rupp seconded. Vote #1- : An amendment was offered by Commissioner Thomas to his underlying motion stating that the working group should be defined as the RSC and OMS Commissioners that desire to participate plus an equal number of other stakeholders to be chose by the RSC and OMS. The amendment passed with two opposed-Public Utility Commission of Texas and New Mexico Public Regulation Commission. Vote #2-The underlying motion was amended to list Issue 2 as third on the priority list. The amended motion passed unanimously. Vote #3 Commissioner Thomas’s underlying motion, as amended by votes #1 and #2, passed with four opposed-Public Utility Commission of Texas, Oklahoma Corporation Commission, New Mexico Public Regulation Commission, and South Dakota Public Utility Commission.

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Commissioner Walker discussed a proposed compromised motion that called for action by both MISO and SPP, interested stakeholder and members of OMS and SPP RSC. The OMS and SPP RSC Seams Liaison Committee offered recommendations in furtherance of their goals. The recommendations called for action by both MISO and SPP, interested stakeholders, and members of both OMS and the SPP RSC. After these recommendations are implemented, the Seams Liaison Committee will shift into a limited, monitoring mode. Commissioner Ted Thomas made a motion to approve the recommendation call for action by both MISO and SPP. Commissioner Scott Rupp seconded. The motion passed unanimously. SCHEDULE OF NEXT MEETINGS Commissioner Kristie Fiegen discussed that the next meeting would be the regularly scheduled monthly meeting in March. With no further business, the meeting adjourned at 4:00 p.m. Respectfully Submitted, Paul Suskie

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Regional State Committee Meeting

January 25, 2021 -Net Conference 12:30 p.m. CT

ADMINISTRATIVE ITEMS

The following members participated: Jeff Byrd, New Mexico Public Regulation Commission (NMPRC)


DeAnn T. Walker, Public Utility Commission of Texas (PUCT) President Kristie Fiegen called the Regional State Committee (RSC) Business Meeting to order at 12:30 p.m. by way of participant list via Webex and a quorum was declared. There were 166 participants (Attendance & Proxies). The first item of business was the adoption of minutes from 10/26/2020 as presented. (RSC Minutes 10/26/2020). Commissioner Randy Christmann moved to approve the minutes; Commissioner Jeff Byrd seconded. The motion was approved unanimously. Commissioner Fiegen thanked Nebraska Power Review (NPR) Board member Dennis Grennan and Mr. John Krajewski for their service to the RSC. Mr. Grennan thanked everybody for their participation and for working through all of the changes this past year, particularly how the meetings were conducted. Mr. Krajewski also thanked the Southwest Power Pool Staff and the Cost Allocation Working Group for their hard work. Commissioner Fiegen welcomed Kara Fornstrom to Southwest Power Pool. Ms. Fornstrom comes to SPP from the Wyoming Commission. Ms. Kandi Hughes (SPP staff) reviewed the RSC action items. Ms. Hughes reviewed the ongoing action items and, later, the new action items with the RSC. (RSC Action Items) UPDATE SPP Report Ms. Barbara Sugg (SPP President and CEO) provided the SPP Report. She began her report by discussing the approval of the Western Energy Imbalance Service (WEIS) Tariff on December 23, 2020 and is looking forward to another historic moment when launched on time and under budget. The majority of WEIS participants have submitted Letters of Interest to join SPP Regional Transmission Organization (RTO). The New Member Forum is underway with the first meeting being held on January 5, 2021. Ms. Sugg discussed the ongoing process between the SPP and MISO coordination and joint study and the technical phase that kicked off in December 2020. Ms. Sugg welcomed Ms. Kara Fornstrom, former Chair of the Wyoming Public Service Commission and Mr. Len Tao, former senior FERC staff member to SPP. Together they bring 30 years of experience from Washington and the Department of Energy.

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Regional State Committee January 25, 2021

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RSC Quarterly Financial Report Mr. Paul Suskie (SPP Staff) provided the RSC financial report for the fourth quarter of 2020 (RSC 2020 Q4 Financials). The RSC continues to be under budget due to reduced travel expenses to the COVID-19 pandemic; there is $150,000 for an RSC Consultant if needed. BUSINESS ITEMS Auditor Cost for Audit and Taxes for 2020 and Engagement Letter Mr. Paul Suskie discussed the Auditor Cost for Audit and Taxes for 2020 and Engagement Letter from Landmark Certified Public Accountants. Commissioner Andrew French moved to approve SPP RSC Engagement Letter for services from Landmark Certified Public Accountants as the RSC Auditor and give Commissioner Fiegen authority to sign and return; Commissioner Jeff Byrd seconded. The motion was approved unanimously. SPP RSC/OMS SEAMS LIAISON COMMITTEE REPORT Commissioner DeAnn Walker presented the RSC/OMS Seams Liaison Committee (SLC) report. Commissioner Walker discussed the goals to provide an update on the RSC survey for SLC issues, provide an overview of discussion on next steps for the SLC and discuss future status of the committee. The RSC made the decision to postpone the vote on the RSC OMS Seams Liaison Committee report until the February 12, 2021 RSC meeting. COST ALLOCATION WORKING GROUP REPORT Mr. Greg Rislov provided the Cost Allocation Working Group report (CAWG Report – Attachment). There was a review of the 2021 CAWG goals and current status. Mr. Krajewski discussed the CAWG recommendation for RSC action on RR436 BEPC Proposed Changes to Attachment J Schedule 2. NPR Board Member Dennis Grennan moved to approve RR436 BEPC proposed changes to Attachment J Schedule 2; Commissioner Jeff Byrd seconded. The motion passed unanimously. Mr. Rislov provided an update on the Standalone Battery Effective Load Carrying Capability (ELCC) Accreditation. The CAWG recommends the RSC endorse the Energy Storage ELCC Accreditation white paper for standalone battery storage. Commissioner Andrew French moved to approve the Standalone Battery ELCC Accreditation. Seconded by NPR Board Member Dennis Grennan. The motion passed unanimously. OTHER RSC MATTERS Commissioner Dana Murphy requested the RSC Reference Documents on the SPP website be up-to-date. With no further business, the meeting adjourned at 2:37 p.m. Respectfully Submitted, Paul Suskie

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No. Action Item Date Originated Status Comments

16-19 Preparation and circulation of RSC Agendas 4/25/2016 In processSPP prepare and circulate draft agendas to RSC and CAWG members earlier for comment.

17-29 Annual Review of Safe Harbor Criteria 7/24/2017 In process

CAWG will bring a proposal to the RSC for the limited annual review of the Safe Harbor Criteria CAWG and will synchronize the limited review with SPP’s annual filing with FERC. *Voted not to conduct 2020 annual review at July 29, 2019 meeting and the next annual review will be a full review completed in 2022.

18-46 RSC/OMS Task Force Update 10/29/2018 In processInclude “RSC/OMS Task Force Update” as an agenda item for the RSC Business Meetings.

19-51Background information on “voting items”

and “potential voting items”4/29/2019 In process

The Sponsor of any voting item or potential voting item, as listed on the agenda, will provide background information and voting results from various stakeholder groups, if necessary. SPP Staff to include applicable links within background materials related to Motions.

19-52 RSC Operational Objectives 4/29/2019 In process

Voted and approved to review and update, as needed, throughout the year and annually. 01/27/2020: RSC President to send to SPP Board Chairmen for dissemination to SPP BOD. Updated: 01/25/21: Update Operational Objectives document on SPP.org including a "last updated" line within document for reference.

19-57 Links to Motions within Materials 10/28/2019 In processSPP Staff include applicable links within background materials related to Motions.

20-8 CAWG: Updated Timeline 10/26/2020 In processCAWG to provide updated timeline (based upon other working group activities) to the RSC at the November 2020 monthly call, and the January 2021 and April 2021 RSC Business Meetings.

21-1 Storage Presentation 1/25/2021 In ProcessSPP staff to give an update on storage at the February 2021 RSC monthly meeting. Updated: Date moved back because of cold weather event

21-3 Resource Documents on SPP.org 1/25/2021 In ProcessSPP staff to ensure RSC resource documents on SPP.org are updated.

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Regional State CommitteeFor the Three Months Ending March 31, 2021

Budget vs. Actual

YTD Actuals YTD Budget Variance

Income Other Income - 123,750 (123,750) Total Income - 123,750 (123,750)

Expense Travel - 71,500 (71,500) Meetings - 14,500 (14,500) Audit - - - Administrative Costs - 250 (250) RSC Consultant - 37,500 (37,500) Technical Conference - - - Total Expense - 123,750 (123,750)

Net Income - - -

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2021 and Beyond Operational Objectives

Regional State Committee Who We Are

The Southwest Power Pool (“SPP”) Regional State Committee (“RSC”) provides collective state regulatory agency input in areas under the RSC’s primary responsibilities and on matters of regional importance related to the development and operation of the bulk electric transmission system. “Any regulatory agency having utility rates or services jurisdiction over a Member may participate fully in all SPP activities, including participation at the SPP Board of Directors meetings. These representatives shall have all the same rights as Members except the right to vote. Participation includes the designation of representatives by each of the regulatory jurisdictions to participate in any type of committee, working group, task force, and Board of Directors meetings.” SPP Bylaws Sec.7.0. The SPP RSC is comprised of retail regulatory commissioners from agencies in Arkansas, Iowa, Kansas, Louisiana, Missouri, Nebraska, New Mexico, North Dakota, Oklahoma, South Dakota and Texas. For further background information on the RSC, please see The History of the RSC for the SPP, Inc. document found on the SPP website here:

https://www.spp.org/documents/58610/history%20rsc%202020%2020200403%20online.pdf

RSC Responsibilities

Under the SPP Bylaws Sec. 7.2, the RSC has primary responsibility for determining regional proposals and the transition process in the following areas:

(a) Whether and to what extent participant funding will be used for transmission enhancements;

(b) Whether license plate or postage stamp rates will be used for the regional access charge;

(c) FTR allocation, where a locational price methodology is used; and

(d) The transition mechanism to be used to assure that existing firm customers receive FTRs equivalent to the customers’ existing firm rights.

The RSC will also determine the approach for resource adequacy across the entire region. In addition, with respect to transmission planning, the RSC will determine whether transmission upgrades for remote resources will be included in the regional transmission planning process and the role of transmission owners in proposing transmission upgrades in the regional planning process.

As the RSC reaches decisions on the methodology that will be used to address any of these issues, SPP will file this methodology pursuant to Section 205 of the Federal Power Act. However, nothing in this section prohibits SPP from filing its own related proposal(s) pursuant to Section 205 of the Federal Power Act. For more information on the SPP Bylaws, please see the e-tariff viewer on the SPP website at the following link:

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https://www.spp.org/documents/58610/history%20rsc%202020%2020200403%20online.pdf

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https://spp.etariff.biz:8443/viewer/viewer.aspx

2021 RSC Operational Objectives

Issue/Potential Steps/Status

RSC Primary Responsibility

Potential Outcome Timeline

HITT – Recommendation C1

Decouple Schedule 9 and 11 Pricing Zones

Issue: HITT recommendation C1 was to decouple Schedule 9 and 11 Pricing Zones. CAWG moved that, if decoupling is found feasible, it would only apply to facilities with an NTC issued after January 1, 2021. CAWG/RSC to work to determine tariff revisions that would be necessary. If larger Schedule 11 pricing zones are desired by RSC/CAWG, develop methodology to establish larger zones and determine potential impacts.

Cost Allocation: SPP Bylaws: Section 7.2 (a) whether and to what extent participant funding will be used for transmission enhancements; and (b) whether license plate or postage stamp rates will be used for the regional access charge.

White paper and revised tariff language to decouple Schedule 9 and 11 and new Schedule 11 transmission pricing zones.

April 2020: First draft of tariff language. July 2020: RSC approve Policy Report and Tariff language. February 2021: Policy Report and Tariff language have been postponed until further analysis is completed by SPP Staff and the Deliverability Steering Committee (“DSC”). Draft Policy Report expected late 2021/early 2022.


Evaluate a Byway Facility Cost Allocation Review

Process

Issue: HITT recommendation to create narrow review process through which byway facilities (> 100 kV and < 300 kV) would receive regional funding.

Cost Allocation: SPP Bylaws: Section 7.2

White paper and revised tariff language to implement Byway Facility Cost Allocation Review Process.

April 2020: Initial draft of process. July 2020: RSC approved White Paper and proposed tariff language. October 2020: RSC approved RR 422, tariff language to implement HITT C2. February 2021: SPP expects to file tariff language late February/early March with 60 day effective date. April 2021: Tariff language filed at FERC.

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https://spp.etariff.biz:8443/viewer/viewer.aspx

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Evaluate cost allocation for transmission storage

devices

Issue: Develop cost allocation methodology for storage devices (i.e. batteries) that qualify as transmission facilities.

Cost Allocation: SPP Bylaws: Section 7.2 (a) whether and to what extent participant funding will be used for transmission enhancements; and

White paper and revised tariff language implementing cost allocation methodology for storage devices that qualify as transmission facilities.

March 2020: Final draft of white paper. July 2020: CAWG/RSC approval of white paper. February 2021: White paper delayed due to additional analysis required, expected CAWG/RSC approval of white paper July 2021.

Secondary HITT Recommendations:

T1: NRIS/ERIS M1: Congestion Hedging S3: Storage White Paper

Issue: Continue work on HITT recommendations for which CAWG/RSC is secondary working group.

SPP Bylaws: Section 7.2 (c) FTR allocation, where a locational price methodology is used; and (d) The transition mechanism to be used to assure that existing firm customers receive FTRs equivalent to the customers’ existing firm rights.

Potential Action Based on Primary Working Group Schedule: February 2021: T1: MOPC approved NEDTF white paper in October 2020 and formed the DSC to implement the TF’s recommendations. Deliverability analysis should be complete by mid-year 2021 and relates to HITT C1 additional analysis. M1: RSC participating in Strategic Planning Committee process to address issue. S3: Jan. 2021 MOPC approved direction of seven initiatives and remanded one to Energy Storage Resource Steering Committee.

Adhere to schedules developed by primary working groups. Deliverability Steering Committee: https://www.spp.org/stakeholder-groups/organizational-groups/board-of-directorsmembers-committee/markets-and-operations-policy-committee/deliverability-steering-committee/ Strategic Planning Committee: https://www.spp.org/stakeholder-groups/organizational-groups/board-of-directorsmembers-committee/strategic-planning-committee/ Electric Storage Resource Steering Committee: https://www.spp.org/stakeholder-groups/organizational-groups/board-of-directorsmembers-committee/markets-and-operations-policy-committee/electric-storage-resources-steering-committee/

OMS/RSC Seams Liaison Committee

(“SLC”):

Issue: Continued work to identify potential improvements in Seams areas and work with SPP and MISO on implementation.

SPP Bylaws, Section 7.0: Regulatory Involvement and Regional State Committee. Four Commissioners

To increase benefits to ratepayers in MISO and SPP regions by improving transactions and operations across the seam and to improve inter-RTO relations through state-led cooperation.

TBD based results of analysis, recommendation from the Joint Committee, and RSC/OMS action. February 2021: RSC approved final recommendations of the OMS/RSC SLC.

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https://www.spp.org/stakeholder-groups/organizational-groups/board-of-directorsmembers-committee/markets-and-operations-policy-committee/deliverability-steering-committee/








https://www.spp.org/stakeholder-groups/organizational-groups/board-of-directorsmembers-committee/strategic-planning-committee/






https://www.spp.org/stakeholder-groups/organizational-groups/board-of-directorsmembers-committee/markets-and-operations-policy-committee/electric-storage-resources-steering-committee/








4

serve on the Committee.

March 2021: OMS approved final recommendations of the OMS/RSC SLC. April 2021: SLC future meetings on quarterly basis. May 2021 TBD –SLC forming working group of Commissioners and stakeholders to address rate pancaking issue.

Z2 Credits – FERC Order on Remand:

Docket No. ER16-1341-003

Issue: FERC directs SPP to provide refunds, with interest calculated pursuant to 18 C.F.R. § 35.19a (2018). FERC also directs SPP to file a report within 120 days of the date of this order detailing how it proposes to make the refunds.

Cost Allocation: SPP Bylaws: Section 7.2 (a) whether and to what extent participant funding will be used for transmission enhancements.

To be determined.

Continued monitoring of effects of various dockets related to Attachment Z2.

Comprehensive Review Steering Committee:

RSC’s Review of SPP’s Communications

February 2021 Cold Weather Event

CAWG February 2021

Event Ad Hoc Study Group

Issue: Initiate a 5-path collaborative review of the 2021 winter storm event with coordination and oversight to be provided by the Comprehensive Review Steering Committee. Areas of review include: Operational, Financial, RSC, Market Monitoring Unit, and Communications.

SPP Bylaws: Section 7.2 The primary initial focus of the RSC will be on the communications piece of the incident. CAWG areas of review include cost allocation for transmission system expansion, allocation of financial transmission rights and resource adequacy.

Goals of SPP Review: • Assess

performance during winter storm event,

• Engage with all stakeholders in a transparent process,

• Identify operational and market issues and challenges,

• Develop recommendations for improving future performance,

• Improve joint capabilities,

• Improve communications and warning system.

Overall assessments and lessons learned to be reported to the board of directors in July 2021.

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5

FERC Order 2222 Task Force:

Adopts reforms to remove barriers to participation of distributed energy resource (“DER”) aggregations in RTOs and ISOs.

Issue: FERC determined current market rules designed for traditional resources can create barriers to entry for emerging technologies and thus were unjust and unreasonable and may restrict efficient operation of resources and competitiveness of wholesale markets.

Distribution System Regulation: Address metering and telemetry requirements for DER aggregations. Address coordination between SPP, the DER Aggregator, the distribution utility and the relevant electric retail regulatory authority. Two RSC members serve on the task force.

To be determined.

July 19th, 2021 for ISO/RTOs. On February 18th SPP requested the Commission to grant an extension to April 28, 2022, to submit its compliance filing in response to Order No. 2222 and to act on the motion by April 1, 2021. April 2021: FERC granted extension to April 28th, 2022.

Strategic & Creative Re-engineering of Integrated

Planning Team: (“SCRIPT”)

Issue: The SCRIPT is responsible for strategically developing broad changes to SPP’s transmission planning processes to better meet customer needs while resolving growing stakeholder concerns about the amount, nature and funding of continued transmission investment amid rapid industry changes.

SPP Bylaws: Section 7.2 Two RSC members serve on the planning team.

To be determined. Items include but not limited to: Appropriate consolidation, modification, or elimination of SPP’s transmission planning and study processes, Improved cost sharing among users of the transmission system that appropriately recognizes causers and beneficiaries of transmission investment decisions, Utilization of processes and information needed to ensure decisions being made about future investment in transmission infrastructure are made with a high degree of confidence and quality.

Duration: The SCRIPT is expected to complete its work by October 2021.

State Commissioner Forum

Issue: Six entities in the Western Interconnect have expressed interest in becoming SPP members. This integration could add Colorado,

SPP New Member Stakeholder Communication Process

Three potential new Commissioners/States would join RSC, necessitating changes to RSC Bylaws.

Potential integration expected late 2022/early2023.

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6

Wyoming, and Montana to the RSC. A State Commission Forum is established to work with SPP staff and a Members Forum on integration of new entities.

Capacity Resource Interconnection Service

(“CRIS”) Cost Allocation Impacts: NRIS,ERIS,

Deliverability Task Force (“NEDTF”)

Issue: During the course of the NEDTF policy proposals, a number of potential cost allocation items were identified and communicated to the CAWG for their review. Section 3.13.3 “Cost Allocation Working Group – CAWG” NEDTF Whitepaper:

SPP Bylaws: Section 7.2

To be determined. February 2021: T1: MOPC approved NEDTF white paper in October 2020 and formed the DSC to implement the TF’s recommendations. DSC scope states duration of the DSC will conclude its work when the MOPC has approved policies and related tactical recommendations necessary to fully implement the NEDTF recommendations.

