agenda - southwest power pool minutes and attachments... · dpp window 100% mar 25 - apr 23 dpp...

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.

SOUTHWEST POWER POOL, INC.

PROJECT COST WORKING GROUP

June 3, 2020

Net Conference

AGENDA

8:30 AM – 2:30 PM

Administrative Items ........................................................................................................................... (5 min)

a) Call to Order & Introductions....................................................................... Tom Hestermann

b) Anti-trust Language .................................................................................................... John O’Dell

c) Receipt of Proxies ........................................................................................................ John O’Dell

d) Review of Agenda ............................................................................................. Tom Hestermann

Review of Past Action Items ................................................................................... John O’Dell (10 min)

Action Item 200 marked complete

Action Item 201 will be addressed at July 2020 meeting

Consent Agenda (Approval Item)* ......................................... Tom Hestermann (5 min)

a) Approval of Meeting Minutes – April 1, 2020

Motion to approve – Brian Johnson, 2nd Kenny Munsell. Approved

unanimously.

ITP schedule update ............................................................................................ Dara Solomon (30 min)

Staff will send requests for the Study Cost Estimate on 6/12/2020 (project list will

be sent out when the SCE is sent out), We plan to start working to schedule

scoping calls with each TO.

Multi - Kummer Ridge - Roundup 115 kV New Line and Patent Gate and Roundup

345/115 kV Substations (Approval Item)* .................................. Boyd Trester (30 min)

Motion to accept the cost estimate deviation as reasonable and acceptable and

reset the baseline used to evaluate future cost estimate deviations - Brian

Johnson, 2nd – Kenny Munsell. Approved unanimously.





Quarterly Report Review (Approval Item)* ................................... John O’Dell (30 min)

Motion to approve report as amended with recommendation for Agenda Item 5 –

Jamie Hayek, 2nd Scott Brunnert. Approved Unanimously.

Aging Report Review* ........................................................................................ Tammy Bright (15 min)

Discussion ensued. Items where baseline has been reset shall not be included in

future lists.

Upgrade Closeout Review* ..................................................................................... John O’Dell (15 min)

PCWG reviewed close out list.

BP 7060 Appendix C Update(AI 204 & 210) update (Approval Item)* John O’Dell (15

min)

Revise per discussion and bring back for approval and inclusion in BP 7060 RR in

July, 2020

BP7060 RR review (Approval Item)* ........................................................ Tammy Bright (30 min)

Determine approval path given that BPWG will be disbanded and bring back for

review in July, 2020.

Discuss interest in Chair position ............................................................. Tom Hestermann (15 min)

Tom announced his intent to retire from the PCWG chair position at the end of

2020. Anyone interested in the chair position shall notify John O’Dell and Tammy

Bright via email by 6/26/2020 to state their interest.

Summary of Action Items .........................................................John O’Dell/Tammy Bright (10 min)

Bring back Action Item 201 for discussion in July

Revise Appendix C draft to correct timing of RFP process

Figure out path of review for BP7060 RR and report back in July

Determine location for September PCWG meeting, Dallas or Net-Conference

Suggested Agenda Items for Next Meeting .......................................... Tom Hestermann (5 min)





Upcoming Meetings:

July 1, 2020 Net Conference

August 5, 2020 Net Conference

September 2, 2020 AEP Dallas Office

October 7, 2020 Net Conference

November 4, 2020 Net Conference

December 2, 2020 AEP Dallas Office

Name Email Role Company

Tom Hestermann [email protected] Chair SUNFLOWER

Brian Johnson [email protected] Vice Chair AEP

Boyd Trester [email protected] Member BEPC

Brenda Jessop (Evergy) [email protected] Member EVERGY

Curt Miller [email protected] Member WFEC

James Ging [email protected] Member KPP

Jamie Hajek [email protected] Member NORTHWESTERN

Jeff Knottek [email protected] Member CITYUTILITIES

Jerry Bradshaw (SPRM) [email protected] Member CITYUTILITIES

Jonah Martin TSGT [email protected] Member TRISTATEGT

KENNETH MUNSELL [email protected] Member XCELENERGY

Matt Mohr [email protected] Member EASTRIVER

Scott Brunnert (OGE) [email protected] Member OGE

Teddy Hutchinson [email protected] Member OPPD

Todd E Meyers [email protected] Member WAPA

Travis Hill [email protected] Member NPPD

Harika Basaran (PUCT) [email protected] Liasion Member PUC.TEXAS

Al Tamimi [email protected] Guest SUNFLOWER

Amanda Wangler [email protected] Guest BEPC

Angie Anderson (Sunflower) [email protected] Guest SUNFLOWER

Brian Rounds (AESL) [email protected] Guest AESLCONSULTING

D Diaz [email protected] Guest STONEPIGMAN

Jason Chaplin (OCC) [email protected] Guest OCCEMAIL

Jason Mazigian [email protected] Guest BEPC

Michael Wegner (ITC) [email protected] Guest ITCTRANSCO

Dara Solomon [email protected] SPP Staff SPP

Denise Martin [email protected] SPP Staff SPP

John O'Dell [email protected] SPP Staff SPP

Sherri Maxey [email protected] SPP Staff SPP

Tammy Bright [email protected] SPP Staff SPP

June 3, 2020, PCWG Net Conference Attendance

1

ANTITRUST STATEMENT

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.

SOUTHWEST POWER POOL, INC.

Project Cost Working Group

Pending Action Items Status Report

June 3, 2020 8:30 AM-2:30 PM

ACTION ITEM DATE

ORIGINATED STATUS COMMENTS

As directed by MOPC at the

January meeting, review and

recommend any changes to the

Quarterly Tracking Report process,

including timing, data requested,

format of data reporting,

interaction with other project cost-

related initiatives, etc.

February

2012 Complete

MOPC Action item complete.

Ongoing project to identify

improvements. Staff will add

this to the PCWG Charter upon

annual update and review.

Create list of Upgrades with

potential to be closed out.

Identify outstanding items

required for close-out process.

December

2018

Complete

Agenda Item 8

Staff and TOs continue to

close out upgrades.

Staff will provide a report of

potential close-out upgrades

at each quarterly face to face

meeting.

Staff to present history of

Conceptual, Study, CPE, & NPE

bandwidths to PCWG.

December

2018

In Progress

Staff to determine who

created estimates used in

NTCs for Priority Projects. Also

determine how cost increases

were discovered. Target July

2020 PCWG meeting.

SPP Staff will advise of Study Cost

Estimate windows for 2020 ITP

assessment.

March 2019 In Progress

Agenda Item 4

This will be covered in ITP

Assessment Schedule updates

going forward.

Research Revision to BP 7060 to

clarify NTC-C reevaluation in

Appendix C.


Agenda Item 9

Tabled for inclusion with page

turn review of BP 7060. Now

dependent on Action Item

210.

ACTION ITEM DATE

ORIGINATED STATUS COMMENTS

Staff to research drivers and

ownership of lead time values

used in for NTC issuance

October

2019 In Progress

Question: Are lead times

expected to represent time to

completion of upgrade after

study concludes? Answer:

Lead times do represent time

to expected completion

although influences, such as

outside agency approval, are

not considered

Staff to research driver for

language in BP 7060, Section 8.3,

which differentiates timing of CPEs

for ITP & Non-ITP projects

October

2019

In Progress

Aging Report -Add review of

projects with no change in cost

compared to baseline as ongoing

quarterly Face to Face agenda

item

December

2019 In Progress

Will be on June 2020 meeting

agenda and presented at all

quarterly face-to-face

meetings going forward.

Add deadlines/timeframes to

Appendix C of BP 7060

December

2019

In Progress

Agenda Item 9

Follow up on WFEC reevaluation

of DeGrasse project March 2020

In Progress

Staff to report back to PCWG

with findings.

Based on Aging report review in

March 2020 meeting, staff to

follow up on WFEC Cogar Project

for updated cost.


Staff to follow up with WFEC

for update on project.

Project updated with 2023

completion date from

3/1/2021.

SouthwestPowerPool SPPorg southwest-power-poolHelping our members work together to

keep the lights on... today and in the future.1

2020 ITP

2020 ITP SCHEDULEDARA SOLOMON

JUNE 2, 2020

22020 ITP

Portfolio Development

2020 2020

Today

Jan Feb Mar Apr May Jun Jul Aug Sep Oct

100% Mar 25 - Apr 23DPP Window

90% Apr 23 - May 26DPP Cure Period

70% Mar 25 - May 26Staff Solutions Development

50% Apr 13 - Jun 1Staff Solutions Evaluation

2% May 8 - Jun 8Port. Dev. Phase 1 (Econ/Reliab)

Jun 15 - Jul 7SCEs Window

Jun 9 - Jul 7Port. Dev. Phase 2 (Econ/Reliab)

Jul 9 - Jul 23Port. Dev. Phase 3 (Econ/Reliab)

Jul 24 - Jul 28Final Port. Dev. (Econ/Reliab)

Jul 29 - Aug 4Optimization

Aug 5 - Aug 18Consolidation

Aug 19 - Sep 1Staging

Aug 19 - Sep 18Benefit Metrics

Sep 2 - Sep 18Rate Impacts

Aug 19 - Sep 18Stability Assessment

Aug 19 - Sep 18Sensitivities Analyses

21% Mar 2 - Sep 28Draft Report

45% Jan 2 - Oct 272020 ITP

May 21 - Jul 7Summit Prep

70% Apr 24 - Jun 1DPP Technical Validation

65% May 1 - Jun 1DPP Solutions Evaluation

Aug 19 - Sep 18Final Reliab. Assessment

Jun 8 - Jun 12Upgrade Determination/Study Cost Estimates (SCEs)

7/7

Summit7/8

MOPC10/14

SPP Board

10/27

Final ESWG/TWG Approval10/2

Send out SCEs6/12

2020 ITP TIMELINE

SCE Window End

32020 ITP

DPP WINDOW (COMPLETE)

• Start: 3/25/2020 12:00 a.m.

• End: 4/23/2020 11:59 p.m.

