JOINT QUARTERLY STAKEHOLDER BRIEFING (SPP Board of ... materials 20190419_pgd.pdfScott Rupp, Missouri Public Service Commission (MoPSC) DeAnn T. Walker, Public Utility Commission of

Antitrust: SPP strictly prohibits use of participation in SPP activities as a forum for engaging in practices or communications that violate the antitrust laws. Please avoid discussion of topics or behavior that would result in anti-competitive behavior, including but not limited to, agreements between or among competitors regarding prices, bid and offer practices, availability of service, product design, terms of sale, division of markets, allocation of customers or any other activity that might unreasonably restrain competition.

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JOINT QUARTERLY STAKEHOLDER BRIEFING (SPP Board of Directors, Members Committee and Regional State Committee)

April 29, 2019

1:00 p.m. Doubletree Warren Place | Grand Ballroom

Tulsa, Oklahoma

1. QUARTERLY BRIEFINGS

a. Federal Energy Regulatory Commission (FERC) Update.………………………Patrick Clarey This report will update Stakeholders on the activities of the Federal Energy Regulatory Commission (FERC).

b. SPP RSC/OMS Seams Liaison Committee Update…………………………….Adam McKinnie

This report will update Stakeholders on the activities of the SPP RSC/OMS Seams Liaison Committee.

c. Holistic Integrated Tariff Team (HITT) Update …………………………..…………..…Tom Kent

This report will update Stakeholders on the activities of the HITT.

d. Transmission Planning Update………………………………………………...…….Lanny Nickell This report will update Stakeholders on the 2019 and 2020 ITP study activities.

e. Assignment of Notification to Construct …….....................................................Lanny Nickell

This report will updated Stakeholders on the Assignment of Notification to Construct 200479 Kansas Power Pool to GridLiance.

f. Integrated Marketplace Update…………………………………………………..………Bruce Rew

This report will update Stakeholders on the Integrated Marketplace.

g. Z2 Waiver Order...……………………………………………………………………........Paul Suskie This report will update the Stakeholders on the February 28, 2019 Order in the Z2 Waiver Docket.

RSC BUSINESS MEETING

2. CALL TO ORDER

3. PRELIMINARY MATTERS

a. Commissioners’ Roll Call and Declaration of a Quorum

b. Meeting Attendees Roll Call c. Adoption of Minutes from January 28, 2019

d. Review of Ongoing 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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4. UPDATE

a. RSC First Quarter 2019 Financial Report & SPP Report…………………….….Paul Suskie

5. BUSINESS ITEMS

a. 2019 RSC Operational Objectives ………………………………………...............Kim O’Guinn This report will update the RSC on the 2019 Operational Objectives. [POTENTIAL VOTING ITEM]

6. CAWG REPORT a. Cost Allocation Working Group (CAWG) Report……………………................Cindy Ireland

This report will update the RSC on the activities of the CAWG, including solicitation of RSC endorsement of the Distributed Energy Resource (DER) Whitepaper. [VOTING ITEM] .

i. Cost Allocation in Wind Rich Areas Update ..........................................John Krajewski This report will update the RSC on the CAWG’s work on this issue.

7. OTHER RSC MATTERS

8. NEW ACTION ITEMS

9. SCHEDULING OF NEXT REGULAR MEETINGS, SPECIAL MEETINGS OR EVENTS

a. RSC Meetings: July 29, 2019 – Des Moines, IA October 28, 2019 – Little Rock, AR

10. ADJOURNMENT OF BUSINESS MEETING

RSC/BOD/MC EXECUTIVE SESSION

11. RSC WILL HOLD AN EXECUTIVE SESSION WITH THE SPP BOARD & MEMBERS COMMITTEE.

* 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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RSC Meeting

January 28, 2019 1:00 p.m.

Doubletree New Orleans New Orleans, LA

President Kim O’Guinn called the Regional State Committee (RSC) meeting to order at 1:01 p.m. The meeting began with the Joint Quarterly Stakeholder briefing. The following briefings were provided; FERC (Patrick Clarey), SPP RSC/OMS Liaison Committee Update (Shari Feist Albrecht), Holistic Integrated Tariff Team (HITT) Update (Tom Kent), Transmission Planning Update (Lanny Nickell) and the Integrated Marketplace Update (Bruce Rew). ADMINISTRATIVE ITEMS

The following members participated: Shari Feist Albrecht, Kansas Corporation Commission (KCC) Jeff Byrd, New Mexico Public Regulation Commission (NMPRC) Bill Robertson for Foster Campbell, Louisiana Public Service Commission (LPSC)

Randel Christmann, North Dakota Public Service Commission (NDPSC) Kristie Fiegen, South Dakota Public Utilities Commission (SDPUC) Dennis Grennan, Nebraska Power Review Board (NPRB) Geri Huser, Iowa Utilities Board (IUB) Dana Murphy, Oklahoma Corporation Commission (OCC) Kim O’Guinn, Arkansas Public Service Commission (APSC) Scott Rupp, Missouri Public Service Commission (MoPSC)

DeAnn T. Walker, Public Utility Commission of Texas (PUCT) President O’Guinn called the RSC Business Meeting to order at 2:21 p.m. with roll call and a quorum was declared. There were 109 people in attendance, either in person or via the phone (Attendance & Proxies – Attachment 1). The first item of business was the approval of the 10/29/18 meeting minutes (RSC Minutes 10/29/18 – Attachment 2). Commissioner Geri Huser moved to approve the minutes with corrections; Commissioner Randy Christmann seconded. The motion was approved unanimously. Ms. Kandi Hughes (SPP staff) reviewed the RSC action items (RSC Action Items – Attachment 3). UPDATES

RSC Fourth Quarter Financial Report Mr. Paul Suskie (SPP staff) provided the RSC financial report for the fourth quarter for 2018 (RSC 2018 Q4 Financials – Attachment 4). He noted that the RSC was under budget for the year with the exception of the audit. The audit was $200 more than what was budgeted. This line item has been adjusted for the next year. SPP Report Mr. Paul Suskie provided the SPP update. Mr. Suskie welcomed and introduced Commissioner Jeff Byrd from the NMPRC, who is an environmental engineer. Mr. Suskie also introduced Ms. Darcy Ortiz and Ms. Susan Certoma as the newest members of the SPP Board of Directors. Paul introduced two guests visiting the RSC meeting, Commissioner Mike Frances from the Louisiana Public Service Commission and FERC staff person, Jette Gebhart, the Deputy Director of the office of Energy Market Regulation at FERC.

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Regional State Committee January 28, 2019

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SPP staff is hosting a two-day market training in New Orleans. The RSC commissioners and their staff are participating in the training. BUSINESS MEETING Ms. Kandi Hughes discussed the audit and tax engagement letter for 2018 (Engagement Letter from Landmark Certified Public Accountants – Attachment 5). Landmark is the company that has been completing the audit and taxes in the past but they have recently changed their name. Commissioner Kristie Fiegen moved to approve that Landmark Certified Public Accountants (formerly known as Thomas & Thomas) will continue with the RSC audit and tax service for the year ended December 31, 2018. Commissioner Dennis Grennan seconded. The motion was approved unanimously. Cost Allocation Working Group (CAWG) Report and Voting Items

CAWG Report Ms. Cindy Ireland (APSC Staff and CAWG Chair) provided the CAWG report (CAWG Report – Attachment 6). Ms. Ireland reviewed the past meetings and some of the more important action items. The CAWG decided to have a vice-chair to act in the event the chair was not available. The vice-chair will follow the succession of the RSC officers. Mr. John Krajewski will be the vice-chair for 2019. There was an update of FERC Docket EL 18-20-001 which relates to placement of transmission assets in an existing zone rather than creating a new zone and the potential cost shifts related to this. A project tracking update was provided. The CAWG receives regular updates during each meeting concerning the cost allocation for projects in wind rich areas, Holistic Integrated Tariff Team (HITT), progress in the west, and RSC/OMS Joint Task Force. Cost Allocation in Wind Rich Areas Mr. John Krajewski (NPRB and CAWG Vice-Chair) provided the report on Cost Allocation in Wind Rich Areas (Wind Rich Cost Allocation – Attachment 7). The activity since October 2018 was provided. The group has analyzed several options that would address cost allocation issues in wind rich zones along with a review of data provided by Sunflower Electric Power. CAWG is going to complete analysis of all of the options before making any recommendation. There is not a consensus among CAWG members regarding any changes to cost allocation. There will be additional discussion at the upcoming February and March CAWG meetings before the group can make a recommendation to HITT and the RSC. The next steps will be to complete analysis of the options, finish drafting a white paper, and develop recommendations to take to the HITT and RSC in April. Commissioner Walker commented that there are some overlapping issues between the wind rich topic and HITT. These two groups need to come together and work together on some areas. Commissioner Murphy agreed and suggested there be a lot of communication between the groups. Commissioner Murphy suggested adding goals or general objectives to the action items. Ms. Kandi Hughes reviewed the action items from the RSC educational session and the RSC meeting. SCHEDULING OF NEXT REGULAR MEETINGS, SPECIAL MEETINGS OR EVENTS

2019: April 29, 2019 – Tulsa, OK July 29, 2019 – Des Moines, IA October 28, 2019 – Little Rock, AR

With no further business, the meeting adjourned at 3:02 p.m. The RSC Commissioners and Board of Directors went into executive session. Respectfully Submitted, Paul Suskie

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Southwest Power Pool, Inc. REGIONAL STATE COMMITTEE

Action Items Status Report April 29, 2019

No. Action Item Date Originated Status Comments

19 Circulation of RSC Agendas 4/25/2016

Ongoing SPP to circulate draft agendas to RSC members and CAWG earlier for comment.

47 Develop RSC/OMS

Communication Plan for RSC Members

10/29/2018

Ongoing RSC Task Force members (from RSC/OMS Joint Task Force) to develop communication plan for the RSC members. (Discussions will continue to take place at NARUC and information will disseminated to the RSC.)

49 Schedule Monthly RSC Calls 01/28/2019

Ongoing Schedule monthly RSC calls to use as needed. Commissioners will send meeting conflicts to President O’Guinn and she will send a survey to the Commissioners to ultimately schedule the calls.

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EPA 111(d) : (1) Lanny Nickell to provide scope document on compliance analysis and an update on

when SPP reliability analysis will be completed

(2) Commissioner Reeves to provide update on possibility of studies to be performed by BPC and GPI, what services those entities are providing

8/25/2014

Completed

Addressed at 9/29/14 Meeting

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

3

Seams Project Task Force: CAWG will consider the issue

at next meeting and bring back to RSC for discussion

8/25/2014 Completed Addressed at 9/29/14 Meeting; On 10/27/14 Meeting as a voting item

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

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

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5 Consideration of RSC Bylaws

changes related to membership eligibility

Ongoing Completed

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 the Bylaws discussed in 2015. Prior to the January 30, 2017 RSC meeting, the current draft of the bylaws was distributed to the RSC. Phone call late August/early September on a Friday (Kandi to work with SS to get it scheduled) to finalize bylaws changes nominating committee; technical clean-up language, Executive Committee inclusion. July 2017 RSC meeting. Plan to vote in October. Send call information/agenda.

6 EPA’s Clean Power Plan –RSC Comments 9/29/2014 Completed Discussed at October 27, 2014 RSC Meeting.

Comments filed on November 24, 2014.

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7 SPC Task Force on New

Members – Discuss 3 RSC Action Items

9/29/2014

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.

8 Cost Allocation for Non-Order 1000 Seams Projects 10/27/2014 Completed RSC vote taken in December 2015 approving 60%

threshold. Approved on January 25, 2015.

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.

11 Educational Session on SPP “Building Blocks” 1/25/2015 Removed

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.

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12 RSC Role in Cost Allocation for New Member Integrations 4/27/2015 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.

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.

14 Capacity Margin Task Force Update 4/27/2015

Completed

After a presentation at the April 2015 RSC meeting, and discussion of the Capacity Margin Task Force, the RSC tasked the CAWG to evaluate how load is forecasted for the purpose of determining the reserve margin. CAWG reported back to the RSC at their July 2015 meeting. Voted and approved at April 2016 meeting.

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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 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

17 Educational Session Topic Request – Role of RSC in

SPP FERC Filings 1/25/2016 Completed Request for SPP Staff to provide educational update

on the FERC filings process and the role of the RSC.

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.

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.

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21 Form Commissioner Forum for Mountain West proposal. 01/30/2017 Completed Phone call scheduled for February 10, 2017 to

discuss further.

22 Establish a Nominating Committee per the RSC

Bylaws 01/30/2017 Completed

Established for providing a slate of officers for RSC. Commissioner Albrecht to draft sample bylaw language in establishing a Nominating Committee for review at July RSC Meeting

23 Aggregate Study Waiver Criteria Review 01/30/2017 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.

24 RSC Retreat Information 04/17/2017 Completed Paul Suskie to send RSC Retreat information to Commissioners.

25

Send new member integration

process documents to RSC members.

07/24/2017 Completed Emailed on July 24, 2017

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26

Paul Suskie to send SPP bylaws to Commissioner

Huser.

07/24/2017 Completed Provided July 24, 2017

27 Consolidate 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.

28 RSC Bylaw Revisions 07/24/2017 Completed

Schedule phone call late August/early September to finalize bylaws changes nominating committee, technical clean-up language, and Executive Committee inclusion. Plan to vote in October. Send call information/agenda.

29 Annual Review of Safe Harbor Criteria 07/24/2017 Completed

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.

30 October Education Session topic(s) 07/24/2017 Completed Kandi Hughes will send request to RSC soliciting

potential educational session topics for October.

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31 FERC Contact Information 10/30/2017 Completed Sam Loudenslager to send Patrick Clarey’s contact information to RSC members.

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.

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.)

34 State 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.

35 RSC Orientation Package 10/30/2017 Completed SPP Staff to put together an orientation package for current and future RSC Commissioners.

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36 April 2018 Retreat Topics 01/29/2018 Completed Email potential retreat topics to Madam President and SPP Staff.

37 Resolution for former RSC Commissioner Steve Stoll 01/29/2018 Completed

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

38 Proposed scope of work of cost allocation issues. 01/29/2018 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.

39 OMS Reference Information 04/23/2018 Completed

Former CAWG Chair Adam McKinnie to distribute OMS reference information (bylaws and past strategic initiatives) for informational purposes to RSC members.

40 Strategic Planning Topics 04/23/2018 Completed RSC members to send strategic planning topics to Chairman Murphy by July 1st for discussion at the July RSC Educational Session.

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41 RSC History Document Revisions/Review 04/23/2018 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.

42 July 2018 Educational Session Topics 04/23/2018 Completed

Remit educational topics for the July RSC Educational Session to President Shari Feist Albrecht.

43 RSC/OMS Joint Task Force 07/30/2018

Completed President Albrecht will poll the RSC members to determine interest in serving on a potential RSC/OMS Joint Task Force. Responses requested by August 10, 2018.

44 Strategic Planning Session 07/30/2018

Completed RSC members to provide comments on Strategic Plan framework to Chairman Murphy by September 1, 2018.

45 October 2018 Educational Session Topics 07/30/2018

Completed Remit educational topics for the October RSC Educational Session to President Shari Feist Albrecht.

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46 RSC/OMS Task Force

Update at January 2019 RSC Business Meeting

10/29/2018

Completed Include “RSC/OMS Task Force Update” as an agenda item for the January 2019 RSC Business Meeting.

47 Develop RSC/OMS

Communication Plan for RSC Members

10/29/2018

Completed RSC Task Force members (from RSC/OMS Joint Task Force) to develop communication plan for the RSC members.

48 Meeting Schedule 10/29/2018

Completed RSC Members to communicate suggestions to the BOD for meeting schedules.

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Regional State CommitteeFor the Three Months Ending March 31, 2019

Budget vs. Actual

YTD Actuals YTD Budget Variance

Income Other Income 92,002 124,250 (32,248) Total Income 92,002 124,250 (32,248)

Expense Travel 66,165 71,500 (5,335) Meetings 24,409 15,000 9,409 Audit - - - Administrative Costs 1,428 250 1,178 RSC Consultant - 37,500 (37,500) Technical Conference - - - Total Expense 92,002 124,250 (32,248)

Net Income - - -

2019 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. 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%20of%20the%20rsc%20(oct.%2010%202018).pdf

RSC Responsibilities

Section 7.0 of the SPP Bylaws comprise the regulatory involvement and the RSC within the SPP Regional Transmission Organization, with Section 7.2 specifically containing the RSC’s primary responsibilities. 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

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205 of the Federal Power Act. For more information on the SPP Bylaws, please the e-tariff viewer on the SPP website at the following link:

http://app.spp.org/etariff_viewer.html

2019 RSC Operational Objectives

Issue/Potential Steps/Status

RSC Primary Responsibility

Timeline Potential Outcome

Cost Allocation: HITT – Issue No.

1B: Review Existing Cost

Allocation Methodologies, and Cost Allocation for Byway facilities in Wind Rich Areas

Issue: HITT Goal for Issue No. 1B: Review existing transmission cost allocation methodologies in light of the implementation of the Integrated Marketplace and significant changes in generating resources. Upon completing the review, and in consideration of recommendations from the HITT for Issue No. 1, the Team will develop any needed high-level cost allocation policy recommendations for the consideration of the RSC/CAWG. CAWG action from 02/11/19. CAWG continue its work on cost allocation for Byway facilities in Wind Rich Areas. Suggestion: Based on any cost allocation recommendations from HITT, the RSC will work with SPP, members, and stakeholders to perform analysis and bring recommendations to MOPC, RSC, and BOD.

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.

TBD based on RSC discussion, HITT recommendation, and CAWG analysis. HITT has a goal to provide high level recommendations to the RSC and BOD in April 2019.

TBD based on RSC discussion, HITT recommendation, and CAWG analysis.

Deleted: ;

Deleted: and

Deleted: ;

Deleted: however, this could be extended to July 2019 meetings if work is not complete.

Deleted: Outcome: To ensure cost allocation methodology is providing equity across the region with costs roughly commensurate with benefits.

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http://app.spp.org/etariff_viewer.html

HITT – Issue No. 1A: Transmission

Planning, and Issue No. 2: Review of

Integrated Marketplace and

Essential Reliability Services

Issue: HITT Goal for Issue No. 1A: Develop high-level policy recommendation as to how SPP can align its transmission planning processes and resource adequacy needs with SPP’s Integrated Marketplace and tariff requirements. HITT Goal for Issue No. 2: Develop a holistic understanding of the SPP’s Integrated Marketplace and the essential services needed for the region in light of significant changes in generating resources and developing technology. Additionally, develop a better understanding of market products in other regions/markets. Upon obtaining this understanding, develop high-level policy recommendation as to how to enhance SPP’s Integrated Marketplace and tariff requirements. Suggestion: Based on any market recommendations from HITT related to items under RSC purview, the RSC will work with SPP, members, and stakeholders to perform analysis and bring recommendations to MOPC, RSC, and BOD.

SPP Bylaws: Section 7.2

TBD based on RSC discussion, HITT recommendation, and CAWG analysis. HITT has a goal to provide high level recommendations to the RSC and BOD in April 2019.

TBD based on RSC discussion, HITT recommendation, and CAWG analysis.

Deleted: Financial Transmission Rights (FTR):

Deleted: &

Deleted: related to any market changes that would impact FTRs

Deleted: Some SPP Load Serving Entities have raised concern about not being able to acquire FTRs when purchasing firm service based on how the markets currently operate.

Deleted: FTRs

Deleted: FTRs:¶¶

Deleted: (c) FTR allocation, where a locational price methodology is used; and ¶¶(d) Transition mechanism to be used to assure that existing firm customers receive FTRs equivalent to the customers’ existing firm rights.

Deleted: however, this could be extended to July 2019 meetings if work is not complete.

Deleted: Outcome: To ensure existing firm customers receive FTRs equivalent to the customers’ existing firm rights.

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OMS/RSC Seams Liaison

Committee:

Issue: Identify potential improvements in Seams areas and work with SPP and MISO on implementation. Status: Currently reviewing and discussing stakeholder responses, consider additional questions for SPP/MISO, discuss request for FERC analysis or an independent analysis (SPP/MISO Market Monitors) to identify transmission solutions that benefit both MISO and SPP customers.

SPP Bylaws, Section 7.0: Regulatory Involvement and Regional State Committee Joint Committee of the Organization of MISO States and the SPP Regional State Committee

TBD based results of analysis, recommendation from the Joint Committee, and RSC/OMS action.

Outcome: Identify potential improvements in the following areas and work with SPP and MISO on implementation: • Increase benefits to ratepayers in both markets by improving market-based transactions and operations across the seam. • Ensure equal consideration of beneficial regional and inter regional projects in transmission planning, including evaluation of projects identified in the Coordinated System Plans. • Support the timely interconnection of new resources that includes consideration of the dynamics of the interconnection queue in both RTOs. • Improve inter-RTO relations through state-led cooperation.

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

TBD: Order on Remand issued 02/28/2019.

TBD Formatted: Font: Bold

Formatted: Font: Bold

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2019 and Beyond Considerations and

Focus Points

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CAWG Report to the RSCApril 29, 2019

Cindy Ireland

Arkansas Public Service Commission

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Goal of Presentation______________________________________

• Discuss CAWG activities since the last RSC meetingFebruary 12, 2019 – Webex/CallMarch 5, 2019 – Dallas, TXApril 11, 2019 – Dallas, TX

• Discuss ongoing and expected future CAWG issues

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FERC______________________________________

• Review of Highway / Byway Cost Allocation

• Review of GridLiance Order in EC18-122

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Project Tracking Update______________________________________

• August 1 – October 31, 2018

• 12 upgrades completed - $19.3 million

• 13 new Notices to Construct (NTCs) - $201 million

• 4 withdrawn NTCs - $82.2 million

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Other Topics______________________________________

• Effective Load Carrying Capability (ELCC) Update

• Safe Harbor Limited Review

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Wind Rich Areas Update______________________________________

• John Krajewski will present to the RSC

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Distributed Energy Resources (DER)______________________________________

• Purpose of the DER Policy whitepaper Further define requirements for demand response

programs and behind-the-meter generation Address if each is treated as a load modifier or capacity

• Endorsement was unanimously approved by CAWG

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Distributed Energy Resources (DER)______________________________________

Recommended Motion:

The RSC endorses the Distributed Energy

Resource whitepaper that was approved by the

Supply Adequacy Working Group at their

December 18, 2018 meeting.

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Ongoing and Expected Future Issues______________________________________

• Cost allocation for projects in wind rich areas

• HITT

• RSC/OMS Seams Liaison Committee

• Safe Harbor Limited Review

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Upcoming CAWG Meetings______________________________________

• May 14, 2019 – Denver, CO

• June 4, 2019 - Dallas, TX

• July 9, 2019 - Dallas, TX

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Dis tr ibuted Energy

Resource Pol icy

October 2018

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Southwest Power Pool, Inc. Revision History

DER Whitepaper

1

Revision History

Date or Version Number

Author Change Description Comments

11/1/2018 Chris Haley Changes based on the Oct. 19th SAWG meeting and Stakeholder comments

11/9/2018 Chris Haley Included changes made at the November 8 SAWG meeting and added header sections under the CDDR section

12/10/2018 Chris Haley Included updates based on Stakeholder comments received since in the Nov. 8th SAWG Meeting

2/5/2019 Chris Haley Cleaned up and approved all of the edits made by the SAWG at the December 2018 meeting where the whitepaper was approved.

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Southwest Power Pool, Inc.

DER Whitepaper

2

Table of Contents Revision History ...........................................................................................................................................1

Background and Introduction ....................................................................................................................3

Distributed Energy Resource Categories...................................................................................................4

Flow Chart ....................................................................................................................................................9

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DER Whitepaper

3

Background and Introduction

As more generators near retirement and SPP’s historical planning reserve margin begins to subside to a margin closer to PRM levels that have been studied (e.g. NCP PRM of 12%), it becomes critical for the SPP Planning Coordinator and Balancing Authority to clearly track and to ensure the availability of demand response programs and behind the meter generation for purposes of meeting the Resource Adequacy Requirement and Winter Season Obligation. As described in Attachment AA, the forecasted Peak Demand of a Load Responsible Entity can be reduced by the impacts of demand response programs or behind-the-meter generation (DERs) that are that either registered or not registered resources in the SPP Integrated Marketplace and do not have SPP firm transmission service. The purpose of this policy paper is to further define the requirements for demand response programs and behind-the-meter generation, and address if each is treated as strictly a modifier for an LRE’s load or as capacity. Resources identified under this policy do not meet the requirements for Firm Capacity or Deliverable Capacity as defined in Attachment AA.

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DER Whitepaper

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Distributed Energy Resource Categories

Controllable and Dispatchable Demand Response Controllable and Dispatchable Demand Response (CDDR) is a specific program used to reduce the forecasted Peak Demand for Load Responsible Entities (LRE). These programs are either registered or not registered in the SPP Integrated Marketplace and will not be considered as capacity resources. The CDDR’s can be controlled or dispatched by SPP or the LRE. CDDR’s must be meet the following requirements: Program Criteria

• Accredited based on a level of reduction for the LRE’s forecasted Peak Demand. o The LRE’s highest forecasted Net Peak Demand shall not be exceeded for a four-hour

timeframe; the highest level of projected reduction achieved during four consecutive hours of the LRE’s forecasted Peak Demand compared to the LRE’s forecasted Net Peak Demand can be claimed for Resource Adequacy. See Figures 1 and 2.

o The four-hour requirement shall be reviewed by the SAWG annually.

Figure 1: Net Peak Demand remains static during the four-hour timeframe

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DER Whitepaper

5

Figure 2: Net Peak Demand is not exceeded during the four-hour timeframe

• If a program is actively managed by an LRE to reduce their peak demand, they have historically done and these programs are incorporated into their load forecast, the level of reduction can be included in the LRE’s forecasted Peak Demand and is not required to meet the testing requirements. The effects of the program must be reported for informational purposes.