Regional Allocation Review Task Force

(RARTF)

The RARTF is responsible for defining “the analytical methods to be used” to “review the reasonableness of the regional allocation methodology and factors (X% and Y%) and the zonal allocation methodology.” The analytical method shall be designed to “determine the cost allocation impacts of the Base Plan Upgrades with Notifications to Construct issued after June 19, 2010 to each pricing

SPP Bylaws: Section 7.2 : Cost allocation Southwest Power Pool Open Access Transmission Tariff, Attachment J, Section III.D. Four Commissioners serve on the TF including its Chair.

Consider improvements, if any, to the long term cumulative equity of cost allocation and benefits for members resulting from SPP’s Integrated Transmission Planning process. RARTF shall prepare and present a report to the Market and Operations Policy Committee (MOPC) and the Regional State Committee (RSC) for approval.

Due in 2022: Study process start 2nd half 2021.

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7

Zone within the SPP Region.”

Identify Other Areas for Future Review

Review RSC areas of responsibility and identify potential issues to address in the future.

SPP Bylaws: Section 7.2

To be determined

Covid-19 impacts. Safe Harbor Criteria Review

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SouthwestPowerPool SPPorg southwest-power-poolHelping our members work together to keep the lights on... today and in the future. 1

CAWG REPORTGREG RISLOV

APRIL 26, 2021

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2

AGENDA

• Update on HITT Initiatives

• Presentations to CAWG

• Questions

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3

HITT INITIATIVES

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4

HITT C1: DECOUPLE SCHEDULE 9 & 11 TRANSMISSION PRICING ZONES• Discussed and reviewed stakeholder requested analysis

• Charles Locke and Don Frerking presented on Zonal LMPs and ATRRs for year 2020

• Discussed studies that will be used by both the Deliverability Task Force and HITT C1 will not be completed until later in 2021.

MOTION: The CAWG suspends further activity on HITT Initiative C1 unless otherwise directed by the RSC or additional information generates a need for earlier consideration of issues related to C1. This suspension will remain in place through at least July 31, 2021. The CAWG will revisit this topic at the August 2021 meeting to determine the status of other parallel path activities and make a determination on whether to re-start work

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5

C2: ESTABLISH BYWAY FACILITY COST ALLOCATION REVIEW PROCESS

• Filed with FERC on April 14, 2021.

• Requested effective date June 14, 2021.

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6

C4: STUDY COST ALLOCATION TRANSMISSION STORAGE DEVICES• Defined and refined in scope and out of scope items

• Reviewed Outline of the whitepaper

• David Schmitt Iowa Utilities Board has accepted another job and will no longer be on the CAWG. Lane Sisung of Louisiana Public Service Commission will be the lead on the initiative

• At this time the timeline is not impacted.

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OTHER PRESENTATIONS

• 2021 Winter Weather Event Ad Hoc Committee

• Strategic and Creative Re-engineering of Integrated Planning Team (SCRIPT)

• Order 2222 – Distributed Energy Resources

• Seams Liaison Committee Priorities

• Joint Studies timeline and update

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8

QUESTIONS

35 of 72

SouthwestPowerPool SPPorg southwest-power-poolHelping our members work together to keep the lights on... today and in the future.

1

CAWG AD HOC WORKING GROUP UPDATEAPRIL 26, 2021

JOHN KRAJEWSKI

CHAIRMAN

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2

GOAL OF PRESENTATION

• Provide brief overview of activities since last RSC meeting

• Planned activities to complete work

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3

MEETINGS

• March 22, 2021

• April 5, 2021

• April 19, 2021

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4

CURRENT STATUS

• Reviewed RSC areas of responsibility

• Narrowed focus of analysis to resource adequacy

• Presentations from SPP staff and MMU

• Reviewed data set in effort to identify key issues

• Participated in meetings with Supply Adequacy Working Group

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5

NEXT STEPS

• Narrow focus to key issues

• Develop conclusions and recommendations

• Draft report for inclusion in final report

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SOUTHWEST POWER POOL, INC.

REGIONAL STATE COMMITTEE EDUCATION SESSION

April 26, 2021

AGENDA

8:15 A.M. – 12:00 P.M.

8:00 AM - RSC Education Session WebEx will be opened for technology checks &

opportunities to visit.

WELCOME

Kristie Fiegen | RSC President

1. SPP RSC AD HOC COLD WEATHER EVENT EDUCATION

Randy Christmann | North Dakota Public Service Commission

a) COMMUNICATION DURING WINTER WEATHER EVENT

Mike Ross/Dustin Smith | SPP Staff

b) DISCUSSION ON FUTURE MEETINGS

Randy Christmann

2. SPP MARKET MONITOR COLD WEATHER EVENT PRESENTATION

Keith Collins | SPP MMU

3. SPP NEW MEMBER COMMISSIONER FORUM

Paul Suskie | SPP Staff

ADJOURNMENT – 12 P.M.

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QUARTERLY PROJECT TRACKING REPORT

Q2 2021

April 2021

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Southwest Power Pool, Inc.

REVISION HISTORY

DATE OR VERSION

NUMBER

AUTHOR CHANGE

DESCRIPTION

COMMENTS

4/12/2021 SPP Staff Submitted to MOPC

4/27/2021 SPP Staff Submitted to Board

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CONTENTS

REVISION HISTORY.......................................................................................................................................................... I

EXECUTIVE SUMMARY ..................................................................................................................................................1

NTC PROJECT SUMMARY ............................................................................................................................................2

COMPLETED UPGRADES...............................................................................................................................................2

NTCS ISSUED.....................................................................................................................................................................4

NTCS WITHDRAWN........................................................................................................................................................9

PORTFOLIO SUMMARY.............................................................................................................................................. 10

PROJECT STATUS SUMMARY .................................................................................................................................. 13

OUT-OF-BANDWIDTH PROJECTS .......................................................................................................................... 14

RESPONSIVENESS REPORT....................................................................................................................................... 15

ITP20 UPGRADES.......................................................................................................................................................... 17

APPENDIX 1 .................................................................................................................................................................... 18

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Q2 2021 Quarterly Projec t Tracking Report 1

EXECUTIVE SUMMARY

SPP actively monitors and supports the progress of transmission expansion projects, emphasizing the

importance of maintaining accountability for areas such as regional grid reliability standards, firm

transmission commitments, and SPP Open Access Transmission Tariff (OATT) cost recovery.

SPP staff solicits quarterly feedback from the project owners to determine the progress of each approved

transmission project. This quarterly report charts the progress of all SPP transmission projects approved

by the SPP Board of Directors (Board) or through a FERC-filed service agreement under the OATT.

Projects in the current portfolio include all Network Upgrades for which construction activities are

ongoing or those for which construction has completed but not all close-out requirements have been

fulfilled in accordance with Section 13 in Business Practice 70601.

1 SPP OATT Business Practices

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https://www.spp.org/spp-documents-filings/?id=18162



NTC PROJECT SUMMARY

In adherence with the OATT and Business Practice 7060, SPP issues NTCs to Designated Transmission

Owners (DTOs) to begin work on Network Upgrades that have been approved or endorsed by the Board

to meet the construction needs of the OATT or Regional Transmission Organization (RTO).

COMPLETED UPGRADES

Figure 1: Completed Upgrades

NTC

ID

IN

SERVICE

DATE

UID OWNER UPGRADE NAME SOURCE

STUDY

COST

ESTIMATE

200407 12/15/2020 51478 SPS Mustang - Seminole 115

kV Ckt 1 New Line 2016 ITPNT $11,037,124

200407 12/15/2020 51479 SPS Mustang 115 kV Terminal

Upgrades 2016 ITPNT $2,629,398

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NTC

ID

IN

SERVICE

DATE


STUDY

COST

ESTIMATE

200407 12/15/2020 51480 SPS Seminole 115 kV Terminal

Upgrades 2016 ITPNT $2,398,399

210496 12/15/2020 51450 SPS Sundown 230/115 kV

Transformer 2018 ITPNT $8,086,787

210497 11/1/2020 72052 WAPA Lewis - Richland 115kV Ckt

1 (WAPA) 2018 ITPNT $136,000

210507 11/3/2020 102156 SPS Eddy County - Kiowa 345

kV Ckt 1 New Line

DPA-2017-

November-808 $64,091,215

210507 11/15/2020 102158 SPS Bopco 115 kV Substation DPA-2017-

November-808 $15,345,796

210525 11/16/2020 112180 OPPD

GEN-2016-115

Interconnection Costs (NU)

(OPPD)

DISIS-2016-002 $7,553

11/16/2020 71943 WAPA Sulphur 115kV - GEN-

2014-001IS Addition (NU)

Generation

Interconnection $2,177,249

1/1/2021 82134 WAPA Gavins Point - Yankton

Junction 115 kV

Generation

Interconnection $1,401,596

10 Upgrade(s) Completed $107,311,117

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NTCS ISSUED

Figure 2: NTCs Issued

NTC

ID

NTC ISSUE

DATE UID OWNER UPGRADE NAME

SOURCE

STUDY

COST

ESTIMATE

OF NEW

UPGRADES

COST

ESTIMATE OF

PREVIOUSLY

APPROVED

UPGRADES

210553 12/9/2020 122631 WAPA

Fort Randall - Spencer

115kV Ckt 1 Re-

conductor

DPA-2019-

May-1037 $2,650,000 $0

210553 12/9/2020 122632 WAPA Martin - Vetal Tap 115

kV Ckt 1 Rebuild

DPA-2019-

May-1037 $3,800,000 $0

210568 11/12/2020 112458 TSMO Sooner - Wekiwa 345

kV New Line 2019 ITP $77,606,498 $0

210569 11/12/2020 112457 WR/EKC Neosho - Riverton

161kV Rebuild (WR)

SPP-2019-

AG1-AFS-2 $3,972,869 $0

48 of 72



NTC

ID

NTC ISSUE


SOURCE

STUDY

COST

ESTIMATE

OF NEW

UPGRADES

COST

ESTIMATE OF

PREVIOUSLY

APPROVED

UPGRADES

210570 11/12/2020 112456 EDE Neosho - Riverton

161kV Rebuild (EDE)

SPP-2019-

AG1-AFS-2 $43,153,324 $0

210574 11/17/2020 122725 SPS Allen - Quaker 115 kV

Ckt 1 Rebuild 2020 ITP $4,732,267 $0

210574 11/17/2020 122727 SPS Allen - Lubbock South

115 kV Ckt 1 Rebuild 2020 ITP $6,817,226 $0

210574 11/17/2020 122869 SPS

Bushland - Deaf Smith

230 kV Terminal

Upgrades

2020 ITP $923,938 $0

210574 11/17/2020 122870 SPS Newhart - Potter 230

kV Terminal Upgrades 2020 ITP $731,282 $0

210574 11/17/2020 122871 SPS Deaf Smith #6 - Friona

115 kV Rebuild 2020 ITP $12,626,190 $0

210574 11/17/2020 122872 SPS Carlisle - Murphy 115

kV Ckt 1 Rebuild 2020 ITP $4,746,175 $0

210574 11/17/2020 122876 SPS

Deaf Smith #6 -

Hereford 115 kV Ckt 1

Rebuild

2020 ITP $6,660,556 $0

210574 11/17/2020 122883 SPS

Lubbock South -

Wolfforth 230 kV Ckt

1 Terminal Upgrades

#2

2020 ITP $872,391 $0

210574 11/17/2020 143167 SPS Cargill - Friona 115 kV

Ckt 1 Rebuild 2020 ITP $817,466 $0

210574 11/17/2020 143168 SPS

Cargill - Deaf Smith

#24 115 kV Ckt 1

Rebuild

2020 ITP $5,501,901 $0

210574 11/17/2020 143169 SPS

Parmer - Deaf Smith

#24 115 kV Ckt 1

Rebuild

2020 ITP $824,574 $0

210574 11/17/2020 143170 SPS

Parmer - Deaf Smith

#20 115 kV Ckt 1

Rebuild

2020 ITP $5,402,384 $0

210575 11/17/2020 122730 AEP

South Shreveport -

Wallace Lake 138 kV

Ckt 1 Rebuild #2

2020 ITP $23,622,577 $0

210575 11/17/2020 122796 AEP

Chisholm Substation

345 kV Terminal

Equipment

2020 ITP $11,999,273 $0

210576 11/17/2020 143156 AEP Grady 138 kV

Capacitor Bank 2020 ITP $688,788 $0

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NTC

ID

NTC ISSUE


SOURCE

STUDY

COST

ESTIMATE

OF NEW

UPGRADES

COST

ESTIMATE OF

PREVIOUSLY

APPROVED

UPGRADES

210577 11/17/2020 112500 EREC

Aberdeen Jct -

Richmond 115 kV Ckt

1 (EREC)

2020 ITP $3,277,500 $0

210577 11/17/2020 122511 EREC Richmond 115/69 kV

Transformer 2020 ITP $2,022,000 $0

210577 11/17/2020 122512 EREC Richmond Capacitor

Bank 69 kV 2020 ITP $222,000 $0

210577 11/17/2020 132894 EREC Richmond 69 kV

Substation 2020 ITP $4,812,500 $0

210578 11/17/2020 122717 GRDA

GRDA1 345 kV

Terminal Upgrades

Transformer Ckt 1

2020 ITP $282,000 $0

210578 11/17/2020 122718 GRDA

GRDA1 161 kV

Terminal Upgrades

Transformer Ckt 1

2020 ITP $423,000 $0

210578 11/17/2020 122801 GRDA

GRDA1 345 kV

Terminal Upgrades

Transformer Ckt 2

2020 ITP $282,000 $0

210578 11/17/2020 122802 GRDA

GRDA1 161 kV

Terminal Upgrades

Transformer Ckt 2

2020 ITP $423,000 $0

210579 11/23/2020 143157 WAPA Bismarck 12.47 kV

Reactors 2020 ITP $2,380,700 $0

210580 11/17/2020 122726 WR/EKC

Meadowlark - Tower

33 115 kV Ckt 1

Rebuild

2020 ITP $1,342,588 $0

210580 11/17/2020 122812 WR/EKC Circleville - Goff 115

kV Ckt 1 Rebuild 2020 ITP $12,114,772 $0

210580 11/17/2020 122814 WR/EKC Goff - Kelly 115 kV Ckt

1 Rebuild 2020 ITP $7,108,395 $0

210581 11/17/2020 122745 BEPC Watford City 230/115

kV Transformer Ckt 1 2020 ITP $3,389,739 $0

210581 11/17/2020 122746 BEPC

Watford City 230/115

kV Ckt 2 Terminal

Equipment

2020 ITP $173,041 $0

210582 11/23/2020 122803 SEPC Russell 115 kV

Capacitor Bank 2020 ITP $2,841,951 $0

210583 11/17/2020 122804 KCPL/EM Northeast 161 kV

Breakers 2020 ITP $887,479 $0

210583 11/17/2020 122805 KCPL/EM Stilwell 161 kV Breaker 2020 ITP $566,485 $0

210583 11/17/2020 122806 KCPL/EM Leeds 161 kV Breaker 2020 ITP $566,485 $0

210583 11/17/2020 122807 KCPL/EM Shawnee Mission 161

kV Breaker 2020 ITP $566,485 $0

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NTC

ID

NTC ISSUE


SOURCE

STUDY

COST

ESTIMATE

OF NEW

UPGRADES

COST

ESTIMATE OF

PREVIOUSLY

APPROVED

UPGRADES

210583 11/17/2020 122808 KCPL/EM Southtown 161 kV

Breaker 2020 ITP $566,485 $0

210583 11/17/2020 122809 KCPL/EM Lake Road 161 kV

Breakers 2020 ITP $1,132,970 $0

210583 11/17/2020 122810 KCPL/EM Craig 161 kV Breakers 2020 ITP $1,132,970 $0

210584 11/17/2020 132893 NWE

Aberdeen Junction

115 kV Terminal

Upgrades

2020 ITP $1,060,000 $0

210584 11/17/2020 143181 NWE

Aberdeen Jct -

Richmond 115 kV Ckt

1 (NWE)

2020 ITP $3,277,500 $0

210585 11/17/2020 143159 MRES Moorehead 230 kV

Reactor 2020 ITP $1,515,440 $0

210586 11/17/2020 112443 WFEC Russett - South Brown

138 kV Ckt 1 Rebuild 2020 ITP $9,959,291 $0

210586 11/17/2020 122577 WFEC

Anadarko -

Gracemont 138kV Ckt

1 Rebuild

2020 ITP $2,850,000 $0

210586 11/17/2020 122722 WFEC

Dover Switch -

O'Keene 138 kV Ckt 1

Terminal Upgrades

2020 ITP $1,010,000 $0

210586 11/17/2020 122753 WFEC

Anadarko -

Gracemont 138 kV Ckt

2 Rebuild

2020 ITP $5,260,000 $0

210586 11/17/2020 122756 WFEC Anadarko 138 kV Ckt

2 Terminal Equipment 2020 ITP $6,075,003 $0

210586 11/17/2020 122864 WFEC Anadarko 138 kV

Breakers #2 2020 ITP $850,000 $0

210586 11/17/2020 122865 WFEC

Mooreland - Aspen

138 kV Terminal

Upgrades

2020 ITP $202,500 $0

210586 11/17/2020 122866 WFEC Mooreland - Pic 138

kV Terminal Upgrades 2020 ITP $405,000 $0

210587 11/17/2020 122823 OGE Border - Woodward

Tap 345 kV Substation 2020 ITP $18,427,752 $0

210587 11/17/2020 122824 OGE Chisholm - Woodward

Border 345 kV Ckt 1 2020 ITP $1,259,660 $0

210587 11/17/2020 122848 OGE Minco 345 kV

Terminal Equipment 2020 ITP $2,288,668 $0

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NTC

ID

NTC ISSUE


SOURCE

STUDY

COST

ESTIMATE

OF NEW

UPGRADES

COST

ESTIMATE OF

PREVIOUSLY

APPROVED

UPGRADES

210587 11/17/2020 122849 OGE Pleasant Valley 345 kV

Substation 2020 ITP $25,500,000 $0

210587 11/17/2020 122850 OGE

Pleasant Valley

345/138 kV

Transformer Ckt 1

2020 ITP $4,225,000 $0

210587 11/17/2020 122851 OGE

Pleasant Valley

345/138 kV

Transformer Ckt 2

2020 ITP $4,225,000 $0

210587 11/17/2020 122858 OGE

Cimarron - Draper 345

kV Terminal Upgrades

#2

2020 ITP $2,288,668 $0

210587 11/17/2020 122863 OGE Midwest 138 kV Ckt 1

Terminal Upgrades 2020 ITP $65,000 $0

210587 11/17/2020 143176 OGE Draper 345 kV

Terminal Equipment 2020 ITP $2,288,668 $0

210589 11/17/2020 122755 OGE Gracemont 138 kV Ckt

2 Terminal Equipment 2020 ITP $405,535 $0

210589 11/17/2020 122818 OGE

Cushing - Shell

Pipeline Cushing Tap

69 kV Ckt 1 Rebuild

2020 ITP $4,281,150 $0

210589 11/17/2020 122819 OGE

Pipeline - Shell

Pipeline Cushing Tap

69 kV Ckt 1 Rebuild

2020 ITP $1,081,649 $0

210590 11/24/2020 143183 KCPL/EM Greenwood 161 kV

Terminal Upgrades

SPP-2020-

AG1-AFS-3 $800,000 $0

210590 11/24/2020 143184 KCPL/EM

Pleasant Hill 161kV

and Lake Winnebago

161 kV Terminal

Upgrades

SPP-2020-

AG1-AFS-3 $430,000 $0

210591 11/23/2020 143162 CPEC Agate 115 kV Reactor 2020 ITP $571,200 $0

210592 1/21/2021 112509 WR/EKC

Wolf Creek -

Blackberry 345kV

Terminal Equipment

2019 ITP $10,056,365 $0

69 Upgrade(s) Issued $375,323,274 $0

Table 2: NTCs Issued

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NTCS WITHDRAWN

Figure 3: NTCs Withdrawn

NTC

ID

NTC

WITHDRAWN

DATE


STUDY

COST

ESTIMATE OF

WITHDRAWN

UPGRADES

210571 11/12/2020 51757 KCPL/EM Crosstown 161 kV

Terminal Upgrades 2018 ITPNT $1,120,000

210571 11/12/2020 51758 KCPL/EM Blue Valley 161 kV

Terminal Upgrades 2018 ITPNT $1,400,000

210571 11/12/2020 51759 KCPL/EM Blue Valley - Crosstown

161kV Ckt1 2018 ITPNT $36,644

210572 11/12/2020 51521 OPPD S964 69 kV Cap Bank 2016 ITPNT $722,660

4 Upgrade(s) Withdrawn $3,279,304

Table 3: NTCs Withdrawn

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PORTFOLIO SUMMARY

SPP staff solicits quarterly feedback from the project owners to determine the progress of each approved

transmission project. This quarterly report charts the progress of projects approved by the SPP Board or

through a FERC filed service agreement under the SPP OATT. Projects included in the portfolio are:

1. Upgrades required to satisfy requests for transmission service (TS)

2. Upgrades required to satisfy requests for generator interconnection (GI)

3. Approved projects from the Integrated Transmission Planning Assessment (ITP)

4. Upgrades within approved Balanced Portfolios2 (BP)

5. Approved high priority upgrades (HP)

6. Endorsed Sponsored Upgrades (SP)

7. Approved Interregional Projects3 (IR)

8. Approved projects from the 20-Year Assessment (ITP20)

9. Approved projects from Generator Retirement Process (GR)

This report will document changes over the previous quarter to report on projects captured in the

Quarterly Project Tracking Portfolio as well as new projects added from various processes listed above. A

summary of the project portfolio is also included.