• Member Review Time:

• Transmission-planning response window (30 calendar days)

• Staff Leader: Tammy Bright ([email protected])

3

mailto:[email protected]

42020 ITP

SOLUTIONS DEVELOPMENT & TECHNICAL VALIDATION

• Start: 3/25/2020

• End: 6/01/2020*

• Staff Leader: Kelsey Allen ([email protected])

* Date at risk; behind schedule

4


52020 ITP

SOLUTIONS EVALUATION

• Start: 4/13/2020

• End: 6/01/2020*

• Staff Leaders:

• Reliability: Neeya Toleman ([email protected])

• Economic/Policy: Adam Bell ([email protected])

• Short Circuit: Nathan Bean ([email protected])

• Operational: Will Tootle ([email protected])

* Date at risk; behind schedule

5





62020 ITP

RELIABILITY PORTFOLIO DEVELOPMENT

• Orig. Rebaselined Start: 5/08/2020

• Actual Start: 5/22/2020 (2 wks. late)

• End: 7/28/2020

• Member Review Time:*

• Phase 1: Hand-off due to Study Cost Estimates (SCE): 6/8/2020

• SCEs and Draft Project List posting: 6/12/2020

• Stakeholder Review: 6/15-7/07 (16 days; not including July 4 holiday on July 3)

• Staff Leaders: Chris Davis ([email protected])

* Dates at risk

6


72020 ITP

ECONOMIC PORTFOLIO DEVELOPMENT (INCLUDES PROJECT GROUPING)

• Orig. Rebaselined Start: 5/08/2020

• Actual Start: 5/22/2020 (2 wks late)

• End: 7/28/2020


• Phase 1: Hand-off due to Study Cost Estimates (SCE): 6/8/2020

• SCEs and Draft Project List posting: 6/12/2020

• Stakeholder Review: 6/15-7/07 (16 days; not including July 4 holiday on July 3)

• Staff Leader: Kelsey Allen ([email protected])

* Dates at risk

7


82020 ITP

STUDY COST ESTIMATES

• Start: 6/15/2020

• End: 7/07/2020


• SCE requests sent out: 6/12/2020

• SCE Response Window: 6/15-7/07 (16 days; not including

July 4 holiday on July 3)

• Staff Leader: John O’Dell ([email protected])

* Dates at risk

8


92020 ITP

PLANNING SUMMIT

• Start: 7/08/2020

• End: 7/08/2020


• Summit Materials to be provided prior to meeting


9


102020 ITP

OPTIMIZATION

• Start: 7/29/2020

• End: 8/04/2020

• Staff Leaders:

• Liz Gephardt ([email protected])

10


112020 ITP

PORTFOLIO CONSOLIDATION

• Start: 8/05/2020

• End: 8/18/2020

• Staff Leaders:

• Joshua Pilgrim ([email protected])

11


122020 ITP

PROJECT STAGING

• Start: 8/19/2020

• End: 9/01/2020

• Staff Leader: Liz Gephardt ([email protected])

12


132020 ITP

BENEFIT METRICS CALCULATION

• Start: 8/19/2020

• End: 9/18/2020

• Staff Leader: Antonio Barber ([email protected])

13


142020 ITP

STABILITY ANALYSIS

• Start: 8/19/2020

• End: 9/18/2020

• Staff Leader: Joshua Pilgrim ([email protected])

14


152020 ITP

SENSITIVITY ANALYSIS

• Start: 8/19/2020

• End: 9/18/2020

• Staff Leader: James Bailey ([email protected])

15


162020 ITP

FINAL RELIABILITY ASSESSMENT

• Start: 8/19/2020

• End: 9/18/2020

• Staff Leader: Neeya Toleman ([email protected])

16


172020 ITP

RATE IMPACTS/ATRR

• Start: 9/02/2020

• End: 9/18/2020

• Staff Leader: Antonio Barber ([email protected])

17


182020 ITP

FINAL REPORT

• Start: 8/1/2020

• End: 9/28/2020

• Final ESWG/TWG Approval in Sept. 2020


18


192020 ITP

TWG/ESWG FINAL APPROVALS

• Start: 9/21/2020

• End: 10/2/2020

• Staff Leaders:

• TWG – Adam Bell ([email protected])

• ESWG – Joshua Norton ([email protected])

19



202020 ITP

MOPC AND SPP BOARD

• MOPC: 10/13-14/2020

• SPP Board: 10/27/2020


• MOPC: 10/2/2020 – 10/12/2020 (6 days)

• SPP Board: 10/20/2020 – 10/27/2020 (5 days)

20



MULTI - KUMMER RIDGE -ROUNDUP 345 KV NEW LINE AND PATENT GATE AND ROUNDUP 345/115 KV SUBSTATIONSBOYD TRESTER

6/3/2020

2

MULTI - KUMMER RIDGE - ROUNDUP 345 KV NEW LINE AND PATENT GATE AND ROUNDUP 345/115 KV SUBSTATIONS

3

PROJECT COST HISTORY

$0

$10,000,000

$20,000,000

$30,000,000

$40,000,000

$50,000,000

$60,000,000

$70,000,000

$80,000,000

$90,000,000

Q22016

Q32016

Q42016

Q12017

Q22017

Q32017

Q42017

Q12018

Q22018

Q32018

Q42018

Q12019

Q22019

Q32019

Q42019

Q12020

Q22020

Current Cost Baseline "-20" "+20"

4

PROJECT OVERVIEWUpgrade ID Owner Upgrade Scope

51543 &

51504BEPC

Tap the 345 kV line from Charlie Creek to Jusdon to construct the new Patent Gate

substation. Install any necessary 345 kV terminal upgrades needed for new

345/115 kV transformer at the new Patent Gate substation. Install new 345/115 kV

transformer at Patent Gate.

51544 &

51503BEPC

Tap the 345 kV line from Antelope Valley Station to Charlie Creek to construct the

new Roundup substation. Install any necessary 345 kV terminal upgrades needed

for new 345/115 kV transformer at the new Roundup substation. Install new

345/115 kV transformer at Roundup

Upgrade ID Owner

Baseline Cost

Estimate

(Adj. for Inflation)

Latest Variance Var. %

51503 & 51544 BEPC $33,762,000 $19,695,315 ($14,066,685) -41.7%

51504 & 51543 BEPC $36,122,000 $29,518,031 ($6,603,969) -18.3%

Total $69,884,000 $49,213,346 ($20,670,654) -29.6%

NTC-C Issuance

5/17/2016

NTC Issuance

12/28/2016

In-Service Date

9/1/2016

Future Projection (Confidence Level)Low

<50% chance

Medium

50-80% chance

High

>80% chance

Estimate the probability that final cost will be within +/-

20% of updated cost estimateX

5

ROUNDUP 345 KV SUBSTATION & TRANSFORMER

51503 & 51544 Major Factors Contributing to Variance Variance

Engineering

Labor

Internal resources were used to minimize project

costs from hired consultants. ($1,483,641)

Construction

Labor

Originally Basin had planned for two transformers at

Roundup. After further investigation, only one

transformer was required. Market conditions were

favorable when procuring labor, steel, and other

equipment.

($11,547,973)

Site Property

Rights

Estimate included cost for potential condemnation

due to the property right issues in the area. Basin

was able to procure the land at a much lower cost

than originally estimated. The size of the substation

was also reduced due to one transformer versus two.

($1,008,614)

Material

At the time this project was constructed, Basin’s

accounting practice consolidated costs for

Construction Labor and Materials. Both of those items

are reflected in that category.

See

Construction

Labor

AFUDC $573,543

Contingency ($600,000)

Total ($14,066,685)

6

PATENT GATE 345 KV SUBSTATION & TRANSFORMER

51504 & 51543 Major Factors Contributing to Variance Variance

Engineering

Labor

Internal resources were used to minimize project costs

from hired consultants. ($1,815,545)

Construction

Labor

Market conditions were favorable when procuring

steel, labor, and other equipment.($4,135,817)

Site Property

Rights

Estimate included cost for potential condemnation due

to the property right issues in the area. Basin was able

to procure the land at a much lower cost than

originally estimated

($1,704,408)

Material

At the time this project was constructed, Basin’s

accounting practice consolidated costs for

Construction Labor and Materials. Both of those items

are reflected in that category.

See

Construction

Labor

AFUDC $1,111,800

Contingency ($60,000)

Total ($6,603,970)

7

APPLICATION OF BP 7060The PCWG will provide recommendations to the MOPC and BOD regarding any Applicable Project whose cost estimate exceeded the +/-20% bandwidth of the established baseline cost estimate. Recommended action(s) may include any of the following:

• Accept the cost estimate deviation as reasonable and acceptable and reestablish the baseline used to evaluate future cost estimate deviations.

• Identify all or a portion of the costs related to the variances and recommend any changes to the NTC that would reduce the cost or avoid the issues that may be causing the increase.

• Issue an NTC Suspension on the project while SPP restudies the project to determine appropriate changes to the NTC, possible withdrawal of the NTC or whether an alternative project should replace the project.

PCWG QUARTERLY

REPORT

JUNE 3, 2020

Southwest Power Pool, Inc.

REVISION HISTORY

DATE OR VERSION

NUMBER

AUTHOR CHANGE

DESCRIPTION

COMMENTS

5/27/2020 SPP Staff Initial Draft

6/3/2020 PCWG Approved by PCWG


CONTENTS

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

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

BACKGROUND ................................................................................................................................................................. 2

REVIEW PROCESS ............................................................................................................................................................ 3

BUSINESS PRACTICE 7060 ........................................................................................................................................... 3

PROCESS CHANGES ....................................................................................................................................................... 3

PROJECT OUTSIDE OF PRECISION BANDWIDTH (+/-20%) ............................................................................ 4

OBSERVED TRENDS ........................................................................................................................................................ 5

MINIMUM DESIGN STANDARDS TASK FORCE .................................................................................................... 6

RECOMMENDATIONS ................................................................................................................................................... 7

APPENDIX 1 ....................................................................................................................................................................... 8

APPENDIX 2 ....................................................................................................................................................................... 9

APPENDIX 3 .................................................................................................................................................................... 10

APPENDIX 4 .................................................................................................................................................................... 12


3Q 2020 PCWG Quarterly Report 1

EXECUTIVE SUMMARY There are thirty-four (34) Applicable Projects included in this report. Of the thirty-four (34)

Applicable Projects, eight (8) Applicable Projects1 are 300 kV and above and twenty-six (26)

additional Applicable Projects are greater than 100 kV but less than 300 kV. These Projects are

subject to review by the Project Cost Working Group (PCWG). Of the Applicable Projects in

Appendix 1, none (0) reported updated cost estimates that were outside the established

precision bandwidth during this quarter. Multi - Kummer Ridge - Roundup 345 kV New Line and

Patent Gate and Roundup 345/115 kV Substations was reported outside the established

precision bandwidth during the previous quarter but is reviewed in this report based on a

request by the TO to have additional time for analysis.

All active Projects subject to PCWG review are included in Appendix 1 of this report. Appendix 2

summarizes all reported Projects based on source study. Appendix 3 summarizes all Projects

currently within +/- 20% variance precision bandwidth but outside of +/- 10% variance from

their Baseline Estimate.

Table 1 below summarizes the cost estimates of active Applicable Projects in Appendix 1 with

established baseline estimates2.

Type No. of

Projects

Total Baseline Cost

Estimate Amount Total Cost

Estimate Variance Var. %

(adj. for inflation)

> 300 8 $979,407,898 $956,793,088 ($22,614,810) -2.3%

100 - 300 26 $937,001,633 $866,313,357 ($70,688,277) -7.5%

Total 34 $1,916,409,531 $1,823,106,445 ($93,303,086) -4.9%

Table 1: Applicable Project Cost Estimate Summary

1 Applicable Projects are defined in Business Practice 7060 as those that are approved for construction and classified

as a Base Plan Upgrade in accordance with the Tariff, have a nominal operating voltage greater than 100 kV and

estimated cost greater than $20 million. . 2 All baseline cost estimate values in this report are adjusted for inflation when applicable. For projects that have not

had updates to the baseline cost estimate, variance percentages may indicate a negative variance.



BACKGROUND

The PCWG was established to create a group with stakeholder input, oversight, and

accountability that can provide a transparent review of transmission cost variances. To ensure

cost estimate variances are addressed in a timely manner, the PCWG will evaluate projects

exceeding allowable variance levels on a monthly basis.

As a part of the project estimate review, the PCWG will provide recommendations to the

Markets and Operations Policy Committee (MOPC) and Regional State Committee (RSC) for

review and to the Board of Directors (Board) for approval. On a quarterly basis, the PCWG will

provide a report of their findings and comments to Stakeholders.