• If a program is not being actively managed, an Operational and Capability Test must be performed in order to claim a reduction level. o If a program not actively managed is deployed, during the summer season, the deployment

of that program can suffice in place of the Operational Test. • Programs in the first year or expansion to an existing program to be reported at 50% of the

programs expected capability, unless validated by testing prior to May 15. o An Operational Test shall be performed during the upcoming summer season and reported

in the LRE’s RAW. Reporting and Documentation

• Must be identified to SPP through the RAW and each LRE must provide written documentation to SPP with the amount and type of program along with the procedures for achieving the demand reduction. o Documentation shall include the time & date of the Operational test, the type of demand

response program, the highest level of projected reduction achieved, the load at the time of reduction and the amount of reduction achieved, and any other information needed to verify CDDR testing requirements are met. State the criteria for determining the impact of the program

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DER Whitepaper

6

• The seasonal demand reduction shall be determined using historical hourly demand data, as provided by the LRE, sufficient to establish the reduction in load associated with the CDDR programs.

State the parameters and procedures for the SPP Balancing Authority to call on the demand response program when needed

Must be signed by an authorized representative of the LRE • LRE’s could be subject to reporting post season data to SPP on the use of the program

including how many times the program was deployed, dates and times of deployment(s), amount of peak demand that was reduced. SPP shall keep the individual testing results confidential and shall only publicly report aggregated information.

Testing • Annual Operational Tests are required for each program to validate its effectiveness. If expected

Operational Test results are not achieved it shall affectively limit the amount an LRE can claim in the next submission of a RAW. A waiver of this limit can be requested of the SAWG and shall be granted only by an affirmative vote of the SAWG o An Operational Test performed annually and documentation submitted to SPP o The test shall be completed during the summer season during a peak load period. o Achieved operational test performed at 50% of the programs capability.

o The achievable level shall be maintained for a minimum of one (1) hour. o The achievable level shall be reached within the period allowed by the agreement between

the LRE & LRE’s customer. o Capability tests will be done once every 5 years

o The amount of load reduction shall be 100% of the claimed capability, or; o The load should be reduced to an amount that is less than the load forecast of the CDDR

customer by an amount equivalent to 100% of the claimed capability o The reduction should be achieved for a minimum of one (1) hour o The test shall be completed during the summer season during a peak load period

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DER Whitepaper

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Controllable and Dispatchable Resource Resources meeting the requirements for Firm or Deliverable Capacity, as defined in Attachment AA, are not included in this policy. A Controllable and Dispatchable Resource (CDR) is a resource controlled or dispatched by the Load Responsible Entity. These resources are not registered in the SPP Integrated Marketplace or not a Designated Resource, but must be able to attest to having firm delivery to load. If a resource is identified as a CDR, it cannot be used as a load modifier unless the resource is Non-Controllable or Non-Dispatchable. If the resource is Non-Controllable and Non- Dispatchable the resource will be considered in the LRE’s forecasted Peak Demand, the same as Non-Dispatchable or Non-Controllable Demand Response. A CDR will also have the following requirements:

• Documentation of the resource including o Location on the SPP Transmission System that will see the impact of the CDR (e.g. load

reduction). This may be a substation bus not owned by the LRE. This may require coordination with the TOP.

o State the operating criteria parameters and procedures for the SPP Balancing Authority to call on the resource when needed.

o Must be listed as capacity resource for Resource Adequacy Requirements in the RAW o Must have its accredited capacity capped at the amount of the LRE’s forecasted peak load

obligation at the discrete point of delivery. o Accreditation, Testing and verification process must be established utilizing SPP Planning

Criteria 7.1, including applicable criteria for intermittent resources. o LRE submits testing and verification data per the SPP Planning Criteria.

Deleted: transmission service

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DER Whitepaper

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Non-Dispatchable or Non-Controllable Demand Response/Resources

• Demand Response programs deemed Non-Controllable and Non-Dispatchable may only be considered in the LRE’s forecasted Peak Demand. This also includes resources that are Non-Controllable and Non-Dispatchable by SPP or the Load Responsible Entity (e.g. roof top solar)

o The Peak Demand that results after incorporation of Non-Controllable and/or Non-Dispatchable Demand Response programs should still considered 50-50 forecast, with a 50% probability of the Peak Demand forecast being too high and a 50% probability of the Peak Demand forecast being too low.

• The seasonal demand reduction shall be determined using historical hourly demand data sufficient to establish the reduction in load associated with the Demand Response programs and may be augmented by an adequate system survey to further determine potential demand.

• Each LRE must report the projected MW level of Peak Demand reduction as an informational line item in the Resource Adequacy Workbook.

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DER Whitepaper

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Flow Chart

Distributed Energy Resource (DER)• Does not include Firm or Deliverable Capacity resources

Controllable and Dispatchable Demand Response (CDDR)

• Demand Response programs• Used to reduce the forecasted Peak Demand for LREs• Must be tested annually• LRE submits testing and verification documentation• Can be Controllable and Dispatchablle by the LRE• Can be registered or not registered in the SPP Integrated

Marketplace• Cannot be considered a capacity resource• Post season reporting• Reported as line item in the Resource Adequacy Workbook

Controllable and Dispatchable Resource (CDR)• Accredited capacity limited to the amount of load at the same location• Accredited and tested per SPP Planning Criteria 7.1• LRE submits testing and verification documentation• Must attest to having firm transmission service to load• Individual units must be identified in the Resource Adequacy

Workbook• Can be Controllable and Dispatchablle by the LRE• Post season reporting• Not registered in the SPP Integrated Marketplace

Non-Controllable or Non-Dispatchable• Demand response and capacity resources considered in the

LRE’s forecasted Peak Demand• Reported as informational only line item in the Resource

Adequacy Workbook

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Wind-Rich Area DiscussionPresented to Regional State Committee

April 29, 2019

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Current Status• Prioritizing Options

• Planned Approach Going Forward

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Prioritizing Options• Developed list of eight options Revise byway cost allocation regionally Revise byway in wind rich areas Four variations of generation injection rate Zonal consolidationMonitor for next two ITP cycles

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Prioritizing Options• Zonal consolidation received most votes

• Revise byway cost allocation for entire region and “monitor” received second-most votes

• Generation injection rate received significant votes but they were spread amongst the options Seven members had a form of generator

injection rate as highest or second-highest priority

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Prioritizing Options• HITT is planning to discuss cost allocation

at meeting on April 17-18

• Will provide input on this item verbally at the RSC meeting and how it affects CAWG work

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Planned Approach• Work through zonal consolidation

approaches with HITT

• Assess impact of changing byway cost allocation on regional basis

• Work on developing a proposed generator injection rate approach that has consensus amongst CAWG

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Planned Approach• Up or down vote on each option in June Start with “Monitor” and if it receives most

votes we do not pursue any of the other options

• Coordinate our vote and recommendations with HITT Plan for HITT was to have straw poll on

various options next week in Tulsa (will advise on those results)

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SECOND QUARTERLY PROJECT TRACKING REPORT 2019

April 2019

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CONTENTS

Executive Summary ................................................................................................................................................................ 3

NTC Project Summary – Reporting Quarter ................................................................................................................. 4

Completed Upgrades ................................................................................................................................................................................ 4

NTCs Issued .................................................................................................................................................................................................. 5

Portfolio Summary .................................................................................................................................................................. 7

Project Status Summary ........................................................................................................................................................................ 10

Out-of-bandwidth Projects ................................................................................................................................................ 11

Responsiveness Report ....................................................................................................................................................... 12

ITP20 Upgrades ...................................................................................................................................................................... 14

Morgan Transformer Project ............................................................................................................................................ 15

Appendix 1 ............................................................................................................................................................................... 16

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Q2 2019 Quarterly Project Tracking Report 3

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 – REPORTING QUARTER

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 NTC Issue

Date Upgrade

ID Upgrade Name Owner Source Study Cost Estimate

200365 1/12/2016 51410 Jal - Teague 115 kV Ckt 1 Rebuild SPS SPP-2014-AG1-AFS-6 $0

200386 5/17/2016 51433 Sayre 138 kV Cap Bank AEP 2016 ITPNT $1,997,360

200430 2/21/2017 51628 Neosho 161 kV Terminal Upgrades WR 2017 ITP10 $91,324

200429 2/22/2017 51730 Knoll - Post Rock 230 kV New Line Ckt 2 MIDW 2017 ITP10 $790,927

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NTC ID NTC Issue

Date Upgrade

ID Upgrade Name Owner Source Study Cost Estimate

200434 2/21/2017 51774 Lula- Tupelo Tap 138 kV Terminal

Upgrades OGE 2017 ITP10 $305,000

200429 2/22/2017 51815 Knoll Sub 230 kV Terminal MIDW 2017 ITP10 $1,938,416

200429 2/22/2017 51816 Post Rock Sub 230 kV Terminal MIDW 2017 ITP10 $1,743,688

200446 5/12/2017 51831 IPC 138 kV Cap Bank AEP 2017 ITPNT $1,917,591

72003 Union Ridge 230kV GEN-2015-069

Addition (NU) WR GI Studies $2,155,752

9 Upgrade(s) Completed $10,940,058

Table 1: Completed Upgrades

NTCS ISSUED

Figure 2: NTCs Issued

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NTC ID NTC Issue

Date UID Owner Upgrade Name Source Study

Estimated Cost of New

Upgrades

Estimated Cost of

Previously Approved Upgrades

210505 12/6/2018 102172 WFEC Clear Creek Tap 69 kV Cap Bank DPA-2018-June-902 $717,209 $0

210506 12/11/2018 51757 KCPL Crosstown 161 kV Terminal Upgrades 2018 ITPNT $1,120,000 $0

210506 12/11/2018 51758 KCPL Blue Valley 161 kV Terminal Upgrades 2018 ITPNT $1,400,000 $0

210506 12/11/2018 51759 KCPL Blue Valley - Crosstown 161kV Ckt1 2018 ITPNT $6,431,824 $0

210507 12/11/2018 92153 SPS Bopco - Road Runner 345 kV Ckt 1 New

Line DPA-2017-

November-808 $29,927,758 $0

210507 12/11/2018 92154 SPS Bopco - China Draw 345 kV Ckt 1 New

Line DPA-2017-

November-808 $30,496,976 $0

210507 12/11/2018 102153 SPS Bopco 345/115 kV Ckt 1 Transformer DPA-2017-

November-808 $6,205,015 $0

210507 12/11/2018 102154 SPS Bopco 345/115 kV Ckt 2 Transformer DPA-2017-

November-808 $6,122,043 $0

210507 12/11/2018 102156 SPS Eddy County - Kiowa 345 kV Ckt 1 New

Line DPA-2017-

November-808 $67,428,932 $0

210507 12/11/2018 102157 SPS Bopco 345 kV Substation DPA-2017-

November-808 $5,153,574 $0

210507 12/11/2018 102158 SPS Bopco 115 kV Substation DPA-2017-

November-808 $11,741,936 $0

11 Upgrade(s) Issued $166,745,267 $0

Table 2: NTCs Issued

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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 of Directors (Board) or through a FERC filed service agreement under the SPP Open Access

Transmission Tariff (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) (ITP20) 4. Upgrades within approved Balanced Portfolios2 (BP) 5. Approved high priority upgrades (HP) 6. Endorsed Sponsored Upgrades (SP) 7. Approved Interregional Projects2 (IR)

This report will document changes over the previous quarter to 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. Projects approved in ITP20 assessments are now

reflected in this total.

Figure 3: Total Portfolio

2 There are currently no Balanced Portfolio or Interregional projects included in Quarterly Project Tracking

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Figure 4: Upgrade Type by Cost Summary3

Figure 5: Estimated Cost for All Projects per In-Service Year

3 Mileage not available for all upgrade categories

$0

$100

$200

$300

$400

$500

$600

2019 2020 2021 2022 2023 2024 2033

GI HP ITP ITP20 SP TS

Esti

mat

ed C

ost

(M

illio

ns)

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Figure 6: Completed Upgrades by Estimated Cost4 Last Four Quarters

Figure 7: Completed Upgrades by Type Last Four Quarters

4Figures 8 and 9 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.

$-

$50

$100

$150

$200

$250

$300

$350

$400

$450

$500

Q2 2018 Q3 2018 Q4 2018 Q1 2019

GI

HP

ITP

ITP20

SP

TSEsti

mat

edC

ost

(M

illio

ns)

0

10

20

30

40

50

60

Q2 2018 Q3 2018 Q4 2018 Q1 2019

GI

HP

ITP

ITP20

SP

TSNu

mb

er o

f P

roje

cts

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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

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

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

Suspended: Project suspended; pending re-evaluation Within NTC Commitment Window: NTC/NTC-C issued, still within the 90-day written

commitment to construct window and no commitment received

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

Within RFP Response Window: RFP issued for the project

Figure 8: Portfolio Project Status

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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. Table 5 provides

summary information and Table 6 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

No projects moved outside of bandwidth parameters during the reporting period.

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 %

No projects moved outside of bandwidth parameters during the reporting period.

Table 4: Out-of-Bandwidth Project Cost Detail

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RESPONSIVENESS REPORT

Table 7 and Figures 10 and 11 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 %

AECC 1 0 0% 0 0% 0 0%

AEP 59 58 98% 2 3% 1 2%

BEPC 23 23 100% 1 4% 0 0%

CBPC 1 0 0% 0 0% 0 0%

CPEC 2 2 100% 0 0% 0 0%

CUS 2 2 100% 0 0% 0 0%

EDE 3 0 0% 0 0% 0 0%

EREC 3 3 100% 0 0% 0 0%

GHP 1 0 0% 0 0% 0 0%

GMO 2 1 50% 0 0% 0 0%

GRDA 7 0 0% 0 0% 0 0%

ITCGP 4 0 0% 0 0% 0 0%

KCPL 13 11 85% 0 0% 0 0%

KPP 1 0 0% 0 0% 0 0%

MIDW 10 10 100% 3 30% 3 30%

MKEC 7 7 100% 0 0% 0 0%

NIPCO 2 0 0% 0 0% 2 100%

NPPD 47 32 68% 14 30% 9 19%

OGE 54 33 61% 5 9% 6 11%

OPPD 15 14 93% 2 13% 0 0%

SEPC 17 16 94% 0 0% 4 24%

SPS 187 184 98% 0 0% 0 0%

TBD 10 0 0% 0 0% 0 0%

TSMO 2 2 100% 0 0% 0 0%

WAPA 9 1 11% 0 0% 1 11%

WFEC 67 27 40% 22 33% 0 0%

WR 36 29 81% 6 17% 2 6%

Total 585 455 78% 55 9% 28 5%

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

30402 50493 OPPD S3459 345/161 kV Transformer Ckt 2 1/1/2033 $12,600,000

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

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MORGAN TRANSFORMER PROJECT

Pursuant to a Joint Operating Agreement and resulting Joint Coordinated System Planning Process

between AECI and SPP, SPP and AECI have agreed to share cost associated with the Morgan Transformer

Project.

Project ID Upgrade ID Owner Upgrade Name Projected In-Service Date

Latest Cost Estimate

31132 51740 AECI Morgan 345/161kV Transformer TBD TBD

31132 51832 AECI Morgan Line Uprate TBD TBD

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APPENDIX 1

(See accompanying list of Quarterly Project Tracking Projects)

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NT

C I

D

PID

UID

Pro

ject

Ow

ne

r

Stat

e(s

)

Pro

ject

Nam

e

Up

grad

e N

ame

Pro

ject

Typ

e

STE

P P

roje

ct T

ype

Pro

ject

Ow

ne

r In

dic

ate

d I

n-

Serv

ice

Dat

e

RT

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ete

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Ne

ed

Dat

e

Lett

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of

No

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on

to

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ruct

Iss

ue

Dat

e

NT

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ou

rce

Stu

dy

Bas

elin

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ost

Est

imat

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Bas

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ost

Est

imat

e

Year

Bas

elin

e C

ost

Est

imat

e

wit

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atio

n

Cu

rre

nt

Co

st E

stim

ate

Fin

al C

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Pro

ject

Sta

tus

Vo

ltag

es

(kV

)

Nu

mb

er

of

Ne

w

Nu

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of

Re

bu

ild/R

eco

nd

uct

or

Nu

mb

er

of

Vo

ltag

e

Co

nve

rsio

n

20003 138 10176 WFEC OKLine - OGE Woodward - WFEC Woodward

69 kVWOODWARD - WOODWARD 69KV CKT 1 Regional Reliability ITP 5/1/2017 4/1/2009 2/13/2008 2007 STEP $1,050,000 2014 $1,187,979 $1,050,000 $2,369,867 COMPLETE 69 3.5

20003 139 10177 WFEC OK Multi - Kingfisher 69 kV CIMARRON - DOVER SW 69KV CKT 1 Regional Reliability ITP 11/1/2008 6/1/2008 2/13/2008 2007 STEP $4,050,000 $3,850,690 RE-EVALUATION 69

19985 140 10179 WFEC OK Line - ACME - W Norman 69 kV ACME - WEST NORMAN 69KV CKT 1 Regional Reliability ITP 8/1/2015 6/1/2008 2/2/2007 2006 STEP $912,000 2014 $1,031,844 $912,000 $1,033,064 COMPLETE 69 3.8

200397 242 10308 WFEC OK Line - Elmore - Paoli 69 kV Rebuild Elmore - Paoli 69 kV Ckt 1 Rebuild Regional Reliability ITP 8/1/2017 6/1/2009 5/17/2016 2016 ITPNT $3,240,000 2016 $3,489,126 $3,240,000 $3,790,002 COMPLETE 69 10.8

20003 361 10471 WFEC OK Line - Fletcher - Marlow Jct 69 kV FLETCHER - MARLOW JCT 69KV CKT 1 Regional Reliability ITP 9/25/2015 6/1/2011 2/13/2008 2007 STEP $2,000,000 2014 $2,262,816 $2,000,000 $2,218,635 COMPLETE 69 7

20003 399 10519 WFEC OK Line - Lindsay - Wallville 69 kV LINDSAY SW - WALLVILLE 69KV CKT 1 Regional Reliability ITP 3/13/2015 6/1/2012 2/13/2008 2007 STEP $1,347,000 2014 $1,524,007 $1,347,000 $1,609,327 COMPLETE 69 4.85

20003 402 10522 WFEC OK Multi - Granfield - Cache SW 138 kV GRANDFIELD - INDIAHOMA 138KV CKT 1 Regional Reliability ITP 10/15/2015 6/1/2012 2/13/2008 2007 STEP $1,125,000 2014 $1,272,834 $1,125,000 $3,578,274 COMPLETE 138 3

20003 402 10523 WFEC OK Multi - Granfield - Cache SW 138 kV CACHE - INDIAHOMA 138KV CKT 1 Regional Reliability ITP 3/31/2015 6/1/2012 2/13/2008 2007 STEP $7,306,000 2014 $8,266,068 $7,306,000 $1,431,400 COMPLETE 138 13.7

20003 402 10524 WFEC OK Multi - Granfield - Cache SW 138 kVGRANDFIELD 138/69KV TRANSFORMER

CKT 1Regional Reliability ITP 4/1/2016 6/1/2012 2/13/2008 2007 STEP $5,000,000 2014 $5,657,041 $5,000,000 $4,868,110 COMPLETE 138/69

200216 451 10583 AEP ARMulti - Chamber Springs - Farmington 161

kV

Chamber Springs - Farmington REC 161

kV Ckt 1Regional Reliability ITP 3/28/2017 6/1/2013 2/20/2013 2013 ITPNT $12,705,537 2013 $14,734,528 $12,705,537 COMPLETE 161 11.1

200166 461 10597 SPS TX/NM Line - Curry - Bailey 115kVBailey County Interchange - Curry County

Interchange 115 kV Ckt 1Regional Reliability ITP 9/29/2016 6/1/2012 4/9/2012 2012 ITPNT $35,099,588 2012 $41,722,380 $38,607,163 $38,607,163 COMPLETE 115 41.5

200216 478 10615 AEP LALine - Forbing Tap - South Shreveport 69

kV

Forbing Tap - South Shreveport 69 kV Ckt

1Regional Reliability ITP 4/13/2016 6/1/2013 2/20/2013 2013 ITPNT $1,221,505 2013 $1,416,572 $1,221,505 COMPLETE 69 2.3

200216 501 10646 AEP TXLine - Evenside - Northwest Henderson 69

kV

Evenside - Northwest Henderson 69 kV

Ckt 1Regional Reliability ITP 5/11/2018 6/1/2018 2/20/2013 2013 ITPNT $11,980,465 2013 $13,893,666 $11,980,465 COMPLETE 69 6.4

200167 503 10648 AEP TX Line - Diana - Perdue 138 kV Diana - Perdue 138 kV Ckt 1 Regional Reliability ITP 12/31/2014 6/1/2013 4/9/2012 2012 ITPNT $1,004,187 2012 $1,193,662 $1,004,187 COMPLETE 138

200216 504 10649 AEP LA Line - Brownlee - North Market 69 kV Brownlee - North Market 69 kV Ckt 1 Regional Reliability ITP 3/22/2017 6/1/2013 2/20/2013 2013 ITPNT $12,424,849 2013 $14,409,016 $17,162,457 COMPLETE 69 4.7

200246 512 10657 AEP LALine - Ellerbe Road - Forbing Tap 69 kV Ckt

1Ellerbe Road - Forbing T 69 kV Ckt 1 Regional Reliability ITP 4/13/2016 6/1/2014 2/19/2014 2014 ITPNT $8,174,689 2014 $9,248,911 $8,174,689 COMPLETE 69 2

20130 764 11007 SPS TXXFR - Happy County 115/69 kV

Transformers

HAPPY INTERCHANGE 115/69KV

TRANSFORMER CKT 1Regional Reliability ITP 6/30/2016 6/1/2012 2/14/2011 2010 STEP $2,809,520 2014 $3,178,714 $1,518,414 COMPLETE 115/69

20130 764 11009 SPS TXXFR - Happy County 115/69 kV

Transformers

HAPPY INTERCHANGE 115/69KV

TRANSFORMER CKT 2Regional Reliability ITP 6/30/2016 6/1/2012 2/14/2011 2010 STEP $2,812,436 2014 $3,182,013 $1,565,056 COMPLETE 115/69

200256 766 11010 SPS TX XFR - Newhart 230/115 kV Ckt 2 Newhart 230/115 kV Ckt 2 Transformer Regional Reliability ITP 12/2/2016 6/1/2015 2/19/2014 2014 ITPNT $6,886,931 2014 $7,791,930 $13,001,665 $13,001,665 COMPLETE 230/115

200229 772 11017 SPS TX Line - Carlisle - Wolfforth 230 kVCarlisle Interchange - Wolfforth

Interchange 230 kV Ckt 1Regional Reliability ITP 3/27/2018 6/1/2017 9/10/2013 2013 ITPNT $32,429,240 2013 $37,607,976 $29,400,000 IN SERVICE 230 16.8

200381 777 11027 SPS TX Sub - East Plant 115 kV Terminal Upgrade East Plant 115 kV Terminal Upgrade Regional Reliability TS 6/1/2017 6/1/2017 4/12/2016SPP-2014-AG1-AFS-

6$5,000 2016 $5,384 $0 COMPLETE 115

200214 802 11064 SPS NMXFR - Eddy Co. 230/115 kV Transformer Ckt

1

Eddy County Interchange 230/115 kV

Transformer Ckt 1Regional Reliability ITP 3/31/2017 6/1/2016 2/20/2013 2013 ITPNT $4,255,145 2013 $4,934,664 $4,529,862 COMPLETE 230/115

20084 834 11101 SPS NMLine - Portales - Zodiac 69 kV to 115 kV

Conversion

PORTALES INTERCHANGE - ZODIAC

115KV CKT 1Regional Reliability ITP 11/30/2015 6/1/2013 2/8/2010 2009 STEP $6,500,000 2014 $7,354,153 $7,588,596 $8,084,263 COMPLETE 115 3

200166 836 11104 SPS TXSub - Convert Muleshoe East 69 kV to 115

kV Convert Muleshoe 69 kV to 115 kV Regional Reliability ITP 12/18/2015 6/1/2012 4/9/2012 2012 ITPNT $4,673,759 2012 $5,555,630 $1,569,093 $1,631,376 COMPLETE 115 0.3 1.5

200214 841 11110 SPS TX XFR - Graham 115/69 kV Ckt 1Graham Interchange 115/69 kV

Transformer Ckt 1Regional Reliability ITP 12/9/2015 6/1/2014 2/20/2013 2013 ITPNT $2,101,391 2013 $2,436,969 $1,337,225 $1,337,255 COMPLETE 115/69

200397 844 11113 WFEC OKLine - Sara Road - Sunshine Canyon 69 kV

Ckt 1 Rebuild

Sara Road - Sunshine Canyon 69 kV Ckt 1

RebuildRegional 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

Multi - Centre St. - Hereford NE 115 kV Ckt

1 and Centre St. and Hereford 115 kV Load

Conversion

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 $10,462,286 $10,000,000 IN SERVICE 115 7.8

200207 865 11142 OPPD NE Line - Sub 917 - Sub 918 69 kV Ckt 1 Sub 917 - Sub 918 69 kV Ckt 1 Regional Reliability ITP 5/21/2018 6/1/2018 2/20/2013 2013 ITPNT $475,340 2013 $551,249 $475,340 COMPLETE 69

200216 879 11158 AEP OK Line - Bluebell - Prattville 138 kV Bluebell - Prattville 138 kV Ckt 1 Regional Reliability ITP 6/2/2015 6/1/2014 2/20/2013 2013 ITPNT $10,241,314 2013 $11,876,785 $10,241,314 COMPLETE 138 9

200208 909 11205 WFEC OKMulti - Payne Switching Station - OU 138

kV conversionCole - OU Switchyard 138 kV Ckt 1 Regional Reliability ITP 7/1/2016 6/1/2013 2/20/2013 2013 ITPNT $1,705,000 2013 $1,977,277 $1,705,000 $1,659,669 COMPLETE 138