Figure 3: Total Active Portfolio (Millions)

2 There are currently no Generator Retirement, Balanced Portfolio or Interregional projects included in Quarterly Project Tracking.

54 of 72



Figure 4: Upgrade by Type Cost Summary3

Figure 5: Estimated Cost for Upgrades by In-Service Year

3 Line mileage not available for all upgrade categories.

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Figure 6: Estimated Cost of Upgrades Completed in Past 4 Quarters4

Figure 7: Number of Upgrades Completed in Past Four Quarters

4 Figures 6 and 7 include Network Upgrades not yet confirmed as completed. Note that the previous quarter’s updated results are

listed as the Transmission Owners may make adjustments to final costs and status of projects completed during the year.

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PROJECT STATUS SUMMARY

SPP assigns a project status to all Network Upgrades based on the projected in-service dates provided by

the DTOs relative to the Need Date determined for the project. Project status definitions are provided

below:

Closed Out: Upgrade is operation, all project activities are complete, & all close-out requirements

fulfilled in accordance with Business Practice 7060. These upgrades will not appear in future

Quarterly Project Tracking reports

Complete: Upgrade is operation and all project activities are complete

Delayed: Projected In-Service Date beyond Need Date; interim mitigation provided or project

may change but time permits the implementation of project

Identified: Upgrade identified and included in Board approved study results

In Service: Upgrade is operational, but not all project activities are complete

On Schedule < 4: On Schedule within 4-year horizon

On Schedule > 4: On Schedule beyond 4-year horizon

Re-evaluation: Project active; pending re-evaluation

RFP Issued: Request for proposal has been issued for competitive upgrade

RFP Pending: Request for proposal issuance for a competitive upgrade is pending

NTC Commitment Window: NTC/NTC-C issued, still within the 90-day written commitment to

construct window and no commitment received

NTC-C Project Estimate Window: Within the NTC-C Project Estimate (CPE) window

Figure 8: Portfolio Project Status (Millions)

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OUT-OF-BANDWIDTH PROJECTS

In adherence to the Business Practice 7060, SPP reports projects that have updated cost values that

exceed their established baseline values based upon a ±20% bandwidth. Variances are determined by

total project cost. The following projects with a cost estimate greater than $5 million were identified as

having exceeded the ±20% bandwidth requirement during the reporting period. Tables below provide

summary information and lists cost detail for out-of-bandwidth projects identified during the reporting

quarter.

PID Project Name Owner NTC Source

Study Upgrade Type In-Service Date

41202 Line - Tulsa Southeast -

E.61st 138 kV Rebuild AEP 2017 ITPNT

Regional

Reliability 12/20/2019

31021

Line - Mustang -

Seminole 115 kV Ckt 1

New Line

SPS 2016 ITPNT Regional

Reliability 12/15/2020

Table 3: Out-of-Bandwidth Project Summary

PID

Baseline

Cost

Estimate

Baseline Cost

Estimate Year

Baseline Cost

Estimate with

Escalation

Latest

Estimate or

Final Cost

$ Variance Variance %

41202 $6,014,381 2017 $6,318,859 $8,151,314 $1,832,455 29.0%

31021 $19,736,026 2016 $21,784,880 $16,064,921 -$5,719,959 -26.3%

Table 4: Out-o- f-Bandwidth Cost Detail

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RESPONSIVENESS REPORT

The table and figures below provide insight into the responsiveness of DTOs constructing Network

Upgrades within SPP in the Quarterly Project Tracking Report. Note: Network Upgrades with statuses of

“Suspended”, “Re-evaluation”, “Within NTC Commitment Window”, “Within NTC-C Project Estimate

Window”, and “Within RFP Response Window” were excluded from this analysis.

Project

Owner

Number

of

Upgrades

Number

of

Upgrades

Reviewed

Reviewed

%

In-Service

Date

Changes

ISD

Change %

Cost

Changes

Cost

Change

%

AEP 22 21 95.5% 1 10.0% 8 30.0%

BEPC 4 4 100.0% 1 7.7% 1 7.7%

CBPC 2 0 0.0% 0 0.0% 0 0.0%

CPEC 1 1 100.0% 0 0.0% 1 0.0%

CUS 2 2 100.0% 0 0.0% 2 100.0%

EDE 4 1 25.0% 0 0.0% 0 0.0%

EREC 5 3 60.0% 3 57.1% 4 57.1%

GHP 1 0 0.0% 0 0.0% 0 0.0%

GMO/EMW 4 3 75.0% 0 0.0% 1 0.0%

GRDA 4 4 100.0% 0 0.0% 4 0.0%

KCPL/EM 12 11 91.7% 0 0.0% 6 50.0%

KPP 1 1 100.0% 1 100.0% 1 100.0%

MRES 1 1 100.0% 0 0.0% 1 0.0%

MWE 1 1 100.0% 0 0.0% 0 0.0%

NPPD 41 3 7.3% 3 4.5% 0 0.0%

NWE 4 2 50.0% 0 0.0% 2 0.0%

OGE 26 15 57.7% 5 14.6% 3 0.0%

OPPD 10 10 100.0% 1 5.6% 0 0.0%

SEPC 9 8 88.9% 3 50.0% 4 25.0%

SPS 103 81 78.6% 0 0.0% 74 53.4%

TBD 12 3 25.0% 0 0.0% 0 0.0%

TSMO 1 1 100.0% 0 0.0% 0 0.0%

TSOK 1 1 100.0% 0 100.0% 1 100.0%

WAPA 12 9 75.0% 0 16.7% 0 16.7%

WFEC 52 8 15.4% 4 3.4% 8 6.8%

WR/EKC 26 25 96.2% 9 20.0% 8 33.3%

Total 361 219 60.66% 31 8.59% 129 35.73%

Table 5: Responsiveness Summary

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Figure 9: In-Service Date Changes

Figure 10: Cost Changes

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ITP20 UPGRADES

ITP20 assessments were performed in 2010 and 2013. While the projects proposed by those studies are

incorporated into the STEP Project List, they were not included in SPP’s project tracking effort as part of

the Quarterly Tracking Report prior to Q1 2019. A list of active ITP20 projects will be maintained in the

STEP Report and Quarterly Project Tracking Report lists going forward. The current ITP20 projects are

listed in the table below.

Project ID Upgrade

ID Owner Upgrade Name

RTO Determined

Need Date

Latest Cost

Estimate

30401 50492 TBD Cass Co. - S.W. Omaha (aka S3454)

345 kV Ckt1 1/1/2033 $33,126,800

30599 50769 AEP South Fayetteville 345/161 kV

Transformer Ckt1 1/1/2033 $12,600,000

30599 50770 TBD Chamber Springs - South Fayetteville

345 kV Ckt1 1/1/2033 $21,295,800

30600 50771 GMO Maryville 345/161 kV Transformer

Ckt1 1/1/2033 $12,600,000

30601 50772 KCPL Nashua 345/161 kV Transformer

Upgrade Ckt11 1/1/2033 $12,600,000

30602 50773 TBD Keystone - Red Willow 345 kV Ckt1 1/1/2033 $130,141,000

30603 50774 TBD Tolk - Tuco 345 kV Ckt1 1/1/2033 $75,718,400

30604 50775 SEPC Holcomb 345/115 kV Transformer

Ckt2 1/1/2033 $12,600,000

30605 50776 TBD Neosho - Wolf Creek 345 kV Ckt1 1/1/2033 $117,126,900

30606 50777 TBD Clinton - Truman 161 kV Ckt1

Reconductor 1/1/2033 $15,701,325

30606 50778 TBD North Warsaw - Truman 161 kV Ckt1

Reconductor 1/1/2033 $1,082,850

30608 50779 WR Auburn 345/115 kV Transformer Ckt2 1/1/2033 $12,600,000

30608 50780 TBD Auburn - Swissvale 345 kV Ckt1

Voltage Conversion 1/1/2033 $20,112,700

30608 50781 TBD Auburn - Jeffrey EC 345 kV Ckt1

Voltage Conversion 1/1/2033 $35,493,000

30607 50782 OGE Muskogee/Pecan Creek 345 kV

Terminal Upgrades 1/1/2033 $34,605,675

Total $547,404,450

Table 6: ITP20 Upgrades

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APPENDIX 1

(See accompanying list of Quarterly Project Tracking Projects)

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200397 242 10308 WFEC OK Elmore - Paoli 69 kV Ckt 1 Rebuild Regional Reliability ITP 3/1/2022 6/1/2009 5/17/2016 2016 ITPNT $3,240,000 2016 $3,665,763 $3,240,000 $4,171,494 Delay - Mitigation 69 10.8

200229 772 11017 SPS TXCarlisle Interchange - Wolfforth Interchange 230 kV

Ckt 1Regional Reliability ITP 3/27/2018 6/1/2017 9/10/2013 2013 ITPNT $32,429,240 2013 $36,690,708 $31,474,329 $31,474,329 Complete 230 16.8

200397 844 11113 WFEC OK Sara Road - Sunshine Canyon 69 kV Ckt 1 Rebuild Regional Reliability ITP 12/31/2019 6/1/2020 5/17/2016 2016 ITPNT $4,725,000 2016 $5,088,308 $4,725,000 $643,784 On Schedule < 4 69 10

200256 856 11127 SPS TX Centre St. - Hereford NE 115 kV Ckt 1 Regional Reliability ITP 4/6/2018 6/1/2014 2/19/2014 2014 ITPNT $9,247,136 2014 $10,207,108 $9,543,280 $9,509,428 Complete 115 7.8

20097 938 11239 TSMO MO Nebraska City - Mullin Creek 345 kV (GMO) High Priority HP 12/15/2016 6/1/2017 7/23/2010 Priority Projects $81,407,015 2015 $83,442,190 $76,578,565 Closed Out 345 65

20104 947 11261 AEP OKBROKEN ARROW NORTH - SOUTH TAP - ONETA

138KV CKT 1 #2Transmission Service TS 5/25/2016 6/1/2015 8/25/2010 SPP-2008-AGP1-AFS-9 $6,072,000 2014 $6,379,395 $6,072,000 Closed Out 138 4.33

20130 1036 11372 SPS TX Soncy Tap 115 kV - New Soncy 115 kV Regional Reliability ITP 12/31/2018 6/1/2015 2/14/2011 2010 STEP $929,500 2014 $1,025,994 $6,415,698 $4,088,429 Complete 115 1.04

200297 1139 11501 SPS TXAllen Substation - Lubbock South Interchange 115

kV Ckt 1Regional Reliability TS 4/26/2019 6/1/2019 5/5/2015 SPP-2012-AG3-AFS-9 $1,164,782 2015 $1,285,701 $186,265 $186,265 Complete 115

200369 1142 11506 SPS TXCanyon East Sub - Randall County Interchange 115

kV Ckt 1 RebuildRegional Reliability TS 3/20/2020 2/1/2014 2/12/2016 SPP-2011-AG3-AFS-11 $12,806,065 2016 $14,135,500 $6,669,003 $5,534,931 Complete 115 18.5

20080 30201 50208 NPPD NE CLARKS 115KV Regional Reliability ITP 6/1/2018 11/1/2012 2/8/2010 2009 STEP $700,000 2014 $772,669 $700,000 Delay - Mitigation 115

20080 30203 50210 NPPD NE ONEILL 115KV Regional Reliability ITP 7/1/2018 11/1/2012 2/8/2010 2009 STEP $700,000 2014 $772,669 $1,739,903 $1,739,903 Closed Out 115

200253 30374 50441 NPPD NE Neligh 345/115 kV Substation Regional Reliability ITP 6/8/2018 6/1/2016 2/19/2014 2014 ITPNT $10,082,325 2017 $10,334,383 $10,281,412 $10,381,296 Closed Out 345/115

200220 30375 50442 NPPD NE Cherry Co. - Gentleman 345 kV Ckt 1 Regional Reliability ITP 4/1/2024 1/1/2018 3/11/2013 2012 ITP10 $204,236,579 2020 $209,342,493 $204,236,579 Delay - Mitigation 345 100.7

200220 30375 50444 NPPD NE Cherry Co. Substation 345 kV Regional Reliability ITP 4/1/2024 1/1/2018 3/11/2013 2012 ITP10 $13,692,681 2020 $14,034,998 $13,692,681 Delay - Mitigation 345

200220 30375 50445 NPPD NE Cherry Co. - Holt Co. 345 kV Ckt 1 Regional Reliability ITP 4/1/2024 1/1/2018 3/11/2013 2012 ITP10 $232,903,698 2020 $238,726,290 $232,903,698 Delay - Mitigation 345 124.3

200220 30375 50446 NPPD NE Holt Co. Substation 345 kV Regional Reliability ITP 4/1/2022 1/1/2018 3/11/2013 2012 ITP10 $12,543,756 2020 $12,857,350 $12,543,756 Delay - Mitigation 345

200395 31068 50447 SPS TX Tuco - Yoakum 345 kV Ckt 1 Regional Reliability ITP 6/1/2020 6/1/2017 5/17/2016 2016 ITPNT $128,473,352 2016 $141,810,542 $123,050,722 $123,050,722 Complete 345 107

210484 31068 50451 SPS TX Yoakum 345/230 kV Ckt 1 Transformer Regional Reliability HP 5/31/2019 6/1/2017 4/27/2018 HPILS $5,047,344 2016 $5,435,437 $10,203,846 $10,203,846 Complete 345/230

200309 30376 50457 SPS NM/TX Hobbs - Yoakum 345 kV Ckt 1 High Priority HP 5/30/2019 6/1/2020 12/3/2014 HPILS $90,628,750 2014 $102,538,112 $80,649,240 $80,649,240 Complete 345 52

30401 50492 TBD NE Cass Co. - S.W. Omaha (aka S3454) 345 kV Ckt1 ITP20 ITP20 1/1/2033 2013 ITP20 $0 $33,126,800 Identified 345

200384 30444 50539 SPS TX Cochran 115 kV Cap Bank Regional Reliability TS 12/31/2018 6/1/2016 4/20/2016 DPA-2013-JUN-342 $1,808,805 2016 $1,900,376 $2,735,646 $2,735,646 Complete 115

200214 30451 50546 SPS NM Atoka - Eagle Creek 115 kV Ckt 1 Regional Reliability ITP 12/31/2018 6/1/2015 2/20/2013 2013 ITPNT $20,808,304 2013 $23,542,686 $21,687,027 $24,272,586 Complete 115 22.1

200229 30469 50564 SPS NM Market St. - South Portales 115 kV Ckt 1 Regional Reliability ITP 7/13/2018 6/1/2018 9/10/2013 2013 ITPNT $6,498,682 2013 $7,352,662 $4,655,778 $4,850,346 Complete 115 6

200229 30469 50565 SPS NM Market St. - Portales 115 kV Ckt 1 Regional Reliability ITP 2/7/2018 6/1/2018 9/10/2013 2013 ITPNT $15,394,429 2013 $17,417,383 $14,407,777 $15,189,905 Complete 115 10.4

200200 30491 50600 WFEC OK Hazelton 69 kV Capacitor Regional Reliability TS 3/1/2017 1/1/2013 3/1/2013 DPA-2012-MAR-143-147 $237,000 2013 $261,604 $735,000 Complete 69

200400 30496 50609 NPPD NE Bobcat Canyon - Scottsbluff 115 kV Ckt 1 Regional Reliability ITP 10/26/2017 6/1/2014 8/17/2016 2014 ITPNT $26,027,015 2016 $26,677,690 $21,204,480 $21,201,741 Closed Out 115 23

200234 30503 50628 WFEC OK Hazelton Capacitor 69 kV #2 Regional Reliability TS 3/1/2017 6/1/2017 10/28/2013DPA-2012-MAR-151-154-161-JUL-218-SEP-243$185,004 2013 $204,210 $0 Complete 69

200262 30510 50637 SPS TX Mustang - Shell CO2 115 kV Ckt 1 Transmission Service TS 4/29/2019 6/1/2015 4/9/2014 SPP-2011-AG3-AFS-11 $15,473,119 2014 $17,506,414 $18,699,621 $18,699,621 Complete 115 7.71

200296 30560 50698 WR/EKC KS Sumner County - Viola 138 kV Ckt 1 Zonal Reliability ITP 5/11/2020 6/1/2019 9/2/2014 2014 ITPNT $34,432,188 2019 $35,292,993 $34,432,188 In Service 138 28

200245 30563 50702 WFEC OK Sandy Corner 138 kV Cap Bank Regional Reliability ITP 6/1/2017 6/1/2017 2/19/2014 2014 ITPNT $504,000 2014 $542,753 $504,000 Complete 138

200246 30573 50718 AEP LA Broadmoor - Fort Humbug 69 kV Ckt 1 Rebuild Regional Reliability ITP 6/21/2017 6/1/2019 2/19/2014 2014 ITPNT $6,695,986 2014 $7,210,844 $6,695,986 $4,352,349 Closed Out 69 1.7

200256 30577 50723 SPS NM CV Pines - Price 115 kV Ckt 1 Rebuild Regional Reliability ITP 1/30/2018 6/1/2017 2/19/2014 2014 ITPNT $4,158,668 2014 $4,590,391 $0 Complete 115 3

200256 30577 50724 SPS NM Capitan - CV Pines 115 kV Ckt 1 Rebuild Regional Reliability ITP 1/30/2018 6/1/2017 2/19/2014 2014 ITPNT $5,415,053 2014 $5,977,205 $1,741,345 $1,727,131 Closed Out 115 5 5

200242 30584 50740 WR/EKC KS Elk Junction - Sedan 69 kV Ckt 1 Rebuild Zonal Reliability ITP 9/11/2019 6/1/2018 2/19/2014 2014 ITPNT $19,015,228 2016 $20,477,321 $15,906,575 $15,906,575 Closed Out 69 19

200294 30596 50757 NPPD NE Broken Bow Wind - Ord 115 kV Ckt 1 Regional Reliability ITP 3/1/2018 6/1/2014 8/26/2014 2014 ITPNT $28,018,664 2018 $28,018,664 $23,583,074 $29,418,126 Closed Out 115 42