This report serves as the PCWG’s recommendation to the MOPC, RSC, and Board and the report

to Stakeholders.

The PCWG members are listed below:

Tom Hestermann, Sunflower, TO, Chair

Brian Johnson, AEP, TO, Vice-Chair

Jerry Bradshaw, CUS, TU

Scott Brunnert, OG&E, TO

James Ging, KPP, TU

Jamie Hajek NWE, TU

Travis Hill, NPPD, TO

Teddy Hutchinson, OPPD, TO

Brenda Jessop, Evergy Companies, TO

Jonah Martin, Tri-State G&T, TU

Todd Meyers, WAPA, TO

Curtis Miller, WFEC, TO

Matthew Mohr, EREC, TU

Kenny Munsell, SPS, TO

Boyd Trester, Basin Electric, TO

John O’Dell, SPP Staff Secretary



REVIEW PROCESS

Cost updates were requested from Designated Transmission Owners (DTOs) according to the

current Quarterly Project Tracking Schedule shown in Appendix 4. This information was

compiled by SPP staff and a report was prepared for review by the PCWG at its regular meeting.

BUSINESS PRACTICE 7060

The PCWG reviews projects in accordance with Business Practice No. 7060, which establishes

applicable precision bandwidths for construction projects.

This report covers all Applicable Projects as defined in Business Practice No. 7060 and subject to

update during the current quarterly project tracking update. The list of active Applicable

Projects is included in Appendix 1 to this report.

There are thirty-four (34) Applicable Projects included in this report. Of the thirty-four (34)

Applicable Projects, eight (8) Applicable Projects3 are 300 kV and above and twenty-six (26)

additional Applicable Projects are greater than 100 kV but less than 300 kV. These Projects are

subject to review by the Project Cost Working Group (PCWG). Of the Applicable Projects in

Appendix 1, none (0) reported updated cost estimates that were outside the established

precision bandwidth during this quarter. In addition, this report includes review of one project

from Q2 2020 (Multi - Kummer Ridge - Roundup 345 kV New Line and Patent Gate and

Roundup) in which the TO previously requested additional time for analysis.

PROCESS CHANGES

During its October 2013 meeting, the MOPC approved a recommendation from the PCWG to

move all projects applicable to Business Practice No. 7050 to Business Practice No. 7060.

Previously, Business Practice 7050 applied to all Projects issued NTCs prior to January 1, 2012

(Legacy Projects). The recommendation stipulated that baseline cost estimates for all Legacy

Projects would be established as the values listed in project tracking as of January 31, 2014, in

coordination with the Quarterly Project Tracking Schedule for quarter 2 of 2014. The

recommendation directed DTOs to complete and submit cost estimates using Standardized Cost

Estimate Reporting Templates for Legacy Projects only if project cost estimates increase 10% or

greater over the baseline amount provided as of January 31, 2014.

3 Applicable Projects are defined in Business Practice 7060 as those that are approved for construction and classified

as a Base Plan Upgrade in accordance with the Tariff, have a nominal operating voltage greater than 100 kV and

estimated cost greater than $20 million. .



The modifications to Business Practice 7060 that were required to implement the

recommendation were approved by the MOPC in January 2014. The changes resulted in the

retirement of Business Practice 7050.

There were fifteen (15) Applicable Projects that were moved from the purview of Business

Practice 7050 to Business Practice 7060. All Legacy Projects formerly in Appendix 1 have been

closed out and are no longer reported.

PROJECT OUTSIDE OF PRECISION BANDWIDTH (+/-20%)

Of the Applicable Projects listed in Appendix 1, one (1) had updated cost estimates that were

outside the established precision bandwidth during a previous quarter. Multi - Kummer Ridge -

Roundup 345 kV New Line and Patent Gate and Roundup 345/115 kV Substations was reported

outside the established precision bandwidth during the reporting period for 2Q 2020 but is

reviewed in this 3Q 2020 report based on the TO’s request for additional time for analysis.

MULTI - KUMMER RIDGE - ROUNDUP 345 KV NEW LINE AND PATENT GATE AND

ROUNDUP 345/115 KV SUBSTATIONS

On April 26, 2016, the SPP Board of Directors approved the Multi - Kummer Ridge - Roundup

115 kV New Line and Patent Gate and Roundup 345/115 kV Substations project to be

constructed as part of the 2016 Integrated Transmission Planning Near-Term Assessment. On

May 17, 2016, SPP issued BEPC the Notification to Construct with Conditions ("NTC-C") No.

200387. On August 17, 2016, SPP also issued BEPC the Notification to Construct with Conditions

(“NTC-C”) No. 200409 for Network Upgrade 51501 (Kummer Ridge - Roundup 345 kV Ckt 1 New

Line). On February 7, 2018, SPP withdrew Notification to Construct for Network Upgrade 51501.

On December 9, 2016, SPP received BEPC’s NTC-C Project Estimates ("CPE") for the Network

Upgrades specified in the NTC-C Nos. 200387 and 200409. SPP has reviewed the CPEs and

determined that the requirements of Condition No. 1 of the NTC-Cs have been met.

Basin provided updated costs of $49,213,346 in a variance report submitted on March 9, 2020.

Compared to an escalated baseline cost of $69,884,000, variance is ($20,670,654) or -29.6%.

This project was put in service on September 1, 2016.

PROJECTS CURRENTLY +/- 10% OF BASELINE ESTIMATE

Projects listed in Appendix 3 are within Business Practice 7060’s bandwidth of +/-20% but are

outside the +/-10% threshold developed by the PCWG to raise attentiveness to the cost

estimates related to these projects. There are eleven (11) projects in the list this quarter.



OBSERVED TRENDS

The PCWG also maintains the Study Estimate Design Guide (SEDG). The PCWG will notify the

MOPC if a trend is developing in cost estimates deviating from the SEDG. The MOPC is

responsible for determining if a review of the SEDG is required. However, this does not preclude

the PCWG from suggesting to the MOPC any other changes to the SEDG.

The PCWG has not observed any adverse trends in the current quarter to report to the MOPC.



MINIMUM DESIGN STANDARDS TASK

FORCE

At its April 8, 2014, meeting, the PCWG discussed the role of the SEDG in the Transmission

Owner Selection Process (TOSP) and further discussed how design standards would be applied

for transmission construction across the diverse group of potential builders in the SPP footprint.

The group approved a recommendation to be made to the Strategic Planning Committee Task

Force for Order 1000 (SPCTF) to consider implementing minimum design standards for

transmission construction within SPP. The recommendation further stated the SEDG should be

considered as a starting point for the minimum design standards.

On May 9, 2014, the SPCTF unanimously endorsed a motion recommending the implementation

of minimum design standards for SPP transmission construction. The SPCTF asked the PCWG in

coordination with the Transmission Working Group (TWG) to further enhance the SEDG to be

used as the minimum design standards guidebook. The SPCTF requested the work be

completed by the October 2014 quarterly meetings of the MOPC, RSC, and Board.

The PCWG formed a task force to complete the work of developing the minimum design

standards guidebook at its May 13, 2014 meeting.

The MDSTF completed the first version of the Minimum Transmission Design Standards for

Competitive Upgrades (MDS) in November 2014 and the PCWG approved an edited version at

its December 2014 meeting. The MOPC approved the MDS unanimously at its January 2015

meeting.

The MDSTF presented the final draft of version 2 of the MDS to the PCWG on October 5, 2016,

and it was approved by a unanimous vote. The final draft of version 2 of the MDS was approved

by the MOPC at the January 2017 meeting.

The PCWG will maintain the MDS going forward.



RECOMMENDATIONS

As described in Business Practice No. 7060, Section 11, the PCWG will provide recommendations

to the MOPC and Board regarding any Applicable Project whose cost estimate exceeds the +/-

20% bandwidth of the established baseline cost estimate. Recommended action(s) may include

any of the following:

i. Accept the cost estimate deviation as reasonable and acceptable and reset the baseline

used to evaluate future cost estimate deviations.

ii. Identify all or a portion of the costs related to the variances and recommend any

changes to the NTC that would reduce the cost or avoid the issues that may be causing

the increase.

iii. Suspend all future expenditures on the project while SPP restudies the project to

determine appropriate changes to the NTC, possible withdrawal of the NTC, or whether

an alternative project should replace the project.

The Board will make the final determination on whether to accept the PCWG recommendation(s)

or to choose an alternative action.

MULTI - KUMMER RIDGE - ROUNDUP 345 KV NEW LINE AND PATENT GATE AND

ROUNDUP 345/115 KV SUBSTATIONS

PCWG recommends that the MOPC and Board accept the cost estimate deviation for Multi -

Kummer Ridge - Roundup 345 kV New Line and Patent Gate and Roundup 345/115 kV

Substations as reasonable and acceptable and reset the baseline used to evaluate future cost

estimate deviations.



APPENDIX 1

See accompanying list of active Applicable Projects



APPENDIX 2

Active Projects Summary by Source Study

Source

Study

No. Of

Projects

Total Escalated

Baseline Total Latest Cost Variance $ Variance %

2012 ITP10 1 $372,506,326 $408,565,094 $36,058,768 9.7%

2012 ITPNT 1 $38,743,378 $38,607,163 ($136,215) -0.4%

2013 ITPNT 5 $171,926,396 $156,525,149 ($15,401,247) -9.0%

2014 ITPNT 4 $185,809,247 $178,909,883 ($6,899,364) -3.7%

2015 ITP10 1 $31,565,746 $31,404,202 ($161,544) -0.5%

2015 ITPNT 3 $116,035,302 $108,889,065 ($7,146,237) -6.2%

2016 ITPNT 3 $121,971,052 $94,888,807 ($27,082,245) -22.2%

2016

ITPNT/HPILS 1 $147,245,979 $131,289,455 ($15,956,524) -10.8%

2017 ITPNT 1 $14,365,735 $14,365,735 $0 0.0%

2018 ITPNT 1 $22,305,819 $21,231,000 ($1,074,819) -4.8%

AG STUDIES 1 $19,732,223 $19,732,223 $0 0.0%

DPA STUDIES 6 $354,093,579 $341,150,007 ($12,943,572) -3.7%

HPILS 5 $278,163,859 $239,548,663 ($38,615,196) -13.9%

IS Integration 1 $41,944,890 $38,000,000 ($3,944,890) -9.4%

Grand Total 34 $1,916,409,531 $1,823,106,445 ($93,303,086) -4.9%



APPENDIX 3

Projects Currently within +/- 20% but outside of +/- 10% Baseline Estimate

PID Project Name Project

Owner

Voltage

Class

(kV)

Status In-Service

Date

Escalated

Baseline

Estimate

Variance

Latest to Esc.

Baseline

Variance

Pct. To

Esc.