20096 936 11236 AEP TX/OK Line - Valliant - NW Texarkana 345 kVNORTHWEST TEXARKANA - VALLIANT

345KV CKT 1High Priority HP 12/16/2016 10/1/2014 6/30/2010 Priority Projects $185,751,250 2016 $200,033,780 $185,751,250 COMPLETE 345 76.25

20097 938 11238 TSMO MOMulti - Nebraska City - Mullin Creek - Sibley

345 kV (GMO)Sibley - Mullin Creek 345 kV High Priority HP 12/14/2016 6/1/2017 7/23/2010 Priority Projects $184,665,083 2015 $203,835,699 $173,500,000 CLOSED OUT 345 105

20097 938 11239 TSMO MOMulti - Nebraska City - Mullin Creek - Sibley

345 kV (GMO)

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 $89,858,113 $76,500,000 CLOSED OUT 345 65

20098 939 11240 OPPD NELine - Nebraska City - Mullin Creek 345 kV

(OPPD)

Nebraska City - Mullin Creek 345 kV

(OPPD)High Priority HP 12/15/2016 6/1/2017 6/30/2010 Priority Projects $70,361,776 2015 $77,666,235 $59,170,665 $59,170,665 COMPLETE 345 45

20104 947 11261 AEP OKLine - Broken Arrow North South Tap -

Oneta 138 kV Ckt 1

BROKEN 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 $6,869,911 $6,072,000 COMPLETE 138 4.33

200404 1001 11315 SPS TXLine - Randall - South Georgia and Osage

Station 115 kV Line Re-termination

Randall County Interchange - South

Georgia Interchange 115 kV Ckt 1Regional Reliability TS 4/19/2017 6/1/2016 7/25/2016

SPP-2015-AG1-AFS-

6$10,316,217 2016 $11,109,437 $13,100,684 COMPLETE 115 2

200214 1003 11317 SPS TXXFR - Grassland 230/115 kV Transformer

Ckt 1

Grassland Interchange 230/115 kV


200256 1004 11318 SPS TX XFR - Swisher 230/115 kV Ckt 1Swisher County Interchange 230/115 kV

Ckt 1 TransformerRegional Reliability ITP 12/3/2015 6/1/2014 2/19/2014 2014 ITPNT $3,183,028 2014 $3,601,304 $2,869,670 $2,869,670 COMPLETE 230/115

20110 1021 11343 OGE OK Line - Arcadia - Redbud 345 kV Ckt 3 ARCADIA - REDBUD 345KV CKT 3 Transmission Service TS 6/1/2019 6/1/2019 8/25/2010SPP-2008-AGP1-

AFS-9$18,000,000 2014 $20,365,348 $18,000,000 ON SCHEDULE < 4 345 5

200214 1031 11355 SPS TXXFR - Crosby Co. 115/69 kV Transformers

Ckt 1 and Ckt 2

Crosby County Interchange 115/69 kV


200214 1031 11356 SPS TXXFR - Crosby Co. 115/69 kV Transformers

Ckt 1 and Ckt 2

Crosby County Interchange 115/69 kV


200166 1033 11358 SPS TXLine - Randall - South Georgia 115 kV

reconductor

Randall County Interchange - South

Georgia Interchange 115 kV Ckt 1 # 2Regional Reliability ITP 4/12/2017 6/1/2017 4/9/2012 2012 ITPNT $6,300,000 2014 $7,127,872 $4,294,271 COMPLETE 115 4.1

20130 1036 11372 SPS TX Line - Soncy convert load to 115 kV 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 $1,051,644 $2,087,292 DELAY - MITIGATION 115 1.04

20132 1084 11424 WFEC OK Line - Alva - Freedom 69 kV Ckt 1 ALVA - FREEDOM 69KV CKT 1 Regional Reliability ITP 3/28/2014 6/1/2011 2/14/2011 2010 STEP $6,243,750 2014 $7,064,230 $6,243,750 $6,066,031 COMPLETE 69 18.5


kV conversionCole - Criner 138 kV Ckt 1 Regional Reliability ITP 4/1/2016 6/1/2013 2/20/2013 2013 ITPNT $1,400,000 2013 $1,623,571 $1,400,000 COMPLETE 138

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

Second 2019 Quarterly Tracking Portfolio

COMPLETE Upgrade is operation and all project activities are complete

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

ON SCHEDULE < 4 On Schedule within 4-year horizon

ON SCHEDULE > 4 On Schedule beyond 4-year horizon

NTC-C PROJECT ESTIMATE Within the NTC-C Project Estimate (CPE) window

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

RFP RESPONSE WINDOW RFP Issued

DELAY - MITIGATION Behind schedule, interim mitigation provided or project may change but time permits the implementation of project; asterisk (*) indicates interim

SUSPENDED NTC/GIA suspended

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

66 of 78

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200297 1139 11501 SPS TXLine - Allen Sub - Lubbock South

Interchange 115 kV Ckt 1

Allen 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 $650,058 ON SCHEDULE < 4 115

200369 1142 11506 SPS TXLine - Canyon East - Randall 115 kV Ckt 1

Rebuild

Canyon East Sub - Randall County

Interchange 115 kV Ckt 1 RebuildRegional Reliability TS 4/17/2020 2/1/2014 2/12/2016

SPP-2011-AG3-AFS-

11$12,806,065 2016 $13,790,731 $5,724,761 DELAY - MITIGATION 115 18.5

200262 1144 11508 SPS TX XFR - Hitchland 230/115 kV Ckt 2 Hitchland 230/115 kV Ckt 2 Transformer Regional Reliability TS 3/29/2017 6/1/2019 4/9/2014SPP-2011-AG3-AFS-

11$4,087,144 2014 $4,624,228 $4,525,487 COMPLETE 230/115

200359 1146 11509 SPS TX XFR - Carlisle 230/115 kV Ckt 1 Carlisle 230/115 kV Ckt 1 Transformer Regional Reliability TS 3/9/2018 10/1/2015 12/2/2015SPP-2014-AG1-AFS-

6$3,853,326 2016 $4,149,611 $3,000,000 IN SERVICE 230/115

200214 1147 11512 SPS TXMulti - Potter - Channing - Dallam 230 kV

ConversionChanning - Potter County 230 kV Ckt 1 Regional Reliability ITP 12/31/2015 6/1/2013 2/20/2013 2013 ITPNT $1,819,440 2013 $2,109,993 $2,512,528 $2,512,528 COMPLETE 230 52


ConversionChanning - XIT 230 kV Ckt 1 Regional Reliability ITP 12/31/2015 6/1/2013 2/20/2013 2013 ITPNT $9,166,904 2013 $10,630,798 $871,088 $871,088 COMPLETE 230 70


ConversionXIT 230/115/13.2 kV Transformer Ckt 1 Regional Reliability ITP 12/31/2015 6/1/2013 2/20/2013 2013 ITPNT $3,863,195 2013 $4,480,122 $9,865,350 $9,865,350 COMPLETE 230/115

20003 30037 50043 WFEC OK Device - Sweet Water Cap 69 kV SWEETWATER 138KV Regional Reliability ITP 3/1/2008 6/1/2008 2/13/2008 2007 STEP $243,000 RE-EVALUATION 69

20003 30043 50049 WFEC OK Device - Twin Lakes Cap 69 kV TWIN LAKES 138KV Regional Reliability ITP 6/1/2008 6/1/2008 2/13/2008 2007 STEP $108,000 RE-EVALUATION 69

20003 30079 50085 WFEC OK Device - Carter Cap 69 kV CARTER JCT 69KV Regional Reliability ITP 10/15/2015 6/1/2010 2/13/2008 2007 STEP $324,000 2014 $366,576 $324,000 $568,369 COMPLETE 69

20017 30160 50168 OGE AR XFR - Ft Smith 500/161 kV Ckt 3FT SMITH 500/161KV TRANSFORMER CKT

5Transmission Service TS 11/10/2017 6/1/2017 1/16/2009

SPP-2006-AG3-AFS-

11$25,635,637 2017 $26,933,441 $25,635,637 COMPLETE 500/161

20017 30164 50172 OGE AR Line - VBI - VBI North 69 kV VBI - VBI NORTH 69KV CKT 1 Transmission Service TS 6/1/2014 6/1/2017 1/16/2009SPP-2006-AG3-AFS-

11$100,000 2014 $113,141 $0 CLOSED OUT 161

20080 30201 50208 NPPD NE Device - Clarks 115 kV CLARKS 115KV Regional Reliability ITP 6/1/2018 11/1/2012 2/8/2010 2009 STEP $700,000 2014 $791,986 $700,000 DELAY - MITIGATION 115

20080 30203 50210 NPPD NE Device - Oneill 115 kV ONEILL 115KV Regional Reliability ITP 7/1/2018 11/1/2012 2/8/2010 2009 STEP $700,000 2014 $791,986 $1,772,846 COMPLETE 115

20122 30296 50334 AEP TX Device - Winnsboro 138 kV WINNSBORO 138KV Regional Reliability ITP 4/21/2016 6/1/2016 2/14/2011 2010 STEP $1,166,400 2014 $1,319,675 $1,166,400 COMPLETE 138

20122 30298 50336 AEP LA Device - Logansport 138 kV LOGANSPORT 138KV Regional Reliability ITP 9/10/2016 6/1/2016 2/14/2011 2010 STEP $1,166,400 2014 $1,319,675 $1,731,419 COMPLETE 138

20136 30320 50366 WFEC OK Line - Canton - Taloga 69 kV ckt 1 CANTON - TALOGA 69KV CKT 1 Transmission Service TS 10/15/2015 6/1/2011 5/27/2011SPP-2009-AGP2-

AFS-6$4,800,000 2014 $5,430,759 $4,800,000 $3,059,477 COMPLETE 69 9.7

200282 30331 50378 SPS NM Device - Eagle Creek 115 kV Eagle Creek 115 kV Cap Bank High Priority HP 3/14/2016 6/1/2015 5/19/2014 HPILS $1,470,325 2014 $1,663,538 $1,416,992 $1,416,992 COMPLETE 115

200166 30351 50401 SPS TX Device - Crosby 115 kV Capacitor Crosby 115 kV #2 Regional Reliability ITP 11/4/2015 6/1/2012 4/9/2012 2012 ITPNT $985,519 2012 $1,171,472 $1,334,087 $1,334,087 COMPLETE 115

200166 30356 50406 SPS TX Multi - Cedar Lake Interchange 115 kVDiamondback Interchange 115/69 kV

Transformer Ckt 1Regional Reliability ITP 8/14/2015 6/1/2012 4/9/2012 2012 ITPNT $5,524,876 2012 $6,567,342 $7,399,322 $6,981,891 COMPLETE 115/69 17.79

200166 30356 50407 SPS TX Multi - Cedar Lake Interchange 115 kVSulphur Interchange - Diamondback

Interchange 115 kV Ckt 1Regional Reliability ITP 8/14/2015 6/1/2012 4/9/2012 2012 ITPNT $7,699,644 2012 $9,152,457 $8,287,874 $9,933,961 COMPLETE 115 12.5

200255 30361 50413 AEP OK Multi - Chisholm - Gracemont 345 kV Chisholm - Gracemont 345kV Ckt 1 (AEP) Regional Reliability ITP 12/7/2017 3/1/2018 2/6/2014 2012 ITP10 $65,082,311 2017 $68,377,103 $65,082,311 COMPLETE 345 72

200255 30361 50414 AEP OK Multi - Chisholm - Gracemont 345 kV Chisholm 345/230 kV Substation Regional Reliability ITP 12/7/2017 3/1/2018 2/6/2014 2012 ITP10 $17,471,695 2017 $18,356,200 $17,471,695 COMPLETE 345/230

200240 30361 50419 OGE OK Multi - Chisholm - Gracemont 345 kV Chisholm - Gracemont 345 kV Ckt 1 (OGE) Regional Reliability ITP 3/1/2018 3/1/2018 12/20/2013 2012 ITP10 $43,853,500 2017 $46,073,583 $37,541,440 COMPLETE 345 30.16

200223 30364 50420 OGE OKMulti - Woodward District EHV - Tatonga -

Matthewson - Cimarron 345 kV

Tatonga - Woodward District EHV 345 kV

Ckt 2Regional Reliability ITP 2/1/2018 3/1/2021 5/23/2013 2012 ITP10 $59,522,400 2013 $69,027,736 $50,594,040 COMPLETE 345 49


Matthewson - Cimarron 345 kVMatthewson - Tatonga 345 kV Ckt 2 Regional Reliability ITP 2/15/2018 3/1/2021 5/23/2013 2012 ITP10 $65,785,650 2013 $76,291,185 $56,387,700 COMPLETE 345 61

200222 30367 50425 ITCGP KS Multi - Elm Creek - Summit 345 kV Elm Creek - Summit 345 kV Ckt 1 (ITCGP) Regional Reliability ITP 3/1/2018 3/1/2018 3/21/2013 2012 ITP10 $31,312,169 2013 $36,312,516 $42,024,978 COMPLETE 345 29.77

200222 30367 50426 ITCGP KS Multi - Elm Creek - Summit 345 kV Elm Creek 345/230 kV Transformer Regional Reliability ITP 12/31/2016 3/1/2018 3/21/2013 2012 ITP10 $5,405,101 2013 $6,268,260 $4,928,468 COMPLETE 345/230

200222 30367 50427 ITCGP KS Multi - Elm Creek - Summit 345 kV Elm Creek 345 kV Terminal Upgrades Regional Reliability ITP 12/31/2016 3/1/2018 3/21/2013 2012 ITP10 $8,243,291 2013 $9,559,690 $12,154,733 COMPLETE 345

200222 30367 50428 ITCGP KS Multi - Elm Creek - Summit 345 kV Elm Creek 230 kV Terminal Upgrades Regional Reliability ITP 12/31/2016 3/1/2018 3/21/2013 2012 ITP10 $1,886,035 2013 $2,187,222 $2,165,198 COMPLETE 230

200253 30374 50441 NPPD NE Multi - Hoskins - Neligh 345 kV Neligh 345/115 kV Substation Regional Reliability ITP 6/8/2018 6/1/2016 2/19/2014 2014 ITPNT $10,082,325 2017 $10,592,743 $10,381,296 COMPLETE 345/115

200220 30375 50442 NPPD NEMulti - Gentleman - Cherry Co. - Holt Co.

345 kVCherry Co. - Gentleman 345 kV Ckt 1 Regional Reliability ITP 5/1/2021 1/1/2018 3/11/2013 2012 ITP10 $139,090,440 2013 $161,302,268 $174,319,989 DELAY - MITIGATION 345 100.7


345 kVCherry Co. Substation 345 kV Regional Reliability ITP 5/1/2021 1/1/2018 3/11/2013 2012 ITP10 $11,896,383 2013 $13,796,157 $9,936,752 DELAY - MITIGATION 345


345 kVCherry Co. - Holt Co. 345 kV Ckt 1 Regional Reliability ITP 5/1/2021 1/1/2018 3/11/2013 2012 ITP10 $146,065,000 2013 $169,390,619 $211,189,224 DELAY - MITIGATION 345 124.3


345 kVHolt Co. Substation 345 kV Regional Reliability ITP 5/1/2021 1/1/2018 3/11/2013 2012 ITP10 $16,324,800 2013 $18,931,763 $13,119,129 DELAY - MITIGATION 345

200395 31068 50447 SPS TX Multi - Tuco - Yoakum 345/230 kV Ckt 1 Tuco - Yoakum 345 kV Ckt 1 Regional Reliability ITP 6/1/2020 6/1/2017 5/17/2016 2016 ITPNT $128,473,352 2016 $138,351,748 $123,902,322 DELAY - MITIGATION 345 107

210484 31068 50451 SPS TX Multi - Tuco - Yoakum 345/230 kV Ckt 1 Yoakum 345/230 kV Ckt 1 Transformer Regional Reliability HP 6/1/2019 6/1/2017 4/27/2018 HPILS $5,047,344 2016 $5,435,437 $4,703,455 DELAY - MITIGATION 345/230

210484 30376 50452 SPS NM Multi - Hobbs - Yoakum 345/230 kV Ckt 1 Hobbs 345/230 kV Ckt 1 Transformer High Priority HP 3/24/2018 6/1/2018 4/27/2018 HPILS $16,204,449 2014 $18,333,847 $13,685,569 COMPLETE 345/230

200190 805 50453 SPS TX Multi - Bowers - Howard 115 kV Ckt 1 Bowers - Howard 115 kV Regional Reliability TS 2/28/2016 6/1/2013 1/18/2013DPA-2011-

SEPTEMBER-095$30,851,077 2013 $35,777,791 $41,063,661 $39,784,124 COMPLETE 115 33


Matthewson - Cimarron 345 kVCimarron - Matthewson 345 kV Ckt 2 Regional Reliability ITP 7/1/2016 3/1/2021 5/23/2013 2012 ITP10 $32,936,400 2013 $38,196,126 $32,936,400 COMPLETE 345 16

200309 30376 50457 SPS NM/TX Multi - Hobbs - Yoakum 345/230 kV Ckt 1 Hobbs - Yoakum 345 kV Ckt 1 High Priority HP 6/1/2020 6/1/2020 12/3/2014 HPILS $90,628,750 2014 $102,538,112 $87,349,796 ON SCHEDULE < 4 345 52


Matthewson - Cimarron 345 kVMatthewson 345 kV Regional Reliability ITP 6/24/2016 3/1/2021 5/23/2013 2012 ITP10 $19,967,850 2013 $23,156,584 $19,967,850 COMPLETE 345

30401 50492 TBD Cass Co. - S.W. Omaha (aka S3454) 345 kVCass Co. - S.W. Omaha (aka S3454) 345 kV

Ckt1Regional Reliability ITP20 1/1/2033 $33,126,800 ON SCHEDULE > 4 345 28

30402 50493 OPPDXfr- S3459-S1209 345/161 transformer no.

2S3459 345/161 kV Transformer Ckt 2 ITP20 1/1/2033 $12,600,000 ON SCHEDULE > 4 345/161

200190 30410 50503 SPS TX Line - Bowers - Canadian 69 kV Rebuild Bowers - Canadian 69 kV Rebuild Regional Reliability TS 7/1/2015 6/1/2012 1/18/2013DPA-2011-

SEPTEMBER-095$34,999,584 2013 $40,588,787 $31,779,309 $31,779,309 COMPLETE 69 39 10

200262 30420 50513 SPS TXLine - Bushland Interchange - Deaf Smith

County Interchange 230 kV Ckt 1

Bushland Interchange - Deaf Smith Co

Interchange 230 kV Ckt 1 Terminal

Upgrade

Regional Reliability TS 12/15/2017 2/1/2014 4/9/2014SPP-2011-AG3-AFS-

11$285,176 2014 $322,650 $261,084 COMPLETE 230

200193 30422 50515 SPS TXXFR - Deaf Smith County Interchange

230/115 kV transformer CKT 1

Deaf Smith County Interchange 230/115

kV Transformer Ckt 1 #2Regional Reliability TS 2/25/2016 6/1/2012 11/20/2012

SPP-2010-AGP1-

AFS-8$4,273,633 2012 $5,080,007 $3,428,156 $3,428,156 COMPLETE 230/115

200214 30423 50516 SPS TXXFR - Deaf Smith County Interchange

230/115 kV Ckt 2

Deaf Smith County Interchange 230/115

kV Transformer Ckt 2Regional Reliability ITP 5/12/2016 6/1/2013 2/20/2013 2013 ITPNT $4,225,233 2013 $4,899,975 $2,976,736 $2,976,736 COMPLETE 230/115

200214 30424 50517 SPS TX/OKLine - Ochiltree - Tri-County Cole 115 kV

Ckt 1

Ochiltree - Tri-County REC Cole 115 kV

Ckt 1 RebuildRegional Reliability ITP 11/20/2015 6/1/2013 2/20/2013 2013 ITPNT $11,332,148 2013 $13,141,817 $13,096,041 $13,096,041 COMPLETE 115 17

200210 30426 50519 MIDW KS Line - Pheasant Run - Seguin 115 kV Ckt 1 Pheasant Run - Seguin 115 kV Ckt 1 Regional Reliability ITP 7/15/2014 6/1/2014 2/20/2013 2013 ITPNT $11,128,231 2013 $12,905,336 $7,811,905 CLOSED OUT 115 19.3

200216 30436 50531 AEP TX Line - New Gladewater - Perdue 138 kV New Gladewater - Perdue 138 kV Ckt 1 Regional Reliability ITP 12/31/2014 6/1/2016 2/20/2013 2013 ITPNT $1,000,000 2013 $1,159,693 $1,000,000 COMPLETE 138

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200242 30437 50532 WR KSMulti - Geary County 345/115 kV and

Geary - Chapman 115 kVGeary County 345/115 kV Substation Regional Reliability ITP 6/1/2018 6/1/2014 2/19/2014 2014 ITPNT $20,530,196 2014 $23,228,032 $22,470,822 COMPLETE 345/115

200241 30438 50533 GRDA OK Line - Kerr - 412 Sub 161 kV Ckt 1Kerr - 412 Sub 161 kV Ckt 1 Terminal

UpgradesRegional Reliability ITP 6/1/2017 6/1/2017 2/19/2014 2014 ITPNT $161,100 2014 $182,270 $161,100 $207,691 COMPLETE 161


Geary - Chapman 115 kV

Chapman Junction - Geary County 115 kV

Ckt 1Regional Reliability ITP 12/13/2018 6/1/2014 2/19/2014 2014 ITPNT $27,938,225 2014 $31,609,537 $28,732,415 IN SERVICE 115 4.67 10.42

200241 30440 50535 GRDA OK Line - 412 Sub - Kansas Tap 161 kV Ckt 1412 Sub - Kansas Tap 161 kV Ckt 1

Terminal Upgrades Regional Reliability ITP 12/31/2018 6/1/2018 2/19/2014 2014 ITPNT $54,500 2014 $61,662 $294,840 DELAY - MITIGATION 161

200384 30444 50539 SPS TX Device - Cochran 115 kV Cap Bank Cochran 115 kV Cap Bank Regional Reliability TS 12/20/2018 6/1/2016 4/20/2016 DPA-2013-JUN-342 $1,808,805 2016 $1,947,885 $2,442,000 DELAY - MITIGATION 115

200231 30449 50545 AEP LALine - Rock Hill - Springridge Pan-Harr REC

138 kV Ckt 1

Rock Hill - Springridge Pan-Harr REC 138

kV Ckt 1Regional Reliability ITP 9/19/2016 6/1/2014 9/23/2013 2013 ITPNT $25,060,655 2013 $29,062,677 $25,060,655 COMPLETE 138 27.6

200214 30451 50546 SPS NM Line - Atoka - Eagle Creek 115 kV Ckt 1 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 $24,131,253 $22,500,000 DELAY - MITIGATION 115 22.1

200214 30466 50560 SPS NM XFR - Potash Junction 115/69 kV Ckt 1Potash Junction 115/69 kV Transformer

Ckt 1Regional Reliability ITP 8/7/2015 6/1/2013 2/20/2013 2013 ITPNT $2,127,697 2013 $2,467,476 $2,422,732 $2,422,732 COMPLETE 115/69

200229 30469 50563 SPS NMMulti - Kilgore Switch - South Portales -

Market St. - Portales 115 kV

Kilgore Switch - South Portales 115 kV Ckt

1Regional Reliability ITP 2/7/2018 6/1/2018 9/10/2013 2013 ITPNT $5,136,476 2013 $5,956,737 $4,551,015 COMPLETE 115 5.3


Market St. - Portales 115 kVMarket St. - South Portales 115 kV Ckt 1 Regional Reliability ITP 7/11/2018 6/1/2018 9/10/2013 2013 ITPNT $6,498,682 2013 $7,536,479 $4,743,822 COMPLETE 115 6


Market St. - Portales 115 kVMarket St. - Portales 115 kV Ckt 1 Regional Reliability ITP 2/7/2018 6/1/2018 9/10/2013 2013 ITPNT $15,394,429 2013 $17,852,818 $15,278,476 COMPLETE 115 10.4

200216 30471 50567 AEP TX Line - Dekalb - New Boston 69 kV Dekalb - New Boston 69 kV Ckt 1 Regional Reliability ITP 6/5/2015 6/1/2013 2/20/2013 2013 ITPNT $16,548,317 2013 $19,190,974 $16,548,317 $15,777,911 CLOSED OUT 69 13.2

200216 30472 50568 AEP LA Line - Hardy Street - Waterworks 69 kV Hardy Street - Waterworks 69 kV Ckt 1 Regional Reliability ITP 6/25/2015 6/1/2013 2/20/2013 2013 ITPNT $7,519,658 2013 $8,720,498 $7,519,658 $5,366,606 CLOSED OUT 69 1.65

200216 30473 50569 AEP ARLine - Midland REC - North Huntington 69

kV

Midland REC - North Huntington 69 kV

Ckt 1Regional Reliability ITP 5/15/2015 6/1/2013 2/20/2013 2013 ITPNT $1,829,026 2013 $2,121,109 $1,829,026 $11,990,487 COMPLETE 69 1.3

200216 30474 50570 AEP AR Line - Midland - Midland REC 69 kV Midland - Midland REC 69 kV Ckt 1 Regional Reliability ITP 5/15/2015 6/1/2013 2/20/2013 2013 ITPNT $5,653,353 2013 $6,556,157 $5,653,353 COMPLETE 69 4.3

200216 30475 50571 AEP AR Line - Howe Interchange - Midland 69 kV Howe Interchange - Midland 69 kV Ckt 1 Regional Reliability ITP 5/15/2015 6/1/2013 2/20/2013 2013 ITPNT $9,145,130 2013 $10,605,547 $9,145,130 COMPLETE 69 7

200207 30478 50574 OPPD NELine - 6815 Tap South in Ckt 623 - Sub 6815

T3 69 kV Ckt 16815 Tap South - Sub 6815 T3 69 kV Ckt 1 Regional Reliability ITP 3/13/2015 6/1/2015 2/20/2013 2013 ITPNT $260,590 2013 $302,205 $260,590 $439,561 COMPLETE 69 0.71