200294 30596 50760 NPPD NE North Loup - Ord 115 kV Ckt 1 Regional Reliability ITP 6/1/2018 6/1/2014 8/26/2014 2014 ITPNT $516,009 2018 $516,009 $548,029 $516,009 Closed Out 115

30599 50769 AEP AR South Fayetteville 345/161 kV Transformer Ckt1 ITP20 ITP20 1/1/2033 2013 ITP20 $0 $12,600,000 Identified 345/161

30599 50770 TBD AR Chamber Springs - South Fayetteville 345 kV Ckt1 ITP20 ITP20 1/1/2033 2013 ITP20 $0 $21,295,800 Identified 345 18

30600 50771 GMO/EMW MO Maryville 345/161 kV Transformer Ckt1 ITP20 ITP20 1/1/2033 2013 ITP20 $0 $12,600,000 Identified 345/161

30601 50772 KCPL/EM KS Nashua 345/161 kV Transformer Upgrade Ckt11 ITP20 ITP20 1/1/2033 2013 ITP20 $0 $12,600,000 Identified 345/161

30602 50773 TBD NE Keystone - Red Willow 345 kV Ckt1 ITP20 ITP20 1/1/2033 2013 ITP20 $0 $130,141,000 Identified 345 110

30603 50774 TBD TX Tolk - Tuco 345 kV Ckt1 ITP20 ITP20 1/1/2033 2013 ITP20 $0 $75,718,400 Identified 345 64

30604 50775 SEPC KS Holcomb 345/115 kV Transformer Ckt2 ITP20 ITP20 1/1/2033 2013 ITP20 $0 $12,600,000 Identified 345/115

30605 50776 TBD KS Neosho - Wolf Creek 345 kV Ckt1 ITP20 ITP20 1/1/2033 2013 ITP20 $0 $117,126,900 Identified 345 86.4

30606 50777 TBD MO Clinton - Truman 161 kV Ckt1 Reconductor ITP20 ITP20 1/1/2033 2013 ITP20 $0 $15,701,325 Identified 161 29

30606 50778 TBD MO North Warsaw - Truman 161 kV Ckt1 Reconductor ITP20 ITP20 1/1/2033 2013 ITP20 $0 $1,082,850 Identified 161 2

30608 50779 WR/EKC KS Auburn 345/115 kV Transformer Ckt2 ITP20 ITP20 1/1/2033 2013 ITP20 $0 $12,600,000 Identified 345/115

30608 50780 TBD KS Auburn - Swissvale 345 kV Ckt1 Voltage Conversion ITP20 ITP20 1/1/2033 2013 ITP20 $0 $20,112,700 Identified 345 17

30608 50781 TBD KS Auburn - Jeffrey EC 345 kV Ckt1 Voltage Conversion ITP20 ITP20 1/1/2033 2013 ITP20 $0 $35,493,000 Identified 345 30

30607 50782 OGE OK Muskogee/Pecan Creek 345 kV Terminal Upgrades ITP20 ITP20 1/1/2033 2013 ITP20 $0 $34,605,675 Identified

200309 30638 50820 SPS NM Kiowa - North Loving 345 kV Ckt 1 High Priority HP 6/1/2018 6/1/2018 12/3/2014 HPILS $25,716,516 2014 $28,386,222 $24,131,196 $25,905,391 Complete 345 20.4

200282 30675 50869 SPS NM China Draw - Yeso Hills 115 kV Ckt 1 High Priority HP 5/3/2019 6/1/2018 5/19/2014 HPILS $14,583,586 2014 $16,499,989 $4,547,820 $4,547,820 Complete 115 18.4

200309 30639 50871 SPS NM Kiowa - Potash Junction 345/115 kV Ckt 1 High Priority HP 4/30/2018 6/1/2018 12/3/2014 HPILS $2,176,451 2014 $2,402,395 $2,951,837 $5,136,295 Complete 345 2

200282 30694 50877 SPS NM Ponderosa 115 kV Substation High Priority HP 6/1/2017 6/1/2018 5/19/2014 HPILS $996,485 2014 $1,073,105 $1,109,068 $1,109,068 Closed Out 115

NTC/GIA suspended

Q2 2021 Quarterly Project Tracking Appendix 1 - Project Status Definitions

Upgrade identified and included in Board approved study results

Upgrade is in service, but not all project activities are complete

NTC/NTC-C issued, still within the 90 day written commitment to construct window and no commitment received

Within the NTC-C Project Estimate (CPE) window

On Schedule within 4-year horizon

On Schedule beyond 4-year horizonON SCHEDULE > 4

IDENTIFIED

IN SERVICE

CLOSED OUT

COMPLETE

Upgrade is operation, all project activities are complete, & all close-out requirements fulfilled

Upgrade is operation and all project activities are complete

Behind schedule, interim mitigation provided or project may change but time permits

SUSPENDED

NTC - COMMITMENT WINDOW

NTC-C PROJECT ESTIMATE WINDOW

ON SCHEDULE < 4

DELAY - MITIGATION

Request for proposal issuance for a competitive upgrade is pending

Request for proposal has been issued for competitive upgradeRFP ISSUED

RFP PENDING

RE-EVALUATION NTC/NTC-C active; pending re-evaluation

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200474 30694 50879 SPS NM Ponderosa Tap 115 kV Substation High Priority HP 6/1/2017 6/1/2018 2/27/2018 HPILS $4,174,446 2014 $4,495,422 $547,377 $547,377 Closed Out 115 0.2

200309 30717 50883 SPS NM China Draw - North Loving 115 kV Ckt 1 High Priority HP 5/25/2015 6/1/2015 12/3/2014 HPILS $13,283,227 2014 $13,615,308 $11,260,834 $11,070,902 Closed Out 115 19.7

200277 30678 50889 NPPD NE Thedford 345/115 kV Transformer High Priority HP 4/1/2024 6/1/2016 5/19/2014 HPILS $9,306,000 2014 $11,061,910 $9,797,157 Delay - Mitigation 345/115

200395 30692 50920 SPS TX Seminole 230/115 kV #1 Transformer Regional Reliability ITP 12/28/2018 6/1/2017 5/17/2016 2016 ITPNT $3,621,405 2016 $3,804,739 $3,355,302 $3,355,302 Complete 230/115

200395 30692 50921 SPS TX Seminole 230/115 kV #2 Transformer Regional Reliability ITP 4/30/2019 6/1/2017 5/17/2016 2016 ITPNT $3,621,405 2016 $3,899,857 $2,587,642 $2,587,642 Complete 230/115

200421 30693 50922 SPS TX Wolfforth 230/115 kV Ckt 1 Transformer Regional Reliability TS 4/15/2021 6/1/2021 1/12/2017 SPP-2015-AG2-AFS-3 $3,510,969 2017 $3,875,453 $3,452,932 On Schedule < 4 230/115

200411 30694 50923 SPS NM Ponderosa - Ponderosa Tap 115 kV Ckt 1 High Priority HP 6/1/2017 6/1/2018 8/17/2016 HPILS $8,030,702 2016 $8,231,470 $10,130,206 $10,130,206 Closed Out 115 9.3

200420 30699 50943 SPS TX Northwest - Rolling Hills 115 kV Rebuild Ckt 1 Regional Reliability TS 5/15/2021 6/1/2021 1/12/2017 SPP-2015-AG1-AFS-6 $4,514,434 2017 $4,983,090 $4,983,968 On Schedule < 4 115 7.2

200360 30914 50952 SPS NM IMC #1 Tap - Livingston Ridge 115 kV Ckt 1 Rebuild Regional Reliability ITP 3/22/2019 6/1/2015 12/7/2015 2015 ITPNT $5,700,000 2018 $5,842,500 $4,706,858 $4,354,881 Complete 115 9.5 9.3

200360 30914 50955 SPS NM Ponderosa Tap - Whitten 115 kV Ckt 1 Rebuild Regional Reliability ITP 1/26/2018 6/1/2015 12/7/2015 2015 ITPNT $2,280,000 2018 $2,280,000 $2,251,591 $1,987,893 Complete 115 3.92

200360 30914 50957 SPS NMIntrepid West - Potash Junction 115 kV Ckt 1

RebuildRegional Reliability ITP 3/22/2019 6/1/2015 12/7/2015 2015 ITPNT $2,455,000 2018 $2,516,375 $2,355,090 $2,332,087 Complete 115 1.5

200360 30914 50958 SPS NM IMC #1 Tap - Intrepid West 115 kV Ckt 1 Rebuild Regional Reliability ITP 3/22/2019 6/1/2015 12/7/2015 2015 ITPNT $3,121,473 2018 $3,199,510 $2,790,027 $2,790,027 Complete 115 3.9

200282 30756 50968 SPS NM Battle Axe 115 kV Substation High Priority HP 12/4/2015 6/1/2018 5/19/2014 HPILS $2,964,499 2014 $3,038,611 $2,664,288 $2,664,288 Closed Out 115

200282 30675 50988 SPS NM Yeso Hills 115 kV Substation High Priority HP 5/3/2019 6/1/2018 5/19/2014 HPILS $1,046,485 2014 $1,184,002 $383,797 $383,797 Complete 115

200455 30755 50992 SPS TX Tuco 230/115 kV Ckt 1 Transformer Transmission Service ITP 6/15/2019 6/1/2018 5/12/2017 2017 ITPNT $3,800,415 2015 $4,194,947 $103,149 $103,149 Complete 230/115

200277 30678 51002 NPPD NE Thedford 345 kV Terminal Upgrades High Priority HP 4/1/2024 6/1/2016 5/19/2014 HPILS $930,800 2014 $1,106,429 $913,714 Delay - Mitigation 345

200262 30766 51039 SPS TXYoakum County Interchange 230/115 kV Ckt 1

TransformerTransmission Service TS 3/15/2019 6/1/2019 4/9/2014 SPP-2011-AG3-AFS-11 $3,632,101 2014 $4,109,389 $2,346,404 $2,346,404 Complete 230/115

200262 30766 51050 SPS TXYoakum County Interchange 230/115 kV Ckt 2

TransformerRegional Reliability TS 5/7/2019 6/1/2019 4/9/2014 SPP-2011-AG3-AFS-11 $3,432,506 2014 $3,883,565 $3,201,912 $3,201,912 Complete 230/115

30786 51069 NPPD NE Dixon County 230kV Substation Generation Interconnection GI 10/1/2018 GI STUDIES $0 $6,404,189 In Service 230

30787 51070 NPPD NE Twin Church - Dixon County 230kV Line Upgrade Generation Interconnection GI 11/1/2018 GI STUDIES $0 $61,774 In Service 230

200382 30809 51096 AEP OK Keystone Dam - Wekiwa 138 kV Ckt 1 Rebuild Regional Reliability TS 6/11/2020 6/1/2021 4/12/2016 SPP-2014-AG1-AFS-6 $4,319,501 2016 $4,767,921 $6,445,009 $6,193,883 Complete 138 2 2 2

200395 30844 51140 SPS TX Amoco - Sundown 230 kV Terminal Upgrades Regional Reliability ITP 2/20/2019 1/1/2019 5/17/2016 2016 ITPNT $1,771,222 2016 $1,907,412 $714,760 $714,760 Complete 230

200326 30866 51170 SPS TX Amarillo South 230 kV Terminal Upgrades Regional Reliability ITP 4/1/2020 2/18/2015 2015 ITPNT $31,198 2015 $36,180 $0 On Schedule < 4 230

200318 30883 51200 NPPD NE Bassett 115 kV Substation Regional Reliability ITP 6/1/2018 6/1/2016 2/18/2015 2015 ITPNT $5,163,000 2015 $5,559,986 $127,220 $192,099 Closed Out 115 0.1

200326 30888 51206 SPS TX Lynn County 115/69 kV Ckt 1 Transformer Regional Reliability ITP 5/15/2019 6/1/2019 2/18/2015 2015 ITPNT $1,699,629 2015 $1,876,072 $2,317,591 $2,317,591 Complete 115/69

200343 30912 51235 SPS KS Stevens Co. 345 kV Substation Regional Reliability ITP 6/1/2018 6/1/2015 8/13/2015 2015 ITPNT $13,831,957 2015 $14,895,505 $13,867,859 $13,433,258 Complete 345 0.1

200360 30914 51250 SPS NM National Enrichment Plant - Targa 115 kV Ckt 1 Regional Reliability ITP 3/20/2019 6/1/2015 12/7/2015 2015 ITPNT $1,874,116 2018 $1,920,969 $1,340,580 $1,095,981 Complete 115 3

200326 30888 51270 SPS TX Lynn County 115 kV Terminal Upgrades Regional Reliability ITP 5/15/2019 6/1/2019 2/18/2015 2015 ITPNT $19,425 2015 $21,442 $298,747 $298,747 Complete 115

200318 30883 51277 NPPD NE Bassett 115 kV Cap Bank Regional Reliability ITP 6/1/2018 6/1/2016 2/18/2015 2015 ITPNT $902,000 2015 $971,355 $3,831,068 $5,563,439 Closed Out 115

30934 51292 NPPD NE Hoskins - Dixon County 230kV Line Upgrade Generation Interconnection GI 11/1/2018 GI STUDIES $0 $308,869 In Service 230

30946 51318 BEPC SD Lower Brule - Witten 230 kV Ckt 1 Regional Reliability ITP 1/1/2018 12/1/2016 IS Integration $31,500,000 2014 $34,770,106 $31,500,000 Re-evaluation 230

30946 51319 BEPC SD Lower Brule 230 kV Substation Regional Reliability ITP 1/1/2018 12/1/2016 IS Integration $4,500,000 2014 $4,967,158 $4,500,000 Re-evaluation 230

30946 51320 BEPC SD Lower Brule - Witten 230 kV Terminal Upgrades Regional Reliability ITP 1/1/2018 12/1/2016 IS Integration $2,000,000 2014 $2,207,626 $2,000,000 Re-evaluation 230

200376 30953 51333 SEPC KS Lane Scott 115 kV Cap Bank Regional Reliability TS 9/19/2019 6/1/2017 7/12/2016 DPA-2015-MARCH-494 $3,852,342 2016 $4,148,551 $4,008,888 $4,008,888 Closed Out 115

30959 51338 WR/EKC KSTap Emporia Energy Center - Wichita 345kV (GEN-

2014-001 NU)Generation Interconnection GI 5/1/2021 GI STUDIES $0 $3,115,802 On Schedule < 4

30956 51339 NPPD NE Antelope 115kV - Add terminal for GEN-2013-032 Generation Interconnection GI 5/1/2017 GI STUDIES $0 $2,868,775 In Service

200384 30971 51358 SPS TX Cochran - Whiteface Tap 69 kV Ckt 1 Rebuild Regional Reliability TS 11/28/2018 6/1/2016 4/20/2016 DPA-2013-JUN-342 $2,254,282 2016 $2,368,405 $2,481,675 $2,481,675 Complete 69

30959 51360 WR/EKC KSTap Emporia Energy Center - Wichita 345kV (GEN-

2014-001 TOIF)Generation Interconnection GI 8/1/2021 GI STUDIES $0 $1,106,149 On Schedule < 4

200365 30987 51406 SPS NM Cunningham - Monument Tap 115 kV Ckt 1 Rebuild Regional Reliability TS 12/20/2019 6/1/2021 1/12/2016 SPP-2014-AG1-AFS-6 $5,129,356 2016 $5,523,755 $5,344,209 $5,344,209 Complete 115

200366 30988 51408 SPS NM Eddy Co. 230 kV Bus Tie Transmission Service TS 12/20/2019 10/1/2017 1/12/2016 SPP-2013-AG3-AFS-6 $19,732,223 2020 $19,732,223 $20,587,544 $20,587,544 Complete 230 0.2

200365 30989 51409 SPS NM Potash Junction 230 kV Terminal Upgrade Regional Reliability TS 6/1/2018 6/1/2018 1/12/2016 SPP-2014-AG1-AFS-6 $63,251 2016 $66,453 $0 Complete 230

200365 30991 51411 SPS NMNational Enrichment Plant - Teague 115 kV Ckt 1

RebuildRegional Reliability TS 12/14/2018 6/1/2018 1/12/2016 SPP-2014-AG1-AFS-6 $4,915,370 2016 $5,164,211 $217,082 $217,082 Complete 115

200397 30995 51430 WFEC OK Harrisburg 69 kV Cap Bank Regional Reliability ITP 12/31/2017 6/1/2017 5/17/2016 2016 ITPNT $450,000 2016 $461,250 $450,000 Re-evaluation 69

200395 30999 51436 SPS TX Potter Co. - Harrington 230 kV Terminal Upgrades Regional Reliability ITP 5/16/2019 6/1/2019 5/17/2016 2016 ITPNT $914,347 2016 $984,652 $1,196,324 $1,196,324 Complete 230

200395 31001 51438 SPS NMAgave Red Hills - Road Runner 115 kV Ckt 1 New

LineRegional Reliability ITP 3/20/2017 4/1/2020 5/17/2016 2016 ITPNT $443,866 2016 $454,963 $443,866 Complete 115 0.8

200395 31001 51440 SPS NMCuster Mountain - Road Runner 115 kV Ckt 1 New

LineRegional Reliability ITP 4/28/2017 4/1/2020 5/17/2016 2016 ITPNT $759,610 2016 $778,600 $237,381 $204,462 Complete 115 11

200392 31002 51444 OGE OK Lincoln - Meeker 138 kV Ckt 1 New Line (OGE) Regional Reliability ITP 7/31/2020 6/1/2017 5/17/2016 2016 ITPNT $750,000 2016 $827,860 $700,000 Complete 138

200397 31002 51445 WFEC OK Lincoln - Meeker 138 kV Ckt 1 New Line (WFEC) Regional Reliability ITP 7/31/2020 6/1/2017 5/17/2016 2016 ITPNT $6,000,000 2016 $6,622,877 $6,000,000 Complete 138

200386 31003 51446 AEP OK Northeastern Station 138 kV Terminal Upgrades Regional Reliability ITP 10/5/2016 6/1/2017 5/17/2016 2016 ITPNT $518,011 2016 $518,011 $518,011 $183,231 Closed Out 138

210496 31007 51450 SPS TX Sundown 230/115 kV Transformer Regional Reliability ITP 12/15/2020 6/1/2019 8/17/2018 2018 ITPNT $4,264,796 $0 $8,086,787 $8,086,787 Closed Out 230/115

200395 31008 51452 SPS NM Artesia Country Club Tap 115 kV Line Tap Regional Reliability ITP 12/17/2018 6/1/2017 5/17/2016 2016 ITPNT $336,134 2016 $353,151 $378,266 $378,266 Complete 115

31014 51467 NPPD NEFriend 115kV Substation - GEN-2014-039 Addition

(TOIF)Generation Interconnection GI 10/15/2017 GI STUDIES $0 $875,000 On Schedule < 4

31014 51468 NPPD NE Friend 115kV Substation - GEN-2014-039 Addition Generation Interconnection GI 10/15/2017 GI STUDIES $0 $4,300,000 On Schedule < 4

200407 31021 51478 SPS TX Mustang - Seminole 115 kV Ckt 1 New Line Regional Reliability ITP 12/15/2020 6/1/2017 8/17/2016 2016 ITPNT $15,007,492 2016 $16,565,463 $11,037,124 $11,037,124 Closed Out 115 19.7

200407 31021 51479 SPS TX Mustang 115 kV Terminal Upgrades Regional Reliability ITP 12/15/2020 6/1/2017 8/17/2016 2016 ITPNT $2,712,194 2016 $2,993,755 $2,629,398 $2,629,398 Closed Out 115 19.7

200407 31021 51480 SPS TX Seminole 115 kV Terminal Upgrades Regional Reliability ITP 12/15/2020 6/1/2017 8/17/2016 2016 ITPNT $2,016,340 2016 $2,225,662 $2,398,399 $2,398,399 Closed Out 115 19.7