Baseline

Latest Cost

772 Line - Carlisle - Wolfforth

230 kV SPS 100 - 300 COMPLETE 3/27/2018 $36,690,708 ($7,290,708) -19.9% $29,400,000

30376 Multi - Hobbs - Yoakum

345/230 kV Ckt 1 SPS > 300 COMPLETE 5/30/2019 $120,424,791 ($23,880,838) -19.8% $96,543,953

30469

Multi - Kilgore Switch -

South Portales - Market

St. - Portales 115 kV

SPS 100 - 300 COMPLETE 7/13/2018 $30,581,497 ($5,937,193) -19.4% $24,644,304

30496

Multi - Bobcat Canyon

345/115 kV and Bobcat

Canyon - Scottsbluff 115

kV

BEPC/

NPPD 100 - 300 COMPLETE 10/26/2017 $40,185,006 ($7,880,844) -19.6% $32,304,163

30639

Multi - Potash Junction -

Road Runner 345 kV

Conv. and Transformers

at Kiowa and Road

Runner

SPS > 300 COMPLETE 4/30/2018 $25,585,269 ($4,911,393) -19.2% $20,673,876

30695

Multi - Livingston Ridge -

Sage Brush - Cardinal 115

kV

SPS 100 - 300 COMPLETE 11/30/2017 $33,671,134 ($5,230,971) -15.5% $28,440,162



PID Project Name Project

Owner

Voltage

Class

(kV)

Status In-Service

Date

Escalated

Baseline

Estimate

Variance

Latest to Esc.

Baseline

Variance

Pct. To

Esc.

Baseline

Latest Cost

30912 Multi - Walkemeyer Tap

- Walkemeyer 345/115 kV

SEPC/

SPS 100 - 300 COMPLETE 6/30/2018 $37,626,062 ($3,849,402) -10.2% $33,776,660

30914 Multi - Road Runner 115

kV Loop Rebuild SPS 100 - 300 COMPLETE 3/22/2019 $22,194,902 ($4,354,355) -19.6% $17,840,547

31021

Line - Mustang -

Seminole 115 kV Ckt 1

New Line

SPS 100 - 300 DELAYED 12/15/2020 $21,784,880 ($4,178,728) -19.2% $17,606,152

31042

Multi - DeGrasse - Knob

Hill 138 kV New Line and

DeGrasse 345/138 kV

Transformer

OGE/

WFEC 100 - 300 DELAYED 12/1/2024 $30,302,172 $5,109,151 16.9% $35,411,323

31068 Multi - Tuco - Yoakum

345/230 kV Ckt 1 SPS > 300 DELAYED 6/1/2020 $147,245,979 ($15,956,524) -10.8% $131,289,455



APPENDIX 4

Quarterly Project Tracking Schedule 2019-2020

2020 3rd Reporting Quarter May '20

TOs Submit Updates S M T W T F S

SPP staff notifies TOs & PCWG of cost

estimates outside of bandwidth of +/- 20% 1 2

TOs provide cost increase justifications 3 4 5 6 7 8 9

SPP staff prepares cost increase data for

PCWG background Materials 10 11 12 13 14 15 16

PCWG Face to Face 17 18 19 20 21 22 23

SPP Staff prepares and submits Quarterly

Project Tracking Report for MOPC 24 25 26 27 28 29 30

MOPC 31

RSC & Board

Holiday June '20

S M T W T F S 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30

July '20

S M T W T F S 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31



2020 4th Reporting Quarter August '20

TOs Submit Updates S M T W T F S

SPP staff notifies TOs & PCWG of cost

estimates outside of bandwidth of +/- 20% 1

TOs provide cost increase justifications 2 3 4 5 6 7 8

SPP staff prepares cost increase data for

PCWG background Materials 9 10 11 12 13 14 15

PCWG Face to Face 16 17 18 19 20 21 22

SPP Staff prepares and submits Quarterly

Project Tracking Report for MOPC 23 24 25 26 27 28 29

MOPC 30 31

RSC & Board

Holiday September '20

S M T W T F S 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30

October '20

S M T W T F S 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31

PID Project NameProject Owner

Source StudyVoltage Class

(kV)Status

In-Service

Complete In-Service Date Study EstimateBaseline Estimate

Variance Latest to Baseline

Variance Pct. to

Baseline

Baseline Estimate Year

Escalated Baseline Estimate

Variance Latest to Esc. Baseline

Variance Pct. To Esc. Baseline

Latest Cost Comment

461 Line - Curry - Bailey 115kV SPS 2012 ITPNT 100 - 300 COMPLETE Y Y 9/29/2016 9,132,270 $35,099,588 $3,507,575 10.0% 2012 $38,743,378 ($136,215) -0.4% $38,607,163772 Line - Carlisle - Wolfforth 230 kV SPS 2013 ITPNT 100 - 300 COMPLETE Y N 3/27/2018 32,790,576 $32,429,240 ($3,029,240) -9.3% 2013 $36,690,708 ($7,290,708) -19.9% $29,400,000805 Multi - Bowers - Howard 115 kV Ckt 1 SPS DPA STUDIES 100 - 300 COMPLETE Y Y 2/28/2016 25,557,920 $33,951,078 $4,971,900 14.6% 2013 $36,480,174 $2,442,804 6.7% $38,922,978

30374 Multi - Hoskins - Neligh 345 kV NPPD 2014 ITPNT > 300 COMPLETE Y Y 6/8/2018 98,697,720 $81,544,517 $694,880 0.9% 2017 $81,796,575 $442,822 0.5% $82,239,39730375 Multi - Gentleman - Cherry Co. - Holt Co. 345 kV NPPD 2012 ITP10 > 300 DELAYED N N 5/1/2021 287,900,000 $313,376,623 $95,188,471 30.4% 2013 $372,506,326 $36,058,768 9.7% $408,565,09430376 Multi - Hobbs - Yoakum 345/230 kV Ckt 1 SPS HPILS > 300 COMPLETE Y Y 5/30/2019 69,907,711 $106,833,199 ($10,289,246) -9.6% 2014 $120,424,791 ($23,880,838) -19.8% $96,543,953

30449Line - Rock Hill - Springridge Pan-Harr REC 138 kV Ckt 1

AEP 2013 ITPNT 100 - 300 COMPLETE Y Y 9/19/2016 25,060,655 $25,060,655 $270,274 1.1% 2013 $26,987,585 ($1,656,656) -6.1% $25,330,929

30451 Line - Atoka - Eagle Creek 115 kV Ckt 1 SPS 2013 ITPNT 100 - 300 COMPLETE Y Y 12/31/2018 19,639,618 $20,808,304 $2,217,692 10.7% 2013 $23,542,686 ($516,690) -2.2% $23,025,996

30469Multi - Kilgore Switch - South Portales - Market St. - Portales 115 kV

SPS 2013 ITPNT 100 - 300 COMPLETE Y Y 7/13/2018 24,951,218 $27,029,587 ($2,385,283) -8.8% 2013 $30,581,497 ($5,937,193) -19.4% $24,644,304

30484Multi - Viola 345/138kV Transformer and 138 kV Lines to Clearwater and Gill

WR 2013 ITPNT 100 - 300 COMPLETE Y Y 11/16/2018 78,162,713 $54,123,920 $0 0.0% 2019 $54,123,920 $0 0.0% $54,123,920

30496Multi - Bobcat Canyon 345/115 kV and Bobcat Canyon - Scottsbluff 115 kV

BEPC/NPPD 2014 ITPNT 100 - 300 COMPLETE Y Y 10/26/2017 35,000,000 $39,204,884 ($6,900,721) -17.6% 2016 $40,185,006 ($7,880,844) -19.6% $32,304,163

30560 Line - Sumner County - Viola 138 kV Ckt 1 WR 2014 ITPNT 100 - 300 DELAYED N N 6/1/2020 51,513,963 $34,432,188 $0 0.0% 2019 $35,292,993 ($860,805) -2.4% $34,432,18830596 Multi - Broken Bow Wind - Ord 115 kV Ckt 1 NPPD 2014 ITPNT 100 - 300 COMPLETE Y Y 6/1/2018 $32,573,600 $28,534,673 $1,399,462 4.9% 2018 $28,534,673 $1,399,462 4.9% $29,934,135

30638Multi - Kiowa - North Loving - China Draw 345/115 kV Ckt 1

SPS HPILS > 300 COMPLETE Y Y 6/1/2018 $62,619,690 $67,617,399 $4,781,343 7.1% 2014 $74,636,957 ($2,238,214) -3.0% $72,398,742

30639Multi - Potash Junction - Road Runner 345 kV Conv. and Transformers at Kiowa and Road Runner

SPS HPILS > 300 COMPLETE Y Y 4/30/2018 $21,560,659 $23,178,991 ($2,505,115) -10.8% 2014 $25,585,269 ($4,911,393) -19.2% $20,673,876

30666 Device - China Draw and Road Runner 115 kV SVC SPS 2015 ITPNT 100 - 300 COMPLETE Y Y 6/8/2016 $38,413,569 $54,843,257 $2,428,601 4.4% 2015 $56,214,338 $1,057,519 1.9% $57,271,858

30695 Multi - Livingston Ridge - Sage Brush - Cardinal 115 kV SPS HPILS 100 - 300 COMPLETE Y Y 11/30/2017 $26,257,165 $32,370,314 ($3,930,152) -12.1% 2016 $33,671,134 ($5,230,971) -15.5% $28,440,162

30717Line - Hopi Sub - North Loving - China Draw 115 kV Ckt 1

SPS HPILS 100 - 300 COMPLETE Y Y 5/25/2015 $22,240,813 $23,264,106 ($1,772,176) -7.6% 2014 $23,845,709 ($2,353,779) -9.9% $21,491,930

30850 Line - Iatan - Stranger 345 kV Ckt 1 Voltage Conversion GMO/WR 2015 ITP10 100 - 300 COMPLETE Y Y 6/1/2018 $15,726,289 $31,565,746 ($161,544) -0.5% 2019 $31,565,746 ($161,544) -0.5% $31,404,202

30912 Multi - Walkemeyer Tap - Walkemeyer 345/115 kV SEPC/SPS 2015 ITPNT 100 - 300 COMPLETE Y Y 6/30/2018 $20,965,055 $35,090,177 ($1,313,517) -3.7% 2017 $37,626,062 ($3,849,402) -10.2% $33,776,66030914 Multi - Road Runner 115 kV Loop Rebuild SPS 2015 ITPNT 100 - 300 COMPLETE Y Y 3/22/2019 $22,043,187 $21,866,137 ($4,025,590) -18.4% 2018 $22,194,902 ($4,354,355) -19.6% $17,840,54730946 Multi - Lower Brule - Witten 230 kV BEPC IS Integration 100 - 300 DELAYED N N 1/1/2018 $38,000,000 $38,000,000 $0 0.0% 2014 $41,944,890 ($3,944,890) -9.4% $38,000,00030988 Sub - Eddy Co. 230 kV Bus Tie SPS AG STUDIES 100 - 300 COMPLETE Y Y 12/20/2019 $9,485,379 $19,732,223 $0 0.0% 2020 $19,732,223 $0 0.0% $19,732,22331021 Line - Mustang - Seminole 115 kV Ckt 1 New Line SPS 2016 ITPNT 100 - 300 DELAYED N N 12/15/2020 $14,323,305 $19,736,026 ($2,129,874) -10.8% 2016 $21,784,880 ($4,178,728) -19.2% $17,606,152

31031Multi - Kummer Ridge - Roundup 345 kV New Line and Patent Gate and Roundup 345/115 kV Substations

BEPC 2016 ITPNT 100 - 300 COMPLETE Y Y 9/1/2016 $69,884,000 $69,884,000 ($28,012,668) -40.1% 2016 $69,884,000 ($28,012,668) -40.1% $41,871,332

31042Multi - DeGrasse - Knob Hill 138 kV New Line and DeGrasse 345/138 kV Transformer