200194 30481 50577 OGE OKLine - El Reno - Service PL El Reno 69 kV

CKT 1El Reno - Service PL El Reno 69 kV CKT 1 Transmission Service TS 6/1/2014 6/1/2017 11/20/2012

SPP-2010-AGP1-

AFS-8$10,000 2013 $11,597 $0 CLOSED OUT 69


kV conversionCriner - Payne Switching Station 138 kV Regional Reliability ITP 9/25/2015 6/1/2013 2/20/2013 2013 ITPNT $3,000,000 2013 $3,479,080 $3,000,000 $3,672,718 COMPLETE 138


kV conversionPayne Switching Station 138 kV Regional Reliability ITP 9/25/2015 6/1/2013 2/20/2013 2013 ITPNT $250,000 2013 $289,923 $250,000 $308,707 COMPLETE 138

200228 30484 50582 WR KSMulti - Viola 345/138kV Transformer and

138 kV Lines to Clearwater and GillViola 345/138 kV Transformer Ckt 1 Regional Reliability ITP 4/19/2018 6/1/2018 9/10/2013 2013 ITPNT $13,331,670 2017 $14,006,586 $10,376,149 COMPLETE 345/138


138 kV Lines to Clearwater and GillClearwater - Viola 138 kV Ckt 1 Regional Reliability ITP 11/16/2018 6/1/2018 9/10/2013 2013 ITPNT $31,492,903 2017 $33,087,231 $26,100,000 IN SERVICE 138 21.8


138 kV Lines to Clearwater and GillGill - Viola 138 kV Ckt 1 Regional Reliability ITP 11/16/2018 6/1/2018 9/10/2013 2013 ITPNT $17,234,744 2017 $18,107,253 $17,234,744 IN SERVICE 138 27.9

200200 30488 50595 WFEC OKMulti - Renfrow - Wakita - Noel Switch 138

kVNoel Switch - Wakita 138 kV Ckt 1 Regional Reliability TS 1/28/2013 1/1/2013 3/1/2013

DPA-2012-MAR-

143-147$17,928,848 2013 $20,791,967 $17,928,848 $19,103,991 COMPLETE 138


kVSandridge Tap - Wakita 138 kV Ckt 1 Regional Reliability TS 6/30/2013 1/1/2013 3/1/2013

DPA-2012-MAR-

143-147$7,220,000 2013 $8,372,986 $7,220,000 $7,250,930 COMPLETE 138


kVWakita 138/69 kV Transformer Ckt 1 Regional Reliability TS 6/24/2013 1/1/2013 3/1/2013

DPA-2012-MAR-

143-147$3,573,553 2013 $4,144,226 $3,573,553 $3,247,997 COMPLETE 138/69

200200 30490 50599 WFEC OK Device - Fairview 69 kV Fairview 69 kV Capacitor Regional Reliability TS 4/24/2015 1/1/2013 3/1/2013DPA-2012-MAR-

143-147$237,000 2013 $274,847 $237,000 $524,345 COMPLETE 69

200200 30491 50600 WFEC OK Device - Hazelton 69 kV Hazelton 69 kV Capacitor Regional Reliability TS 3/1/2017 1/1/2013 3/1/2013DPA-2012-MAR-

143-147$237,000 2013 $274,847 $735,000 COMPLETE 69


Geary - Chapman 115 kVGeary County 345 kV Regional Reliability ITP 5/17/2018 6/1/2014 2/19/2014 2014 ITPNT $16,190,561 2014 $18,318,134 $16,290,638 COMPLETE 345

200210 30494 50606 MIDW KSLine - Hays Plant - South Hays 115 kV Ckt 1

RebuildHays Plant - South Hays 115 kV Ckt 1 #2 Regional Reliability ITP 10/13/2016 6/1/2013 2/20/2013 2013 ITPNT $8,832,219 2013 $10,242,666 $9,392,940 CLOSED OUT 115 3.87

200231 30495 50607 AEP LA Sub - Messick 500/230 kV Layfield 500/230 kV Transformer Ckt 1 Regional Reliability ITP 4/29/2016 6/1/2013 9/23/2013 2013 ITPNT $30,369,537 2013 $35,219,352 $22,851,755 COMPLETE 500/230

200400 30496 50609 NPPD NEMulti - Bobcat Canyon 345/115 kV and

Bobcat Canyon - Scottsbluff 115 kVBobcat Canyon - Scottsbluff 115 kV Ckt 1 Regional Reliability ITP 10/26/2017 6/1/2014 8/17/2016 2014 ITPNT $26,027,015 2016 $28,028,248 $21,201,741 COMPLETE 115 23

200200 30497 50610 WFEC OKLine - Buffalo - Buffalo Bear - Ft. Supply 69

kVBuffalo Bear - Buffalo 69 kV Ckt 1 Regional Reliability TS 12/19/2014 12/1/2013 3/1/2013

DPA-2012-MAR-

143-147$6,000,000 2013 $6,958,161 $1,500,000 $4,094,378 COMPLETE 69

200200 30497 50611 WFEC OKLine - Buffalo - Buffalo Bear - Ft. Supply 69

kVBuffalo Bear - Ft. Supply 69 kV Ckt 1 #2 Regional Reliability TS 12/19/2014 12/1/2013 3/1/2013

DPA-2012-MAR-

143-147$1,500,000 2013 $1,739,540 $6,000,000 $960,410 COMPLETE 69


138 kV Lines to Clearwater and GillViola 345 kV Terminal Equipment Regional Reliability ITP 4/19/2018 6/1/2018 9/10/2013 2013 ITPNT $5,007,657 2017 $5,261,170 $2,718,649 COMPLETE 345

200231 30495 50615 AEP LA Sub - Messick 500/230 kV Layfield 500 kV Terminal Upgrades Regional Reliability ITP 4/29/2016 6/1/2013 9/23/2013 2013 ITPNT $21,508,234 2013 $24,942,957 $32,212,715 COMPLETE 500


kV

Sandridge Tap - Renfrow 138 kV Ckt 1

(WFEC)Regional Reliability TS 4/30/2014 1/1/2013 3/1/2013

DPA-2012-MAR-

143-147$2,000,000 2013 $2,319,387 $2,000,000 $1,700,835 COMPLETE 138

200234 30501 50624 WFEC OKMulti - Renfrow - Medford Tap - Chikaskia

138 kVMedford Tap - Pond Creek 138 kV (WFEC) Regional Reliability TS 4/1/2016 5/1/2013 10/28/2013

DPA-2012-MAR-

151-154-161-JUL-

218-SEP-243

$3,540,000 2015 $3,907,498 $3,540,000 $5,754,747 COMPLETE 138 13

200234 30502 50626 WFEC OK Device - Renfrow-Sandridge 138 kV Renfrow-Sandridge Capacitor 138 kV Regional Reliability TS 4/1/2019 6/1/2017 10/28/2013

DPA-2012-MAR-

151-154-161-JUL-

218-SEP-243

$185,004 2013 $214,548 $185,004 $131,775 RE-EVALUATION 138

200234 30503 50628 WFEC OK Device - Hazelton 69 kV #2 Hazelton Capacitor 69 kV #2 Regional Reliability TS 3/1/2017 6/1/2017 10/28/2013

DPA-2012-MAR-

151-154-161-JUL-

218-SEP-243

$185,004 2013 $214,548 $0 COMPLETE 69

200263 30507 50634 MIDW KS Line - Hays Plant - Vine Street 115 kV Ckt 1Hays Plant - Vine Street 115kV Ckt 1

Terminal UpgradeRegional Reliability TS 10/1/2014 2/1/2014 3/31/2014

SPP-2011-AG3-AFS-

11$15,720 2014 $17,786 $15,720 CLOSED OUT 115

200369 30509 50636 SPS TXLine - Canyon East Sub - Canyon West Sub

115 kV Ckt 1

Canyon East Sub - Canyon West Sub 115

kV Ckt 1 RebuildRegional Reliability TS 5/18/2016 2/1/2014 2/12/2016

SPP-2011-AG3-AFS-

11$2,694,811 2016 $2,902,017 $5,013,917 $5,013,917 COMPLETE 115 3.7

200262 30510 50637 SPS TX Line - Mustang - Shell CO2 115 kV Ckt 1 Mustang - Shell CO2 115 kV Ckt 1 Transmission Service TS 5/1/2019 6/1/2015 4/9/2014SPP-2011-AG3-AFS-


200410 30552 50690 SPS NMLine - Oxy Permian Sub - West Bender Sub

115 kV Ckt 1

Oxy Permian Sub - West Bender Sub 115

kV Ckt 1 RebuildRegional Reliability ITP 10/28/2016 6/1/2018 8/17/2016 2014 ITPNT $973,674 2013 $1,129,163 $742,000 COMPLETE 115 0.5

200256 30555 50693 SPS NM Quahada Switching Station 115 kV Quahada Switching Station 115 kV Regional Reliability ITP 7/9/2015 6/1/2015 2/19/2014 2014 ITPNT $6,943,260 2014 $7,855,661 $7,668,328 $7,668,328 COMPLETE 115 0.68

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200296 30560 50698 WR KS Line - Sumner County - Viola 138 kV Ckt 1 Sumner County - Viola 138 kV Ckt 1 Zonal Reliability ITP 6/1/2020 6/1/2019 9/2/2014 2014 ITPNT $51,513,963 2014 $58,283,321 $48,513,963 DELAY - MITIGATION 138 28

200258 30561 50699 OPPD NE XFR - S1366 161/69 kV Ckt 1 S1366 161/69 kV Ckt 1 Transformer Regional Reliability ITP 5/31/2016 6/1/2016 2/19/2014 2014 ITPNT $4,426,730 2014 $5,008,439 $3,263,075 COMPLETE 161/69

200245 30563 50702 WFEC OK Device - Sandy Corner 138 kV Sandy Corner 138 kV Cap Bank Regional Reliability ITP 6/1/2017 6/1/2017 2/19/2014 2014 ITPNT $504,000 2014 $570,230 $504,000 COMPLETE 138

200309 30569 50708 SPS NMMulti - Potash Junction - Road Runner

230/115 kV Ckt 1

Potash Junction - Road Runner 230 kV Ckt

1High Priority HP 10/27/2015 6/1/2015 12/3/2014 HPILS $43,096,827 2014 $48,760,104 $48,898,787 $48,898,787 COMPLETE 230 40.4

200309 30569 50709 SPS NMMulti - Potash Junction - Road Runner

230/115 kV Ckt 1Road Runner 230/115 kV Substation High Priority HP 10/27/2015 6/1/2015 12/3/2014 HPILS $10,576,672 2014 $11,966,534 $10,842,567 $59,759,398 COMPLETE 230/115 1

200246 30573 50718 AEP LALine - Broadmoor - Fort Humbug 69 kV Ckt

1

Broadmoor - Fort Humbug 69 kV Ckt 1

RebuildRegional Reliability ITP 6/21/2017 6/1/2019 2/19/2014 2014 ITPNT $6,695,986 2014 $7,575,893 $6,695,986 COMPLETE 69 1.7

200246 30574 50719 AEP TXLine - Daingerfield - Jenkins Rec 69 kV Ckt 1

Rebuild

Daingerfield - Jenkins REC T 69 kV Ckt 1


200246 30575 50720 AEP TXLine - Hallsville - Longview Heights 69 kV

Ckt 1

Hallsville - Longview Heights 69 kV Ckt 1


200246 30576 50721 AEP TX Line - Hallsville - Marshall 69 kV Ckt 1 Hallsville - Marshall 69 kV Ckt 1 Rebuild Regional Reliability ITP 6/2/2017 6/1/2014 2/19/2014 2014 ITPNT $15,248,925 2014 $17,252,760 $19,751,448 COMPLETE 69 11.2

200256 30577 50722 SPS NMLine - Chavis - Price - CV Pines - Capitan

115 kV Ckt 1Chaves - Price 115 kV Ckt 1 Rebuild Regional Reliability ITP 1/30/2018 6/1/2017 2/19/2014 2014 ITPNT $4,701,279 2014 $5,319,066 $5,961,279 COMPLETE 115 5 5


115 kV Ckt 1CV 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 $4,705,151 $4,319,668 COMPLETE 115 3


115 kV Ckt 1Capitan - 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 $6,126,635 $4,343,227 COMPLETE 115 5 5

200333 30578 50725 SPS TX Multi - Bailey Co. - Lamb Co. 115 kV Bailey Co. - Bailey Co. Pump 115 kV Ckt 1 Regional Reliability ITP 6/15/2021 6/1/2016 2/18/2015 2014 ITPNT $8,208,578 2014 $9,287,253 $9,715,422 DELAY - MITIGATION 115

200333 30578 50729 SPS TX Multi - Bailey Co. - Lamb Co. 115 kVBailey Co. Pump - Sundan Rural 115 kV

Ckt 1Regional Reliability ITP 6/15/2021 6/1/2016 2/18/2015 2014 ITPNT $8,038,605 2014 $9,094,944 $8,753,365 DELAY - MITIGATION 115 11.7

200333 30578 50731 SPS TX Multi - Bailey Co. - Lamb Co. 115 kVNew Amherst 116/69 kV Ckt 1

TransformerRegional Reliability ITP 4/15/2021 6/1/2016 2/18/2015 2014 ITPNT $5,367,770 2014 $6,073,139 $5,695,912 DELAY - MITIGATION 115/69 0.2

200333 30578 50732 SPS TX Multi - Bailey Co. - Lamb Co. 115 kV New Amherst - Sudan Rural 115 kV Ckt 1 Regional Reliability ITP 11/15/2021 6/1/2016 2/18/2015 2014 ITPNT $5,074,202 2014 $5,740,994 $5,713,799 DELAY - MITIGATION 115 8.6

200475 30580 50733 WR KS Line - Crestview - Kenmar 69 kV Kenmar - Northeast 69 kV Ckt 1 Rebuild Regional Reliability ITP 11/7/2017 6/1/2014 2/21/2018 2014 ITPNT $5,590,592 2014 $6,325,242 $5,531,119 $5,531,119 COMPLETE 69 1.74

200333 30578 50734 SPS TX Multi - Bailey Co. - Lamb Co. 115 kVNew Amherst 115 kV Terminal Upgrades

Ckt 1Regional Reliability ITP 11/15/2021 6/1/2016 2/18/2015 2014 ITPNT $3,028,707 2014 $3,426,704 $3,064,697 DELAY - MITIGATION 115

200333 30578 50735 SPS TX Multi - Bailey Co. - Lamb Co. 115 kV Lamb Co. - New Amherst 115 kV Ckt 1 Regional Reliability ITP 3/15/2022 6/1/2016 2/18/2015 2014 ITPNT $16,737,611 2014 $18,937,071 $18,918,945 DELAY - MITIGATION 115 13.71

200401 30578 50736 SPS TX Multi - Bailey Co. - Lamb Co. 115 kVWest Littlefield - West Littlefield Tap 115

kV Ckt 1Regional Reliability ITP 5/15/2021 6/1/2016 5/25/2016 2014 ITPNT $3,187,532 2016 $3,432,623 $795,547 DELAY - MITIGATION 115 8.6

200247 30582 50738 OGE OK Device - Wildhorse 69 kV Wildhorse 69 kV Cap Bank Regional Reliability ITP 5/19/2017 6/1/2017 2/19/2014 2014 ITPNT $740,254 2014 $837,529 $484,391 $423,176 CLOSED OUT 69

200242 30584 50739 WR KS Line - Montgomery - Sedan 69 kV Ckt 1Elk Junction - Montgomery 69 kV Ckt 1

RebuildZonal Reliability ITP 12/28/2017 6/1/2018 2/19/2014 2014 ITPNT $16,110,343 2016 $17,349,077 $17,074,331 $17,074,331 COMPLETE 69 7.9

200242 30584 50740 WR KS Line - Montgomery - Sedan 69 kV Ckt 1 Elk Junction - Sedan 69 kV Ckt 1 Rebuild Zonal Reliability ITP 12/31/2019 6/1/2018 2/19/2014 2014 ITPNT $19,015,228 2016 $20,477,321 $19,015,228 DELAY - MITIGATION 69 19

200320 30588 50745 OPPD NE Multi - Fremont - S991 E 161/69 kV Ckt 1 Fremont 161/69 kV Transformer Ckt 1 Regional Reliability ITP 2/1/2019 6/1/2016 2/18/2015 2015 ITPNT $1,952,654 2018 $2,001,470 $1,952,654 DELAY - MITIGATION 161/69

200320 30588 50746 OPPD NE Multi - Fremont - S991 E 161/69 kV Ckt 1 Fremont - S991 E 69 kV Ckt 1 Regional Reliability ITP 4/22/2019 6/1/2016 2/18/2015 2015 ITPNT $4,854,430 2018 $4,975,791 $4,854,430 DELAY - MITIGATION 161/69 3.5

200320 30588 50747 OPPD NE Multi - Fremont - S991 E 161/69 kV Ckt 1 S1226 161kV Ckt 1 Regional Reliability ITP 4/22/2019 6/1/2016 2/18/2015 2015 ITPNT $20,690,401 2018 $21,207,661 $20,690,401 DELAY - MITIGATION 161 19.4

200258 30590 50748 OPPD NE Multi - S906 - S912 69 kV S906 - S924 69 kV Ckt 1 Rebuild Regional Reliability ITP 6/1/2018 6/1/2019 2/19/2014 2014 ITPNT $1,360,327 2014 $1,539,085 $1,360,327 COMPLETE 69 1.34

200258 30590 50749 OPPD NE Multi - S906 - S912 69 kVS924 - S912 69 kV Ckt 1 Terminal

Upgrades Regional Reliability ITP 6/1/2018 6/1/2019 2/19/2014 2014 ITPNT $69,679 2014 $78,835 $69,679 COMPLETE 69

200256 856 50754 SPS TX

Multi - Centre St. - Hereford NE 115 kV Ckt

1 and Centre St. and Hereford 115 kV Load

Conversion

Hereford 115 kV Load Conversion Regional Reliability ITP 12/15/2016 6/1/2014 2/19/2014 2014 ITPNT $435,146 2014 $492,328 $727,279 COMPLETE 115

200294 30596 50757 NPPD NEMulti - Broken Bow Wind - Ord 115 kV Ckt

1Broken 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 $28,719,131 $28,018,664 COMPLETE 115 42

200392 30597 50758 OGE OK Multi - Knob Hill - Lane - Noel 138 kV Ckt 1 Knob Hill - Lane - Noel 138 kV Ckt 1 Regional Reliability ITP 9/30/2018 6/1/2017 5/17/2016 2016 ITPNT $4,009,000 2016 $4,317,255 $4,647,152 COMPLETE 138 1.65

200361 30598 50759 AEP TX Device - Letourneau 69 kV Cap Bank Letourneau 69 kV Cap Bank Regional Reliability ITP 6/26/2017 6/1/2017 12/11/2015 2016 ITPNT $1,409,347 2016 $1,517,713 $1,409,347 COMPLETE 69

200294 30596 50760 NPPD NEMulti - Broken Bow Wind - Ord 115 kV Ckt

1North Loup - Ord 115 kV Ckt 1 Regional Reliability ITP 6/1/2018 6/1/2014 8/26/2014 2014 ITPNT $516,009 2018 $528,909 $516,009 COMPLETE 115

200258 30561 50761 OPPD NE XFR - S1366 161/69 kV Ckt 1 S1366 161 kV Ckt 1 Terminal Upgrades Regional Reliability ITP 5/31/2016 6/1/2016 2/19/2014 2014 ITPNT $422,270 2014 $477,760 $623,116 $422,270 COMPLETE 161

200299 30581 50763 OGE OKLine - Park Lane - Ahloso - Harden City -

Frisco - Lula 69/138 kV Ckt 1

Ahloso - Park Lane 138 kV Ckt 1 Voltage

ConversionRegional Reliability ITP 1/19/2016 6/1/2015 9/18/2014 2014 ITPNT $5,693,264 2014 $6,441,406 $5,693,264 $7,594,703 CLOSED OUT 138 4.31



Ahloso - Harden City 138 kV Ckt 1 Voltage

ConversionRegional Reliability ITP 4/1/2016 6/1/2015 9/18/2014 2014 ITPNT $6,929,179 2014 $7,839,730 $6,929,179 $7,409,811 CLOSED OUT 138 10.96 10.96



Frisco - Harden City 138 kV Ckt 1 Voltage




Frisco - Lula 138 kV Ckt 1 Voltage


200255 30361 50768 AEP OK Multi - Chisholm - Gracemont 345 kV Chisholm 230 kV Regional Reliability ITP 12/7/2017 3/1/2018 2/6/2014 2012 ITP10 $1,270,623 2017 $1,334,948 $1,270,623 COMPLETE 230 2

30599 50769 AEP

Multi - South Fayetteville 345/161 kV

Transformer & Chamber Springs - South

Fayetteville 345 kV line

South Fayetteville 345/161 kV

Transformer Ckt1ITP20 1/1/2033 $12,600,000 ON SCHEDULE > 4 345/161

30599 50770 TBD

Multi - South Fayetteville 345/161 kV

Transformer & Chamber Springs - South

Fayetteville 345 kV line

Chamber Springs - South Fayetteville 345

kV Ckt1ITP20 1/1/2033 $21,295,800 ON SCHEDULE > 4 345 18

30600 50771 GMO XFR - Maryville 345/161 kV Maryville 345/161 kV Transformer Ckt1 ITP20 1/1/2033 $12,600,000 ON SCHEDULE > 4 345/161

30601 50772 KCPL XFR - Nashua 345/161 kVNashua 345/161 kV Transformer Upgrade

Ckt11ITP20 1/1/2033 $12,600,000 ON SCHEDULE > 4 345/161

30602 50773 TBD Line - Keystone - Red Willow 345 kV Keystone - Red Willow 345 kV Ckt1 ITP20 1/1/2033 $130,141,000 ON SCHEDULE > 4 345 110

30603 50774 TBD Line - Tolk - Tuco 345 kV Tolk - Tuco 345 kV Ckt1 ITP20 1/1/2033 $75,718,400 ON SCHEDULE > 4 345 64

30604 50775 SEPC XFR - 2nd Holcomb 345/115 kV Holcomb 345/115 kV Transformer Ckt2 ITP20 1/1/2033 $12,600,000 ON SCHEDULE > 4 345/115

30605 50776 TBD Line - Neosho - Wolf Creek 345 kV Neosho - Wolf Creek 345 kV Ckt1 ITP20 1/1/2033 $117,126,900 ON SCHEDULE > 4 345 99

30606 50777 TBDMulti - Clinton - Truman - North Warsaw

161 kV Rebuild

Clinton - Truman 161 kV Ckt1

ReconductorITP20 1/1/2033 $15,701,325 ON SCHEDULE > 4 161 29

30606 50778 TBDMulti - Clinton - Truman - North Warsaw

161 kV Rebuild

North Warsaw - Truman 161 kV Ckt1

ReconductorITP20 1/1/2033 $1,082,850 ON SCHEDULE > 4 161 2

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30608 50779 WR

Multi - Jeffrey EC - Auburn - Swissvale 345

kV Conversion & Auburn 345/115 kV

Transformer

Auburn 345/115 kV Transformer Ckt2 ITP20 1/1/2033 $12,600,000 ON SCHEDULE > 4 345/115

30608 50780 TBD



Transformer

Auburn - Swissvale 345 kV Ckt1 Voltage

ConversionITP20 1/1/2033 $20,112,700 ON SCHEDULE > 4 345 17

30608 50781 TBD



Transformer

Auburn - Jeffrey EC 345 kV Ckt1 Voltage

ConversionITP20 1/1/2033 $35,493,000 ON SCHEDULE > 4 345 30

30607 50782 OGE Sub - Muskogee/Pecan Creek 345 kVMuskogee/Pecan Creek 345 kV Terminal

UpgradesITP20 1/1/2033 $34,605,675 ON SCHEDULE > 4

200256 30616 50794 SPS NM Sub - Curry County 115 kV Curry County Interchange 115 kV Regional Reliability ITP 5/7/2018 6/1/2018 2/19/2014 2014 ITPNT $813,381 2014 $920,266 $2,965,311 COMPLETE 115

200310 30619 50802 AEP OKLine - Darlington - Roman Nose 138 kV Ckt

1

Darlington - Roman Nose 138 kV Ckt 1

(AEP)High Priority HP 6/29/2017 6/1/2015 12/2/2014 HPILS $11,652,107 2014 $13,183,289 $11,652,107 COMPLETE 138 14.25

200311 30622 50805 OGE OKMulti - Knipe - SW Station - Linwood &

Warwick Tap 138 kV Ckt 1SW Station - Warwick Tap 138 kV Ckt 1 High Priority HP 5/11/2018 6/1/2018 12/2/2014 HPILS $12,767,120 2014 $14,444,824 $12,767,120 COMPLETE 138 14.22


Warwick Tap 138 kV Ckt 1Linwood - SW Station 138 kV Ckt 1 High Priority HP 5/11/2018 6/1/2018 12/2/2014 HPILS $9,899,440 2014 $11,200,308 $9,899,440 COMPLETE 138 15.49


Warwick Tap 138 kV Ckt 1Knipe - SW Station 138 kV Ckt 1 High Priority HP 5/11/2018 6/1/2018 12/2/2014 HPILS $8,218,020 2014 $9,297,935 $9,128,020 COMPLETE 138 8.2

200397 30628 50813 WFEC OK Device - Freedom 69 kV Cap Bank Freedom 69 kV Cap Bank Regional Reliability ITP 9/29/2015 6/1/2015 5/17/2016 2016 ITPNT $237,000 2016 $255,223 $237,000 $330,386 COMPLETE 69

200284 30635 50817 WFEC OK Device - Eagle Chief 69 kV Eagle Chief 69 kV Cap Bank High Priority HP 6/1/2015 6/1/2015 5/19/2014 HPILS $190,000 2014 $214,968 $237,000 COMPLETE 69