200395 31022 51481 SPS TX Canyon East Tap - Randall 115 kV Ckt 1 Rebuild Regional Reliability ITP 5/16/2019 6/1/2017 5/17/2016 2016 ITPNT $4,804,292 2016 $5,173,697 $4,413,984 $4,413,984 Complete 115

200397 31065 51484 WFEC OK Cleo Junction 138 kV Terminal Upgrades Regional Reliability ITP 5/31/2023 6/1/2017 5/17/2016 2016 ITPNT $4,000,000 2016 $4,525,633 $4,000,000 Delay - Mitigation 138

200390 31025 51487 GRDA OK Sallisaw 161 kV Terminal Upgrades Regional Reliability ITP 6/1/2017 5/17/2016 2016 ITPNT $2,266,000 2016 $2,563,771 $2,266,000 Re-evaluation 161

200397 31041 51526 WFEC OK Driftwood 138 kV Substation Regional Reliability ITP 4/1/2022 6/1/2017 5/17/2016 2016 ITPNT $550,000 2016 $622,275 $600,000 Delay - Mitigation 138

200397 31041 51527 WFEC OK Driftwood 138/69 kV Transformer Regional Reliability ITP 4/1/2022 6/1/2017 5/17/2016 2016 ITPNT $3,000,000 2016 $3,394,225 $3,600,000 Delay - Mitigation 138/69

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200419 31042 51531 WFEC OK DeGrasse 138 kV Substation (WFEC) Regional Reliability ITP 12/1/2024 6/1/2017 12/27/2016 2016 ITPNT $1,400,000 2017 $1,545,338 $5,700,000 Delay - Mitigation 138 2

200395 31051 51549 SPS TX Terry Co. - Wolfforth 115 kV Terminal Upgrades Regional Reliability ITP 6/1/2018 4/1/2020 5/17/2016 2016 ITPNT $1,461,643 2016 $1,535,639 $598,335 $598,335 Complete 115

200386 31057 51558 AEP OK Army Ammo - McAlester 69 kV Ckt 1 Rebuild Zonal Reliability ITP 12/18/2019 6/1/2017 5/17/2016 2016 ITPNT $13,512,897 2016 $14,551,912 $11,805,970 $8,544,022 Complete 69

200386 31057 51559 AEP OKArmy Ammo - Savanna - Pittsburg 69 kV Ckt 1

RebuildZonal Reliability ITP 11/20/2022 6/1/2017 5/17/2016 2016 ITPNT $15,146,464 2016 $17,136,833 $15,595,092 Delay - Mitigation 69

200386 31057 51560 AEP OK Atoka - Atoka Pump - Pittsburg 69 kV Ckt 1 Rebuild Zonal Reliability ITP 11/20/2022 6/1/2017 5/17/2016 2016 ITPNT $21,668,582 2016 $24,516,011 $21,981,548 Delay - Mitigation 69

200420 31061 51565 SPS NM Livingston Ridge - Wipp 115 kV Ckt 1 Rebuild Regional Reliability TS 4/15/2021 6/1/2021 1/12/2017 SPP-2015-AG1-AFS-6 $264,157 2017 $291,580 $283,759 On Schedule < 4 115

200420 31063 51567 SPS NM Carlsbad - Pecos 115 kV Terminal Upgrades Regional Reliability TS 6/1/2021 6/1/2021 1/12/2017 SPP-2015-AG1-AFS-6 $767,347 2017 $847,008 $890,000 On Schedule < 4 115 0.03

200418 31042 51569 OGE OK DeGrasse 138 kV Substation (OGE) Regional Reliability ITP 4/17/2019 6/1/2017 12/27/2016 2016 ITPNT $7,723,383 2017 $8,114,379 $4,562,495 Complete 138

30786 51577 NPPD NE Dixon County 230kV Substation (TOIF) Generation Interconnection GI 11/1/2018 GI STUDIES $0 $501,197 In Service 230

30937 51602 SPS TXTUCO 230kV Switching Station GEN-2012-020

Addition (TOIF)Generation Interconnection GI 12/14/2018 GI STUDIES $0 $260,000 On Schedule < 4

30956 51610 NPPD NEAntelope 115kV - Add terminal for GEN-2013-032

(TOIF)Generation Interconnection GI 10/3/2018 GI STUDIES $0 $873,106 In Service

200444 31079 51623 SPS TX Tuco - Stanton 115 kV Terminal Upgrades Economic ITP 12/31/2018 1/1/2017 2/22/2017 2017 ITP10 $283,963 2017 $291,062 $0 In Service 115

200444 31081 51625 SPS TX Indiana - SP-Erskine 115 kV Terminal Upgrades Economic ITP 2/28/2020 1/1/2017 2/22/2017 2017 ITP10 $1,133,153 2017 $1,220,282 $940,000 Delay - Mitigation 115

200428 31085 51630 KCPL/EM MO Northeast - Charlotte - Crosstown 161 kV Reactor Economic ITP 3/1/2018 1/1/2018 2/22/2017 2017 ITP10 $500,000 2017 $512,500 $204,681 $204,681 Complete 161

200458 31086 51631 WR/EKC KS DePaul - Girard Jct 69 kV Regional Reliability TS 11/15/2018 12/31/2018 6/23/2017 DPA-2016-March-596 $2,908,572 2017 $2,981,286 $5,699,405 $5,699,405 Complete 69 1.71

200433 31144 51764 WFEC OK Tupelo 138 kV Terminal Upgrades Economic ITP 12/31/2021 1/1/2020 2/21/2017 2017 ITP10 $100,000 2017 $110,381 $410,000 Delay - Mitigation 138

200457 31175 51818 SPS TX Cox Interchange - Hale Co Interchange 115 kV Ckt 1 Regional Reliability TS 4/15/2021 6/1/2021 5/15/2017 SPP-2016-AG1-AFS-3 $13,355,250 2017 $14,741,697 $11,926,496 On Schedule < 4 115 19.7

200457 31176 51819 SPS TXHockley County Interchange 115 kV Terminal

UpgradesRegional Reliability TS 11/15/2019 6/1/2021 5/15/2017 SPP-2016-AG1-AFS-3 $228,066 2017 $239,612 $197,304 $199,390 Complete 115

200444 41189 61836 SPS TX Martin - Pantex North 115 kV Terminal Upgrades Economic ITP 3/15/2018 1/1/2017 2/22/2017 2017 ITP10 $324,392 2017 $332,502 $0 Complete 115

200444 41189 61837 SPS TXPantex South - Highland Tap 115 kV Terminal

UpgradesEconomic ITP 3/15/2018 1/1/2017 2/22/2017 2017 ITP10 $324,392 2017 $332,502 $0 Complete 115

200455 41192 61840 SPS TX Coulter 115 kV Terminal Upgrades Regional Reliability ITP 5/15/2020 6/1/2018 5/12/2017 2017 ITPNT $286,869 2017 $308,927 $276,699 $276,699 Closed Out 115

200455 41194 61844 SPS TX Plant X 230 kV Terminal Upgrades Regional Reliability ITP 12/31/2018 6/1/2018 5/12/2017 2017 ITPNT $217,734 2017 $223,177 $0 Delay - Mitigation 230

200455 41194 61845 SPS TX Sundown 230 kV Terminal Upgrades Regional Reliability ITP 12/31/2018 6/1/2018 5/12/2017 2017 ITPNT $360,540 2017 $369,554 $360,540 Delay - Mitigation 230

210496 41197 61850 SPS TXTerry County - LG Clauene 115 kV Terminal

UpgradesRegional Reliability ITP 12/31/2019 6/1/2019 8/17/2018 2018 ITPNT $888,216 2018 $910,421 $369,516 $369,516 Complete 115

200455 41198 61852 SPS TX Texas County 115 kV Terminal Upgrades #1 Regional Reliability ITP 12/31/2018 6/1/2018 5/12/2017 2017 ITPNT $98,639 2017 $101,105 $98,639 Delay - Mitigation 115

200455 41198 61853 SPS TX Texas County 115 kV Terminal Upgrades #2 Regional Reliability ITP 12/31/2018 6/1/2018 5/12/2017 2017 ITPNT $108,430 2017 $111,141 $108,430 Delay - Mitigation 115

200476 41200 61856 WAPA ND Williston 115 kV Terminal Upgrades Regional Reliability ITP 11/20/2017 6/1/2018 2/21/2018 2017 ITPNT $5,000 2017 $5,000 $5,000 $403 Complete 115

200446 41202 61858 AEP OK Tulsa Southeast - E.61st 138 kV Rebuild Regional Reliability ITP 12/20/2019 6/1/2018 5/12/2017 2017 ITPNT $6,014,381 2017 $6,318,859 $7,238,795 $8,151,314 Complete 138 1.8

200448 41209 61869 EDE MO Nichols – Republic North 69 kV Reconductor Regional Reliability ITP 4/13/2018 6/1/2018 5/12/2017 2017 ITPNT $4,050,000 2017 $4,151,250 $4,050,000 $5,263,657 Complete 69 10

200448 41209 61870 EDE MORepublic Hines Street - Republic North 69 kV

ReconductorRegional Reliability ITP 4/13/2018 6/1/2018 5/12/2017 2017 ITPNT $1,450,000 2017 $1,486,250 $1,450,000 $3,868,242 Complete 69 3.5

200448 41209 61871 EDE MORepublic East - Republic Hines Street 69 kV

ReconductorRegional Reliability ITP 4/13/2018 6/1/2018 5/12/2017 2017 ITPNT $800,000 2017 $820,000 $800,000 $3,278,100 Complete 69 1.6

200452 51236 71926 WAPA SD Roberts County 115 kV Substation Regional Reliability ITP 1/1/2019 6/1/2018 5/12/2017 2017 ITPNT $4,300,000 2017 $4,517,688 $3,957,000 Complete 115

200452 51236 71927 WAPA SD XFR - Roberts County 115/69 kV Transformer Regional Reliability ITP 9/30/2019 6/1/2018 5/12/2017 2017 ITPNT $1,200,000 2017 $1,260,750 $1,200,000 Complete 115

51239 71933 NPPD NEHolt County 345kV (Tap Grand Prairie - Grand Island

345kV) - GEN-2015-023 Addition (TOIF)Generation Interconnection GI 10/1/2020 GI STUDIES $0 $4,700,000 On Schedule < 4

51239 71934 NPPD NEHolt County 345kV (Tap Grand Prairie - Grand Island

345kV) - GEN-2015-023 Addition (NU)Generation Interconnection GI 11/1/2020 GI STUDIES $0 $5,900,000 On Schedule < 4 345

51241 71939 SEPC KSJohnson Corner 115kV - GEN-2015-021 Addition

(TOIF)Generation Interconnection GI 4/7/2020 GI STUDIES $0 $894,061 $1,017,205 Complete 0.05

30781 71940 NPPD NERosemont 115kV Substation GEN-2008-123N

Addition (TOIF)Generation Interconnection GI 11/1/2017 GI STUDIES $0 $1,880,000 On Schedule < 4

51242 71941 WAPA SD Sulphur 115kV - GEN-2014-001IS Addition (TOIF) Generation Interconnection GI 9/15/2020 GI STUDIES $0 $216,180 $227,363 In Service

51242 71942 WAPA SD Sulphur 115kV - GEN-2014-001IS Addition (SANU) Generation Interconnection GI 9/15/2020 GI STUDIES $0 $7,109,676 In Service

51242 71943 WAPA SD Sulphur 115kV - GEN-2014-001IS Addition (NU) Generation Interconnection GI 11/16/2020 GI STUDIES $0 $8,529,876 In Service

200455 51246 71949 SPS TX Nichols 230 kV Terminal Upgrades Regional Reliability ITP 5/15/2020 12/1/2018 5/12/2017 2017 ITPNT $490,000 2017 $527,676 $96,529 $96,529 Closed Out 230

51247 71951 OGE OK Cleo Corner 138kV GEN-2015-048 Addition (TOIF) Generation Interconnection GI 10/1/2020 GI STUDIES $0 $410,000 Re-evaluation

51247 71952 OGE OK Cleo Corner 138kV GEN-2015-048 Addition (NU) Generation Interconnection GI 10/1/2020 GI STUDIES $0 $2,558,000 Re-evaluation

51248 71953 OGE OK Cleo Corner - Cleo Plant Tap 138kV Ckt 1 Generation Interconnection GI 10/1/2020 GI STUDIES $0 $61,890 Re-evaluation

200479 51249 71954 KPP KS City of Winfield - Rainbow 69 kV Ckt 1 Regional Reliability TS 12/31/2020 6/1/2021 2/27/2018 SPP-2016-AG2-AFS-2 $3,600,000 2018 $3,782,250 $4,966,538 On Schedule < 4 4

200466 51249 71955 WR/EKC KS Oak - Rainbow 69 kV Ckt 1 Regional Reliability TS 6/1/2021 6/1/2021 9/21/2017 SPP-2016-AG2-AFS-1 $7,831,427 2017 $8,644,430 $5,742,060 On Schedule < 4 69 5.1

200466 51252 71958 WR/EKC KSCreswell (CRSW TX-1) 138/69/13.2 kV Transformer

Ckt 1Regional Reliability TS 12/31/2020 6/1/2021 9/21/2017 SPP-2016-AG2-AFS-1 $3,486,230 2017 $3,754,288 $3,277,797 On Schedule < 4 138/69

200466 51252 71959 WR/EKC KSCreswell (CRSW TX-2) 138/69/13.2 kV Transformer

Ckt 2Regional Reliability TS 6/1/2021 6/1/2021 9/21/2017 SPP-2016-AG2-AFS-1 $3,621,491 2017 $3,997,448 $2,735,801 On Schedule < 4 138/69

210536 41199 71960 SPS TX Etter - Moore 115 kV Rebuild Regional Reliability ITP 12/15/2021 6/1/2018 10/29/2019 2017 ITPNT $9,037,903 2017 $9,976,154 $1,194,165 Delay - Mitigation 115 10.25

200477 51254 71963 NPPD NE Monolith 345 kV Substation Regional Reliability TS 1/1/2023 12/1/2020 2/21/2018 DPA-2016-December-703 $12,692,888 2018 $13,668,852 $12,692,888 Delay - Mitigation 345 0.2

200477 51254 71964 NPPD NE Monolith 345/115 kV Transformer #1 Regional Reliability TS 1/1/2023 12/1/2020 2/21/2018 DPA-2016-December-703 $5,179,657 2018 $5,577,924 $5,179,657 Delay - Mitigation 345/115

200477 51254 71965 NPPD NE Monolith 345/115 kV Transformer #2 Regional Reliability TS 1/1/2023 12/1/2020 2/21/2018 DPA-2016-December-703 $5,179,657 2018 $5,577,924 $5,179,657 Delay - Mitigation 345/115

200477 51254 71966 NPPD NE Monolith 115 kV Substation Upgrades Regional Reliability TS 1/1/2023 12/1/2020 2/21/2018 DPA-2016-December-703 $11,271,233 2018 $12,137,885 $11,271,233 Delay - Mitigation 115 2.6

200477 51254 71967 NPPD NE Sheldon - Monolith 115 kV Ckt 1 New Line Regional Reliability TS 1/1/2023 12/1/2020 2/21/2018 DPA-2016-December-703 $1,273,506 2018 $1,371,427 $1,273,506 Delay - Mitigation 115 1

200477 51254 71968 NPPD NE Sheldon 115 kV Terminal Upgrades Regional Reliability TS 1/1/2023 12/1/2020 2/21/2018 DPA-2016-December-703 $3,703,266 2018 $3,988,012 $3,703,266 Delay - Mitigation 115

200470 51260 71976 CBPC IA Prestage Family 69 kV Cap Bank Regional Reliability TS 9/1/2018 8/1/2018 1/19/2018 DPA-2017-March-735 $1,017,500 2018 $1,017,500 $1,017,500 $1,091,821 Complete 69 1.5

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51261 71982 NPPD NE Belvidere – Fairbury 115kV circuit #1 Generation Interconnection GI 11/1/2019 GI STUDIES $0 $1,700,000 Re-evaluation 115/115

51261 71983 NPPD NE Beatrice – Harbine 115kV circuit #1 Generation Interconnection GI 11/1/2019 GI STUDIES $0 $900,000 Re-evaluation 115/115

51262 71984 NPPD NETobias 345kV Substation GEN-2015-088 Addition

(TOIF)Generation Interconnection GI 1/1/2019 GI STUDIES $0 $700,000 On Schedule < 4 345/345

51262 71985 NPPD NETobias 345kV Substation GEN-2015-088 Addition

(NU)Generation Interconnection GI 1/1/2019 GI STUDIES $0 $11,700,000 On Schedule < 4 345/345

200483 51277 72004 OPPD NE S1255 - S1260 161 kV Ckt 1 New Line Regional Reliability TS 1/27/2020 1/1/2020 2/27/2018 DPA-2017-May-746 $14,770,262 2018 $15,518,007 $9,435,262 Complete 161 5.9

210486 51278 72006 WAPA ND Bismarck 115 kV Terminal Upgrades Sponsored Upgrade SP 1/31/2023 6/1/2024 8/17/2018 SUS-002 $90,000 2018 $96,920 $90,000 On Schedule < 4 115

200482 51280 72011 WFEC OK Dover SW 69 kV Cap Bank Regional Reliability TS 9/1/2023 6/1/2019 2/27/2018 DPA-2017-August-767-774-776 $500,000 2018 $538,445 $500,000 Delay - Mitigation 69

200482 51281 72012 WFEC OK Cherokee SW 69 kV Cap Bank Regional Reliability TS 8/1/2023 6/1/2018 2/27/2018 DPA-2017-August-767-774-776 $1,000,000 2018 $1,076,891 $1,000,000 Delay - Mitigation 69

210483 51282 72013 WFEC OK Park Community 138 kV Substation Regional Reliability TS 6/15/2018 6/1/2018 4/26/2018 DPA-2017-August-767-774-776 $2,000,000 2018 $2,000,000 $2,000,000 Complete 138

210483 51282 72014 WFEC OK Omega - Park Community 138 kV Ckt 1 New Line Regional Reliability TS 7/1/2019 6/1/2018 4/26/2018 DPA-2017-August-767-774-776 $4,700,000 2018 $4,817,500 $4,700,000 Delay - Mitigation 138 9.4

210483 51282 72015 WFEC OKOmega - Watonga SW 138 kV Ckt 1 Voltage

ConversionRegional Reliability TS 5/31/2021 6/1/2019 4/26/2018 DPA-2017-August-767-774-776 $7,950,000 2018 $8,561,280 $7,950,000 Delay - Mitigation 138 7.9 7.9

210483 51282 72016 WFEC OKOkeene - Watonga SW 138 kV Ckt 1 Voltage


210483 51282 72018 WFEC OKCalumet - Watonga SW 138 kV Ckt 1 Voltage


210483 51282 72019 WFEC OK Calumet - Concho 138 kV Ckt 1 Voltage Conversion Regional Reliability TS 9/1/2022 6/1/2020 4/26/2018 DPA-2017-August-767-774-776 $1,250,000 2018 $1,346,113 $1,250,000 Delay - Mitigation 138 9

210483 51282 72020 WFEC OK Calumet - Cana 138 kV Ckt 1 Voltage Conversion Regional Reliability TS 12/1/2023 6/1/2020 4/26/2018 DPA-2017-August-767-774-776 $4,550,000 2018 $4,899,852 $4,550,000 Delay - Mitigation 138 9.1 9.1

210483 51282 72021 WFEC OK Calumet 138 kV Substation Regional Reliability TS 11/1/2022 6/1/2019 4/26/2018 DPA-2017-August-767-774-776 $4,000,000 2018 $4,307,562 $4,000,000 Delay - Mitigation 138

210483 51282 72022 WFEC OK Cana - El Reno Jct 138 kV Ckt 1 Voltage Conversion Regional Reliability TS 11/1/2023 6/1/2019 4/26/2018 DPA-2017-August-767-774-776 $5,650,000 2018 $6,084,432 $5,650,000 Delay - Mitigation 138 3.3 3.3