OGE/WFEC 2016 ITPNT 100 - 300 DELAYED N N 12/1/2024 $30,500,000 $28,807,044 $6,604,279 22.9% 2017 $30,302,172 $5,109,151 16.9% $35,411,323

31068 Multi - Tuco - Yoakum 345/230 kV Ckt 1 SPS 2016 ITPNT/HPILS > 300 DELAYED N N 6/1/2020 $133,612,272 $133,520,696 ($2,231,241) -1.7% 2016 $147,245,979 ($15,956,524) -10.8% $131,289,45531139 Line - Crosstown - Blue Valley 161 kV New Line KCPL 2018 ITPNT 100 - 300 DELAYED N N 6/30/2023 $6,431,824 $21,231,000 $0 0.0% 2018 $22,305,819 ($1,074,819) -4.8% $21,231,000

41223 Line - New East Ruthville - SW Minot 115 kV New Line CPEC 2017 ITPNT 100 - 300 COMPLETE Y Y 12/19/2019 $21,780,000 $14,365,735 $0 0.0% 2020 $14,365,735 $0 0.0% $14,365,735

51254 Multi - Sheldon - Monolith 115 kV NPPD DPA STUDIES 100 - 300 DELAYED N N 1/1/2023 $39,300,207 $39,300,207 $0 0.0% 2018 $41,289,780 ($1,989,573) -4.8% $39,300,20751282 Multi - Park Community - Sunshine 138 kV WFEC DPA STUDIES 100 - 300 DELAYED N N 1/1/2024 $76,400,000 $82,700,000 $4,044,251 4.9% 2018 $86,437,188 $307,063 0.4% $86,744,25151327 Line - Cogar - OU SW 138 kV WFEC DPA STUDIES 100 - 300 DELAYED N N 3/1/2024 $31,100,000 $31,100,000 $0 0.0% 2018 $32,674,438 ($1,574,438) -4.8% $31,100,00061347 Multi - China Draw - Road Runner 345 kV SPS DPA STUDIES > 300 DELAYED N N 11/15/2021 $91,074,869 $89,647,302 ($5,319,480) -5.9% 2019 $91,888,485 ($7,560,663) -8.2% $84,327,82271347 Line - Eddy County - Kiowa 345 kV New Line SPS DPA STUDIES > 300 ON SCHEDULE N N 11/15/2020 $49,015,426 $63,730,259 ($2,975,510) -4.7% 2019 $65,323,515 ($4,568,766) -7.0% $60,754,749



AGING REPORT-PCWG ACTION ITEM 2096/3/2020

TAMMY BRIGHT

2

PCWG ACTION ITEM 209

Aging Report - Add review of projects with no

change in cost compared to baseline as

ongoing quarterly Face to Face agenda.

• Projects must be within 24 months of

projected in service date to be included

• Projects that have been re-baselined that are

not in service will be included in this list.

3

AGING REPORT

PID Project NameProject

OwnerStatus

In-Service

Date

Meeting

Date

Baseline

Estimate

Variance

Pct. to

Baseline

Baseline

Estimate

Year

Escalated

Baseline

Estimate

Variance

Pct. To

Esc.

Baseline

Latest Cost

30560Line - Sumner County - Viola 138 kV

Ckt 1WR DELAYED 6/1/20 6/3/2020 $34,432,188 0.0% 2019 $35,292,993 -2.4% $34,432,188

30946 Multi - Lower Brule - Witten 230 kV BEPC DELAYED 1/1/18 6/3/2020 $38,000,000 0.0% 2014 $41,944,890 -9.4% $38,000,000

30988 Sub - Eddy Co. 230 kV Bus Tie SPS COMPLETE 12/20/19 6/3/2020 $19,732,223 0.0% 2020 $19,732,223 0.0% $19,732,223

41223Line - New East Ruthville - SW

Minot 115 kV New LineCPEC COMPLETE 12/19/19 6/3/2020 $14,365,735 0.0% 2020 $14,365,735 0.0% $14,365,735

• PID 30560 Baseline Reset 4Q 2019



4

QUARTERLY PROJECT TRACKING RESPONSIVENESS REPORT 2Q 2020

Project Owner

Number of Upgrades

Number of Upgrades Reviewed

Reviewed %In-Service Date

ChangesISD Change % Cost Changes Cost Change %

AECC 1 0 0% 0 0% 0 0%

AEP 57 56 98% 6 11% 2 4%

BEPC 23 8 35% 0 0% 7 30%

CBPC 1 0 0% 0 0% 0 0%

CPEC 3 3 100% 3 100% 2 67%

CUS 2 2 100% 0 0% 0 0%

EDE 3 0 0% 0 0% 0 0%

EREC 3 3 100% 1 33% 1 33%

GHP 1 0 0% 0 0% 0 0%

GMO 2 1 50% 0 0% 0 0%

GRDA 3 1 33% 0 0% 1 33%

KCPL 9 8 89% 2 22% 2 22%

KPP 1 0 0% 0 0% 0 0%

MIDW 5 5 100% 0 0% 0 0%

NIPCO 2 0 0% 0 0% 0 0%

NPPD 38 0 0% 0 0% 2 5%

NWE 2 0 0% 0 0% 0 0%

OGE 29 8 28% 6 21% 2 7%

OPPD 13 13 100% 0 0% 0 0%

SEPC 8 7 88% 2 25% 1 13%

SPS 173 173 100% 57 33% 70 40%

TBD 10 0 0% 0 0% 0 0%

TSMO 2 2 100% 0 0% 0 0%

WAPA 10 0 0% 0 0% 0 0%

WFEC 35 0 0% 0 0% 0 0%

WR 28 25 89% 1 4% 5 18%

Total 464 315 67.89% 78 16.81% 95 20.47%

*Reporting period was 11/1/2019-1/31/2020

5


0

20

40

60

80

100

120

140

160

180

200

AEC

C

AEP

BEP

C

CB

PC

CP

EC

CU

S

EDE

EREC

GH

P

GM

O

GR

DA

KC

PL

KP

P

MID

W

NIP

CO

NP

PD

NW

E

OG

E

OP

PD

SEP

C

SPS

TBD

TSM

O

WA

PA

WFE

C

WR

In-Service Date Changes No In-Service Date Change

0

20

40

60

80

100

120

140

160

180

200

AEC

C

AEP

BEP

C

CB

PC

CP

EC

CU

S

EDE

EREC

GH

P

GM

O

GR

DA

KC

PL

KP

P

MID

W

NIP

CO

NP

PD

NW

E

OG

E

OP

PD

SEP

C

SPS

TBD

TSM

O

WA

PA

WFE

C

WR

Cost Changes No Cost Change

6

PCWG ACTION

Does PCWG wish to request additional

information from Designated Transmission

Owners on projects listed on slide 1?



POTENTIAL UPGRADE CLOSE-OUTS: PCWG ACTION ITEM 200JUNE 3, 2020

JOHN O’DELL

2


Create list of upgrades with potential to be

closed out per Section 13 of BP 7060. Identify

outstanding items required for close-out

process. Projects must be within 24 months of

projected in service date to be included.

• Action Item created December 2018

• Update provided March 2020

3

CLOSE OUT REQUIREMENTSBP 7060 SECTION 13

• Letter of Commercial Operation with company letterhead submitted to [email protected]

• All pertinent modeling information to the SPP Engineering Department through the Models On Demand (MOD) system;

• Actual cost amount to-date of Network Upgrade as reflected through one or both of the following methods:

o Base Plan Funded Network Upgrades – submitted through formula rate updates

o Non-Base Plan Funded Network Upgrades –submitted through the Project Tracking update process; and

• All pertinent Geographical Information Systems (GIS) data to the SPP Engineering Department through the appropriate file sharing system (only applicable to Network Upgrades that include greenfield transmission lines).

4

BP 7060 SECTION 13

If a DTO does not provide one or more of the requirements listed above for a Network Upgrade within two calendar years after the in-service date reported in Project Tracking, SPP staff will provide a report to the following organizational groups, in escalation based on the length of time the information is delinquent:

i. Level 1 – Report provided to PCWG after 2-year delinquency is identified;

ii. Level 2 – Report provided to MOPC and RSC at their next regularly scheduled meetings if delinquent

three months after Level 1 report; and

iii. Level 3 – Report provided to BOD at its next regularly scheduled meeting if delinquent three months after Level 2 report. Subsequently, reports provided to BOD each regularly scheduled meeting until delinquency is resolved.

5

UPGRADE CLOSE OUT LIST

• 130 upgrades shown in February 2019 list

• 85 from that list upgrades have been closed

out

• There are currently 179 upgrades with status

of In Service or Complete

• 105 have been in service more than 2 years

6

PCWG ACTION

Does PCWG wish to take action on any

upgrade(s) identified in the report?

NTCID

PID

UID

ProjectOwner

UpgradeNam

e

ProjectType

ProjectOwnerIndicatedIn‐

ServiceDate

RTODeterminedNeedDate

LatestNTCIssueDate

NTCSourceStudy

ProjectStatus

Project

Description/Com

ments

InFebruary2019PCW

Glist

LetterofCom

mercial

Operation

ModIformatio

Amountto‐dateCost

GISData

200214 1031 11355 SPS CrosbyCountyInterchange115/69kVTransformerC RegionalReliability 5/1/2015 6/1/2013 2/20/2013 2013ITPNT Complete UpgradeCrosbyCounty115/69kVtransformerCkt1to84MVA. Y Y Y Y200309 30717 50870 SPS HopiSub‐NorthLoving115kVCkt1 HighPriority 5/25/2015 6/1/2015 12/3/2014 HPILS Complete Constructnew9.5‐mile115kVlinefromHopiSubtoNorthLoving115kV Y Y Y Y200309 30717 50883 SPS ChinaDraw‐NorthLoving115kVCkt1 HighPriority 5/25/2015 6/1/2015 12/3/2014 HPILS Complete Constructnew19.7‐mile115kVlinefromNorthLovingtoChinaDraw Y Y Y200190 30410 50503 SPS Bowers‐Canadian69kVRebuild RegionalReliability 7/1/2015 6/1/2012 1/18/2013 DPA‐2011‐SEPTEMBER‐095 Complete Rebuild49‐mile69kVlinebetweenBowersandCanadianwith795ACSRconductor. Y Y Y Y

200256 30555 50693 SPS QuahadaSwitchingStation115kV RegionalReliability 7/9/2015 6/1/2015 2/19/2014 2014ITPNT Complete Install4‐breakerringbusatQuahadatoconnectthe115kVlinesfromCunninghamtoPCAInterchangeandLeaNationaltoMaljamar. Y Y Y Y