200309 30638 50819 SPS NMMulti - Kiowa - North Loving - China Draw

345/115 kV Ckt 1China Draw - North Loving 345 kV Ckt 1 High Priority HP 5/30/2018 6/1/2018 12/3/2014 HPILS $19,255,234 2014 $21,785,530 $19,170,280 COMPLETE 345 18.2


345/115 kV Ckt 1Kiowa - North Loving 345 kV Ckt 1 High Priority HP 5/21/2018 6/1/2018 12/3/2014 HPILS $25,716,516 2014 $29,095,877 $23,263,242 COMPLETE 345 20.4

200282 30824 50821 SPS NM XFR - Potash Junction 230/115 kV Ckt 1 Potash Junction 230/115 kV Ckt 1 High Priority HP 4/15/2016 6/1/2015 5/19/2014 HPILS $3,508,346 2014 $3,969,371 $3,782,261 $3,782,261 COMPLETE 230/115

200335 30644 50827 MKEC KS Line - Anthony - Harper 138 kV Ckt 1 Anthony - Harper 138 kV Ckt 1 High Priority HP 3/27/2018 6/1/2018 2/18/2015 HPILS $13,253,238 2014 $14,994,822 $11,368,608 IN SERVICE 138 14.8

200276 30645 50828 MKEC KS Line - Harper - Rago 138 kV Ckt 1 Harper - Rago 138 kV Ckt 1 High Priority HP 12/20/2017 6/1/2015 5/19/2014 HPILS $11,475,555 2016 $12,357,918 $12,661,249 COMPLETE 138 12.5


345/115 kV Ckt 1

China Draw 345/115 kV Ckt 1

TransformerHigh Priority HP 5/30/2018 6/1/2018 12/3/2014 HPILS $4,649,045 2014 $5,259,968 $5,960,784 COMPLETE 345/115


345/115 kV Ckt 1

China Draw 345 kV Ckt 1 Terminal

UpgradesHigh Priority HP 5/30/2018 6/1/2018 12/3/2014 HPILS $4,172,734 2014 $4,721,066 $5,469,757 COMPLETE 345

200309 30637 50851 SPS NM Multi - Hobbs - Kiowa 345 kV Ckt 1 Kiowa 345 kV Substation High Priority HP 3/24/2018 6/1/2018 12/3/2014 HPILS $10,383,515 2018 $10,643,103 $11,734,613 COMPLETE 345


345/115 kV Ckt 1

North Loving 345/115 kV Ckt 1



345/115 kV Ckt 1North Loving 345 kV Terminal Upgrades High Priority HP 5/21/2018 6/1/2018 12/3/2014 HPILS $7,873,653 2014 $8,908,316 $5,345,796 COMPLETE 345

200309 30639 50862 SPS NM

Multi - Potash Junction - Road Runner 345

kV Conv. and Transformers at Kiowa and

Road Runner

Road Runner 345/115 kV Ckt 1


200309 30639 50863 SPS NM



Road Runner

Road Runner 345 kV Substation

ConversionHigh Priority HP 4/27/2018 6/1/2018 12/3/2014 HPILS $11,569,711 2014 $13,090,066 $6,055,705 COMPLETE 345

200371 30666 50864 SPS NMDevice - China Draw and Road Runner 115

kV SVCChina Draw 115 kV SVC Regional Reliability ITP 6/8/2016 4/1/2015 2/12/2016 2015 ITPNT $25,925,187 2015 $28,616,556 $25,925,187 COMPLETE 115

200309 30639 50868 SPS NM



Road Runner

Kiowa 345/115 kV Ckt 1 Transformer High Priority HP 4/27/2018 6/1/2018 12/3/2014 HPILS $5,443,140 2014 $6,158,413 $5,883,877 COMPLETE 345/115

200282 30675 50869 SPS NM Multi - China Draw - Yeso Hills 115 kV China Draw - Yeso Hills 115 kV Ckt 1 High Priority HP 12/30/2023 6/1/2018 5/19/2014 HPILS $14,583,586 2014 $16,499,989 $15,400,000 DELAY - MITIGATION 115 18.4

200309 30717 50870 SPS NMLine - Hopi Sub - North Loving - China Draw

115 kV Ckt 1Hopi Sub - North Loving 115 kV Ckt 1 High Priority HP 5/25/2015 6/1/2015 12/3/2014 HPILS $9,980,879 2014 $11,292,448 $11,345,995 $3,566,068 COMPLETE 115 9.5

200309 30639 50871 SPS NM



Road Runner

Kiowa - Potash Junction 345/115 kV Ckt 1 High Priority HP 4/27/2018 6/1/2018 12/3/2014 HPILS $2,176,451 2014 $2,462,455 $2,782,144 COMPLETE 345 2

200282 30756 50873 SPS NM Multi - Battle Axe - Road Runner 115 kV Battle Axe - Road Runner 115 kV Ckt 1 High Priority HP 11/12/2015 6/1/2018 5/19/2014 HPILS $13,816,310 2014 $15,631,887 $8,143,031 COMPLETE 115 18.9

200282 30672 50874 SPS NM Multi - Dollarhide - Toboso Flats 115 kV Dollarhide - Toboso Flats 115 kV Ckt 1 High Priority HP 6/1/2018 6/1/2018 5/19/2014 HPILS $5,062,341 2014 $5,727,574 $5,062,341 IN SERVICE 115 7.4

200309 30637 50875 SPS NM Multi - Hobbs - Kiowa 345 kV Ckt 1 Hobbs - Kiowa 345 kV Ckt 1 High Priority HP 3/24/2018 6/1/2018 12/3/2014 HPILS $48,383,526 2018 $49,593,114 $47,464,598 COMPLETE 345 47.24

200282 30694 50877 SPS NM Multi - Ponderosa - Ponderosa Tap 115 kV Ponderosa 115 kV Substation High Priority HP 6/1/2017 6/1/2018 5/19/2014 HPILS $996,485 2014 $1,127,431 $1,081,000 COMPLETE 115

200474 30694 50879 SPS NM Multi - Ponderosa - Ponderosa Tap 115 kV Ponderosa Tap 115 kV Substation High Priority HP 6/1/2017 6/1/2018 2/27/2018 HPILS $4,174,446 2014 $4,723,002 $4,312,000 COMPLETE 115 0.2

200370 30649 50881 SPS NMMulti - Andrews 230/115 kV Transformer

and Andrews - NEF 115 kV Ckt 1Andrews 230/115 kV Ckt 1 Transformer High Priority HP 4/4/2016 6/1/2015 2/12/2016 HPILS $10,671,660 2016 $11,492,211 $11,500,000 COMPLETE 230/115 0.1

200282 30649 50882 SPS NMMulti - Andrews 230/115 kV Transformer

and Andrews - NEF 115 kV Ckt 1Andrews - NEF 115 kV Ckt 1 High Priority HP 4/4/2016 6/1/2015 5/19/2014 HPILS $3,523,472 2014 $3,986,485 $3,031,564 $3,031,564 COMPLETE 115 2.1

200309 30717 50883 SPS NMLine - Hopi Sub - North Loving - China Draw

115 kV Ckt 1China Draw - North Loving 115 kV Ckt 1 High Priority HP 5/25/2015 6/1/2015 12/3/2014 HPILS $13,283,227 2014 $15,028,752 $10,291,637 $17,588,398 COMPLETE 115 19.7

200277 30678 50889 NPPD NE XFR - Thedford 345/115 kV Thedford 345/115 kV Transformer High Priority HP 5/1/2021 6/1/2016 5/19/2014 HPILS $9,306,000 2014 $10,528,885 $9,306,001 DELAY - MITIGATION 345/115

200313 30688 50915 OGE OKLine - Park Lane - Seminole 138 kV

Terminal UpgradesPark Lane 138 kV Terminal Upgrades Transmission Service TS 1/29/2016 6/1/2015 1/30/2015

SPP-2012-AG2-AFS-

8$89,100 2015 $98,350 $89,100 $32,923 CLOSED OUT 138

200395 30692 50920 SPS TX XFR - Seminole 230/115 kV #1 and #2 Seminole 230/115 kV #1 Transformer Regional Reliability ITP 11/14/2019 6/1/2017 5/17/2016 2016 ITPNT $3,621,405 2016 $3,899,857 $2,986,806 DELAY - MITIGATION 230/115

200395 30692 50921 SPS TX XFR - Seminole 230/115 kV #1 and #2 Seminole 230/115 kV #2 Transformer Regional Reliability ITP 5/14/2019 6/1/2017 5/17/2016 2016 ITPNT $3,621,405 2016 $3,899,857 $3,203,043 DELAY - MITIGATION 230/115

200421 30693 50922 SPS TXXFR - Wolfforth 230/115 kV Ckt 1

TransformerWolfforth 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 $3,688,712 $3,936,000 ON SCHEDULE < 4 230/115

200411 30694 50923 SPS NM Multi - Ponderosa - Ponderosa Tap 115 kV Ponderosa - Ponderosa Tap 115 kV Ckt 1 High Priority HP 6/1/2017 6/1/2018 8/17/2016 HPILS $8,030,702 $4,462,000 COMPLETE 115 9.3

200395 31067 50924 SPS NMSub - Livingston Ridge 115 kV Substation

Conversion

Livingston Ridge 115 kV Substation

ConversionRegional Reliability ITP 11/30/2017 6/1/2017 5/17/2016 2016 ITPNT $5,283,323 2016 $5,689,561 $5,365,000 COMPLETE 115

200309 30695 50925 SPS NMMulti - Livingston Ridge - Sage Brush -

Cardinal 115 kVSage Brush 115 kV Substation High Priority HP 12/16/2016 6/1/2018 12/3/2014 HPILS $3,822,672 2014 $4,325,002 $2,472,695 COMPLETE 115


Cardinal 115 kVLivingston Ridge - Sage Brush 115 kV Ckt 1 High Priority HP 11/30/2017 6/1/2018 2/22/2017 HPILS $13,187,417 2016 $14,201,406 $11,510,000 COMPLETE 115 13.9

200411 30825 50931 SPS NMLine - China Draw - Wood Draw 115 kV Ckt

1China Draw - Wood Draw 115 kV Ckt 1 High Priority HP 6/15/2017 6/1/2018 8/17/2016 HPILS $13,704,501 2014 $15,505,385 $14,200,000 COMPLETE 115 14

200420 30699 50943 SPS TX Line - Northwest - Rolling Hills 115 kV Ckt 1Northwest - Rolling Hills 115 kV Rebuild

Ckt 1Regional Reliability TS 6/1/2021 6/1/2021 1/12/2017

SPP-2015-AG1-AFS-

6$4,514,434 2017 $4,742,977 $4,514,434 ON SCHEDULE < 4 115 7.2

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Cardinal 115 kVCardinal 115 kV Substation High Priority HP 12/15/2016 6/1/2018 12/3/2014 HPILS $6,115,613 2014 $6,919,255 $6,025,000 COMPLETE 115 0.2

200360 30914 50952 SPS NM Multi - Road Runner 115 kV Loop RebuildIMC #1 Tap - Livingston Ridge 115 kV Ckt

1 RebuildRegional Reliability ITP 4/15/2019 6/1/2015 12/7/2015 2015 ITPNT $5,700,000 2018 $5,842,500 $5,100,000 DELAY - MITIGATION 115 9.5 9.3

200365 30708 50954 SPS NMLine - Ochoa - Ponderosa Tap 115 kV Ckt 1

Rebuild

Ochoa - Ponderosa Tap 115 kV Ckt 1

RebuildRegional Reliability TS 6/1/2018 6/1/2018 1/12/2016

SPP-2014-AG1-AFS-

6$7,032,376 2016 $7,573,100 $4,625,000 COMPLETE 115

200360 30914 50955 SPS NM Multi - Road Runner 115 kV Loop RebuildPonderosa Tap - Whitten 115 kV Ckt 1


200360 30914 50957 SPS NM Multi - Road Runner 115 kV Loop RebuildIntrepid West - Potash Junction 115 kV

Ckt 1 RebuildRegional Reliability ITP 4/15/2019 6/1/2015 12/7/2015 2015 ITPNT $2,455,000 2018 $2,516,375 $1,315,000 DELAY - MITIGATION 115 1.5

200360 30914 50958 SPS NM Multi - Road Runner 115 kV Loop RebuildIMC #1 Tap - Intrepid West 115 kV Ckt 1



Cardinal 115 kVCardinal - Sage Brush 115 kV Ckt 1 High Priority HP 12/15/2016 6/1/2018 2/22/2017 HPILS $9,244,612 2014 $10,459,430 $8,120,000 COMPLETE 115 17.5

200282 30756 50968 SPS NM Multi - Battle Axe - Road Runner 115 kV Battle Axe 115 kV Substation High Priority HP 12/4/2015 6/1/2018 5/19/2014 HPILS $2,964,499 2014 $3,354,059 $3,006,810 COMPLETE 115

200282 30675 50988 SPS NM Multi - China Draw - Yeso Hills 115 kV Yeso Hills 115 kV Substation High Priority HP 12/30/2023 6/1/2018 5/19/2014 HPILS $1,046,485 2014 $1,184,002 $1,046,485 DELAY - MITIGATION 115

200306 30731 50990 AEP TXLine - Mt. Pleasant - West Mt. Pleasant 69

kV Ckt 1

Mt Pleasant - West Mt Pleasant 69 kV Ckt

1 RebuildRegional Reliability TS 4/20/2015 6/1/2015 11/24/2014 DPA-2013-SEP-351 $4,715,419 2015 $5,204,940 $7,381,799 COMPLETE 69 2.72

200362 30732 50991 MKEC KSMulti - Anthony - Bluff City - Caldwell -

Mayfield - Milan - Viola 138 kV Ckt 1Anthony - Bluff City 138 kV Ckt 1 High Priority HP 5/25/2018 6/1/2015 12/21/2015 HPILS $17,226,557 2016 $18,551,118 $14,668,533 IN SERVICE 138 12.9

200455 30755 50992 SPS TX XFR - Tuco 230/115 kV Ckt 1 Tuco 230/115 kV Ckt 1 Transformer Transmission Service ITP 9/30/2017 6/1/2018 5/12/2017 2017 ITPNT $3,800,415 2015 $4,194,947 $30,000 COMPLETE 230/115


Mayfield - Milan - Viola 138 kV Ckt 1Bluff City - Caldwell 138 kV Ckt 1 High Priority HP 5/25/2018 6/1/2015 12/21/2015 HPILS $9,378,604 2016 $10,099,731 $10,062,955 IN SERVICE 138 15.2


Mayfield - Milan - Viola 138 kV Ckt 1Caldwell - Mayfield 138 kV Ckt 1 High Priority HP 5/25/2018 6/1/2015 12/21/2015 HPILS $7,527,006 2016 $8,105,762 $5,997,653 IN SERVICE 138 10


Mayfield - Milan - Viola 138 kV Ckt 1Mayfield - Milan 138 kV Ckt 1 High Priority HP 5/25/2018 6/1/2015 12/21/2015 HPILS $6,608,453 2016 $7,116,581 $5,565,556 IN SERVICE 138 6.6

200277 30678 51002 NPPD NE XFR - Thedford 345/115 kV Thedford 345 kV Terminal Upgrades High Priority HP 5/1/2021 6/1/2016 5/19/2014 HPILS $930,800 2014 $1,053,115 $930,800 DELAY - MITIGATION 345

200272 30747 51014 AEP OK Line - Grady - Round Creek 138 kV Ckt 1 Grady - Round Creek 138 kV Ckt 1 High Priority HP 11/5/2015 6/1/2015 5/19/2014 HPILS $12,132,497 2014 $13,726,807 $12,132,497 COMPLETE 138

200272 30748 51015 AEP OKLine - Grady - Phillips Gas 138 kV Ckt 1 and

2Grady - Phillips 138 kV Ckt 1 and 2 High Priority HP 12/31/2014 6/1/2015 5/19/2014 HPILS $8,318,584 2014 $9,411,714 $8,318,584 COMPLETE 138 4

200272 30750 51017 AEP OK Line - Stonewall - Wapanucka 138 kV Ckt 1 Stonewall - Wapanucka 138 kV Ckt 1 High Priority HP 12/31/2013 6/1/2015 5/19/2014 HPILS $8,934,149 2014 $10,108,169 $8,934,149 $7,200,874 COMPLETE 138 6.4

200397 30597 51030 WFEC OK Multi - Knob Hill - Lane - Noel 138 kV Ckt 1Knob Hill - Noel 138 kV Ckt 1 Terminal

UpgradesRegional Reliability ITP 10/1/2018 6/1/2017 5/17/2016 2016 ITPNT $450,000 2016 $484,601 $450,000 $259,006 COMPLETE 138

200298 30761 51033 AEP LALine - Cedar Grove - South Shreveport 138

kVCedar Grove - South Shreveport 138 kV Transmission Service TS 6/1/2020 6/1/2020 9/30/2014

SPP-2010-AGP1-

AFS-8$6,566,218 2014 $7,429,073 $6,566,218 ON SCHEDULE < 4 138

200339 30762 51034 AEP LA Multi - Ellerbe Road - Lucas 69 kV Ellerbe Road - Lucas 69 kV Ckt 1 Rebuild Regional Reliability TS 3/1/2019 3/1/2019 3/17/2015DPA-2013-MAR-

296$6,629,465 2015 $7,317,689 $9,905,114 ON SCHEDULE < 4 69 3.2

200339 30762 51035 AEP LA Multi - Ellerbe Road - Lucas 69 kVEllerbe Road - Lucas 69 kV Terminal

UpgradesRegional Reliability TS 3/1/2019 3/1/2019 3/17/2015

DPA-2013-MAR-

296$652,658 2015 $720,412 $1,144,751 ON SCHEDULE < 4 69

200262 30766 51039 SPS TXXFR - Yoakum County Interchange 230/115

kV Ckts 1 and 2

Yoakum 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 $1,382,307 ON SCHEDULE < 4 230/115

200272 30770 51047 AEP OK Sub - Ellis 138 kV Ellis 138 kV Substation High Priority HP 6/1/2013 6/1/2015 5/19/2014 HPILS $4,100,000 2014 $4,638,774 $4,100,000 $4,086,696 COMPLETE 138

200286 30771 51048 MIDW KSMulti - Midwest Pump - Midwest Pump

Tap 115 kV Ckt 1Midwest Pump Tap 115 kV Substation High Priority HP 7/2/2016 6/1/2015 5/19/2014 HPILS $4,477,251 2014 $5,065,598 $4,477,251 COMPLETE 115

200286 30771 51049 MIDW KSMulti - Midwest Pump - Midwest Pump

Tap 115 kV Ckt 1

Midwest Pump - Midwest Pump Tap 115

kV Ckt 1High Priority HP 7/2/2016 6/1/2015 5/19/2014 HPILS $2,443,469 2014 $2,764,561 $2,443,469 COMPLETE 115 6

200262 30766 51050 SPS TXXFR - Yoakum County Interchange 230/115

kV Ckts 1 and 2

Yoakum County Interchange 230/115 kV

Ckt 2 TransformerRegional Reliability TS 5/31/2019 6/1/2019 4/9/2014

SPP-2011-AG3-AFS-

11$3,432,506 2014 $3,883,565 $5,500,796 ON SCHEDULE < 4 230/115

30786 51069 NPPD Sub - Dixon County 230kV Dixon County 230kV SubstationGeneration

InterconnectionGI 10/1/2018 $6,404,189 IN SERVICE 230

30787 51070 NPPDLine - Twin Church - Dixon County 230kV

Ckt 1

Twin Church - Dixon County 230kV Line

Upgrade

Generation

InterconnectionGI 11/1/2018 $61,774 IN SERVICE 230

200382 30809 51096 AEP OKLine - Keystone Dam - Wekiwa 138 kV Ckt

1 Rebuild

Keystone Dam - Wekiwa 138 kV Ckt 1


SPP-2014-AG1-AFS-

6$4,319,501 2016 $4,651,630 $4,319,501 ON SCHEDULE < 4 138 2 2 2

200395 30817 51109 SPS TXLine - Canyon West - Dawn - Panda - Deaf

Smith 115 kV Ckt 1 RebuildCanyon West - Dawn 115 kV Ckt 1 Rebuild Regional Reliability ITP 2/1/2018 6/1/2017 5/17/2016 2016 ITPNT $6,519,222 2018 $6,682,203 $5,987,379 COMPLETE 115 13.7


Smith 115 kV Ckt 1 RebuildDawn - Panda 115 kV Ckt 1 Rebuild Regional Reliability ITP 4/5/2018 6/1/2017 5/17/2016 2016 ITPNT $4,212,298 2018 $4,317,605 $3,586,100 COMPLETE 115 8.4


Smith 115 kV Ckt 1 RebuildDeaf Smith - Panda 115 kV Ckt 1 Rebuild Regional Reliability ITP 12/15/2018 6/1/2017 5/17/2016 2016 ITPNT $2,055,714 2018 $2,107,107 $2,837,945 DELAY - MITIGATION 115 3.5

200297 30820 51112 SPS TXCarlisle Interchange - Tuco Interchange

230 kV Ckt 1

Carlisle Interchange - Tuco Interchange

230 kV Ckt 1 Terminal UpgradeTransmission Service TS 10/24/2016 10/1/2015 5/5/2015

SPP-2012-AG3-AFS-

9$362,250 2015 $399,856 $289,000 COMPLETE 230

200311 30619 51117 OGE OKLine - Darlington - Roman Nose 138 kV Ckt

1

Darlington - Roman Nose 138 kV Ckt 1

(OGE)High Priority HP 12/15/2016 6/1/2015 12/2/2014 HPILS $12,701,091 2014 $14,370,119 $12,701,091 $11,483,883 CLOSED OUT 138 13.2

200360 30914 51131 SPS NM Multi - Road Runner 115 kV Loop RebuildByrd Tap - Monument Tap 115 kV Ckt 1

RebuildRegional Reliability ITP 12/14/2018 6/1/2015 12/7/2015 2015 ITPNT $4,000,000 2018 $4,100,000 $3,525,000 DELAY - MITIGATION 115 4.6

200371 30666 51132 SPS NMDevice - China Draw and Road Runner 115

kV SVCRoad Runner 115 kV SVC Regional Reliability ITP 4/1/2016 4/1/2015 2/12/2016 2015 ITPNT $28,918,070 2015 $31,920,138 $28,918,070 COMPLETE 115

200330 30838 51133 OPPD NEXFR - Sub 3459 345/161 kV Ckt 1

TransformerSub 3459 345/161 kV Transformer Regional Reliability ITP 6/1/2018 6/1/2019 2/18/2015 2015 ITP10 $6,588,939 2015 $7,272,956 $6,588,939 COMPLETE 345/161

200330 30838 51136 OPPD NEXFR - Sub 3459 345/161 kV Ckt 1

TransformerSub 3459 345 kV Terminal Upgrades Regional Reliability ITP 6/1/2018 6/1/2019 2/18/2015 2015 ITP10 $3,604,757 2015 $3,978,977 $3,604,757 COMPLETE 345

200416 30843 51139 OGE OKSub - Cimarron - Draper 345 kV Terminal

Upgrades

Cimarron - Draper 345 kV Terminal

UpgradesRegional Reliability ITP 12/1/2017 4/1/2019 11/14/2016 2015 ITP10 $1,500,000 2015 $1,655,719 $1,500,000 $1,121,449 COMPLETE 345

200395 30844 51140 SPS TXSub - Amoco - Sundown 230 kV Terminal

Upgrades

Amoco - Sundown 230 kV Terminal

UpgradesRegional Reliability ITP 12/14/2018 1/1/2019 5/17/2016 2016 ITPNT $1,771,222 2016 $1,907,412 $627,000 ON SCHEDULE < 4 230

200328 30850 51151 KCPL MOLine - Iatan - Stranger 345 kV Ckt 1 Voltage

ConversionIatan 345 kV Voltage Conversion Economic ITP 6/1/2018 1/1/2019 2/25/2015 2015 ITP10 $3,263,000 2015 $3,601,741 $1,885,731 $1,885,731 COMPLETE 345 18

200336 30859 51163 SPS NMDevice - Plains Interchange 115 kV Cap

BankPlains Interchange 115 kV Cap Bank Regional Reliability ITP 4/4/2018 6/1/2019 2/26/2015 2015 ITP10 $1,217,275 2015 $1,343,644 $1,630,000 COMPLETE 115

200326 30866 51170 SPS TXSub - Amarillo South 230 kV Terminal

UpgradesAmarillo South 230 kV Terminal Upgrades Regional Reliability ITP 4/1/2020 4/1/2020 2/18/2015 2015 ITPNT $31,198 2015 $34,437 $31,198 ON SCHEDULE < 4 230

200314 30873 51187 AEP OKLine - Southwestern Station - Carnegie

138kV Ckt 1 Rebuild

Southwestern Station - Carnegie 138 kV

Ckt 1 RebuildRegional Reliability ITP 7/6/2017 6/1/2016 2/18/2015 2015 ITPNT $15,821,763 2015 $17,464,266 $9,397,311 COMPLETE 138 16.52 138

200326 30875 51189 SPS NMLine - PCA Interchange - Quahada 115 kV

Ckt 1 Rebuild

PCA Interchange - Quahada 115 kV Ckt 1


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200319 30876 51190 OGE OKLine - Little River - Maud 69 kV Ckt 1

RebuildLittle River - Maud 69 kV Ckt 1 Rebuild Regional Reliability ITP 10/21/2016 6/1/2015 2/18/2015 2015 ITPNT $387,822 2015 $428,083 $361,871 $332,916 CLOSED OUT 69 10.7

200318 30883 51200 NPPD NE Multi - Bassett 115 kV Bassett 115 kV Substation Regional Reliability ITP 6/1/2018 6/1/2016 2/18/2015 2015 ITPNT $5,163,000 2015 $5,698,986 $5,163,000 COMPLETE 115 0.1