210483 51282 72023 WFEC OKEl Reno - El Reno Jct 138 kV Ckt 1 Voltage

ConversionRegional Reliability TS 6/1/2022 6/1/2019 4/26/2018 DPA-2017-August-767-774-776 $4,000,000 2018 $4,307,562 $3,500,000 Delay - Mitigation 138

210483 51282 72024 WFEC OK El Reno - Mustang 138 kV Ckt 1 Voltage Conversion Regional Reliability TS 5/1/2022 6/1/2019 4/26/2018 DPA-2017-August-767-774-776 $4,000,000 2018 $4,307,562 $11,750,000 Delay - Mitigation 138 21.3 21.3

210483 51282 72025 WFEC OKMustang - Sara Road 138 kV Ckt 1 Voltage


210483 51282 72026 WFEC OKSara Road - Sunshine 138 kV Ckt 1 Voltage

ConversionRegional Reliability TS 12/1/2020 6/1/2019 4/26/2018 DPA-2017-August-767-774-776 $1,050,000 2018 $1,103,156 $5,000,000 Delay - Mitigation 138 10 10

210483 51282 72027 WFEC OK Cogar - El Reno Jct 138 kV Ckt 1 Voltage Conversion Regional Reliability TS 1/1/2024 6/1/2020 4/26/2018 DPA-2017-August-767-774-776 $5,000,000 2018 $5,384,453 $5,300,000 Delay - Mitigation 138 10.6 10.6

210483 51282 72029 WFEC OKKingfisher SW - Park Community 138 kV Ckt 1 New

LineRegional Reliability TS 6/15/2018 6/1/2018 4/26/2018 DPA-2017-August-767-774-776 $4,500,000 2018 $4,500,000 $4,500,000 $5,762,251 Complete 138 9

210483 51282 72030 WFEC OK Kingfisher SW 138 kV Substation Regional Reliability TS 6/1/2022 6/1/2018 4/26/2018 DPA-2017-August-767-774-776 $4,000,000 2018 $4,307,562 $4,000,000 Delay - Mitigation 138

210483 51282 72031 WFEC OK Concho - Kingfisher SW 138 kV Ckt 1 New Line Regional Reliability TS 11/1/2022 6/1/2019 4/26/2018 DPA-2017-August-767-774-776 $4,250,000 2018 $4,576,785 $4,250,000 Delay - Mitigation Window 138 8.5

51283 72032 WR/EKC KSWild Plains 345kV Switching Station GEN-2015-052

Interconnection (TOIF)Generation Interconnection GI 12/1/2019 GI STUDIES $0 $566,193 On Schedule < 4

51283 72033 WR/EKC KSWild Plains 345kV Switching Station GEN-2015-052

Interconnection (NU)Generation Interconnection GI 12/1/2019 GI STUDIES $0 $13,362,472 On Schedule < 4

51283 72034 OGE OKWild Plains 345kV Switching Station GEN-2015-052

Interconnection (NU - OGE)Generation Interconnection GI 12/31/2020 GI STUDIES $0 $20,000 On Schedule < 4

210493 51285 72037 CUS MO Brookline 345kV Reactor Regional Reliability ITP 12/31/2019 6/1/2019 8/17/2018 2018 ITPNT $3,471,864 2018 $3,558,661 $2,509,599 $2,509,599 Closed Out 345

210493 51285 72038 CUS MO Brookline 345kV Substation Expansion Regional Reliability ITP 12/31/2019 6/1/2019 8/17/2018 2018 ITPNT $794,411 2018 $814,271 $662,655 $662,655 Closed Out 345

210492 51295 72050 BEPC MT Lewis - Richland 115kV Ckt 1 (BEPC) Regional Reliability ITP 9/18/2020 6/1/2019 8/17/2018 2018 ITPNT $5,000 2018 $5,253 $19,107 $19,107 Complete 115

210497 51295 72052 WAPA MT Lewis - Richland 115kV Ckt 1 (WAPA) Regional Reliability ITP 11/1/2020 6/1/2019 8/17/2018 2018 ITPNT $100,000 2019 $102,500 $136,000 In Service 115 0.1

210491 51300 72066 AEP AR Fig Five - VBI North 69kV Ckt 1 Regional Reliability ITP 4/11/2019 6/1/2019 8/17/2018 2018 ITPNT $3,357,600 2018 $3,441,540 $3,357,600 $1,922,899 Closed Out 69

210498 51305 72076 WR/EKC KS Lawrence Hill 230/115kV Transformer Regional Reliability ITP 12/15/2020 6/1/2019 8/17/2018 2018 ITPNT $5,781,164 2018 $6,073,835 $6,162,133 Delay - Mitigation 230

210496 51316 72095 SPS TX Carlisle - Murphy 115 kV Terminal Upgrades Regional Reliability ITP 3/11/2022 6/1/2022 8/17/2018 2018 ITPNT $232,952 2018 $250,864 $674,000 On Schedule < 4 115

210489 51327 82111 WFEC OKCogar - Cleveland Jct 138 kV Ckt 1 Voltage

ConversionRegional Reliability TS 3/1/2024 12/31/2018 7/9/2018 DPA-2017-December-815 $10,000,000 2018 $10,768,906 $10,000,000 Delay - Mitigation 138

210489 51327 82112 WFEC OKCleveland Jct - Amber Tap 138 kV Ckt 1 Voltage


210489 51327 82113 WFEC OKAmber Tap - Blanchard 138 kV Ckt 1 Voltage


210489 51327 82114 WFEC OK Blanchard - OU SW 138 kV Ckt 1 Voltage Conversion Regional Reliability TS 4/1/2021 12/31/2018 7/9/2018 DPA-2017-December-815 $300,000 2018 $323,067 $300,000 Delay - Mitigation 138

210489 51327 82115 WFEC OKCleveland Jct - Anadarko 138 kV Ckt 1 Voltage


51328 82116 WR/EKC KSEmporia Energy Center 345 kV Substation GEN-

2015-073 Interconnection (TOIF)Generation Interconnection GI 11/5/2019 GI STUDIES $0 $1,208,638 $1,208,638 Complete

51328 82117 WR/EKC KSEmporia Energy Center 345 kV Substation GEN-

2015-073 Interconnection (NU)Generation Interconnection GI 11/5/2019 GI STUDIES $0 $1,105,091 $1,105,091 Complete

210499 51331 82125 GHP MO Nixa Downtown - Nixa Espy 69 kV Ckt1 Regional Reliability ITP 11/22/2019 6/1/2019 8/17/2018 2018 ITPNT $1,402,000 2018 $1,437,050 $3,373,306 $3,373,307 Closed Out 69

51332 82126 OGE OKGracemont 345 kV Substation GEN-2015-093

Interconnection (TOIF)Generation Interconnection GI 10/14/2022 GI STUDIES $0 $1,099,958 On Schedule < 4

51332 82127 OGE OKGracemont 345 kV Substation GEN-2015-093


51333 82128 OGE OKTap Cleveland - Sooner 345 kV Substation GEN-2015-

066 Interconnection (TOIF)Generation Interconnection GI 10/15/2022 GI STUDIES $0 $1,099,958 On Schedule < 4

51333 82129 OGE OKTap Cleveland - Sooner 345 kV Substation GEN-2015-

066 Interconnection (NU)Generation Interconnection GI 10/15/2022 GI STUDIES $0 $9,213,042 On Schedule < 4

51335 82132 NPPD NEBelden 115 kV Substation GEN-2015-076

Interconnection (TOIF)Generation Interconnection GI 10/1/2020 GI STUDIES $0 $300,000 On Schedule < 4

51335 82133 NPPD NEBelden 115 kV Substation GEN-2015-076


51338 82134 WAPA SD Gavins Point - Yankton Junction 115 kV Generation Interconnection GI 1/1/2021 GI STUDIES $0 $1,401,596 In Service

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51337 82137 AEP OKTuskahoma 138 kV Substation GEN-2016-028

Interconnection (TOIF)Generation Interconnection GI 9/30/2020 GI STUDIES $0 $700,000 Complete

51337 82138 AEP OKTuskahoma 138 kV Substation GEN-2016-028

Interconnection (NU)Generation Interconnection GI 9/30/2020 GI STUDIES $0 $8,700,000 Complete

210512 51339 82139 OGE OK Kildare - White Eagle 138 kV Ckt 1 Rebuild Sponsored Upgrade SP 10/29/2019 6/1/2019 4/3/2019 SUS-004 $7,200,000 2019 $7,200,000 $7,200,000 Complete 138 11.22

210496 61346 92151 SPS TX McDowell Creek 230/115kV Substation Regional Reliability ITP 4/16/2022 6/1/2019 8/17/2018 2018 ITPNT $9,069,324 2018 $9,766,670 $9,622,359 Delay - Mitigation 230 0.2

210496 61346 92152 SPS TX McDowell Creek 230/115kV Transformer Regional Reliability ITP 4/16/2022 6/1/2019 8/17/2018 2018 ITPNT $5,226,730 2018 $5,628,617 $6,262,553 Delay - Mitigation 230/115

210507 61347 92153 SPS NM Bopco - Road Runner 345 kV Ckt 1 New Line Regional Reliability TS 11/15/2021 12/1/2018 12/11/2018 DPA-2017-November-808 $29,927,758 2019 $31,442,851 $28,009,136 Delay - Mitigation 345 21

210507 61347 92154 SPS NM Bopco - China Draw 345 kV Ckt 1 New Line Regional Reliability TS 11/15/2021 12/1/2021 12/11/2018 DPA-2017-November-808 $30,496,976 2019 $32,040,885 $30,000,956 On Schedule < 4 345 19

210507 61347 102153 SPS NM Bopco 345/115 kV Ckt 1 Transformer Regional Reliability TS 11/15/2021 12/1/2018 12/11/2018 DPA-2017-November-808 $6,205,015 2019 $6,519,144 $7,010,444 Delay - Mitigation 345/115

210507 61347 102154 SPS NM Bopco 345/115 kV Ckt 2 Transformer Regional Reliability TS 11/15/2021 12/1/2021 12/11/2018 DPA-2017-November-808 $6,122,043 2019 $6,431,971 $7,072,858 On Schedule < 4 345/115

210507 71347 102156 SPS NM Eddy County - Kiowa 345 kV Ckt 1 New Line Regional Reliability TS 11/3/2020 6/1/2024 12/11/2018 DPA-2017-November-808 $63,730,259 2019 $65,323,515 $64,091,215 $64,091,215 Closed Out 345 34

210507 61347 102157 SPS NM Bopco 345 kV Substation Regional Reliability TS 11/15/2021 12/1/2018 12/11/2018 DPA-2017-November-808 $5,153,574 2019 $5,414,474 $3,398,975 Delay - Mitigation 345

210507 61347 102158 SPS NM Bopco 115 kV Substation Regional Reliability TS 11/15/2020 12/1/2018 12/11/2018 DPA-2017-November-808 $11,741,936 2019 $12,035,484 $15,345,796 In Service 115

210548 71348 102159 OPPD NE S3761 345 kV Substation Regional Reliability TS 6/1/2021 6/1/2021 12/13/2019 DPA-2018-February-841 $4,610,067 2018 $4,964,538 $4,610,067 On Schedule < 4 345/161

210548 71348 102160 OPPD NE S3761 - S3455 345 kV New Line Regional Reliability TS 6/1/2021 6/1/2021 12/13/2019 DPA-2018-February-841 $17,036,209 2019 $17,898,667 $17,036,209 On Schedule < 4 345 5.6

210548 71348 102161 OPPD NES1361 161 kV Substation and 345/161 kV

TransformerRegional Reliability TS 6/1/2021 6/1/2021 12/13/2019 DPA-2018-February-841 $9,707,827 2019 $10,199,286 $9,707,827 On Schedule < 4 161

210548 71348 102162 OPPD NE S1260 161/69 kV Transformer (161 kV) Regional Reliability TS 6/1/2021 6/1/2021 12/13/2019 DPA-2018-February-841 $1,105,064 2019 $1,161,008 $1,105,064 On Schedule < 4 161/69

210548 71348 102163 OPPD NE S1209 - S1231 Ckt 2 161 kV Reconductor Regional Reliability TS 6/1/2021 6/1/2021 12/13/2019 DPA-2018-February-841 $3,647,471 2019 $3,832,124 $3,647,471 On Schedule < 4 161 3.3

210548 71348 102165 OPPD NE S1259 - S1260 161 kV Rebuild Regional Reliability TS 6/1/2021 6/1/2021 12/13/2019 DPA-2018-February-841 $2,107,486 2019 $2,214,177 $2,107,486 On Schedule < 4 161 2.56

210548 71348 102166 OPPD NE S1255 161 kV Terminal Upgrades (new breakers) Regional Reliability TS 6/1/2021 6/1/2021 12/13/2019 DPA-2018-February-841 $654,180 2019 $687,298 $654,180 On Schedule < 4 161

71350 102168 OGE OKRanch Road 345kV Substation GEN-2015-034

Addition (TOIF)Generation Interconnection GI 6/16/2020 GI STUDIES $0 $1,099,958 Complete

71350 102169 OGE OKRanch Road 345kV Substation GEN-2015-034

Addition (NU)Generation Interconnection GI 6/16/2020 GI STUDIES $0 $925,042 Complete

71351 102170 OGE OKJohnston County 345kV Substation GEN-2015-036

Addition (TOIF)Generation Interconnection GI 9/30/2020 GI STUDIES $0 $892,334 Complete

71351 102171 OGE OKJohnston County 345kV Substation GEN-2015-036

Addition (NU)Generation Interconnection GI 9/30/2020 GI STUDIES $0 $1,132,666 Complete

210505 71352 102172 WFEC OK Clear Creek Tap 69 kV Cap Bank Regional Reliability TS 12/1/2020 12/1/2019 12/6/2018 DPA-2018-June-902 $717,209 2019 $735,139 $717,209 Delay - Mitigation Window 69

210525 81357 112180 OPPD NE GEN-2016-115 Interconnection Costs (NU) (OPPD) Generation Interconnection GI 11/16/2020 6/26/2020 11/1/2019 DISIS-2016-002 $7,553 2020 $7,553 $7,553 Complete

210556 81362 112187 OGE OK Henessey 138 kV Ckt 1 Terminal Upgrades Generation Interconnection GI 6/1/2021 12/31/2020 3/17/2020 DISIS-2016-002 $142,965 2020 $146,539 $142,965 Delay - Mitigation

210511 81423 112253 WFEC OK GEN-2016-020 Interconnection Costs (WFEC) Generation Interconnection GI 11/1/2019 4/3/2019 DISIS-2016-001 $10,000 2019 $10,000 $10,000 On Schedule < 4

81467 112300 SEPC KS Mingo 115kV Substation GEN-2015-064 (TOIF) Generation Interconnection GI 1/20/2020 GI STUDIES $0 $911,033 $877,711 Complete

81467 112301 SEPC KS Mingo 115kV Substation GEN-2015-064 (NU) Generation Interconnection GI 1/20/2020 GI STUDIES $0 $4,517,777 $4,794,504 Complete

210548 71348 112357 OPPD NE S1260 161/69 kV Transformer (69 kV) Regional Reliability TS 6/1/2021 12/13/2019 DPA-2018-February-841 $1,799,221 2019 $1,890,307 $1,799,221 Complete 161/69

210540 81498 112358 OGE OK Westmoore 138 kV Breakers Regional Reliability ITP 6/1/2021 6/1/2021 11/18/2019 2019 ITP $271,289 2020 $278,071 $271,289 On Schedule < 4 138

210544 81500 112360 AEP OK Riverside Station 138 kV Breakers Regional Reliability ITP 5/1/2023 6/1/2021 11/18/2019 2019 ITP $16,288,000 2020 $16,695,200 $33,619,929 Re-evaluation 138 1.56

210544 81501 112361 AEP OK Southwestern Station 138 kV Breakers Regional Reliability ITP 12/15/2023 6/1/2021 11/18/2019 2019 ITP $4,421,345 2020 $4,531,879 $4,194,065 Delay - Mitigation 138

210541 81502 112362 SPS NM Carlsbad Interchange 115 kV Breaker Regional Reliability ITP 6/1/2021 11/18/2019 2019 ITP $552,668 2019 $580,647 $552,668 On Schedule < 4 115

210541 81503 112363 SPS TX Hale County Interchange 115 kV Breakers Regional Reliability ITP 12/18/2020 6/1/2021 11/18/2019 2019 ITP $1,658,004 2019 $1,699,454 $1,658,004 On Schedule < 4 115

210541 81504 112364 SPS TX Denver City Interchange North 115 kV Breaker Regional Reliability ITP 3/15/2021 6/1/2021 11/18/2019 2019 ITP $496,400 2020 $508,810 $409,145 On Schedule < 4 115

210541 81586 112365 SPS TX Denver City Interchange South 115 kV Breakers Regional Reliability ITP 3/15/2021 6/1/2021 11/18/2019 2019 ITP $415,519 2020 $425,907 $261,933 On Schedule < 4 115

210538 81505 112366 NPPD NE Canaday 115 kV Breakers Regional Reliability ITP 2/1/2020 6/1/2021 11/18/2019 2019 ITP $2,600,000 2020 $2,600,000 $2,555,908 Complete 115

210538 81506 112367 NPPD NE Hastings 115 kV Breakers Regional Reliability ITP 1/1/2021 6/1/2021 11/18/2019 2019 ITP $550,000 2020 $563,750 $506,813 On Schedule < 4 115

210538 81507 112368 NPPD NE Moore 13.8 kV Breaker Regional Reliability ITP 5/1/2021 6/1/2021 11/18/2019 2019 ITP $510,000 2020 $522,750 $679,553 On Schedule < 4 138

210539 81508 112369 KCPL/EM KS Craig 161 kV Breaker Regional Reliability ITP 12/31/2021 6/1/2021 11/18/2019 2019 ITP $311,400 2019 $327,165 $291,361 Delay - Mitigation 161

210539 81509 112370 KCPL/EM MO Leeds 161 kV Breakers Regional Reliability ITP 9/24/2020 6/1/2021 11/18/2019 2019 ITP $468,500 2019 $480,213 $276,821 In Service 161

210539 81510 112371 KCPL/EM MO Midtown 161 kV Breakers Regional Reliability ITP 9/11/2019 6/1/2021 11/18/2019 2019 ITP $502,440 2021 $0 $363,914 $363,914 Closed Out 161

210539 81511 112372 KCPL/EM MO Southtown 161 kV Breakers Regional Reliability ITP 12/31/2021 6/1/2021 11/18/2019 2019 ITP $898,600 2019 $944,092 $1,004,980 Delay - Mitigation 161

210545 81513 112377 WFEC OK Anadarko 138 kV Breakers Regional Reliability ITP 8/1/2027 6/1/2021 11/18/2019 2019 ITP $828,359 2020 $849,068 $838,500 Delay - Mitigation 138

210545 81514 112378 WFEC OK Washita 69 kV Breaker Regional Reliability ITP 6/1/2021 6/1/2021 11/18/2019 2019 ITP $52,400 2020 $53,710 $52,400 On Schedule < 4 69

210545 81515 112379 WFEC OK Mooreland 138 kV Breakers #2 Regional Reliability ITP 5/1/2022 6/1/2021 11/18/2019 2019 ITP $822,500 2020 $843,063 $2,160,000 Delay - Mitigation

210545 81515 112380 WFEC OK Mooreland 69 kV Breakers #2 Regional Reliability ITP 6/1/2022 6/1/2021 11/18/2019 2019 ITP $128,300 2020 $131,508 $204,000 Delay - Mitigation

210542 81516 112381 WR/EKC KS Baileyville - South Seneca 115kV Ckt 1 Regional Reliability ITP 6/1/2022 4/1/2021 11/18/2019 2019 ITP $3,067,168 2020 $3,143,847 $3,067,168 Delay - Mitigation Window 115 4