200214 30466 50560 SPS PotashJunction115/69kVTransformerCkt1 RegionalReliability 8/7/2015 6/1/2013 2/20/2013 2013ITPNT Complete UpgradePotashJunction115/69kVtransformerCkt1to84MVA. Y Y Y Y200166 30356 50406 SPS DiamondbackInterchange115/69kVTransformerCk RegionalReliability 8/31/2015 6/1/2012 4/9/2012 2012ITPNT Complete Installnew115/69kVtransformeratnewDiamondbackInterchangenearCedarLake Y Y Y Y200214 1031 11356 SPS CrosbyCountyInterchange115/69kVTransformerC RegionalReliability 9/10/2015 6/1/2013 2/20/2013 2013ITPNT Complete UpgradeCrosbyCounty115/69kVtransformerCkt2to84MVA. Y Y Y Y200166 30351 50401 SPS Crosby115kV#2 RegionalReliability 11/4/2015 6/1/2012 4/9/2012 2012ITPNT Complete Install14.4MvarcapacitoratCrosby115kV. Y Y Y Y200282 30756 50873 SPS BattleAxe‐RoadRunner115kVCkt1 HighPriority 11/12/2015 6/1/2018 5/19/2014 HPILS Complete Constructnew18.9‐mile115kVlinefromRoadRunnertoBattleAxe Y Y Y Y200214 30424 50517 SPS Ochiltree‐Tri‐CountyRECCole115kVCkt1Rebuild RegionalReliability 11/20/2015 6/1/2013 2/20/2013 2013ITPNT Complete Rebuild16.9‐mile115kVlinefromOchiltreetoTri‐CountyRECColeCkt1 Y Y Y Y20084 834 11101 SPS PORTALESINTERCHANGE‐ZODIAC115KVCKT1 RegionalReliability 11/30/2015 6/1/2013 2/8/2010 2009STEP Complete Convertexisting3milePortalesInterchange‐Zodiac69kVlinetooperateat115kV Y Y Y Y200256 1004 11318 SPS SwisherCountyInterchange230/115kVCkt1Transf RegionalReliability 12/3/2015 6/1/2014 2/19/2014 2014ITPNT Complete Upgradeexisting230/115kVtransformeratSwisherto250MVA. Y Y Y Y

200282 30756 50968 SPS BattleAxe115kVSubstation HighPriority 12/4/2015 6/1/2018 5/19/2014 HPILS Complete Constructnew115kVBattleAxesubstation.Installanynecessary115kVterminalequipment. Y Y Y

200214 841 11110 SPS GrahamInterchange115/69kVTransformerCkt1 RegionalReliability 12/9/2015 6/1/2014 2/20/2013 2013ITPNT Complete UpgradeGraham115/69kVtransformerCkt1to84MVA. Y Y Y Y

200166 836 11104 SPS ConvertMuleshoe69kVto115kV RegionalReliability 12/18/2015 6/1/2012 4/9/2012 2012ITPNT Complete TapBaileyCountyInterchange‐PlantX115kVlineandconvertMuleshoeEastsubstationto115kVoperation. Y Y Y Y

200214 1147 11512 SPS Channing‐PotterCounty230kVCkt1 RegionalReliability 12/31/2015 6/1/2013 2/20/2013 2013ITPNT Complete Convert26milesof115kVlinefromChanningtoPotterto230kVandupgradenecessaryterminalequipmentatPotter. Y Y Y Y

200214 1147 11514 SPS Channing‐XIT230kVCkt1 RegionalReliability 12/31/2015 6/1/2013 2/20/2013 2013ITPNT Complete Convert35milesof115kVlinefromChanningtonewXITsubstation(nearDallam)to230kV. Y Y Y Y

200214 1147 11515 SPS XIT230/115/13.2kVTransformerCkt1 RegionalReliability 12/31/2015 6/1/2013 2/20/2013 2013ITPNT Complete Install230/115kVtransformeratXITsubstation. Y Y Y Y200214 1003 11317 SPS GrasslandInterchange230/115kVTransformerCkt1 RegionalReliability 2/19/2016 6/1/2013 2/20/2013 2013ITPNT Complete UpgradeGrassland230/115kVtransformerCkt1to250MVA. Y Y Y Y200193 30422 50515 SPS DeafSmithCountyInterchange230/115kVTransform RegionalReliability 2/25/2016 6/1/2012 11/20/2012 SPP‐2010‐AGP1‐AFS‐8 Complete UpgradeDeafSmithCountyInterchange230/115kVCkt1transformerto250MVA. Y Y Y Y

200190 805 50453 SPS Bowers‐Howard115kV RegionalReliability 2/28/2016 6/1/2013 1/18/2013DPA‐2011‐SEPTEMBER‐095 Complete

Buildnew38‐mile115kVlinefromBowersInterchange‐Howard.AtBowers,install115kVbreakerpositionstoservethenewtransmissionline,convertingtoathree‐breakerringconfiguration.

Y Y Y Y

200282 30331 50378 SPS EagleCreek115kVCapBank HighPriority 3/14/2016 6/1/2015 5/19/2014 HPILS Complete Install14.4‐MvarcapacitorbankatEagleCreek115kVbus Y Y Y Y

200371 30666 51132 SPS RoadRunner115kVSVC RegionalReliability 4/1/2016 4/1/2015 2/12/2016 2015ITPNT Complete InstallnewSVCatRoadRunner115kVsubstationwitheffectiverangeof‐50/+200MVAR. Y Y Y Y

200370 30649 50881 SPS Andrews230/115kVCkt1Transformer HighPriority 4/4/2016 6/1/2015 2/12/2016 HPILS Complete Installtwo230/115kV167MVAtransformersatAndrewssubstationforacombinedemergencyratingof334MVA.Installanynecessaryterminalequipment. Y Y Y Y

200282 30649 50882 SPS Andrews‐NEF115kVCkt1 HighPriority 4/4/2016 6/1/2015 5/19/2014 HPILS Complete Constructnew2.1‐mile115kVlinefromAndrewstoNationalEnrichmentFacility(NEF). Y Y Y Y200216 478 10615 AEP ForbingTap‐SouthShreveport69kVCkt1 RegionalReliability 4/13/2016 6/1/2013 2/20/2013 2013ITPNT Complete Rebuild2.3‐mile69kVlinefromForbingtoSouthShreveportwith1233.6ACSR/TW Y Y Y Y

200246 512 10657 AEP EllerbeRoad‐ForbingT69kVCkt1 RegionalReliability 4/13/2016 6/1/2014 2/19/2014 2014ITPNT Complete Rebuild2.0‐mile69kVlinefromEllerbeRoadtoForbingTwith1233.6ACSR/TWconductor. Y Y Y Y

200369 30509 50636 SPS CanyonEastSub‐CanyonWestSub115kVCkt1Rebu RegionalReliability 5/18/2016 2/1/2014 2/12/2016 SPP‐2011‐AG3‐AFS‐11 Complete Rebuild3.73‐mile115kVlinefromCanyonEastSubtoCanyonWestSub. Y Y Y Y20104 947 11261 AEP BROKENARROWNORTH‐SOUTHTAP‐ONETA138K TransmissionService 5/25/2016 6/1/2015 8/25/2010 SPP‐2008‐AGP1‐AFS‐9 InService Rebuild4.33of795ACSRwith1590ACSR. Y Y Y Y200371 30666 50864 SPS ChinaDraw115kVSVC RegionalReliability 6/8/2016 4/1/2015 2/12/2016 2015ITPNT Complete InstallnewSVCatChinaDraw115kVsubstationwitheffectiverangeof‐50/+200MVAR. Y Y Y Y20130 764 11007 SPS HAPPYINTERCHANGE115/69KVTRANSFORMERCK RegionalReliability 6/30/2016 6/1/2012 2/14/2011 2010STEP Complete UpgradeHappyCounty115/69kVTransformer#1to84/96MVA Y Y Y Y20130 764 11009 SPS HAPPYINTERCHANGE115/69KVTRANSFORMERCK RegionalReliability 6/30/2016 6/1/2012 2/14/2011 2010STEP Complete UpgradeHappyCounty115/69kVTransformer#2to84/96MVA Y Y Y

200231 30449 50545 AEP RockHill‐SpringridgePan‐HarrREC138kVCkt1 RegionalReliability 9/19/2016 6/1/2014 9/23/2013 2013ITPNT Complete Rebuild27.6‐mile138kVlinefromRockHilltoSpringridgePan‐HarrRECwith1926.9ACSR/TWconductor. Y Y Y Y

200166 461 10597 SPS BaileyCountyInterchange‐CurryCountyInterchange RegionalReliability 9/29/2016 6/1/2012 4/9/2012 2012ITPNT Complete Build40milesof115kVtransmissionlinebetweenBaileyCountyandCurryCounty Y Y Y Y

200386 31003 51446 AEP NortheasternStation138kVTerminalUpgrades RegionalReliability 10/5/2016 6/1/2017 5/17/2016 2016ITPNT Complete InstallterminalupgradesatNortheasternstation138kVsubstationonterminalfor138kVlinetoOolagah. Y Y Y Y

200297 30820 51112 SPS CarlisleInterchange‐TucoInterchange230kVCkt1T TransmissionService 10/24/2016 10/1/2015 5/5/2015 SPP‐2012‐AG3‐AFS‐9 Complete ReplacethewavetrapatCarlislesubstation.ReplacethewavetrapontheCarlislelineterminalatTucosubstation. Y Y Y Y

200410 30552 50690 SPS OxyPermianSub‐WestBenderSub115kVCkt1Reb RegionalReliability 10/28/2016 6/1/2018 8/17/2016 2014ITPNT Complete Rebuild0.5‐mile115kVlinefromOxyPermianSubtoWestBenderSub Y Y Y Y200256 766 11010 SPS Newhart230/115kVCkt2Transformer RegionalReliability 12/2/2016 6/1/2015 2/19/2014 2014ITPNT Complete Addsecond230/115kV250MVAtransformeratNewhartsubstation. Y Y Y Y

20097 938 11238 TSMO Sibley‐MullinCreek345kV HighPriority 12/14/2016 6/1/2017 7/23/2010PriorityProjects Complete

Buildanew105mile345kVlinewithatleast3000AcapacityfromSibleytoanewMullinCreek(formerlyMaryville)substation.UpgradetheSibleysubstationwiththenecessarybreakersandterminalequipment.

Y Y

20097 938 11239 TSMO NebraskaCity‐MullinCreek345kV(GMO) HighPriority 12/15/2016 6/1/2017 7/23/2010

PriorityProjects Complete

Buildanew345kVsubstationatMullinCreek(formerlyMaryville)witharingbusandnecessaryterminalequipment.Buildanew65mile345kVlinewithatleast3000AcapacityfromthenewMullinCreeksubstationtotheMissouri/NebraskastatebordertowardsOPPD'sNebraskaCitysubstation.