200319 30884 51202 OGE OKXFR - Stillwater 138/69 kV Ckt 1

TransformerStillwater 138/69 kV Ckt 1 Transformer Regional Reliability ITP 6/1/2019 6/1/2019 2/18/2015 2015 ITPNT $3,989,023 2015 $4,403,135 $2,786,625 RE-EVALUATION 138/69

200326 30888 51206 SPS TXXFR - Lynn County 115/69 kV Ckt 1

TransformerLynn County 115/69 kV Ckt 1 Transformer Regional Reliability ITP 6/1/2019 6/1/2019 2/18/2015 2015 ITPNT $1,699,629 2015 $1,876,072 $2,302,251 ON SCHEDULE < 4 115/69

200406 30889 51207 AEP LALine - Linwood - South Shreveport 138kV

Ckt 1 Rebuild

Linwood - South Shreveport 138 kV Ckt 1


200326 30894 51214 SPS TX Device - Cargill 115 kV Cap Bank Cargill 115 kV Cap Bank Regional Reliability ITP 12/31/2018 6/1/2019 2/18/2015 2015 ITPNT $1,262,485 2015 $1,393,547 $1,670,657 ON SCHEDULE < 4 115

200314 30895 51215 AEP LALine - Brooks Street - Edwards Street 69kV

Ckt 1 Rebuild

Brooks Street - Edwards Street 69 kV Ckt

1 RebuildRegional Reliability ITP 12/20/2017 6/1/2016 2/18/2015 2015 ITPNT $4,294,228 2015 $4,740,025 $4,294,228 COMPLETE 69 0.85

200319 30900 51220 OGE OK Sub - Warner Tap 69 kV Terminal Upgrades Warner Tap 69 kV Terminal Upgrades Regional Reliability ITP 10/1/2016 6/1/2015 2/18/2015 2015 ITPNT $2,565,000 2015 $2,831,280 $3,345,000 $2,232,219 CLOSED OUT 69

200343 30912 51235 SPS KSMulti - Walkemeyer Tap - Walkemeyer

345/115 kVStevens Co. 345 kV Substation Regional Reliability ITP 6/8/2018 6/1/2015 8/13/2015 2015 ITPNT $13,831,957 2015 $15,267,892 $13,796,000 COMPLETE 345 0.1

200343 30913 51237 SPS NM Multi - RIAC 115 kV Voltage Conversion RIAC 115 kV Voltage Conversion Regional Reliability ITP 11/30/2018 6/1/2015 8/13/2015 2015 ITPNT $4,811,635 2015 $5,311,145 $5,169,697 DELAY - MITIGATION 115 0.1 1.5

200344 30912 51240 SEPC KSMulti - Walkemeyer Tap - Walkemeyer

345/115 kVWalkemeyer - Stevens Co. 115 kV Ckt 1 Regional Reliability ITP 6/30/2018 6/1/2015 8/13/2015 2015 ITPNT $767,645 2015 $847,336 $1,605,731 $1,605,731 CLOSED OUT 115 1


345/115 kVWalkemeyer 115 kV Terminal Upgrades Regional Reliability ITP 6/21/2018 6/1/2015 8/13/2015 2015 ITPNT $5,668,987 2015 $6,257,501 $8,019,463 $8,019,463 CLOSED OUT 115

200360 30914 51245 SPS NM Multi - Road Runner 115 kV Loop Rebuild Cardinal - Targa 115 kV Ckt 1 Rebuild Regional Reliability ITP 12/14/2017 6/1/2015 12/7/2015 2015 ITPNT $2,435,548 2018 $2,496,437 $1,600,000 COMPLETE 115 3

200360 30914 51250 SPS NM Multi - Road Runner 115 kV Loop RebuildNational Enrichment Plant - Targa 115 kV

Ckt 1Regional Reliability ITP 4/5/2019 6/1/2015 12/7/2015 2015 ITPNT $1,874,116 2018 $1,920,969 $1,874,116 DELAY - MITIGATION 115 3

200319 30884 51269 OGE OKXFR - Stillwater 138/69 kV Ckt 1

TransformerStillwater 138 kV Terminal Upgrades Regional Reliability ITP 6/1/2019 6/1/2019 2/18/2015 2015 ITPNT $611,398 RE-EVALUATION 138

200326 30888 51270 SPS TXXFR - Lynn County 115/69 kV Ckt 1

TransformerLynn County 115 kV Terminal Upgrades Regional Reliability ITP 6/1/2019 6/1/2019 2/18/2015 2015 ITPNT $19,425 2015 $21,442 $0 ON SCHEDULE < 4 115

200394 30917 51271 SEPC KS Device - Ellsworth 115 kV Cap Bank Ellsworth 115 kV Cap Bank Regional Reliability ITP 4/27/2018 6/1/2017 5/17/2016 2016 ITPNT $2,983,396 2016 $3,212,791 $2,458,273 $2,458,273 COMPLETE 115

200365 30918 51272 SPS NMLine - Byrd Tap - Cooper Ranch - Oil Center -

Lea Road 115 kV Ckt 1 Rebuild

Cooper Ranch - Oil Center 115 kV Ckt 1


SPP-2014-AG1-AFS-

6$3,044,258 2016 $3,278,333 $1,700,000 ON SCHEDULE < 4 115 2.6


Lea Road 115 kV Ckt 1 Rebuild

Byrd Tap - Cooper Ranch 115 kV Ckt 1


SPP-2014-AG1-AFS-

6$3,261,324 2016 $3,512,089 $3,195,000 ON SCHEDULE < 4 115 5.7

200318 30921 51276 NPPD NELine - Ainsworth - Ainsworth Wind 115 kV

Ckt 1 Rebuild

Ainsworth - Ainsworth Wind 115 kV Ckt 1

RebuildRegional Reliability ITP 6/1/2020 6/1/2020 2/18/2015 2015 ITPNT $200,000 2015 $220,763 $584,800 ON SCHEDULE < 4 115

200318 30883 51277 NPPD NE Multi - Bassett 115 kV Bassett 115 kV Cap Bank Regional Reliability ITP 6/1/2018 6/1/2016 2/18/2015 2015 ITPNT $902,000 2015 $995,639 $902,000 COMPLETE 115

200337 30850 51283 GMO MOLine - Iatan - Stranger 345 kV Ckt 1 Voltage

Conversion

Iatan - Stranger Creek 345 kV Ckt 1

Voltage Conversion (GMO)Economic ITP 6/1/2018 1/1/2019 2/25/2015 2015 ITP10 $6,237,000 2015 $6,884,481 $7,688,424 $7,688,424 COMPLETE 345

200338 30850 51284 WR KSLine - Iatan - Stranger 345 kV Ckt 1 Voltage

Conversion

Iatan - Stranger Creek 345 kV Ckt 1

Voltage Conversion (WR)Economic ITP 6/1/2018 1/1/2019 2/25/2015 2015 ITP10 $28,010,000 2015 $30,917,799 $23,000,000 COMPLETE 345 10.83

30934 51292 NPPD Line - Hoskins - Dixon County 230kV Ckt 1Hoskins - Dixon County 230kV Line

Upgrade

Generation


30943 51306 BEPC ND Multi - AVS - Charlie Creek 345 kV AVS - Charlie Creek 345 kV Ckt 2 Regional Reliability ITP 1/1/2016 12/1/2017IS Integration

Study$96,000,000 2014 $108,615,188 $65,407,395 $42,848,001 COMPLETE 345 66.4

30943 51307 BEPC ND Multi - AVS - Charlie Creek 345 kV AVS 345 kV Substation Regional Reliability ITP 6/1/2016 12/1/2017IS Integration

Study$3,000,000 2014 $3,394,225 $6,121,210 $6,224,797 COMPLETE 345

30943 51308 BEPC ND Multi - AVS - Charlie Creek 345 kV Charlie Creek 345 kV Substation Regional Reliability ITP 1/1/2016 12/1/2017IS Integration

Study$9,000,000 2014 $10,182,674 $11,268,556 $9,303,943 COMPLETE 345

30944 51310 BEPC NDMulti - Charlie Creek - Judson - Williston

345/230 kVCharlie Creek - Judson 345 kV Ckt 1 Regional Reliability ITP 1/1/2016 12/1/2017

IS Integration

Study$103,000,000 2014 $116,535,046 $71,704,347 $41,081,928 COMPLETE 345 73.7


345/230 kVJudson 345/230 kV Substation Regional Reliability ITP 12/22/2015 12/1/2017

IS Integration

Study$19,000,000 2014 $21,496,756 $24,758,086 $16,400,623 COMPLETE 345


345/230 kVJudson - Williston 230 kV Ckt 1 Regional Reliability ITP 1/1/2016 12/1/2017

IS Integration

Study$2,400,000 2014 $2,715,380 $3,159,903 $1,846,581 COMPLETE 230 2

30945 51314 BEPC ND Multi - Judson - Tande - Neset 345/230 kV Judson - Tande 345 kV Ckt 1 Regional Reliability ITP 11/11/2017 12/1/2017IS Integration

Study$86,000,000 2014 $97,301,106 $66,207,772 COMPLETE 345 61.2

30945 51315 BEPC ND Multi - Judson - Tande - Neset 345/230 kV Tande 345/230 kV Substation Regional Reliability ITP 10/31/2017 12/1/2017IS Integration

Study$18,000,000 2014 $20,365,348 $18,000,000 COMPLETE 345

30945 51316 BEPC ND Multi - Judson - Tande - Neset 345/230 kV Neset - Tande 230 kV Ckt 1 Regional Reliability ITP 1/1/2016 12/1/2017IS Integration

Study$3,000,000 2014 $3,394,225 $364,982 COMPLETE 230 1

30945 51317 BEPC ND Multi - Judson - Tande - Neset 345/230 kV Neset 230 kV Terminal Upgrades Regional Reliability ITP 10/31/2017 12/1/2017IS Integration

Study$4,000,000 2014 $4,525,633 $4,000,000 COMPLETE 230

30946 51318 BEPC SD Multi - Lower Brule - Witten 230 kV Lower Brule - Witten 230 kV Ckt 1 Regional Reliability ITP 1/1/2018 12/1/2016IS Integration

Study$31,500,000 2014 $35,639,359 $31,500,000 DELAY - MITIGATION 230

30946 51319 BEPC SD Multi - Lower Brule - Witten 230 kV Lower Brule 230 kV Substation Regional Reliability ITP 1/1/2018 12/1/2016IS Integration


30946 51320 BEPC SD Multi - Lower Brule - Witten 230 kVLower Brule - Witten 230 kV Terminal

UpgradesRegional Reliability ITP 1/1/2018 12/1/2016

IS Integration



345/115 kV

Walkemeyer Tap 345 kV Substation

(SEPC)Regional Reliability ITP 6/30/2018 6/1/2015 8/13/2015 2015 ITPNT $3,126,209 2017 $3,284,473 $3,686,933 IN SERVICE 345 0.5


345/115 kVStevens Co. 345/115 kV Transformer Regional Reliability ITP 6/30/2018 6/1/2015 8/13/2015 2015 ITPNT $11,695,379 2015 $12,909,510 $8,305,939 IN SERVICE 345

200376 30952 51332 SEPC KS Device - Ingalls 115 kV Cap Bank Ingalls 115 kV Cap Bank Regional Reliability TS 7/11/2018 6/1/2017 7/12/2016DPA-2015-MARCH-

494$5,522,822 2016 $5,947,475 $5,410,042 $5,410,042 COMPLETE 115 0.1

200376 30953 51333 SEPC KS Device - Lane Scott 115 kV Cap Bank Lane Scott 115 kV Cap Bank Regional Reliability TS 10/31/2019 6/1/2017 7/12/2016DPA-2015-MARCH-

494$3,852,342 2016 $4,148,551 $4,068,523 DELAY - MITIGATION 115

30955 51335 OGESUB - Otter 138kV - rebuild and add

terminal for GEN-2014-064

Otter 138kV - rebuild and add terminal

for GEN-2014-064 NU

Generation

InterconnectionGI 10/15/2018 $2,807,651 COMPLETE

30959 51338 WRSub - Tap Emporia Energy Center - Wichita

345kV (GEN-2014-001 Substation)

Tap Emporia Energy Center - Wichita

345kV (GEN-2014-001 NU)

Generation

InterconnectionGI $0 ON SCHEDULE < 4

30956 51339 NPPDMulti - GEN-2013-032 Interconnection

Work

Antelope 115kV - Add terminal for GEN-

2013-032

Generation

InterconnectionGI 5/1/2017 $2,868,775 IN SERVICE

30960 51341 OGESUB - Beaver County 345kV - Add 345kV


Beaver County Substation - Add 345kV


Generation

InterconnectionGI 12/31/2019 $3,952,199 ON SCHEDULE < 4

200384 30971 51358 SPS TXLine - Cochran - Whiteface Tap 69 kV Ckt 1

Rebuild

Cochran - Whiteface Tap 69 kV Ckt 1

RebuildRegional Reliability TS 12/20/2018 6/1/2016 4/20/2016 DPA-2013-JUN-342 $2,254,282 2016 $2,427,615 $2,250,325 DELAY - MITIGATION 69

30959 51360 WRSub - Tap Emporia Energy Center - Wichita

345kV (GEN-2014-001 Substation)

Tap Emporia Energy Center - Wichita

345kV (GEN-2014-001 TOIF)

Generation

InterconnectionGI 1/18/2020 $600,000 ON SCHEDULE < 4

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30955 51362 OGESUB - Otter 138kV - rebuild and add


Otter 138kV - rebuild and add terminal

for GEN-2014-064 TOIF

Generation

InterconnectionGI 10/15/2018 $410,000 COMPLETE

30975 51368 SEPCSub - Buckner 345kV GEN-2010-045

Addition

Buckner 345kV Substation GEN-2010-045

Addition (TOIF)

Generation

InterconnectionGI $4,000,000 ON SCHEDULE < 4

30975 51369 SEPCSub - Buckner 345kV GEN-2010-045

Addition

Buckner 345kV Substation GEN-2010-045

Addition (NU)

Generation

InterconnectionGI $8,200,000 ON SCHEDULE < 4


Mayfield - Milan - Viola 138 kV Ckt 1Viola 138 kV Line Tap (MKEC) High Priority HP 5/25/2018 6/1/2015 12/21/2015 HPILS $4,414,629 2016 $4,754,073 $3,330,055 IN SERVICE 138 0.3 5.1

200363 30732 51395 WR KSMulti - Anthony - Bluff City - Caldwell -

Mayfield - Milan - Viola 138 kV Ckt 1Viola 138 kV Line Tap (WR) High Priority HP 5/31/2018 6/1/2015 12/21/2015 HPILS $3,915,388 2016 $4,216,445 $2,162,471 COMPLETE 138

200365 30987 51406 SPS NMLine - Cunningham - Monument Tap 115

kV Ckt 1 Rebuild

Cunningham - Monument Tap 115 kV Ckt

1 RebuildRegional Reliability TS 11/29/2019 6/1/2021 1/12/2016

SPP-2014-AG1-AFS-

6$5,129,356 2016 $5,523,755 $5,055,000 ON SCHEDULE < 4 115


Lea Road 115 kV Ckt 1 RebuildLea Road - Oil Center 115 kV Ckt 1 Rebuild Regional Reliability TS 6/15/2021 6/1/2021 1/12/2016

SPP-2014-AG1-AFS-


200366 30988 51408 SPS NM Sub - Eddy Co. 230 kV Bus Tie Eddy Co. 230 kV Bus Tie Transmission Service TS 11/30/2019 10/1/2017 1/12/2016SPP-2013-AG3-AFS-


200365 30989 51409 SPS NMSub - Potash Junction 230 kV Terminal

UpgradePotash 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 $68,114 $63,251 COMPLETE 230

200365 30990 51410 SPS NM Line - Jal - Teague 115 kV Ckt 1 Rebuild Jal - Teague 115 kV Ckt 1 Rebuild Regional Reliability TS 12/15/2018 6/1/2021 1/12/2016SPP-2014-AG1-AFS-

6$6,640,592 2016 $7,151,191 $0 COMPLETE 115

200365 30991 51411 SPS NMLine - National Enrichment Plant - Teague

115 kV Ckt 1 Rebuild

National Enrichment Plant - Teague 115

kV Ckt 1 RebuildRegional Reliability TS 12/15/2018 6/1/2018 1/12/2016

SPP-2014-AG1-AFS-

6$4,915,370 2016 $5,293,316 $500,000 DELAY - MITIGATION 115

200397 30995 51430 WFEC OK Device - Harrisburg 69 kV Cap Bank Harrisburg 69 kV Cap Bank Regional Reliability ITP 12/31/2017 6/1/2017 5/17/2016 2016 ITPNT $450,000 2016 $484,601 $450,000 RE-EVALUATION 69

200395 30996 51431 SPS TXSub - Hobbs - Yoakum Tap 230 kV

Substation and TransformerHobbs - Yoakum Tap 230 kV Substation Regional Reliability ITP 12/15/2019 6/1/2017 5/17/2016 2016 ITPNT $9,710,319 2016 $10,456,951 $12,065,504 DELAY - MITIGATION 230/115 0.6

200395 30996 51432 SPS TXSub - Hobbs - Yoakum Tap 230 kV

Substation and Transformer

Hobbs - Yoakum Tap 230/115 kV

TransformerRegional Reliability ITP 12/15/2019 6/1/2017 5/17/2016 2016 ITPNT $3,020,218 2016 $3,252,444 $3,133,198 DELAY - MITIGATION 230/115 0.6

200386 30997 51433 AEP OK Device - Sayre 138 kV Cap Bank Sayre 138 kV Cap Bank Regional Reliability ITP 12/19/2018 6/1/2017 5/17/2016 2016 ITPNT $758,441 2016 $816,758 $1,997,360 COMPLETE 138

200395 30999 51436 SPS TXSub - Potter Co. - Harrington 230 kV

Terminal Upgrades

Potter Co. - Harrington 230 kV Terminal

UpgradesRegional Reliability ITP 6/1/2019 6/1/2019 5/17/2016 2016 ITPNT $914,347 2016 $984,652 $920,343 ON SCHEDULE < 4 230

200395 31001 51438 SPS NM

Line - Road Runner - Agave Red

Hills/Ochoa/Custer Mountain 115 kV New

Line

Agave 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 $477,996 $443,866 COMPLETE 115 0.8

200395 31001 51439 SPS NM



Line

Ochoa - Road Runner 115 kV Ckt 1 New

LineRegional Reliability ITP 3/20/2017 4/1/2020 5/17/2016 2016 ITPNT $519,061 2016 $558,971 $321,590 COMPLETE 115 0.8

200395 31001 51440 SPS NM



Line

Custer 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 $818,017 $759,610 COMPLETE 115 11

200395 31001 51441 SPS NM



Line

Road Runner 115 kV Terminal Upgrades Regional Reliability ITP 3/28/2017 4/1/2020 5/17/2016 2016 ITPNT $4,580,864 2016 $4,933,089 $4,580,864 COMPLETE 115

200395 31001 51442 SPS NM



Line

Ochoa 115 kV Terminal Upgrades Regional Reliability ITP 3/28/2017 4/1/2020 5/17/2016 2016 ITPNT $25,280 2016 $27,224 $119,406 COMPLETE 115

200395 31001 51443 SPS NM



Line

Agave Red Hills 115 kV Terminal

UpgradesRegional Reliability ITP 3/28/2017 4/1/2020 5/17/2016 2016 ITPNT $25,280 2016 $27,224 $25,280 COMPLETE 115

200392 31002 51444 OGE OKLine - Lincoln - Meeker 138 kV Ckt 1 New

Line

Lincoln - Meeker 138 kV Ckt 1 New Line

(OGE)Regional Reliability ITP 7/31/2019 6/1/2017 5/17/2016 2016 ITPNT $750,000 2016 $807,668 $700,000 DELAY - MITIGATION 138

200397 31002 51445 WFEC OKLine - Lincoln - Meeker 138 kV Ckt 1 New

Line

Lincoln - Meeker 138 kV Ckt 1 New Line

(WFEC)Regional Reliability ITP 3/1/2019 6/1/2017 5/17/2016 2016 ITPNT $6,000,000 2016 $6,461,344 $6,000,000 $2,157,636 DELAY - MITIGATION 138

200386 31003 51446 AEP OKSub - Northeastern Station 138 kV

Terminal Upgrades

Northeastern Station 138 kV Terminal

UpgradesRegional Reliability ITP 10/5/2016 6/1/2017 5/17/2016 2016 ITPNT $518,011 2016 $557,841 $518,011 COMPLETE 138

200386 31005 51448 AEP OK Sub - Elk City 138 kV Move Load Elk City 138 kV Move Load Regional Reliability ITP 5/25/2018 6/1/2017 5/17/2016 2016 ITPNT $2,904,911 2016 $3,128,271 $2,904,911 COMPLETE 138

210496 31007 51450 SPS TX XFR - Sundown 230/115 kV Transformer Sundown 230/115 kV Transformer Regional Reliability ITP 12/31/2021 6/1/2019 8/17/2018 2018 ITPNT $4,264,796 DELAY - MITIGATION 230/115

200395 31008 51452 SPS NM Multi - Artesia County 115 kV Artesia Country Club Tap 115 kV Line Tap Regional Reliability ITP 12/15/2019 6/1/2017 5/17/2016 2016 ITPNT $336,134 2016 $361,980 $502,904 DELAY - MITIGATION 115

200395 31008 51453 SPS NM Multi - Artesia County 115 kVArtesia Country Club - Artesia Country

Club Tap 115 kV Ckt 1 New LineRegional Reliability ITP 12/15/2019 6/1/2017 5/17/2016 2016 ITPNT $3,092,796 2016 $3,330,603 $2,273,540 DELAY - MITIGATION 115 3

200406 31009 51454 AEP OK Line - Duncan - Tosco 69 kV Ckt 1 Rebuild Duncan - Tosco 69 kV Ckt 1 Rebuild Regional Reliability ITP 5/4/2018 6/1/2018 8/17/2016 2016 ITPNT $5,974,766 2016 $6,434,170 $5,974,766 COMPLETE 69 3.86 3.86 69

31014 51467 NPPDSub - Friend 115kV Substation - GEN-2014-

039 Addition

Friend 115kV Substation - GEN-2014-039

Addition (TOIF)

Generation


31014 51468 NPPDSub - Friend 115kV Substation - GEN-2014-

039 Addition

Friend 115kV Substation - GEN-2014-039

Addition

Generation


31016 51471 SPSLine - Plant X - Tolk 230kV rebuild circuit #1

and #2Plant X - Tolk 230kV rebuild circuit #1

Generation


31016 51472 SPSLine - Plant X - Tolk 230kV rebuild circuit #1

and #2Plant X - Tolk 230kV rebuild circuit #2

Generation


31017 51473 SPSXFR - TUCO Interchange 345/230kV CKT 1

Replacement

TUCO Interchange 345/230kV CKT 1

Replacement

Generation


31018 51474 OGESub - Minco 345kV GEN-2014-056 & GEN-

2015-057 Addition

Minco 345kV Substation GEN-2014-056

Addition (TOIF)

Generation


200407 31021 51478 SPS TXLine - Mustang - Seminole 115 kV Ckt 1

New Line

Mustang - Seminole 115 kV Ckt 1 New

LineRegional Reliability ITP 9/15/2020 6/1/2017 8/17/2016 2016 ITPNT $15,007,492 2016 $16,161,427 $15,007,492 DELAY - MITIGATION 115 19.7


New LineMustang 115 kV Terminal Upgrades Regional Reliability ITP 9/15/2020 6/1/2017 8/17/2016 2016 ITPNT $2,712,194 2016 $2,920,736 $2,500,387 DELAY - MITIGATION 115 19.7


New LineSeminole 115 kV Terminal Upgrades Regional Reliability ITP 9/15/2020 6/1/2017 8/17/2016 2016 ITPNT $2,016,340 2016 $2,171,378 $2,628,163 DELAY - MITIGATION 115 19.7

200395 31022 51481 SPS TXLine - Canyon East Tap - Randall 115 kV Ckt

1 Rebuild

Canyon East Tap - Randall 115 kV Ckt 1

RebuildRegional Reliability ITP 5/15/2020 6/1/2017 5/17/2016 2016 ITPNT $4,804,292 2016 $5,173,697 $4,867,059 DELAY - MITIGATION 115

200397 31065 51484 WFEC OKSub - Cleo Junction 138 kV Terminal

UpgradesCleo Junction 138 kV Terminal Upgrades Regional Reliability ITP 12/31/2019 6/1/2017 5/17/2016 2016 ITPNT $4,000,000 2016 $4,307,563 $4,000,000 DELAY - MITIGATION 138

200390 31024 51486 GRDA OK Device - Skiatook 69 kV Cap Bank Skiatook 69 kV Cap Bank Regional Reliability ITP 9/10/2018 6/1/2017 5/17/2016 2016 ITPNT $1,134,600 2016 $1,221,840 $1,134,600 COMPLETE 69

200390 31025 51487 GRDA OK Sub - Sallisaw 161 kV Terminal Upgrades Sallisaw 161 kV Terminal Upgrades Regional Reliability ITP 12/31/2018 6/1/2017 5/17/2016 2016 ITPNT $2,266,000 2016 $2,440,234 $2,266,000 RE-EVALUATION 161

200417 31031 51503 BEPC ND

Multi - Kummer Ridge - Roundup 345 kV

New Line and Patent Gate and Roundup

345/115 kV Substations

Roundup 345/115 kV Transformer Regional Reliability ITP 9/1/2016 6/1/2017 12/28/2016 2016 ITPNT $6,662,000 2016 $7,174,245 $6,662,000 COMPLETE 345/115

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200417 31031 51504 BEPC ND




Patent Gate 345/115 kV Transformer Regional Reliability ITP 9/1/2016 6/1/2017 12/28/2016 2016 ITPNT $6,122,000 2016 $6,592,724 $6,662,000 COMPLETE 345/115