210542 81516 112383 WR/EKC KS Marshall County - Smittyville 115kV Ckt 1 Regional Reliability ITP 6/1/2022 4/1/2021 11/18/2019 2019 ITP $2,528,868 2020 $2,592,090 $2,528,868 Delay - Mitigation Window 115 2.2

210544 81520 112389 AEP OK Tulsa SE - S Hudson 138kV Ckt 1 Rebuild Regional Reliability ITP 5/27/2022 6/1/2021 11/18/2019 2019 ITP $6,724,237 2020 $6,892,343 $6,724,237 Delay - Mitigation 138/138 2

210544 81523 112393 AEP OK Tulsa SE - 21st Street Tap 138 kV Ckt 1 Regional Reliability ITP 5/27/2022 6/1/2021 11/18/2019 2019 ITP $1,307,802 2020 $1,340,497 $1,307,802 Delay - Mitigation 138/138 1.5

210545 81525 112395 WFEC OK Gypsum 69 kV Capacitor Bank Regional Reliability ITP 6/1/2021 6/1/2021 11/18/2019 2019 ITP $400,000 2020 $410,000 $400,000 On Schedule < 4 69/69

210542 81526 112396 WR/EKC KS Getty East - Skelly 69kV Ckt 1 Terminal Upgrades Regional Reliability ITP 11/4/2019 4/1/2021 11/18/2019 2019 ITP $114,821 2020 $114,821 $122,831 $122,831 In Service 69/69

210538 81533 112403 NPPD NE Firth Cap Bank 115kV Ckt 1 Regional Reliability ITP 6/1/2024 4/1/2021 11/18/2019 2019 ITP $608,900 2020 $624,123 $608,900 Delay - Mitigation 115/115

210538 81533 112404 NPPD NE Firth 115 kV Substation Expansion Regional Reliability ITP 6/1/2024 4/1/2021 11/18/2019 2019 ITP $3,600,000 2020 $3,690,000 $2,991,100 Delay - Mitigation 115/115

210541 81542 112425 SPS TX Amoco - Sundown 115kV Terminal Upgrades Economic ITP 6/1/2020 1/1/2023 11/18/2019 2019 ITP $408,507 2020 $408,507 $85,828 $85,828 Closed Out 115/115

210542 81545 112428 WR/EKC KSLawrence Energy Center - Midland 115 kV Terminal

UpgradesEconomic ITP 5/22/2020 1/1/2021 11/18/2019 2019 ITP $30,939 2020 $30,939 $35,883 $35,883 Complete 115/115

210541 81548 112433 SPS TX Hansford - Spearman 115 kV Rebuild Economic ITP 4/15/2021 1/1/2021 11/18/2019 2019 ITP $828,359 2020 $849,068 $721,693 On Schedule < 4 115/115

210545 81550 112435 WFEC OK East Kingfisher - Kingfisher 138 kV Rebuild Economic ITP 1/1/2021 1/1/2021 11/18/2019 2019 ITP $1,000,000 2020 $1,025,000 $1,000,000 On Schedule < 4 138/138

210586 81553 112443 WFEC OK Russett - South Brown 138 kV Ckt 1 Rebuild Economic ITP 12/1/2027 1/1/2022 11/17/2020 2020 ITP $10,267,391 2021 $10,267,391 $10,267,391 Delay - Mitigation Window 138/138

210543 81557 112451 SEPC KS Arnold - Ransom 115kV Terminal Upgrades Economic ITP 1/1/2025 1/1/2025 11/18/2019 2019 ITP $462,000 2020 $473,550 $462,000 On Schedule < 4 115/115

210543 81557 112452 SEPC KS Pile - Scott City 115kV Terminal Upgrades Economic ITP 1/1/2025 1/1/2025 11/18/2019 2019 ITP $1,633,500 2020 $1,674,338 $1,633,500 On Schedule < 4 115/115

210543 81557 112453 SEPC KS Scott City - Setab 115kV Terminal Upgrades Economic ITP 1/1/2025 1/1/2025 11/18/2019 2019 ITP $1,556,500 2020 $1,595,413 $1,556,500 On Schedule < 4 115/115

210570 81559 112456 EDE KS Neosho - Riverton 161kV Rebuild (EDE) Transmission Service TS 10/1/2023 11/12/2020 SPP-2019-AG1-AFS-2 $43,153,324 2020 $44,232,157 $43,153,324 On Schedule < 4 161 25.9

210569 81559 112457 WR/EKC KS Neosho - Riverton 161kV Rebuild (WR) Transmission Service TS 6/1/2023 10/1/2023 11/12/2020 SPP-2019-AG1-AFS-2 $4,008,402 2020 $4,108,612 $4,008,402 On Schedule < 4 161 2.7

210593 81561 112458 TSOK OK Sooner - Wekiwa 345 kV New Line Economic ITP 1/1/2026 2/10/2021 2019 ITP $97,111,851 2020 $99,539,647 $0 On Schedule < 4 345/345

210544 81561 112460 AEP OKSand Springs - Sheffield Steel 138 kV Terminal

UpgradesEconomic ITP 1/1/2026 1/1/2026 11/18/2019 2019 ITP $733,520 2020 $751,858 $733,520 On Schedule < 4 138/138

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210544 81571 112488 AEP OK Pryor Junction 138/115 kV Transformer Regional Reliability ITP 11/30/2021 6/1/2021 11/18/2019 2019 ITP $9,155,167 2020 $9,384,046 $9,155,167 Delay - Mitigation 138/115

210577 81497 112500 EREC SD Aberdeen Jct - Richmond 115 kV Ckt 1 (EREC) Regional Reliability ITP 11/1/2021 12/1/2022 11/17/2020 2020 ITP $4,270,000 2021 $4,270,000 $4,270,000 On Schedule < 4 115 13.4

210544 81561 112502 AEP NM Sooner - Wekiwa 345 kV Terminal Upgrades (AEP) Economic ITP 1/1/2026 1/1/2026 11/18/2019 2019 ITP $3,165,684 2019 $3,325,947 $5,383,105 On Schedule < 4 345 0.06

210592 81547 112509 WR/EKC TX Wolf Creek 345kV Terminal Equipment Economic ITP 1/1/2026 1/21/2021 2019 ITP $2,850,232 2019 $2,994,525 $10,056,365 On Schedule > 4 345

210515 81581 112510 SPS ND Hobbs Interchange to Millen Rebuild 115 kV Ckt1 Regional Reliability TS 6/1/2022 6/1/2022 6/7/2019 DPA-2018-Mar-854 $3,165,684 2019 $3,325,947 $0 On Schedule < 4 3.5

210515 81581 122510 SPS ND Johnson Draw 115 kV Capacitor Bank Regional Reliability TS 6/1/2022 6/1/2022 6/7/2019 DPA-2018-Mar-854 $3,749,224 2019 $3,939,028 $2,850,232 On Schedule < 4 115

210577 81497 122511 EREC SD Richmond 115/69 kV Transformer Regional Reliability ITP 11/1/2021 12/1/2022 11/17/2020 2020 ITP $1,102,500 2021 $1,102,500 $1,102,500 On Schedule < 4

210577 81497 122512 EREC SD Richmond 69 kV Capacitor Bank Regional Reliability ITP 11/1/2021 12/1/2022 11/17/2020 2020 ITP $230,000 2021 $230,000 $230,000 On Schedule < 4 69

210560 81614 122570 BEPC ND Neset - Northshore 230 kV Ckt 1 Regional Reliability TS 12/31/2022 6/1/2019 6/10/2020 DPA-2018-August-918 $33,023,153 2020 $33,848,732 $33,155,575 Delay - Mitigation 230 30

210559 81614 122571 MWE ND Northshore - New Town 115 kV Ckt 1 Regional Reliability TS 9/5/2021 6/1/2019 6/10/2020 DPA-2018-August-918 $19,235,485 2020 $19,716,372 $19,235,485 Delay - Mitigation 115 20.5

210560 81614 122572 BEPC SD North Shore 230/115 kV Transformer Regional Reliability TS 12/31/2022 6/1/2019 6/10/2020 DPA-2018-August-918 $5,920,939 2020 $6,068,962 $3,176,320 Delay - Mitigation 230/115

210560 81614 122575 BEPC OK Northshore 230 kV Substation Regional Reliability TS 12/31/2022 6/1/2019 6/10/2020 DPA-2018-August-918 $20,938,350 2020 $21,461,809 $20,938,350 Delay - Mitigation

210522 81616 122576 NWE SDAberdeen City - Aberdeen Industrial Park 115 kV Ckt

1 New LineSponsored Upgrade SP 12/31/2019 12/31/2019 9/6/2019 SUS-006 $3,200,009 2019 $3,200,009 $3,200,009 On Schedule < 4 115

210586 81617 122577 WFEC SD Anadarko - Gracemont 138kV Ckt 1 Rebuild Economic ITP 12/1/2026 1/1/2021 11/17/2020 2020 ITP $2,850,000 2020 $2,850,000 $5,750,000 Delay - Mitigation Window 138

210527 81626 122593 EREC OK Wentworth 69 kV Substation Regional Reliability TS 6/1/2019 8/1/2019 10/17/2019 DPA-2018-January-821 $2,073,095 2020 $2,073,095 $989,556 Complete 69

210527 81626 122594 EREC SD Wentworth 69 kV Capacitor Bank Regional Reliability TS 7/1/2019 8/1/2019 10/17/2019 DPA-2018-January-821 $600,675 2020 $600,675 $600,675 Complete 69

210545 81627 122597 WFEC KS Marietta 69 kV Regional Reliability ITP 12/1/2021 12/1/2021 11/18/2019 2019 ITP $100,000 2020 $102,500 $100,000 On Schedule < 4 69

210522 81616 122599 NWE KS Aberdeen A-Tap Breaker 115 kV Sponsored Upgrade SP 12/31/2021 12/31/2021 9/6/2019 SUS-006 $552,668 2019 $580,647 $552,668 On Schedule < 4 115

210564 81489 122600 OGE OKGracemont - Lawton East Side 345 kV Substation

GEN-2016-091 (NU) (OKGE)Generation Interconnection GI 12/31/2020 9/22/2020 8/11/2020 DISIS-2016-002 $10,000 2020 $10,000 $10,000 Delay - Mitigation

210565 81481 122622 WR/EKC KS Swissvale 345 kV Substation Upgrades Generation Interconnection GI 12/31/2022 8/28/2020 DISIS-2016-002 $139,825 2020 $143,321 $139,825 On Schedule < 4

81481 122623 WR/EKC KS Swissvale 345 kV Terminal Upgrades Generation Interconnection GI 12/31/2022 GI STUDIES $10,000 2020 $10,250 $10,000 On Schedule < 4

210553 81637 122631 WAPA SD/NE Fort Randall - Spencer 115kV Ckt 1 Re-conductor Regional Reliability TS 6/1/2023 6/1/2023 12/9/2020 DPA-2019-May-1037 $0 $2,650,000 On Schedule < 4

210553 81637 122632 WAPA SD Martin - Vetal Tap 115 kV Ckt 1 Rebuild Regional Reliability TS 6/1/2022 6/1/2022 12/9/2020 DPA-2019-May-1037 $0 $3,800,000 $3,800,000 On Schedule > 4

210554 81638 122639 OGE OK Forest Hill 69 kV Terminal Upgrade Regional Reliability TS 6/1/2021 1/1/2021 3/17/2020 DPA-2019-January-974 $43,867 2020 $44,964 $25,000 On Schedule < 4

210551 81648 122650 WR/EKC KS Caney River - Neosho 345 kV Terminal Upgrades Sponsored Upgrade SP 6/25/2020 10/1/2020 12/31/2019 SUS-013 $419,116 2020 $419,116 $511,343 Complete

210557 81652 122657 CBPC IA Sub - Donald Feldman 69kV Switching Station Regional Reliability TS 6/1/2020 4/8/2020 DPA-2019-March-1011 $1,100,000 2020 $1,127,500 $1,227,000 On Schedule < 4

210563 81656 122664 NPPD NE Pauline - Hastings 115 kV Ckt 1 & Ckt 2 Reconductor Sponsored Upgrade SP 12/1/2022 12/1/2022 7/14/2020 SUS-014 $6,000,000 2020 $6,150,000 $6,000,000 On Schedule < 4

210558 81673 122713 AEP OK Kerr - Locust Grove 115 kV Ckt 1 Transmission Service TS 6/1/2022 6/1/2022 5/29/2020 SPP-2019-AG2-AFS-3 $3,160,967 2020 $3,160,967 $3,160,967 Delay - Mitigation 115 0.49

210578 81675 122717 GRDA OKGRDA1 345 kV Terminal Upgrades Transformer Ckt

1Economic ITP 1/1/2022 11/17/2020 2020 ITP $282,000 On Schedule < 4 0/0


1Economic ITP 1/1/2022 11/17/2020 2020 ITP $423,000 On Schedule < 4 345/161

210586 81679 122722 WFEC OKDover Switch - O'Keene 138 kV Ckt 1 Terminal

UpgradesEconomic ITP 12/31/2025 1/1/2022 11/17/2020 2020 ITP $910,000 2021 $910,000 $910,000 Delay - Mitigation Window

210574 81682 122725 SPS TX Allen - Quaker 115 kV Ckt 1 Rebuild Regional Reliability ITP 6/1/2022 11/17/2020 2020 ITP $4,732,267 On Schedule < 4 3.5

210580 81683 122726 WR/EKC KS Meadowlark - Tower 33 115 kV Ckt 1 Rebuild Regional Reliability ITP 10/1/2020 6/1/2023 11/17/2020 2020 ITP $1,468,940 2021 $1,468,940 $1,342,588 Complete 0.94

210574 81684 122727 SPS TX Allen - Lubbock South 115 kV Ckt 1 Rebuild Regional Reliability ITP 6/1/2022 11/17/2020 2020 ITP $6,817,226 On Schedule < 4 6

210575 81687 122730 AEP LASouth Shreveport - Wallace Lake 138 kV Ckt 1

Rebuild #2Regional Reliability ITP 6/1/2024 11/17/2020 2020 ITP $23,622,577 On Schedule < 4 11.2

210581 81768 122745 BEPC ND Watford City 230/115 kV Transformer Ckt 1 (KV1A) Regional Reliability ITP 6/1/2022 11/17/2020 2020 ITP $3,389,739 NTC - Commitment Window 230/115

210581 81768 122746 BEPC ND Watford City 230/115 kV Transformer Ckt 2 (KV2A Regional Reliability ITP 6/1/2022 11/17/2020 2020 ITP $173,041 NTC - Commitment Window 230/115

210586 81617 122753 WFEC OK Anadarko - Gracemont 138 kV Ckt 2 Rebuild Economic ITP 9/1/2026 1/1/2023 11/17/2020 2020 ITP $1,750,000 Delay - Mitigation Window

210589 81617 122755 OGE OK Gracemont 138 kV Ckt 2 Terminal Equipment Economic ITP 1/1/2023 11/17/2020 2020 ITP $405,535 NTC-C PROJECT ESTIMATE WINDOW

210586 81617 122756 WFEC OK Anadarko 138 kV Ckt 2 Terminal Equipment Economic ITP 1/1/2023 11/17/2020 2020 ITP $405,535 NTC-C PROJECT ESTIMATE WINDOW

210575 81717 122796 AEP OK Chisholm Substation 345 kV Terminal Upgrades Economic ITP 4/30/2023 1/1/2022 11/17/2020 2020 ITP $12,210,634 Delay - Mitigation Window 0.2


2Economic ITP 1/1/2022 11/17/2020 2020 ITP $282,000 NTC-C PROJECT ESTIMATE WINDOW


2Economic ITP 1/1/2022 11/17/2020 2020 ITP $423,000 NTC-C PROJECT ESTIMATE WINDOW345/161

210582 81719 122803 SEPC KS Russell 115 kV Capacitor Bank Regional Reliability ITP 6/1/2022 11/23/2020 2020 ITP $2,841,951 On Schedule < 4

210583 81720 122804 KCPL/EM KS Northeast 161 kV Breakers Regional Reliability ITP 6/1/2022 11/17/2020 2020 ITP $887,479 Delay - Mitigation Window

210583 81721 122805 KCPL/EM KS Stilwell 161 kV Breaker Regional Reliability ITP 6/1/2022 11/17/2020 2020 ITP $566,485 Delay - Mitigation Window

210583 81722 122806 KCPL/EM KS Leeds 161 kV Breaker Regional Reliability ITP 6/1/2022 11/17/2020 2020 ITP $566,485 Delay - Mitigation Window

210583 81723 122807 KCPL/EM KS Shawnee Mission 161 kV Breaker Regional Reliability ITP 6/1/2022 11/17/2020 2020 ITP $566,485 Delay - Mitigation Window

210583 81724 122808 KCPL/EM KS Southtown 161 kV Breaker Regional Reliability ITP 6/1/2022 11/17/2020 2020 ITP $566,485 Delay - Mitigation Window

210583 81725 122809 GMO/EMW KS Lake Road 161 kV Breakers Regional Reliability ITP 6/1/2022 11/17/2020 2020 ITP $1,132,970 Delay - Mitigation Window

210583 81726 122810 KCPL/EM KS Craig 161 kV Breakers Regional Reliability ITP 6/1/2022 11/17/2020 2020 ITP $1,132,970 Delay - Mitigation Window

210580 81728 122812 WR/EKC KS Circleville - Goff 115 kV Ckt 1 Rebuild Regional Reliability ITP 6/1/2021 6/1/2025 11/17/2020 2020 ITP $13,028,143 2021 $13,028,143 $12,114,772 On Schedule < 4 14.5

210580 81730 122814 WR/EKC KS Goff - Kelly 115 kV Ckt 1 Rebuild Regional Reliability ITP 6/1/2021 6/1/2025 11/17/2020 2020 ITP $5,602,343 2021 $5,602,343 $5,811,876 On Schedule < 4

210589 81733 122818 OGE OKCushing - Shell Pipeline Cushing Tap 69 kV Ckt 1

RebuildRegional Reliability ITP 6/1/2023 11/17/2020 2020 ITP $4,281,150 On Schedule < 4 4.71

210589 81733 122819 OGE OKPipeline - Shell Pipeline Cushing Tap 69 kV Ckt 1

RebuildRegional Reliability ITP 6/1/2023 11/17/2020 2020 ITP $1,081,649 On Schedule < 4 1.19

210587 81717 122823 OGE OK Border - Woodward Tap 345 kV Substation Economic ITP 1/1/2022 11/17/2020 2020 ITP $11,500,000 NTC-C PROJECT ESTIMATE WINDOW

210587 81717 122824 OGE OK Chisholm - Woodward Border 345 kV Ckt 1 (OGE) Economic ITP 1/1/2022 11/17/2020 2020 ITP $1,259,660 NTC-C PROJECT ESTIMATE WINDOW 0.84

210587 81741 122848 OGE OK Minco 345 kV Terminal Equipment Economic ITP 1/1/2025 11/17/2020 2020 ITP $2,288,668 NTC-C PROJECT ESTIMATE WINDOW345/138

210587 81741 122849 OGE OK Pleasant Valley 345 kV Substation Economic ITP 1/1/2025 11/17/2020 2020 ITP $25,500,000 NTC-C PROJECT ESTIMATE WINDOW345/138

210587 81741 122850 OGE OK Pleasant Valley 345/138 kV Transformer Ckt 1 Economic ITP 1/1/2025 11/17/2020 2020 ITP $4,225,000 NTC-C PROJECT ESTIMATE WINDOW345/138

210587 81741 122851 OGE OK Pleasant Valley 345/138 kV Transformer Ckt 2 Economic ITP 1/1/2025 11/17/2020 2020 ITP $4,225,000 NTC-C PROJECT ESTIMATE WINDOW345/138

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210587 81741 122858 OGE OK Cimarron - Draper 345 kV Terminal Upgrades #2 Economic ITP 1/1/2025 11/17/2020 2020 ITP $2,288,668 NTC-C PROJECT ESTIMATE WINDOW