Y Y

200256 856 50754 SPS Hereford115kVLoadConversion RegionalReliability 12/15/2016 6/1/2014 2/19/2014 2014ITPNT Complete ConvertdistributiontransformerhighsideatHerefordfrom69kVto115kV. Y Y Y Y

200309 30695 50951 SPS Cardinal115kVSubstation HighPriority 12/15/2016 6/1/2018 12/3/2014 HPILS Complete Constructnew115kVCardinalsubstation.Installanynecessary115kVterminalequipment. Y Y Y Y

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200436 30695 50967 SPS Cardinal‐SageBrush115kVCkt1 HighPriority 12/15/2016 6/1/2018 2/22/2017 HPILS Complete Constructnew19‐mile115kVlinefromtoCardinaltoSageBrush Y Y Y Y

200309 30695 50925 SPS SageBrush115kVSubstation HighPriority 12/16/2016 6/1/2018 12/3/2014 HPILS Complete Constructnew115kVSageBrushsubstationwith3ringbusconfiguration.Installanynecessary115kVterminalequipment. Y Y Y Y

200326 30875 51189 SPS PCAInterchange‐Quahada115kVCkt1Rebuild RegionalReliability 2/25/2017 6/1/2016 2/18/2015 2015ITPNT Complete Rebuild11.1‐mile115kVlinefromPCAInterchangetoQuahada N Y Y Y200200 30491 50600 WFEC Hazelton69kVCapacitor RegionalReliability 3/1/2017 1/1/2013 3/1/2013 DPA‐2012‐MAR‐143‐147 Complete Installtwo4.8MvarcapacitorsatHazelton69kVfortotalof9.6Mvar N Y Y

200234 30503 50628 WFEC HazeltonCapacitor69kV#2 RegionalReliability 3/1/2017 6/1/2017 10/28/2013DPA‐2012‐MAR‐151‐154‐161‐JUL‐

218‐SEP‐243 Complete Installnew69kV4.8‐MvarcapacitoratHazeltonsubstation. N Y Y

200395 31001 51438 SPS AgaveRedHills‐RoadRunner115kVCkt1NewLine RegionalReliability 3/20/2017 4/1/2020 5/17/2016 2016ITPNT Complete Constructnew115kVlinefromAgaveRedHillstoRoadRunner. N Y Y200395 31001 51439 SPS Ochoa‐RoadRunner115kVCkt1NewLine RegionalReliability 3/20/2017 4/1/2020 5/17/2016 2016ITPNT Complete Constructnew115kVlinefromOchoatoRoadRunner. N Y Y Y

200395 31001 51441 SPS RoadRunner115kVTerminalUpgrades RegionalReliability 3/28/2017 4/1/2020 5/17/2016 2016ITPNT Complete InstallanyterminalupgradesneededtoaccommodatenewlineterminalsforOchoa,AgaveRedHills,andCusterMountain. N Y Y Y

200395 31001 51442 SPS Ochoa115kVTerminalUpgrades RegionalReliability 3/28/2017 4/1/2020 5/17/2016 2016ITPNT Complete InstallanyterminalupgradesneededtoaccommodatenewlineterminalfromRoadRunner. N Y Y Y

200395 31001 51443 SPS AgaveRedHills115kVTerminalUpgrades RegionalReliability 3/28/2017 4/1/2020 5/17/2016 2016ITPNT Complete InstallanyterminalupgradesneededtoaccommodatenewlineterminalfromRoadRunner. N Y Y Y

200262 1144 11508 SPS Hitchland230/115kVCkt2Transformer RegionalReliability 3/29/2017 6/1/2019 4/9/2014 SPP‐2011‐AG3‐AFS‐11 Complete Addsecond230/115kV250MVAtransformeratHitchland. N Y Y Y200214 802 11064 SPS EddyCountyInterchange230/115kVTransformerCk RegionalReliability 3/31/2017 6/1/2016 2/20/2013 2013ITPNT Complete UpgradeEddyCounty230/115kVtransformerCkt1to250MVA. N Y Y Y200166 1033 11358 SPS RandallCountyInterchange‐SouthGeorgiaInterchan RegionalReliability 4/12/2017 6/1/2017 4/9/2012 2012ITPNT Complete Reconductor4.1milesof6.1‐mile115kVlinefromRandallCountytoSouthGeorgia N Y Y Y

200404 1001 11315 SPS RandallCountyInterchange‐SouthGeorgiaInterchan RegionalReliability 4/19/2017 6/1/2016 7/25/2016

SPP‐2015‐AG1‐AFS‐6 Complete

Constructapproximately2milesofnew115kVlinefromRandallCo.InterchangetowardsOsageSubstationconnectingtoSouthGeorgialine.Tienew115kVlineintoexistingcircuitV70nearOsageSubstation.Reconfigurethe115kVtransmissionlinesaroundOsageSubstation:removecircuitV04terminationfromOsageSubstationandremovecircuitbacktoManhattanTap(remove3‐terminalcondition);removecircuitsV67andV05terminationsfromOsageSubstationandtiethemtogetheraroundOsageSubstation;leaveonlycircuitsV43andT75terminatedattheOsageSubstation.Addnew115kVterminalatRandallCo.InterchangeandrebuildRandall115kVbustobreakerandone‐halfdesign.UpgradeterminalequipmentandresetrelaysatSouthGeorgiaInterchange.

N Y Y Y

200395 31001 51440 SPS CusterMountain‐RoadRunner115kVCkt1NewLin RegionalReliability 4/28/2017 4/1/2020 5/17/2016 2016ITPNT Complete Addnew1‐milesegmenttoexisting115kVlinefromCusterMountaintoOchoa,re‐terminatingatRoadRunner. N Y Y

30956 51339 NPPD Antelope115kV‐AddterminalforGEN‐2013‐032 GenerationInterconnection 5/1/2017

InServiceInstalltwo(2)115kVcircuitbreakersandassociatedswitches,structures,andassociatedequipment.Addone(1)115kVdead‐endtower,arresters,lineswitch,revenuemeterandotherlinerelayingequipmentnecessarytointerconnecttheInterconnectionCustomerInterconnectionFacilities;Replaceone(1)115kVcircuitbreakerduetoshortcircuitover‐duty.

N Y

200381 777 11027 SPS EastPlant115kVTerminalUpgrade RegionalReliability 6/1/2017 6/1/2017 4/12/2016 SPP‐2014‐AG1‐AFS‐6 Complete ReplaceCTatEastPlant115kVsubstationtoincreasetheratingofthe115kVlinefromEastPlanttoManhattan. N Y Y Y

200241 30438 50533 GRDA Kerr‐412Sub161kVCkt1TerminalUpgrades RegionalReliability 6/1/2017 6/1/2017 2/19/2014 2014ITPNT Complete Replace1200Ampswitchwitha2000AmpswitchatKerrsubstation161kVbus. N Y Y Y200245 30563 50702 WFEC SandyCorner138kVCapBank RegionalReliability 6/1/2017 6/1/2017 2/19/2014 2014ITPNT Complete Add20MvarofcapacitanceatSandyCorner138kV. N Y

200282 30694 50877 SPS Ponderosa115kVSubstation HighPriority 6/1/2017 6/1/2018 5/19/2014 HPILS Complete Constructnew115kVPonderosasubstation.Installanynecessary115kVterminalequipment. N Y Y

200474 30694 50879 SPS PonderosaTap115kVSubstation HighPriority 6/1/2017 6/1/2018 2/27/2018 HPILS Complete Taptheexisting115kVlinefromOchoatoWhittentoconstructnew115kVPonderosaTapsubstation.Installanynecessary115kVterminalequipment. N Y Y

200411 30694 50923 SPS Ponderosa‐PonderosaTap115kVCkt1 HighPriority 6/1/2017 6/1/2018 8/17/2016 HPILS Complete Constructnew9.3‐mile115kVlinefromnewPonderosasubstationtonewPonderosaTapsubstation. N Y Y

200246 30576 50721 AEP Hallsville‐Marshall69kVCkt1Rebuild RegionalReliability 6/2/2017 6/1/2014 2/19/2014 2014ITPNT Complete Rebuild11.2‐mile69kVlinefromHallsvilletoMarshallwith1233.6ACSR/TWconductor.Upgradejumpers,CTratios,andrelaysettingsatMarshall. N Y Y Y

200411 30825 50931 SPS ChinaDraw‐WoodDraw115kVCkt1 HighPriority 6/15/2017 6/1/2018 8/17/2016 HPILS Complete Constructnew14‐mile115kVlinefromChinaDrawtoWoodDraw N Y Y Y

200246 30573 50718 AEP Broadmoor‐FortHumbug69kVCkt1Rebuild RegionalReliability 6/21/2017 6/1/2019 2/19/2014 2014ITPNT Complete Rebuild1.7‐mile69kVlinefromFortHumbugtoBroadmoorwith1233.6ACSR/TWconductor.UpgradejumpersatFortHumbugalongwithjumpersandbusatBroadmoor. N Y Y Y

200400 30496 50609 NPPD BobcatCanyon‐Scottsbluff115kVCkt1 RegionalReliability 10/26/2017 6/1/2014 8/17/2016 2014ITPNT Complete Installnew22‐mile115kVlinefromBobcatCanyontoScottsbluffandinstallanynecessaryterminalequipment. N Y Y Y

200476 41200 61856 WAPA Williston115kVTerminalUpgrades RegionalReliability 11/20/2017 6/1/2018 2/21/2018 2017ITPNT Complete Install115kVterminalupgradesneededatWillistontoincreasetheratingoftheWilliston‐Judsonline. N Y Y

200395 31067 50924 SPS LivingstonRidge115kVSubstationConversion RegionalReliability 11/30/2017 6/1/2017 5/17/2016 2016ITPNT Complete ConvertLivingstonRidgefrom69kVto115kV.Installanynecessary115kVterminalequipment. N Y Y Y

200436 30695 50926 SPS LivingstonRidge‐SageBrush115kVCkt1 HighPriority 11/30/2017 6/1/2018 2/22/2017 HPILS Complete Constructnew27‐mile115kVlinefromLivingstonRidgetonewSageBrushsubstation. N Y Y Y200262 30420 50513 SPS BushlandInterchange‐DeafSmithCoInterchange23 RegionalReliability 12/15/2017 2/1/2014 4/9/2014 SPP‐2011‐AG3‐AFS‐11 Complete Upgrade800AmpwavetrapatbothBushlandInterchangeandDeafSmithInterchange. N Y Y Y200360 30914 50955 SPS PonderosaTap‐Whitten115kVCkt1Rebuild RegionalReliability 1/26/2018 6/1/2015 12/7/2015 2015ITPNT Complete Reconductor5.9‐mile115kVlinefromPonderosaTaptoWhitten N Y Y

200256 30577 50722 SPS Chaves‐Price115kVCkt1Rebuild RegionalReliability 1/30/2018 6/1/2017 2/19/2014 2014ITPNT Complete Rebuild5‐mile69kVlinefromChavestoPriceconvertingto115kV.InstallanynecessaryterminalequipmentatChaves. N Y Y Y

200256 30577 50723 SPS CVPines‐Price115kVCkt1Rebuild RegionalReliability 1/30/2018 6/1/2017 2/19/2014 2014ITPNT Complete Rebuild3‐mile69kVlinefromCVPinestoPriceconvertingto115kV. N Y200256 30577 50724 SPS Capitan‐CVPines115kVCkt1Rebuild RegionalReliability 1/30/2018 6/1/2017 2/19/2014 2014ITPNT Complete Rebuild5‐mile69kVlinefromCapitantoCVPinesconvertingto115kV. N Y Y

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200229 30469 50565 SPS MarketSt.‐Portales115kVCkt1 RegionalReliability 2/7/2018 6/1/2018 9/10/2013 2013ITPNT Complete Buildnew10.4‐mile115kVlinefromMarketSt.toPortalesandinstallnecessaryterminalequipment. N Y Y

200294 30596 50757 NPPD BrokenBowWind‐Ord115kVCkt1 RegionalReliability 3/1/2018 6/1/2014 8/26/2014 2014ITPNT Complete Buildanew35‐mile115kVlinefromOrdtoBrokenBowWindandinstallnecessaryterminalequipment. N Y Y Y

200428 31085 51630 KCPL Northeast‐Charlotte‐Crosstown161kVReactor Economic 3/1/2018 1/1/2018 2/22/2017 2017ITP10 Complete Installnew2‐ohmlinereactoratNortheastsubstationonthe161kVlinefromNortheasttoCharlottetoCrosstown. N Y Y Y