200388 31032 51506 BEPC NDMulti - Plaza 115 kV Substation and

Blaisdell - Plaza 115 kV New LinePlaza 115 kV Substation Regional Reliability ITP 2/1/2018 6/1/2017 5/17/2016 2016 ITPNT $4,110,395 2016 $4,426,446 $3,918,000 COMPLETE 115


Blaisdell - Plaza 115 kV New LineBlaisdell - Plaza 115 kV New Line Regional Reliability ITP 2/1/2018 6/1/2017 5/17/2016 2016 ITPNT $15,272,151 2016 $16,446,436 $14,841,308 COMPLETE 115 36


Blaisdell - Plaza 115 kV New LinePlaza 115 kV Cap Bank Regional Reliability ITP 2/1/2018 6/1/2017 5/17/2016 2016 ITPNT $820,000 2016 $883,050 $283,000 COMPLETE 115

200388 31033 51509 BEPC NDLine - Berthold - Southwest Minot 115 kV

Ckt 1 Reconductor

Berthold - Southwest Minot 115 kV Ckt 1

ReconductorRegional Reliability ITP 10/1/2017 6/1/2017 5/17/2016 2016 ITPNT $3,731,074 2016 $4,017,959 $2,876,720 COMPLETE 115 26.44

200393 31038 51521 OPPD NE Device - S964 69 kV Cap Bank S964 69 kV Cap Bank Regional Reliability ITP 6/1/2020 6/1/2020 5/17/2016 2016 ITPNT $722,660 2016 $778,226 $722,660 ON SCHEDULE < 4 69

200406 31039 51524 AEP OKLine - Comanche Tap - Tosco 69 kV Ckt 1

Rebuild

Comanche Tap - Tosco 69 kV Ckt 1

RebuildRegional Reliability ITP 12/19/2016 6/1/2020 8/17/2016 2016 ITPNT $4,365,864 2016 $4,701,558 $4,365,864 COMPLETE 69 3.2 3.2 69

200397 31041 51526 WFEC OKMulti - Driftwood 138/69 kV Substation

and TransformerDriftwood 138 kV Substation Regional Reliability ITP 9/1/2019 6/1/2017 5/17/2016 2016 ITPNT $550,000 2016 $592,290 $550,000 DELAY - MITIGATION 138

200397 31041 51527 WFEC OKMulti - Driftwood 138/69 kV Substation

and TransformerDriftwood 138/69 kV Transformer Regional Reliability ITP 9/1/2019 6/1/2017 5/17/2016 2016 ITPNT $3,000,000 2016 $3,230,672 $3,600,000 DELAY - MITIGATION 138/69

200418 31042 51528 OGE OK

Multi - DeGrasse - Knob Hill 138 kV New

Line and DeGrasse 345/138 kV

Transformer

DeGrasse 345 kV Substation Regional Reliability ITP 6/1/2019 6/1/2017 12/27/2016 2016 ITPNT $7,700,661 2017 $8,090,507 $13,758,800 DELAY - MITIGATION 345 0.38

200418 31042 51529 OGE OK



Transformer

DeGrasse 345/138 kV Transformer Regional Reliability ITP 6/1/2019 6/1/2017 12/27/2016 2016 ITPNT $3,600,000 2017 $3,782,250 $3,281,064 DELAY - MITIGATION 345/138

200418 31042 51530 OGE OK



Transformer

DeGrasse - Knob Hill 138 kV New Line Regional Reliability ITP 6/1/2019 6/1/2017 12/27/2016 2016 ITPNT $8,383,000 2017 $8,807,389 $7,155,975 DELAY - MITIGATION 138 12.36

200419 31042 51531 WFEC OK



Transformer

DeGrasse 138 kV Substation (WFEC) Regional Reliability ITP 7/1/2020 6/1/2017 12/27/2016 2016 ITPNT $1,400,000 2017 $1,470,875 $5,700,000 RE-EVALUATION 138 2

200417 31031 51543 BEPC ND




Patent Gate 345 kV Substation Regional Reliability ITP 9/1/2016 6/1/2017 12/28/2016 2016 ITPNT $30,000,000 2016 $32,306,719 $30,000,000 COMPLETE 345

200417 31031 51544 BEPC ND




Roundup 345 kV Substation Regional Reliability ITP 9/1/2016 6/1/2017 12/28/2016 2016 ITPNT $27,100,000 2016 $29,183,736 $27,100,000 COMPLETE 345

200395 31051 51549 SPS TXSub - Terry Co. - Wolfforth 115 kV Terminal

Upgrades

Terry Co. - Wolfforth 115 kV Terminal

UpgradesRegional Reliability ITP 6/1/2018 4/1/2020 5/17/2016 2016 ITPNT $1,461,643 2016 $1,574,030 $1,461,643 COMPLETE 115

200386 31057 51558 AEP OK

Line - Atoka - Atoka Pump - Pittsburg -

Savanna - Army Ammo - McAlester City 69

kV Ckt 1 Rebuild

Army Ammo - McAlester 69 kV Ckt 1

RebuildZonal Reliability ITP 12/31/2019 6/1/2017 5/17/2016 2016 ITPNT $13,512,897 2016 $14,551,912 $13,512,897 DELAY - MITIGATION 69

200386 31057 51559 AEP OK



kV Ckt 1 Rebuild

Army Ammo - Savanna - Pittsburg 69 kV

Ckt 1 RebuildZonal Reliability ITP 12/31/2019 6/1/2017 5/17/2016 2016 ITPNT $15,146,464 2016 $16,311,085 $13,767,520 DELAY - MITIGATION 69

200386 31057 51560 AEP OK



kV Ckt 1 Rebuild

Atoka - Atoka Pump - Pittsburg 69 kV Ckt

1 RebuildZonal Reliability ITP 12/31/2019 6/1/2017 5/17/2016 2016 ITPNT $21,668,582 2016 $23,334,693 $23,047,526 DELAY - MITIGATION 69

200386 31058 51561 AEP OKLine - Fort Towson - Kiamichi Pump Tap -

Valliant 69 kV Ckt 1 Rebuild

Fort Towson - Kiamichi Pump Tap 69 kV

Ckt 1 RebuildRegional Reliability ITP 6/1/2019 6/1/2018 5/17/2016 2016 ITPNT $11,778,983 2016 $12,684,677 $11,778,983 DELAY - MITIGATION 69

200386 31058 51562 AEP OKLine - Fort Towson - Kiamichi Pump Tap -

Valliant 69 kV Ckt 1 Rebuild

Kiamichi Pump Tap - Valliant 69 kV Ckt 1

RebuildRegional Reliability ITP 6/1/2019 6/1/2018 5/17/2016 2016 ITPNT $7,699,929 2016 $8,291,982 $7,699,929 DELAY - MITIGATION 69

200420 31061 51565 SPS NMLine - Livingston Ridge - Wipp 115 kV Ckt 1

Rebuild

Livingston Ridge - Wipp 115 kV Ckt 1


SPP-2015-AG1-AFS-

6$264,157 2017 $277,530 $301,000 DELAY - MITIGATION 115

200420 31062 51566 SPS NMXFR - Pecos 230/115 kV Transformer

UpgradePecos 230/115 kV Transformer Upgrade Regional Reliability TS 6/1/2021 1/12/2017

SPP-2015-AG1-AFS-

6$3,423,416 2017 $3,596,726 $3,681,706 ON SCHEDULE < 4 230/115

200420 31063 51567 SPS NMSub - Carlsbad - Pecos 115 kV Terminal

Upgrades

Carlsbad - Pecos 115 kV Terminal

UpgradesRegional Reliability TS 6/1/2021 6/1/2021 1/12/2017

SPP-2015-AG1-AFS-

6$767,347 2017 $806,194 $890,000 ON SCHEDULE < 4 115 0.03

200418 31042 51569 OGE OK



Transformer

DeGrasse 138 kV Substation (OGE) Regional Reliability ITP 6/1/2019 6/1/2017 12/27/2016 2016 ITPNT $7,723,383 2017 $8,114,379 $4,562,495 DELAY - MITIGATION 138

200399 30496 51570 BEPC NEMulti - Bobcat Canyon 345/115 kV and

Bobcat Canyon - Scottsbluff 115 kVStegall 345 kV Terminal Upgrades Regional Reliability ITP 6/1/2017 6/1/2014 8/17/2016 2014 ITPNT $2,499,727 COMPLETE 345

30786 51577 NPPD Sub - Dixon County 230kV Dixon County 230kV Substation (TOIF)Generation


200437 31073 51578 MIDW KS XFR - Heizer 115/69 kV Ckt 4 Transformer Heizer 115/69 kV Ckt 4 Transformer Regional Reliability TS 6/1/2021 2/8/2017SPP-2015-AG2-AFS-

3$2,724,891 2017 $2,862,839 $2,663,963 ON SCHEDULE < 4 115/69

30937 51602 SPSSUB - TUCO 230kV Switching Station GEN-

2012-020 Addition

TUCO 230kV Switching Station GEN-2012-

020 Addition (TOIF)

Generation


30960 51609 OGESUB - Beaver County 345kV - Add 345kV


Beaver County Substation - Add 345kV

terminal for GEN-2013-030 (TOIF)

Generation


30956 51610 NPPDMulti - GEN-2013-032 Interconnection

Work

Antelope 115kV - Add terminal for GEN-

2013-032 (TOIF)

Generation

InterconnectionGI 10/3/2018 $873,106 IN SERVICE

31075 51614 KCPLSub - Tap Centerville-Marmaton 161kV

GEN-2015-016 Addition

Tap Centerville-Marmaton 161kV GEN-

2015-016 Addition (NU)

Generation


200463 31075 51615 WR KSSub - Tap Centerville-Marmaton 161kV


Tap Centerville-Marmaton 161kV GEN-

2015-016 Addition (WERE)

Generation

InterconnectionGI 7/21/2018 10/31/2018 8/16/2017 GEN-2015-016 $116,449 2017 $122,344 $110,000 COMPLETE

200444 31079 51623 SPS TXSub - Tuco - Stanton 115 kV Terminal

UpgradesTuco - Stanton 115 kV Terminal Upgrades Economic ITP 12/31/2018 1/1/2017 2/22/2017 2017 ITP10 $283,963 2017 $298,339 $0 DELAY - MITIGATION 115

200444 31080 51624 SPS TXSub - Stanton - Indiana 115 kV Terminal

Upgrades

Stanton - Indiana 115 kV Terminal

UpgradesEconomic ITP 1/1/2017 2/22/2017 2017 ITP10 $0 DELAY - MITIGATION 115

200444 31081 51625 SPS TXSub - Indiana - SP-Erskine 115 kV Terminal

Upgrades

Indiana - SP-Erskine 115 kV Terminal

UpgradesEconomic ITP 2/28/2020 1/1/2017 2/22/2017 2017 ITP10 $1,133,153 2017 $1,190,519 $1,178,153 DELAY - MITIGATION 115

200467 31082 51626 WR KSSub - Butler - Altoona 138 kV Terminal

Upgrades

Butler - Altoona 138 kV Terminal

UpgradesEconomic ITP 9/21/2018 1/1/2017 11/14/2017 2017 ITP10 $247,332 2017 $259,853 $247,332 COMPLETE 138

200430 31083 51628 WR KSSub - Neosho - Riverton 161 kV Terminal

UpgradesNeosho 161 kV Terminal Upgrades Economic ITP 12/7/2018 1/1/2017 2/21/2017 2017 ITP10 $137,488 2017 $144,448 $91,324 COMPLETE 161

200428 31085 51630 KCPL MODevice - Northeast - Charlotte - Crosstown

161 kV Reactor

Northeast - Charlotte - Crosstown 161 kV

ReactorEconomic ITP 3/1/2018 1/1/2018 2/22/2017 2017 ITP10 $500,000 2017 $525,313 $204,681 $204,681 COMPLETE 161

200458 31086 51631 WR KSLine - DePaul - Girard Jct - Franklin -

Frontenac 69 kVDePaul - Girard Jct 69 kV Regional Reliability TS 11/15/2018 12/31/2018 6/23/2017

DPA-2016-March-

596$2,908,572 2017 $3,055,818 $5,444,469 IN SERVICE 69 1.71

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200458 31086 51632 WR KSLine - DePaul - Girard Jct - Franklin -

Frontenac 69 kVFranklin - Frontenac 69 kV Regional Reliability TS 11/15/2018 12/31/2018 6/23/2017

DPA-2016-March-

596$9,287,542 2017 $9,757,724 $8,274,295 IN SERVICE 69 3.43

200429 31127 51730 MIDW KSLine - Knoll - Post Rock 230 kV New Line

Ckt 2 Knoll - Post Rock 230 kV New Line Ckt 2 Economic ITP 11/11/2018 1/1/2017 2/22/2017 2017 ITP10 $475,463 2017 $499,533 $790,927 COMPLETE 230 0.68

200431 31131 51738 AEP AR/OKLine - Siloam Springs - Siloam Springs City


Siloam Springs - Siloam Springs City 161

kV Ckt 1 Rebuild (AEP)Economic ITP 1/1/2020 1/1/2017 2/21/2017 2017 ITP10 $4,780,000 2017 $5,021,988 $4,780,000 DELAY - MITIGATION 161

200432 31131 51739 GRDA OKLine - Siloam Springs - Siloam Springs City


Siloam Springs - Siloam Springs City 161

kV Ckt 1 Rebuild (GRDA)Economic ITP 3/1/2019 1/1/2017 2/21/2017 2017 ITP10 $312,400 2017 $328,215 $440,000 DELAY - MITIGATION 161

31132 51740 AECI Multi - Morgan 345/161 kV Morgan 345/161kV TransformerRegional Reliability -

Non OATT

210506 31139 51757 KCPL MOLine - Crosstown - Blue Valley 161 kV New

LineCrosstown 161 kV Terminal Upgrades Regional Reliability ITP 6/30/2023 6/1/2020 12/11/2018 2018 ITPNT $1,120,000

DELAY - MITIGATION

WINDOW161


LineBlue Valley 161 kV Terminal Upgrades Regional Reliability ITP 6/30/2023 6/1/2020 12/11/2018 2018 ITPNT $1,400,000

DELAY - MITIGATION

WINDOW161


LineBlue Valley - Crosstown 161kV Ckt1 Regional Reliability ITP 6/30/2023 6/1/2020 12/11/2018 2018 ITPNT $6,431,824

DELAY - MITIGATION

WINDOW161

200433 31144 51764 WFEC OKSub - Tupelo - Tupelo Tap 138 kV Terminal

UpgradesTupelo 138 kV Terminal Upgrades Economic ITP 12/1/2020 1/1/2020 2/21/2017 2017 ITP10 $100,000 2017 $105,063 $0 DELAY - MITIGATION 138

31147 51766 SPSSub - Tap Tolk - Yoakum 230kV

(Needmore) - GEN-2013-027 Addition

Tap Tolk - Yoakum 230kV (Needmore) -

GEN-2013-027 Addition (TOIF)

Generation


31147 51767 SPSSub - Tap Tolk - Yoakum 230kV

(Needmore) - GEN-2013-027 Addition

Tap Tolk - Yoakum 230kV (Needmore) -

GEN-2013-027 Addition (NU)

Generation


200434 31150 51774 OGE OKSub - Lula - Tupelo Tap 138 kV Terminal

Upgrades

Lula- Tupelo Tap 138 kV Terminal

Upgrades Economic ITP 1/18/2019 1/1/2020 2/21/2017 2017 ITP10 $305,000 2017 $320,441 $305,000 COMPLETE 138


Ckt 2 Knoll Sub 230 kV Terminal Economic ITP 11/11/2018 1/1/2017 2/22/2017 2017 ITP10 $1,903,595 2017 $1,999,964 $1,938,416 COMPLETE 230


Ckt 2 Post Rock Sub 230 kV Terminal Economic ITP 11/11/2018 1/1/2017 2/22/2017 2017 ITP10 $1,493,227 2017 $1,568,822 $1,743,688 COMPLETE 230

200457 31175 51818 SPS TXLine - Cox Interchange - Hale Co

Interchange 115 kV Rebuild

Cox Interchange - Hale Co Interchange

115 kV Ckt 1Regional Reliability TS 12/15/2022 6/1/2021 5/15/2017

SPP-2016-AG1-AFS-


200457 31176 51819 SPS TXSub - Hockley County Interchange 115 kV

Terminal Upgrades

Hockley County Interchange 115 kV

Terminal UpgradesRegional Reliability TS 10/15/2019 6/1/2021 5/15/2017

SPP-2016-AG1-AFS-

3$228,066 2017 $239,612 $275,000 ON SCHEDULE < 4 115

200423 31183 51826 OGE OK Sub - Muskogee 161 kV Terminal UpgradesHancock - Muskogee 161 kV Ckt 1

Terminal UpgradesRegional Reliability TS 7/10/2018 6/1/2021 1/12/2017

SPP-2016-AG1-AFS-

1$37,638 2017 $39,543 $37,638 COMPLETE 161

200446 31186 51831 AEP TX/AR Device - IPC 138 kV Cap Bank IPC 138 kV Cap Bank Regional Reliability ITP 12/13/2018 12/1/2018 5/12/2017 2017 ITPNT $1,298,048 2017 $1,363,762 $1,917,591 COMPLETE 138

31132 51832 AECI Multi - Morgan 345/161 kV Morgan Line UprateRegional Reliability -

Non OATT

200455 41188 61834 SPS TX Sub - Hale County 115 kV Hale County 115 kV Terminal Upgrades Regional Reliability ITP 12/1/2018 5/12/2017 2017 ITPNT $766,323 2017 $805,118 $766,323 ON SCHEDULE < 4 115

200444 41189 61836 SPS TXSub - Martin - Pantex N 115 kV Terminal

Upgrades

Martin - Pantex North 115 kV Terminal

UpgradesEconomic ITP 3/15/2018 1/1/2017 2/22/2017 2017 ITP10 $324,392 2017 $340,814 $324,392 COMPLETE 115

200444 41189 61837 SPS TXSub - Martin - Pantex N 115 kV Terminal

Upgrades

Pantex South - Highland Tap 115 kV

Terminal UpgradesEconomic ITP 3/15/2018 1/1/2017 2/22/2017 2017 ITP10 $324,392 2017 $340,814 $324,392 COMPLETE 115

200455 41192 61840 SPS TX Sub - Coulter 115 kV Coulter 115 kV Terminal Upgrades Regional Reliability ITP 6/1/2018 5/12/2017 2017 ITPNT $286,869 2017 $301,392 $286,869 DELAY - MITIGATION 115

200455 41194 61844 SPS TX Sub - Plant X - Sundown 230 kV Plant X 230 kV Terminal Upgrades Regional Reliability ITP 12/31/2018 6/1/2018 5/12/2017 2017 ITPNT $217,734 2017 $228,757 $0 DELAY - MITIGATION 230

200455 41194 61845 SPS TX Sub - Plant X - Sundown 230 kV Sundown 230 kV Terminal Upgrades Regional Reliability ITP 12/31/2018 6/1/2018 5/12/2017 2017 ITPNT $360,540 2017 $378,792 $360,540 DELAY - MITIGATION 230

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

Upgrades

Terry County - LG Clauene 115 kV

Terminal UpgradesRegional Reliability ITP 12/31/2019 6/1/2019 8/17/2018 2018 ITPNT $888,216 DELAY - MITIGATION 115

200455 41198 61852 SPS OK Sub - Texas County - Hitchland 115 kV bus Texas County 115 kV Terminal Upgrades

#1 Regional Reliability ITP 12/31/2018 6/1/2018 5/12/2017 2017 ITPNT $98,639 2017 $103,633 $98,639 DELAY - MITIGATION 115

200455 41198 61853 SPS OK Sub - Texas County - Hitchland 115 kV bus Texas County 115 kV Terminal Upgrades

#2Regional Reliability ITP 12/31/2018 6/1/2018 5/12/2017 2017 ITPNT $108,430 2017 $113,919 $108,430 DELAY - MITIGATION 115

200476 41200 61856 WAPA ND Sub - Williston 115 kV Williston 115 kV Terminal Upgrades Regional Reliability ITP 11/20/2017 6/1/2018 2/21/2018 2017 ITPNT $5,000 2017 $5,253 $5,000 COMPLETE 115

200446 41202 61858 AEP OKLine - Tulsa Southeast - E.61st 138 kV

RebuildTulsa Southeast - E.61st 138 kV Rebuild Regional Reliability ITP 6/1/2019 6/1/2018 5/12/2017 2017 ITPNT $6,014,381 2017 $6,318,859 $6,014,381 DELAY - MITIGATION 138 1.8

200448 41209 61869 EDE MO

Line - Line -– Republic East – Republic

Hines Street – Republic North – Nichols 69

kV Reconductor

Nichols – Republic North 69 kV

Reconductor Regional Reliability ITP 4/13/2018 6/1/2018 5/12/2017 2017 ITPNT $4,050,000 2017 $4,255,031 $4,050,000 COMPLETE 69 10

200448 41209 61870 EDE MO



kV Reconductor

Republic Hines Street - Republic North 69

kV ReconductorRegional Reliability ITP 6/1/2018 6/1/2018 5/12/2017 2017 ITPNT $1,450,000 2017 $1,523,406 $1,450,000 COMPLETE 69 3.5

200448 41209 61871 EDE MO



kV Reconductor

Republic East - Republic Hines Street 69

kV ReconductorRegional Reliability ITP 6/1/2018 6/1/2018 5/12/2017 2017 ITPNT $800,000 2017 $840,500 $800,000 IN SERVICE 69 1.6

200462 41223 61894 CPEC NDLine - New East Ruthville - SW Minot 115

kV New Line

East Ruthville - SW Minot 115 kV New

LineRegional Reliability ITP 12/31/2019 6/1/2018 8/2/2017 2017 ITPNT $20,746,000 2017 $21,796,266 $20,746,000 DELAY - MITIGATION 115 23.8

200462 41223 61895 CPEC NDLine - New East Ruthville - SW Minot 115

kV New Line

East Ruthville - SW Minot 115 kV line

Terminal UpgradesRegional Reliability ITP 12/31/2019 6/1/2018 8/2/2017 2017 ITPNT $1,035,000 2017 $1,087,397 $1,035,000 DELAY - MITIGATION 115

200452 51236 71926 WAPA SD Multi - Roberts County - Sisseton 115kV 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 DELAY - MITIGATION 115

200452 51236 71927 WAPA SD Multi - Roberts County - Sisseton 115kVXFR - Roberts County 115/69 kV

TransformerRegional Reliability ITP 9/30/2019 6/1/2018 5/12/2017 2017 ITPNT $1,200,000 2017 $1,260,750 $1,200,000 DELAY - MITIGATION 115

51239 71933 NPPD

Sub - Holt County 345kV (Tap Grand Prairie

- Grand Island 345kV) - GEN-2015-023

Addition

Holt County 345kV (Tap Grand Prairie -

Grand Island 345kV) - GEN-2015-023

Addition (TOIF)

Generation


51239 71934 NPPD

Sub - Holt County 345kV (Tap Grand Prairie

- Grand Island 345kV) - GEN-2015-023

Addition

Holt County 345kV (Tap Grand Prairie -

Grand Island 345kV) - GEN-2015-023

Addition (NU)

Generation

InterconnectionGI 11/1/2020 $5,900,000 ON SCHEDULE < 4 345

51240 71935 NPPDSub - Hoskins 345kV - GEN-2015-007

Addition

Hoskins 345kV - GEN-2015-007 Addition

(TOIF)

Generation


51240 71936 NPPDSub - Hoskins 345kV - GEN-2015-007

Addition


(NU)

Generation

InterconnectionGI 11/1/2019 $4,600,000 ON SCHEDULE < 4 345

51240 71937 TBDSub - Hoskins 345kV - GEN-2015-007

Addition


(MISO)

Generation

InterconnectionGI 10/1/2019 $50,000 ON SCHEDULE < 4 345

200450 51236 71938 EREC SD Multi - Roberts County - Sisseton 115kV Roberts County - Sisseton 69 kV New Line Regional Reliability ITP 9/30/2019 6/1/2018 5/12/2017 2017 ITPNT $603,000 2017 $633,527 $603,000 DELAY - MITIGATION 69 1.9

51241 71939 SEPCSub - Johnson Corner 115kV - GEN-2015-

021 Addition

Johnson Corner 115kV - GEN-2015-021

Addition (TOIF)

Generation

InterconnectionGI 5/1/2019 $1,423,651 ON SCHEDULE < 4 0.05

30781 71940 NPPDSub - Rosemont 115kV Substation GEN-

2008-123N Addition

Rosemont 115kV Substation GEN-2008-

123N Addition (TOIF)

Generation


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51242 71941 WAPAMulti - Sulphur 115kV - GEN-2014-001IS

Addition

Sulphur 115kV - GEN-2014-001IS Addition

(TOIF)

Generation



Addition


(SANU)

Generation



Addition


(NU)

Generation


200446 41233 71945 AEP OKLine - Broken Arrow North - Lynn Lane East

138 kV Ckt 1

Broken Arrow North - Lynn Lane East 138

kV Ckt 1 ReconductorRegional Reliability ITP 6/1/2019 6/1/2018 5/12/2017 2017 ITPNT $5,714,095 2017 $6,003,371 $5,714,095 DELAY - MITIGATION 138 7.13

200455 51246 71949 SPS TX Sub - Nichols - 230 kV Nichols 230 kV Terminal Upgrades Regional Reliability ITP 12/1/2018 5/12/2017 2017 ITPNT $490,000 2017 $514,806 $257,295 ON SCHEDULE < 4 230

51247 71951 OGESub - Cleo Corner 138kV GEN-2015-048

Addition

Cleo Corner 138kV GEN-2015-048

Addition (TOIF)

Generation

InterconnectionGI 6/14/2019 $410,000 RE-EVALUATION

51247 71952 OGESub - Cleo Corner 138kV GEN-2015-048

Addition

Cleo Corner 138kV GEN-2015-048

Addition (NU)