210587 81741 122863 OGE OK Midwest 138 kV Ckt 1 Terminal Upgrades Economic ITP 1/1/2025 11/17/2020 2020 ITP $65,000 NTC-C PROJECT ESTIMATE WINDOW

210586 81751 122864 WFEC OK Anadarko 138 kV Breakers #2 Regional Reliability ITP 6/1/2022 11/17/2020 2020 ITP $850,000 On Schedule < 4

210586 81679 122865 WFEC OK Mooreland - Aspen 138 kV Terminal Upgrades Economic ITP 4/1/2022 1/1/2022 11/17/2020 2020 ITP $202,500 Delay - Mitigation Window

210586 81679 122866 WFEC OK Mooreland - Pic 138 kV Terminal Upgrades Economic ITP 4/1/2022 1/1/2022 11/17/2020 2020 ITP $405,000 Delay - Mitigation Window

210574 81755 122869 SPS TX Bushland - Deaf Smith 230 kV Terminal Upgrades Regional Reliability ITP 4/15/2022 4/1/2022 11/17/2020 2020 ITP $923,938 Delay - Mitigation Window 33

210574 81756 122870 SPS TX Newhart - Potter 230 kV Terminal Upgrades Regional Reliability ITP 12/15/2022 4/1/2022 11/17/2020 2020 ITP $731,282 On Schedule < 4 67

210574 81757 122871 SPS TX Deaf Smith #6 - Friona 115 kV Rebuild Regional Reliability ITP 4/1/2022 4/1/2022 11/17/2020 2020 ITP $12,626,190 Delay - Mitigation Window 17.4

210574 81758 122872 SPS TX Carlisle - Murphy 115 kV Ckt 1 Rebuild Regional Reliability ITP 6/1/2022 6/1/2022 11/17/2020 2020 ITP $4,746,175 On Schedule < 4 4

210574 81760 122876 SPS TX Deaf Smith #6 - Hereford 115 kV Ckt 1 Rebuild Regional Reliability ITP 4/1/2022 4/1/2022 11/17/2020 2020 ITP $6,660,556 On Schedule < 4 7.3

210574 81763 122883 SPS TXLubbock South - Wolfforth 230 kV Ckt 1 Terminal

Upgrades #2Regional Reliability ITP 6/1/2022 6/1/2022 11/17/2020 2020 ITP $872,391 On Schedule < 4 14.6

210584 81497 132893 NWE SD Aberdeen Junction 115 kV Terminal Upgrades Regional Reliability ITP 12/31/2021 12/1/2022 11/17/2020 2020 ITP $1,060,000 On Schedule < 4

210577 81497 132894 EREC SD Richmond 69 kV Substation Regional Reliability ITP 11/1/2021 12/1/2022 11/17/2020 2020 ITP $5,738,500 NTC - Commitment Window 115/69

210576 91875 143156 AEP OK Grady 138 kV Capacitor Bank Regional Reliability ITP 12/1/2022 12/1/2022 11/17/2020 2020 ITP $1,184,404 NTC - Commitment Window

210579 91876 143157 WAPA ND Bismarck 12.47 kV Reactors Regional Reliability ITP 4/1/2022 4/1/2022 11/23/2020 2020 ITP $2,143,217 NTC - Commitment Window

210585 91878 143159 MRES MN Moorehead 230 kV Reactor Regional Reliability ITP 4/1/2022 11/17/2020 2020 ITP $1,515,440 Delay - Mitigation Window

210591 91881 143162 CPEC ND Agate 115 kV Reactor Regional Reliability ITP 4/1/2022 11/23/2020 2020 ITP $571,200 On Schedule < 4

210574 91884 143167 SPS TX Cargill - Friona 115 kV Ckt 1 Rebuild Regional Reliability ITP 4/1/2022 11/17/2020 2020 ITP $817,466 On Schedule < 4 1.15

210574 91888 143168 SPS TX Cargill - Deaf Smith #24 115 kV Ckt 1 Rebuild Regional Reliability ITP 4/1/2022 11/17/2020 2020 ITP $5,501,901 On Schedule < 4

210574 91889 143169 SPS TX Parmer - Deaf Smith #24 115 kV Ckt 1 Rebuild Regional Reliability ITP 4/1/2022 11/17/2020 2020 ITP $824,574 On Schedule < 4 1.16

210574 91890 143170 SPS TX Parmer - Deaf Smith #20 115 kV Ckt 1 Rebuild Regional Reliability ITP 4/1/2022 11/17/2020 2020 ITP $5,402,384 On Schedule < 4 7.6

210587 81741 143176 OGE OK Draper 345 kV Terminal Equipment Economic ITP 1/1/2025 11/17/2020 2020 ITP $2,288,668 NTC-C PROJECT ESTIMATE WINDOW

210584 81497 143181 NWE SD Aberdeen Jct - Richmond 115 kV Ckt 1 (NWE) Regional Reliability ITP 12/1/2022 11/17/2020 2020 ITP $3,277,500 On Schedule < 4 14.4

210590 91891 143183 GMO/EMW KS Greenwood 161 kV Terminal Upgrades Transmission Service TS 12/31/2021 12/31/2021 11/24/2020 SPP-2020-AG1-AFS-3 $600,168 On Schedule < 4 161

210590 91892 143184 GMO/EMW KSPleasant Hill 161kV and Lake Winnebago 161 kV

Terminal UpgradesTransmission Service TS 12/31/2021 6/1/2021 11/24/2020 SPP-2020-AG1-AFS-3 $430,000 On Schedule < 4 161

210540 81499 112359 OGE OK Santa Fe 138 kV Breakers Regional Reliability ITP 6/1/2021 6/1/2021 11/18/2019 2019 ITP $406,935 On Schedule < 4 138

81547 122598 TBD KS Blackberry - Wolf Creek 345 kV Economic ITP 1/1/2026 2019 ITP $142,601,178 NTC - Commitment Window

81661 122675 WR KSGEN-2016-162 and 163 Interconnection (TOIF)

(WERE)Generator Interconnection GI GI STUDIES $1,198,282 On Schedule < 4

81741 133085 TBD OK Minco - Pleasant Valley 345 kV Ckt 1 Economic ITP 1/1/2025 2020 ITP $57,512,100 Identified

81741 133106 TBD Ok Draper - Pleasant Valley 345 kV Ckt 2 Economic ITP 1/1/2025 2020 ITP $23,400,139 Identified

210579 91880 143161 WAPA ND Devil's Lake 115 kV Reactor Regional Reliability ITP 4/1/2022 11/23/2020 2020 ITP $1,190,000 NTC - Commitment Window

210575 81717 143182 AEP OK Chisholm - Woodward Border 345 kV Ckt 1 (AEP) Economic ITP 1/1/2022 11/17/2020 2020 ITP $1,000,000 NTC - Commitment Window

30960 51341 OGE OKBeaver County Substation - Add 345kV terminal for

GEN-2013-030Generator Interconnection GI 10/28/2019 GI STUDIES $4,842,217 Complete

30960 51609 OGE OKBeaver County Substation - Add 345kV terminal for

GEN-2013-030 (TOIF)Generator Interconnection GI 10/28/2019 GI STUDIES $1,099,958 Complete

210540 81532 112402 OGE OKCleo Corner - Cleo Junction 69kV Ckt 1 Terminal

UpgradesRegional Reliability ITP 12/31/2021 6/1/2022 11/18/2019 2019 ITP $16,602 2020 $16,602 $16,602 On Schedule < 4 69/69

210540 81556 112449 OGE OKCimarron - Northwest 345kV Ckt 1 Terminal

UpgradesEconomic ITP 6/17/2020 1/1/2021 11/18/2019 2019 ITP $166,504 2020 $166,504 $87,625 Closed Out 345/345

210540 81556 112450 OGE OK Northwest - Mathewson 345 kV Terminal Upgrades Economic ITP 6/1/2020 1/1/2021 11/18/2019 2019 ITP $369,869 2020 $369,869 $169,560 Closed Out 345/345

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No. Action Item Date Originated Status Comments Addressed at 9/29/14 Meeting

14-2 RARTF: Update on RARTF and New Metrics 8/25/2014 Completed Addressed at 9/29/14 Meeting

14-3Seams Project Task Force: CAWG will

consider the issue at next meeting and bring back to RSC for discussion

CompletedAddressed at 9/29/14 Meeting; On 10/27/14

Meeting as a voting item

14-4

SPC Task Force on New Members: RSC should email Commissioner Murphy with any concerns or topics. Update to be provided

at next RSC meeting

8/25/2014 Completed Addressed at 9/29/14 Meeting

Discussed at December 1, 2014 meeting, January 2015 Educational Session and

March 9, 2015 Meeting. The bylaws draft modifications were discussed at the RSC

retreat and meeting on July 27, 2015. Bylaws changes were considered at the

September 21, 2015 meetings but were not approved. January 25, 2016 – RSC Goal for

2016 to consider adopting the clean-up of

14-6 EPA’s Clean Power Plan –RSC Comments 9/29/2014 CompletedDiscussed at October 27, 2014 RSC

Meeting. Comments filed on November 24, 2014.

14-7SPC Task Force on New Members –

Discuss 3 RSC Action Items9/29/2014 Completed

Discussed at October 27, 2014 Meeting and December 1, 2014 Meeting. On January 2015 Educational Session for discussion and January 2015 Meeting Agenda as a

voting item. Feedback was provided to SPC TF on NM on items 1 and 2 on January 26, 2015 and subsequent to the March 9, 2015 RSC teleconference. The RSC will continue to discuss item 3 on cost allocation and has

delegated this item to the CAWG (Action Item 12). On July 27, 2015, the RSC

approved a scoping document developed by CAWG. The SPC TF on New Members

finalized its report, which was approved by the SPC in July 2015. The RSC approved

the New Member Process document with the addition of catch-al language permitting the RSC to invoke the new member process for

matters within the RSC’s responsibility.

14-8Cost Allocation for Non-Order 1000 Seams

Projects10/27/2014 Completed

RSC vote taken in December 2015 approving 60% threshold. Approved on

January 25, 2015.

14-9 Goals and Objectives for 2015 RSC Year 12/1/2014 Completed

Discussed at December 1, 2014 meeting and draft goals were reviewed on January

26, 2015, March 9, 2015, April 27, 2015 and September 21, 2015.

15-11Educational Session on SPP “Building

Blocks”1/25/2015 Completed

Educational Session on the SPP “Building Blocks” – possible topic for July retreat. Unclear what this was intended to cover. Removed when list of retreat topics was

updated.

15-12RSC Role in Cost Allocation for New

Member Integrations4/27/2015 Completed

In January 2015, the RSC tasked the CAWG with looking at what role the RSC should

have in regards to Cost Allocation methodology for new members joining SPP.

The RSC tasked the CAWG to develop a scoping document on how to apply cost allocation for new members joining SPP.

The Scope Document developed by CAWG was approved by the RSC on July 27, 2015.

At its October 2016 meeting, the RSC approved the process document developed

by the CAWG.

15-13 Aggregate Study Waiver Criteria 4/27/2015 Completed

The RSC determined it should review the eligibility requirements set out in Section

III.B.1 (specifically the 20% threshold), and whether the requirements are applicable

today in light of the changes to the transmission system since the requirements were approved. The RSC tasked the CAWG to evaluate the eligibility requirements for a

waiver request to see if the requirements are still applicable to the transmission system as it operates now. CAWG presented a draft scoping document to the RSC on July 27,

2015. A recommendation by the CAWG to retain the study waiver criteria was approved

by the RSC on January 30, 2017.

15-14 Capacity Margin Task Force Update 4/27/2015 CompletedAfter a presentation at the April 2015 RSC meeting, and discussion of the Capacity Margin Task Force the RSC tasked the

16-15 RSC Goals for 2016 1/25/2016 Completed

RSC discussed goals for 2016 at the January 2016 Educational Session. Any

additional goals should be submitted to Erin Cullum for distribution in advance of the April

2016 RSC meeting.

16-16 Engagement Term of RSC Auditor 1/25/2016 Completed

Determine the initial arrangement with the RSC auditor and the number of years for

reengagement. Erin Cullum will review the agreement and inform the RSC

16-17Educational Session Topic Request – Role

of RSC in SPP FERC Filings1/25/2016 Completed

Request for SPP Staff to provide educational update on the FERC filings process and the

role of the RSC.

16-18 Talking Points on CPP 1/25/2016 Completed Request for SPP’s talking points on the

CPP. Erin Cullum will distribute the link to posted comments.

16-20 Z2 Crediting Overview 4/25/2016 Completed

SPP to provide higher level overview of Z2 key points, significance, and state specific

information (if possible). This will be provided in advance of the next RSC

Meeting.

17-21Form Commissioner Forum for Mountain

West proposal.1/30/2017 Completed

Phone call scheduled for February 10, 2017 to discuss further.

17-22 Establish a Nominating Committee per the 1/30/2017 Completed Established for providing a slate of officers

17-23 Aggregate Study Waiver Criteria Review 1/30/2017 Completed

Annual CAWG review for limited time period (i.e. not in perpetuity). CAWG to present

recommendation(s) to the RSC in July 2017 on how the RSC should proceed in reviewing

the Aggregate Study Criteria.

14-1

14-5

Completed8/25/2014EPA 111(d) : (1) Lanny Nickell to provide

scope document on compliance analysis and

Completed12/1/2014Consideration of RSC Bylaws changes

related to membership eligibility

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17-24 RSC Retreat Information 4/17/2017 CompletedPaul Suskie to send RSC Retreat

information to Commissioners.

17-25Send new member integration process

documents to RSC members.7/24/2017 Completed Emailed on July 24, 2017

17-26Paul Suskie to send SPP bylaws to

Commissioner Huser.7/24/2017 Completed Provided July 24, 2017

17-27Consolidate all previously approved RSC

policies into one document.7/24/2017 Completed

SPP Staff working to consolidate said policies and will include as a part of the

orientation package referenced in Action Item No. 35.

17-28 RSC Bylaw Revisions 7/24/2017 Completed

17-30 October Education Session topic(s) 7/24/2017 CompletedKandi Hughes will send request to RSC

soliciting potential educational session topics for October.

17-31 FERC Contact Information 10/30/2017 CompletedSam Loudenslager to send Patrick Clarey’s

contact information to RSC members.

17-32 January 2018 Education Session Topic(s) 10/30/2017 Completed

Kandi Hughes will send request to RSC soliciting potential educational session topics

for January 2018. One topic suggested is the Mountain West Transmission Group.

17-33 RSC Website Page Revisions 10/30/2017 Completed

Contact Communications to update officers’ titles on website. Add secretary/treasurer to

the website, as well. (Update: the SPP website is moving in-house and will be

updated as soon as practically possible.)

17-34State Commissioner Forum for Mountain

West proposal.10/30/2017 Completed

RSC Member to review online documents pertaining to Mountain West. Commissioner Fiegen will send a Doodle Poll to schedule a State Commissioner Forum to be held during

the last week of November.

17-35 RSC Orientation Package 10/30/2017 CompletedSPP Staff to put together an orientation

package for current and future RSC Commissioners.

18-36 April 2018 Retreat Topics 1/29/2018 Completed Email potential retreat topics to Madam

President and SPP Staff.

18-37Resolution for former RSC Commissioner

Steve Stoll1/29/2018 Completed

SPP Staff to secure Commissioner Fiegen’s signature for Resolution for former RSC

Commissioner Steve Stoll.

18-38Proposed scope of work of cost allocation

issues.1/29/2018 Completed

CAWG will work with SPP Staff and Stakeholders on a proposed scope of work

and identifying interrelated issues as it relates to issues of cost allocation and report

at the April 2018 meeting.

18-39 OMS Reference Information 4/23/2018 Completed

Former CAWG Chair Adam McKinnie to distribute OMS reference information

(bylaws and past strategic initiatives) for informational purposes to RSC members.

18-40 Strategic Planning Topics 4/23/2018 Completed

RSC members to send strategic planning topics to Chairman Murphy by July 1st for discussion at the July RSC Educational

Session.

18-41 RSC History Document Revisions/Review 4/23/2018 Completed

SPP Staff will send updated revisions to RSC/CAWG members who will then send any further edits to Sam Loudenslager by early July for discussion at the July RSC

Educational Session.

18-42 July 2018 Educational Session Topics 4/23/2018 CompletedRemit educational topics for the July RSC

Educational Session to President Shari Feist Albrecht.

18-43 RSC/OMS Joint Task Force 7/30/2018 CompletedPresident Albrecht will poll the RSC

members to determine interest in serving on a potential RSC/OMS Joint Task Force.

18-44 Strategic Planning Session 7/30/2018 CompletedRSC members to provide comments on Strategic Plan framework to Chairman

18-45 October 2018 Educational Session Topics 7/30/2018 Completed Remit educational topics for the October

18-48 Meeting Schedule 10/29/2018 CompletedRSC Members to communicate suggestions

to the BOD for meeting schedules.

18-49 Schedule Monthly RSC Calls 1/28/2019 CompletedSchedule monthly RSC calls to use as

needed. Commissioners will send meeting conflicts to President O’Guinn and she will

19-50In-Person RSC Meetings (May and June

2019)4/29/2019 Completed

SPP Staff to check the availability of the DFW Hyatt to host in-person RSC meetings

on May 30, 2019 and June 24, 2019. 19-53 FERC Docket No. PL19-3-000 – OMS 7/29/2019 Completed Sam Loudenslager to circulate OMS-filed

19-54 Establish a Nominating Committee for 2019. 7/29/2019 CompletedSame Nominating Committee from 2019 retained (TX, OK, SD) who will provide a

slate of officers for 2020 RSC.

19-55 RSC Educational Session Topics 10/28/2019 Completed

Topic: Conservative Operations; Update: 04/27/2020: Will be covered at the July 2020

RSC Educational Session. Topic: FERC ROE NOPR update to be covered at the

June RSC Monthly Call.

19-56 2020 Work Plan 10/28/2019 CompletedRSC should develop a 2020 Work Plan. It

was decided that the 2020 Operational Objectives met this action item.

19-58 345kv Map (ITP Assessment) 10/28/2019 CompletedSPP Staff to provide 345kv-only map to

RSC.

19-59 Travel Policy 10/28/2019 CompletedClarify travel policy related to SPP

RSC/OMS Seams Liaison Committee.

19-60 Meeting Logistics 10/28/2019 CompletedChairman Altenbaumer to discuss potential meeting logistics options at a monthly RSC

conference call. 19-61 HITT 10/28/2019 Completed HITT Recommendations Updates.

20-1 Aging Infrastructure Information 1/27/2020 CompletedFollow up information provided to RSC on

aging infrastructure.

20-2 Generator Retirement 4/27/2020 CompletedMonthly updates provided to RSC on

generator retirement and status on other working groups.

20-3 SPP Strategic Plan 7/27/2020 Completed

SPP Staff to send Strategic Plan slide deck, including the proposed timeline, that was

presented in the Educational Session to the RSC.

20-5 RSC Strategic Planning 10/26/2020 Completed

Provide strategic planning slides from the October RSC Education Session to RSC

Commissioners and provide another update to the RSC at the January 2021 Education

Session.

20-4 August 2020 Monthly Call 7/27/2020 Completed

The following three topics to be included on the agenda for the next RSC monthly call: 1)

SPP Strategic Plan w/Mr. Green’s participation; 2) Joint RTO filings,

coordination efforts, etc.; and the 2021 RSC proposed budget. (Completed)

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20-6 Meeting Survey 10/26/2020 Completed

Provide Meeting Survey to the RSC Commissioners. Results to be discussed on

a future RSC monthly call.

20-7 FERC Order 2222 10/26/2020 Completed

Provide presentation on Order 2222 to the RSC at the January 2021 Education

Session.

21-2 Seams Presentation 1/25/2021 CompletedPublically noticed Seams presentation at the February 2021 RSC monthly meeting.

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