Generation

InterconnectionGI 6/14/2019 $2,558,000 RE-EVALUATION

51248 71953 OGELine - Cleo Corner – Cleo Plant Tap 138kV

Ckt 1Cleo Corner - Cleo Plant Tap 138kV Ckt 1

Generation

InterconnectionGI 6/14/2019 $61,890 RE-EVALUATION

200469 51249 71954 KPP KSLine - City of Winfield - Oak 69 kV

ReconductorCity of Winfield - Rainbow 69 kV Ckt 1 Regional Reliability TS 6/1/2021 2/27/2018

SPP-2016-AG2-AFS-

2$3,600,000 2018 $3,690,000 $3,600,000 ON SCHEDULE < 4

200466 51249 71955 WR KSLine - City of Winfield - Oak 69 kV

ReconductorOak - Rainbow 69 kV Ckt 1 Regional Reliability TS 6/1/2021 6/1/2021 9/21/2017

SPP-2016-AG2-AFS-

2$7,831,427 2017 $8,227,893 $7,831,427 ON SCHEDULE < 4 69 5.1

200466 51252 71958 WR KSXFR - Creswell 138/69/13.2 kV

Transformers

Creswell (CRSW TX-1) 138/69/13.2 kV

Transformer Ckt 1Regional Reliability TS 6/1/2021 6/1/2021 9/21/2017

SPP-2016-AG2-AFS-

2$3,486,230 2017 $3,662,720 $3,486,230 ON SCHEDULE < 4 138/69

200466 51252 71959 WR KSXFR - Creswell 138/69/13.2 kV

Transformers

Creswell (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-

2$3,621,491 2017 $3,804,829 $3,621,491 ON SCHEDULE < 4 138/69

200455 41199 71960 SPS TX Line - Etter - Moore - 115 kV Etter - Moore 115 kV Rebuild Regional Reliability ITP 9/15/2020 6/1/2018 5/12/2017 2017 ITPNT $9,037,903 2017 $9,495,447 $6,911,107 RE-EVALUATION 115 10.25

200454 51253 71961 NIPCO IASub - L-10 Southern 69 kV Terminal

UpgradesL-10 Southern 69 kV Terminal Upgrades Regional Reliability ITP 7/1/2019 6/1/2018 5/12/2017 2017 ITPNT $710,000 2017 $745,944 $769,995 DELAY - MITIGATION 69

200454 51253 71962 NIPCO IASub - L-10 Southern 69 kV Terminal

UpgradesJ16 69 kV Substation Regional Reliability ITP 7/1/2019 6/1/2018 5/12/2017 2017 ITPNT $1,220,000 2017 $1,281,763 $1,354,032 DELAY - MITIGATION 69

200477 51254 71963 NPPD NE Multi - Sheldon - Monolith 115 kV Monolith 345 kV Substation Regional Reliability TS 1/1/2021 12/1/2020 2/21/2018DPA-2016-

December-703$12,692,888 2018 $13,010,210 $12,692,888

DELAY - MITIGATION

WINDOW345 0.2

200477 51254 71964 NPPD NE Multi - Sheldon - Monolith 115 kV Monolith 345/115 kV Transformer #1 Regional Reliability TS 1/1/2021 12/1/2020 2/21/2018DPA-2016-

December-703$5,179,657 2018 $5,309,148 $5,179,657

DELAY - MITIGATION

WINDOW345/115

200477 51254 71965 NPPD NE Multi - Sheldon - Monolith 115 kV Monolith 345/115 kV Transformer #2 Regional Reliability TS 1/1/2021 12/1/2020 2/21/2018DPA-2016-

December-703$5,179,657 2018 $5,309,148 $5,179,657

DELAY - MITIGATION

WINDOW345/115

200477 51254 71966 NPPD NE Multi - Sheldon - Monolith 115 kV Monolith 115 kV Substation Upgrades Regional Reliability TS 1/1/2021 12/1/2020 2/21/2018DPA-2016-

December-703$11,271,233 2018 $11,553,014 $11,271,233

DELAY - MITIGATION

WINDOW115 2.6

200477 51254 71967 NPPD NE Multi - Sheldon - Monolith 115 kV Sheldon - Monolith 115 kV Ckt 1 New Line Regional Reliability TS 1/1/2021 12/1/2020 2/21/2018DPA-2016-

December-703$1,273,506 2018 $1,305,344 $1,273,506

DELAY - MITIGATION

WINDOW115 1

200477 51254 71968 NPPD NE Multi - Sheldon - Monolith 115 kV Sheldon 115 kV Terminal Upgrades Regional Reliability TS 1/1/2021 12/1/2020 2/21/2018DPA-2016-

December-703$3,703,266 2018 $3,795,848 $3,703,266

DELAY - MITIGATION

WINDOW115

200470 51260 71976 CBPC IA Device - Prestage Family 69 kV Cap Bank Prestage Family 69 kV Cap Bank Regional Reliability TS 9/1/2018 8/1/2018 1/19/2018DPA-2017-March-

735$1,017,500 2018 $1,042,938 $1,017,500 COMPLETE 69 1.5

51261 71980 NPPDMulti - Belvidere 115kV Substation GEN-

2015-087 Addition

Belvidere 115kV Substation GEN-2015-

087 Addition (TOIF)

Generation

InterconnectionGI 11/1/2019 $300,000 RE-EVALUATION 115


2015-087 Addition

Belvidere 115kV Substation GEN-2015-

087 Addition (NU)

Generation

InterconnectionGI 11/1/2019 $5,300,000 RE-EVALUATION 115


2015-087 AdditionBelvidere – Fairbury 115kV circuit #1

Generation

InterconnectionGI 11/1/2019 $1,700,000 RE-EVALUATION 115/115


2015-087 AdditionBeatrice – Harbine 115kV circuit #1

Generation

InterconnectionGI 11/1/2019 $900,000 RE-EVALUATION 115/115

51262 71984 NPPDSub - Tobias 345kV Substation GEN-2015-

088 Addition

Tobias 345kV Substation GEN-2015-088

Addition (TOIF)

Generation

InterconnectionGI 1/1/2019 $700,000 ON SCHEDULE < 4 345/345

51262 71985 NPPDSub - Tobias 345kV Substation GEN-2015-

088 Addition

Tobias 345kV Substation GEN-2015-088

Addition (NU)

Generation

InterconnectionGI 1/1/2019 $11,700,000 ON SCHEDULE < 4 345/345

51276 72002 WRSub - Union Ridge 230kV GEN-2015-069

Addition

Union Ridge 230kV GEN-2015-069

Addition (TOIF)

Generation


51276 72003 WRSub - Union Ridge 230kV GEN-2015-069

Addition

Union Ridge 230kV GEN-2015-069

Addition (NU)

Generation


200483 51277 72004 OPPD OK Line - S1255 - S1260 161 kV S1255 - S1260 161 kV Ckt 1 New Line Regional Reliability TS 1/1/2020 1/1/2020 2/27/2018DPA-2017-May-

746$14,770,262 2018 $15,139,519 $14,770,262 ON SCHEDULE < 4 161 5.9

200482 51280 72011 WFEC NE Device - Dover SW 69 kV Cap Bank Dover SW 69 kV Cap Bank Regional Reliability TS 6/1/2022 6/1/2019 2/27/2018DPA-2017-August-

767-774-776$500,000 2018 $512,500 $500,000

DELAY - MITIGATION

WINDOW69

200482 51281 72012 WFEC OK Device - Cherokee SW 69 kV Cap Bank Cherokee SW 69 kV Cap Bank Regional Reliability TS 6/1/2022 6/1/2018 2/27/2018DPA-2017-August-

767-774-776$1,000,000 2018 $1,025,000 $1,000,000

DELAY - MITIGATION

WINDOW69

210483 51282 72013 WFEC OK Multi - Park Community - Sunshine 138 kV Park Community 138 kV Substation Regional Reliability TS 6/15/2018 6/1/2018 4/26/2018DPA-2017-August-

767-774-776$2,000,000 2018 $2,050,000 $2,000,000 COMPLETE 138

210483 51282 72014 WFEC OK Multi - Park Community - Sunshine 138 kVOmega - Park Community 138 kV Ckt 1

New LineRegional 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 OK Multi - Park Community - Sunshine 138 kVOmega - Watonga SW 138 kV Ckt 1

Voltage ConversionRegional Reliability TS 10/31/2019 6/1/2019 4/26/2018

DPA-2017-August-

767-774-776$7,950,000 2018 $8,148,750 $7,950,000

DELAY - MITIGATION

WINDOW138 7.9 7.9

210483 51282 72016 WFEC OK Multi - Park Community - Sunshine 138 kVOkeene - Watonga SW 138 kV Ckt 1


DPA-2017-August-

767-774-776$6,750,000 2018 $6,918,750 $6,750,000

DELAY - MITIGATION

WINDOW138 13.5 13.5

210483 51282 72018 WFEC OK Multi - Park Community - Sunshine 138 kVCalumet - Watonga SW 138 kV Ckt 1


DPA-2017-August-

767-774-776$8,400,000 2018 $8,610,000 $8,400,000 DELAY - MITIGATION 138 16.8 16.8

210483 51282 72019 WFEC OK Multi - Park Community - Sunshine 138 kVCalumet - Concho 138 kV Ckt 1 Voltage

ConversionRegional Reliability TS 6/1/2020 6/1/2020 4/26/2018

DPA-2017-August-

767-774-776$1,250,000 2018 $1,281,250 $1,250,000

DELAY - MITIGATION

WINDOW138 9

210483 51282 72020 WFEC OK Multi - Park Community - Sunshine 138 kVCalumet - Cana 138 kV Ckt 1 Voltage


DPA-2017-August-

767-774-776$4,550,000 2018 $4,663,750 $4,550,000

DELAY - MITIGATION

WINDOW138 9.1 9.1

210483 51282 72021 WFEC OK Multi - Park Community - Sunshine 138 kV Calumet 138 kV Substation Regional Reliability TS 10/1/2020 6/1/2019 4/26/2018DPA-2017-August-

767-774-776$4,000,000 2018 $4,100,000 $4,000,000

DELAY - MITIGATION

WINDOW138

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210483 51282 72022 WFEC OK Multi - Park Community - Sunshine 138 kVCana - El Reno Jct 138 kV Ckt 1 Voltage


DPA-2017-August-

767-774-776$5,650,000 2018 $5,791,250 $5,650,000

DELAY - MITIGATION

WINDOW138 3.3 3.3

210483 51282 72023 WFEC OK Multi - Park Community - Sunshine 138 kVEl Reno - El Reno Jct 138 kV Ckt 1 Voltage


DPA-2017-August-

767-774-776$4,000,000 2018 $4,100,000 $3,250,000

DELAY - MITIGATION

WINDOW138

210483 51282 72024 WFEC OK Multi - Park Community - Sunshine 138 kVEl Reno - Mustang 138 kV Ckt 1 Voltage


DPA-2017-August-

767-774-776$4,000,000 2018 $4,100,000 $10,650,000

DELAY - MITIGATION

WINDOW138 21.3 21.3

210483 51282 72025 WFEC OK Multi - Park Community - Sunshine 138 kVMustang - Sara Road 138 kV Ckt 1 Voltage


DPA-2017-August-

767-774-776$10,650,000 2018 $10,916,250 $1,050,000

DELAY - MITIGATION

WINDOW138 2.1 2.1

210483 51282 72026 WFEC OK Multi - Park Community - Sunshine 138 kVSara Road - Sunshine 138 kV Ckt 1


DPA-2017-August-

767-774-776$1,050,000 2018 $1,076,250 $5,000,000

DELAY - MITIGATION

WINDOW138 10 10

210483 51282 72027 WFEC OK Multi - Park Community - Sunshine 138 kVCogar - El Reno Jct 138 kV Ckt 1 Voltage


DPA-2017-August-

767-774-776$5,000,000 2018 $5,125,000 $5,300,000

DELAY - MITIGATION

WINDOW138 10.6 10.6

210483 51282 72028 WFEC OK Multi - Park Community - Sunshine 138 kV Cogar 138/69 kV Transformer Regional Reliability TS 6/1/2020 4/26/2018DPA-2017-August-

767-774-776$4,500,000 2018 $4,612,500 $4,500,000

DELAY - MITIGATION

WINDOW138/69

210483 51282 72029 WFEC OK Multi - Park Community - Sunshine 138 kVKingfisher 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 $4,612,500 $4,500,000 COMPLETE 138 9

210483 51282 72030 WFEC OK Multi - Park Community - Sunshine 138 kV Kingfisher SW 138 kV Substation Regional Reliability TS 10/1/2019 6/1/2018 4/26/2018DPA-2017-August-

767-774-776$4,000,000 2018 $4,100,000 $4,000,000 DELAY - MITIGATION 138

210483 51282 72031 WFEC OK Multi - Park Community - Sunshine 138 kVConcho - Kingfisher SW 138 kV Ckt 1 New

LineRegional Reliability TS 11/1/2020 6/1/2019 4/26/2018

DPA-2017-August-

767-774-776$4,250,000 2018 $4,356,250 $4,250,000

DELAY - MITIGATION

WINDOW138 8.5

51283 72032 WRSub - Wild Plains 345kV Switching Station

GEN-2015-052 Interconnection

Wild Plains 345kV Switching Station GEN-

2015-052 Interconnection (TOIF)

Generation


51283 72033 WRSub - Wild Plains 345kV Switching Station



2015-052 Interconnection (NU)

Generation


51283 72034 OGESub - Wild Plains 345kV Switching Station



2015-052 Interconnection (NU - OGE)

Generation


210493 51285 72037 CUS MO Multi - Brookline 345kV Brookline 345kV Reactor Regional Reliability ITP 12/31/2019 6/1/2019 8/17/2018 2018 ITPNT $3,471,864 2018 $3,558,661 $3,471,864 DELAY - MITIGATION 345

210493 51285 72038 CUS MO Multi - Brookline 345kV Brookline 345kV Substation Expansion Regional Reliability ITP 12/31/2019 6/1/2019 8/17/2018 2018 ITPNT $794,411 2018 $814,271 $794,411 DELAY - MITIGATION 345

210495 51292 72047 KCPL KSSub - Brookridge - Overland Park 161kV

Terminal Upgrades

Brookridge - Overland Park 161kV

Terminal UpgradesRegional Reliability ITP 2/1/2020 6/1/2019 8/17/2018 2018 ITPNT $745,000 2018 $763,625 $745,000 DELAY - MITIGATION 161

210495 51294 72049 KCPL KSSub - Olathe - Switzer 161kV Ckt1 Terminal

UpgradesOlathe - Switzer 161kV Ckt1 Regional Reliability ITP 2/1/2020 6/1/2019 8/17/2018 2018 ITPNT $1,088,000 2018 $1,115,200 $1,088,000 DELAY - MITIGATION 161

210492 51295 72050 BEPC MT Line - Lewis - Richland 115kV Ckt 1 Lewis - Richland 115kV Ckt 1 (BEPC) Regional Reliability ITP 12/31/2019 6/1/2019 8/17/2018 2018 ITPNT $5,000 ON SCHEDULE > 4 115

210497 51295 72052 WAPA MT Line - Lewis - Richland 115kV Ckt 1 Lewis - Richland 115kV Ckt 1 (WAPA) Regional Reliability ITP 6/1/2019 6/1/2019 8/17/2018 2018 ITPNT $100,000 2019 $100,000 $136,000 ON SCHEDULE < 4 115 0.1

210491 51300 72066 AEP AR Multi - Fig Five - VBI 69kV Fig Five - VBI North 69kV Ckt 1 Regional Reliability ITP 6/1/2019 6/1/2019 8/17/2018 2018 ITPNT $3,357,600 2018 $3,441,540 $3,357,600 ON SCHEDULE < 4 69

210490 51300 72067 AECC AR Multi - Fig Five - VBI 69kV Fig 5 - VBI North 69 kV Ckt 1 #2 Regional Reliability ITP 6/1/2019 6/1/2019 8/17/2018 2018 ITPNT $51,200 2018 $52,480 $52,100 ON SCHEDULE < 4 69

210498 51305 72076 WR KS XFR - Lawrence Hill 230/115kV Lawrence Hill 230/115kV Transformer Regional Reliability ITP 6/1/2020 6/1/2019 8/17/2018 2018 ITPNT $5,781,164 2018 $5,925,693 $5,781,164 DELAY - MITIGATION 230

210496 51316 72095 SPS TXCarlisle - Murphy 115kV Terminal

Upgrades

Carlisle - Murphy 115 kV Terminal

UpgradesRegional Reliability ITP 2/16/2019 6/1/2022 8/17/2018 2018 ITPNT $232,952 2018 $238,776 $232,952 ON SCHEDULE < 4 115

210489 51327 82111 WFEC OK Line - Cogar - OU SW 138 kVCogar - Cleveland Jct 138 kV Ckt 1 Voltage


DPA-2017-

December-815$10,000,000 2018 $10,250,000 $10,000,000

DELAY - MITIGATION

WINDOW138

210489 51327 82112 WFEC OK Line - Cogar - OU SW 138 kVCleveland Jct - Amber Tap 138 kV Ckt 1


DPA-2017-

December-815$6,900,000 2018 $7,072,500 $6,900,000

DELAY - MITIGATION

WINDOW138

210489 51327 82113 WFEC OK Line - Cogar - OU SW 138 kVAmber Tap - Blanchard 138 kV Ckt 1


DPA-2017-

December-815$7,600,000 2018 $7,790,000 $7,600,000

DELAY - MITIGATION

WINDOW138

210489 51327 82114 WFEC OK Line - Cogar - OU SW 138 kVBlanchard - OU SW 138 kV Ckt 1 Voltage


DPA-2017-

December-815$300,000 2018 $307,500 $300,000

DELAY - MITIGATION

WINDOW138

210489 51327 82115 WFEC OK Line - Cogar - OU SW 138 kVCleveland Jct - Anadarko 138 kV Ckt 1


DPA-2017-

December-815$6,300,000 2018 $6,457,500 $6,300,000

DELAY - MITIGATION

WINDOW138

51328 82116 WRSub - Emporia Energy Center 345 kV

Substation GEN-2015-073 Interconnection

Emporia Energy Center 345 kV Substation

GEN-2015-073 Interconnection (TOIF)

Generation


51328 82117 WRSub - Emporia Energy Center 345 kV


Emporia Energy Center 345 kV Substation

GEN-2015-073 Interconnection (NU)

Generation


210494 51330 82123 EREC SD Multi - Lakeview County 69kV Lakeview 69 kV Substation #3 Regional Reliability ITP 2/1/2020 6/1/2019 8/17/2018 2018 ITPNT $3,732,000 2018 $3,825,300 $3,732,000 DELAY - MITIGATION 69

210494 51330 82124 EREC SD Multi - Lakeview County 69kV Lakeview 69 kV Capacitor Bank Regional Reliability ITP 2/1/2020 6/1/2019 8/17/2018 2018 ITPNT $1,740,000 2018 $1,783,500 $1,740,000 DELAY - MITIGATION 69

210499 51331 82125 GHP MO Line - Nixa Downtown - Nixa Espy Nixa Downtown - Nixa Espy Ckt1 Regional Reliability ITP 12/31/2019 6/1/2019 8/17/2018 2018 ITPNT $1,402,000 2018 $1,437,050 $1,402,000 DELAY - MITIGATION 69

51332 82126 OGESub - Gracemont 345 kV Substation GEN-

2015-093 Interconnection

Gracemont 345 kV Substation GEN-2015-

093 Interconnection (TOIF)

Generation


51332 82127 OGESub - Gracemont 345 kV Substation GEN-


Gracemont 345 kV Substation GEN-2015-

093 Interconnection (NU)

Generation


51333 82128 OGESub - Tap Cleveland - Sooner 345 kV


Tap Cleveland - Sooner 345 kV Substation

GEN-2015-066 Interconnection (TOIF)

Generation


51333 82129 OGESub - Tap Cleveland - Sooner 345 kV


Tap Cleveland - Sooner 345 kV Substation

GEN-2015-066 Interconnection (NU)

Generation


51334 82130 OGESub - Osage 69 kV Substation GEN-2016-

009 Interconnection

Osage 69 kV Substation GEN-2016-009

Interconnection (TOIF)

Generation


51334 82131 OGESub - Osage 69 kV Substation GEN-2016-

009 Interconnection

Osage 69 kV Substation GEN-2016-009

Interconnection (NU)

Generation


51335 82132 NPPDSub - Belden 115 kV Substation GEN-2015-

076 Interconnection

Belden 115 kV Substation GEN-2015-076

Interconnection (TOIF)

Generation


51335 82133 NPPDSub - Belden 115 kV Substation GEN-2015-

076 Interconnection

Belden 115 kV Substation GEN-2015-076

Interconnection (NU)

Generation


51338 82134 WAPALine - Gavins Point - Yankton Junction 115

kVGavins Point - Yankton Junction 115 kV

Generation


51336 82135 SPSSub - Lost Draw 115 kV Substation GEN-


Lost Draw 115 kV Substation GEN-2015-


Generation


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51336 82136 SPSSub - Lost Draw 115 kV Substation GEN-


Lost Draw 115 kV Substation GEN-2015-


Generation


51337 82137 AEPSub - Tuskahoma 138 kV Substation GEN-


Tuskahoma 138 kV Substation GEN-2016-


Generation


51337 82138 AEPSub - Tuskahoma 138 kV Substation GEN-


Tuskahoma 138 kV Substation GEN-2016-


Generation


210496 61346 92151 SPS KS XFR - McDowell 230/115 kV Ckt 1 McDowell Creek 230/115kV Substation Regional Reliability ITP 5/28/2021 6/1/2019 8/17/2018 2018 ITPNT $9,069,324 2018 $9,296,057 $9,069,324 DELAY - MITIGATION 230 0.2

210496 61346 92152 SPS KS XFR - McDowell 230/115 kV Ckt 1 McDowell Creek 230/115kV Transformer Regional Reliability ITP 5/28/2021 6/1/2019 8/17/2018 2018 ITPNT $5,226,730 2018 $5,357,398 $5,226,730 DELAY - MITIGATION 230/115

210507 61347 92153 SPS NM Multi - China Draw - Road Runner 345 kVBopco - Road Runner 345 kV Ckt 1 New


DPA-2017-

November-808$29,927,758

DELAY - MITIGATION

WINDOW345 21

210507 61347 92154 SPS NM Multi - China Draw - Road Runner 345 kVBopco - China Draw 345 kV Ckt 1 New


DPA-2017-

November-808$30,496,976

DELAY - MITIGATION

WINDOW345 19

210507 61347 102153 SPS NM Multi - China Draw - Road Runner 345 kV Bopco 345/115 kV Ckt 1 Transformer Regional Reliability TS 4/15/2020 12/1/2018 12/11/2018DPA-2017-

November-808$6,205,015

DELAY - MITIGATION

WINDOW345/115

210507 61347 102154 SPS NM Multi - China Draw - Road Runner 345 kV Bopco 345/115 kV Ckt 2 Transformer Regional Reliability TS 4/15/2020 12/1/2021 12/11/2018DPA-2017-

November-808$6,122,043 ON SCHEDULE > 4 345/115

210507 71347 102156 SPS NMLine - Eddy County - Kiowa 345 kV New

Line

Eddy County - Kiowa 345 kV Ckt 1 New


DPA-2017-

November-808$63,730,259 ON SCHEDULE < 4 345 34

210507 61347 102157 SPS NM Multi - China Draw - Road Runner 345 kV Bopco 345 kV Substation Regional Reliability TS 4/15/2020 12/1/2018 12/11/2018DPA-2017-

November-808$5,153,574

DELAY - MITIGATION

WINDOW345

210507 61347 102158 SPS NM Multi - China Draw - Road Runner 345 kV Bopco 115 kV Substation Regional Reliability TS 4/15/2020 12/1/2018 12/11/2018DPA-2017-

November-808$11,741,936

DELAY - MITIGATION

WINDOW115

71349 102167 WAPASub - Granite Falls 115 kV Substation GEN-


Granite Falls 115 kV Substation GEN-2016-


Generation


71350 102168 OGESUB - Ranch Road 345kV Substation GEN-

2015-034 Addition

Ranch Road 345kV Substation GEN-2015-

034 Addition (TOIF)

Generation


71350 102169 OGESUB - Ranch Road 345kV Substation GEN-

2015-034 Addition

Ranch Road 345kV Substation GEN-2015-

034 Addition (NU)

Generation


71351 102170 OGESUB - Johnston County 345kV Substation


Johnston County 345kV Substation GEN-

2015-036 Addition (TOIF)

Generation


71351 102171 OGESUB - Johnston County 345kV Substation


Johnston County 345kV Substation GEN-

2015-036 Addition (NU)

Generation


210505 71352 102172 WFEC OK Device - Clear Creek Tap 69 kV Cap Bank Clear Creek Tap 69 kV Cap Bank Regional Reliability TS 12/1/2019 12/1/2019 12/6/2018DPA-2018-June-

902$717,209 ON SCHEDULE < 4 69

31018 112173 OGESub - Minco 345kV GEN-2014-056 & GEN-

2015-057 Addition

Minco 345kV Substation GEN-2015-057

Addition (NU)

Generation


81467 112297 SEPC Mingo 345 kV SubstationMingo 345kV Substation GEN-2015-065

(TOIF)

Generation

InterconnectionGI $2,016,000 ON SCHEDULE > 4


(NU)

Generation

InterconnectionGI $8,232,063 ON SCHEDULE > 4

81467 112299 SEPC Mingo 345 kV SubstationMingo Substation Relay GEN-2015-065

(NU)

Generation

InterconnectionGI $15,000 ON SCHEDULE > 4


(TOIF)

Generation



(NU)

Generation


78 of 78

Documents

JOINT QUARTERLY STAKEHOLDER BRIEFING (SPP Board of ... materials 20190419_pgd.pdfScott Rupp, Missouri Public Service Commission (MoPSC) DeAnn T. Walker, Public Utility Commission of