200246 30575 50720 AEP Hallsville‐LongviewHeights69kVCkt1Rebuild RegionalReliability 3/2/2018 6/1/2014 2/19/2014 2014ITPNT Complete Rebuild6.6‐mile69kVlinefromLongviewHeightstoHallsvillewith1233.6ACSR/TWconductor.Upgradejumpers,CTratios,andrelaysettingsatLongviewHeights. N Y Y Y

200359 1146 11509 SPS Carlisle230/115kVCkt1Transformer RegionalReliability 3/9/2018 10/1/2015 12/2/2015 SPP‐2014‐AG1‐AFS‐6 InService Upgrade230/115kVtransformeratCarlisle. N Y Y Y

200444 41189 61836 SPS Martin‐PantexNorth115kVTerminalUpgrades Economic 3/15/2018 1/1/2017 2/22/2017 2017ITP10 Complete UpgradeanynecessaryterminalequipmentatMartinand/orPantexNorthtoincreasetheratingofthe115kVlinebetweenthetwosubstations. N Y Y

200444 41189 61837 SPS PantexSouth‐HighlandTap115kVTerminalUpgrad Economic 3/15/2018 1/1/2017 2/22/2017 2017ITP10 Complete UpgradeanynecessaryterminalequipmentatPantexSouthand/orHighlandTaptoincreasetheratingofthe115kVlinebetweenthetwosubstations. N y Y

200229 772 11017 SPS CarlisleInterchange‐WolfforthInterchange230kVC RegionalReliability 3/27/2018 6/1/2017 9/10/2013 2013ITPNT InService Buildnew16.8‐mile230kVlinefromCarlisletoWolfforthSouthandinstallnecessaryterminalequipment. N Y Y

200336 30859 51163 SPS PlainsInterchange115kVCapBank RegionalReliability 4/4/2018 6/1/2019 2/26/2015 2015ITP10 Complete Installone(1)14.4‐MVARcapacitorbankatthePlainsInterchange115kVsubstation. N Y Y Y

200256 856 11127 SPS CentreSt.‐HerefordNE115kVCkt1 RegionalReliability 4/6/2018 6/1/2014 2/19/20142014ITPNT InService

Buildnew5.1‐mile115kVlinefromCentreSt.toHerefordNE.ConvertdistributiontransformerhighsideatCentreSt.from69kVto115kV.InstallanynecessaryterminalequipmentatHerefordNE.

N Y Y

200448 41209 61869 EDE Nichols–RepublicNorth69kVReconductor RegionalReliability 4/13/2018 6/1/2018 5/12/2017 2017ITPNT Complete Reconductor9.7‐mile69linefromNicholstoRepublicNorth. N Y Y200448 41209 61870 EDE RepublicHinesStreet‐RepublicNorth69kVRecondu RegionalReliability 4/13/2018 6/1/2018 5/12/2017 2017ITPNT Complete Reconductor3.9‐mile69kVlinefromRepublicHinesStreettoRepublicNorth N Y Y200448 41209 61871 EDE RepublicEast‐RepublicHinesStreet69kVReconduc RegionalReliability 4/13/2018 6/1/2018 5/12/2017 2017ITPNT Complete Reconductor1.3‐mile69kVlinefromRepublicEasttoRepublicHinesStreet N Y Y

200309 30639 50871 SPS Kiowa‐PotashJunction345/115kVCkt1 HighPriority 4/30/2018 6/1/2018 12/3/2014 HPILS Complete Construct1‐mileofdoublecircuitstructuresfromthenewKiowasubstationtoPotashJunction.ConstructCircuit1with345kVconductorandCircuit2with115kVconductor. N Y Y

200256 30616 50794 SPS CurryCountyInterchange115kV RegionalReliability 5/7/2018 6/1/2018 2/19/2014 2014ITPNT Complete Installtwo115kVbreakersatCurryCountyInterchangetoconvertthehighsideoftheCurryCountydistributiontransformerto115kV. N Y Y Y

200406 30889 51207 AEP Linwood‐SouthShreveport138kVCkt1Rebuild RegionalReliability 5/10/2018 6/1/2017 8/17/2016 2016ITPNT Complete Rebuildthe2.4‐mile138kVlinefromLinwoodtoCedarGrovetoSouthShreveport.UpgradethejumpersatLinwood. N Y Y

200216 501 10646 AEP Evenside‐NorthwestHenderson69kVCkt1 RegionalReliability 5/11/2018 6/1/2018 2/20/2013 2013ITPNT Complete Rebuild6.4‐mile69kVlinefromEvensidetoNorthwestHendersonwith1233.6ACSR/TW.ReplacebreakeratEvenside. N Y Y

200386 31005 51448 AEP ElkCity138kVMoveLoad RegionalReliability 5/25/2018 6/1/2017 5/17/2016 2016ITPNT Complete Moveloadfrom69kVbusto138kVbusatElkCity N Y Y200309 30638 50820 SPS Kiowa‐NorthLoving345kVCkt1 HighPriority 6/1/2018 6/1/2018 12/3/2014 HPILS Complete Constructnew20.4‐mile345kVlinefromnewKiowasubstationtoNorthLoving. N Y Y

200343 30912 51235 SPS StevensCo.345kVSubstation RegionalReliability 6/1/2018 6/1/2015 8/13/2015 2015ITPNT Complete Taptheexisting345kVlinefromFinneytoHitchlandtoconstructthenewStevensCo.substation.Installanynecessary345kVterminalequipment. N Y Y

200294 30596 50760 NPPD NorthLoup‐Ord115kVCkt1 RegionalReliability 6/1/2018 6/1/2014 8/26/2014 2014ITPNT Complete Increaselineclearanceon115kVlinefromNorthLouptoOrdto100degreeC.Upgradedisconnectswitches,CTs,andjumpersatNorthLoup. N Y Y Y

200282 30672 50874 SPS Dollarhide‐TobosoFlats115kVCkt1 HighPriority 6/1/2018 6/1/2018 5/19/2014 HPILS InService Constructnew7.4‐mile115kVlinefromnewTobosoFlatssubstationtoDollarhide N Y

200330 30838 51133 OPPD Sub3459345/161kVTransformer RegionalReliability 6/1/2018 6/1/2019 2/18/2015 2015ITP10 Complete Installnew345/161kVtransformeratSub3459.Installanynecessary161kVterminalequipment. N Y Y

200330 30838 51136 OPPD Sub3459345kVTerminalUpgrades RegionalReliability 6/1/2018 6/1/2019 2/18/2015 2015ITP10 Complete Installany345kVterminalequipmentrequiredfornew345/161kVtransformeratSub3459. N Y Y

200318 30883 51200 NPPD Bassett115kVSubstation RegionalReliability 6/1/2018 6/1/2016 2/18/2015 2015ITPNT Complete Taptheexisting115kVlinefromAinsworthtoStuarttoconstructthenewBassettsubstation. N Y Y Y

200318 30883 51277 NPPD Bassett115kVCapBank RegionalReliability 6/1/2018 6/1/2016 2/18/2015 2015ITPNT Complete Installone(1)9‐MVARcapacitorbankatthenewBassett115kVsubstation. N Y Y Y200365 30989 51409 SPS PotashJunction230kVTerminalUpgrade RegionalReliability 6/1/2018 6/1/2018 1/12/2016 SPP‐2014‐AG1‐AFS‐6 Complete ReplacewavetrapatPotashJunction230kVsubstation. N Y Y

200395 31051 51549 SPS TerryCo.‐Wolfforth115kVTerminalUpgrades RegionalReliability 6/1/2018 4/1/2020 5/17/2016 2016ITPNT Complete UpgradeterminalequipmentatTerryCo.andWolfforthtoincreasetheratingofthe115kVlinefromTerryCo.toWolfforth. N Y Y

200253 30374 50441 NPPD Neligh345/115kVSubstation RegionalReliability 6/8/2018 6/1/2016 2/19/2014 2014ITPNT Complete BuildnewsubstationatNeligh.Installanew345/115kVtransformerandallnecessary345kVequipmentatNeligh. N Y Y

210483 51282 72013 WFEC ParkCommunity138kVSubstation RegionalReliability 6/15/2018 6/1/2018 4/26/2018 DPA‐2017‐August‐767‐774‐776 Complete NewParkCommunity138kVsubstationwith3‐terminalflatbus. N Y Y

210483 51282 72029 WFEC KingfisherSW‐ParkCommunity138kVCkt1NewLi RegionalReliability 6/15/2018 6/1/2018 4/26/2018 DPA‐2017‐August‐767‐774‐776 Complete Constructnew9.0mile138kVlinefromKingfisherSW‐ParkCommunity. N Y Y Y

20080 30203 50210 NPPD ONEILL115KV RegionalReliability 7/1/2018 11/1/2012 2/8/2010 2009STEP Complete Addasecond18MvarcapacitorbankatOneill115kVsubstationforatotalof36Mvaratthislocation. N Y Y Y

200229 30469 50564 SPS MarketSt.‐SouthPortales115kVCkt1 RegionalReliability 7/13/2018 6/1/2018 9/10/2013 2013ITPNT Complete Buildnew6‐mile115kVlinefromSouthPortalestoMarketSt.andinstallnecessaryterminalequipment. N Y Y

200470 51260 71976 CBPC PrestageFamily69kVCapBank RegionalReliability 9/1/2018 8/1/2018 1/19/2018 DPA‐2017‐March‐735 Complete Addtwonew9.6MVARcapacitorbanks(19.2MVARtotal)atthenewPrestageFamily69kVstation N Y Y

30786 51069 NPPD DixonCounty230kVSubstation GenerationInterconnection 10/1/2018 InService 230kVLineTerminalincludingfour(4)breakersubstationaddition N Y Y

NTCID

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30956 51610 NPPD Antelope115kV‐AddterminalforGEN‐2013‐032(TO GenerationInterconnection 10/3/2018InService

Addone(1)115kVdead‐endtower,arresters,lineswitch,revenuemeterandotherlinerelayingequipmentnecessarytointerconnecttheInterconnectionCustomerInterconnectionFacilitiestothenewTransmissionOwnersubstation.

N Y

30787 51070 NPPD TwinChurch‐DixonCounty230kVLineUpgrade GenerationInterconnection 11/1/2018 InService Increaseclearancestoaccommodate320MVAfacilityrating N Y

30934 51292 NPPD Hoskins‐DixonCounty230kVLineUpgrade GenerationInterconnection 11/1/2018 InService IncreaseclearancesonHoskins‐DixonCounty230kVlinetoaccommodate320MVAfacilityratingtoaddressloadingissues N Y Y

30786 51577 NPPD DixonCounty230kVSubstation(TOIF) GenerationInterconnection 11/1/2018

InService

DixonCounty230kVSubstationAddition:Build230kVSubstationadditionontheTwinChurch–Hoskins230kVtoaccommodatenew230kVinterconnection.Includes:230kVdead‐endtower,arresters,lineswitch,revenuemeterandotherlinerelayingequipmentnecessarytointerconnecttheInterconnectionCustomerInterconnectionFacilitiestothenewTransmissionOwnersubstation.

N Y

200458 31086 51631 WR DePaul‐GirardJct69kV RegionalReliability 11/15/2018 12/31/2018 6/23/2017 DPA‐2016‐March‐596 Complete 1.71milesoftheexistingDePaul‐GirardJct.69kVlinewillberebuiltwithsingle1192.5BuntingACSR. N Y Y Y

200384 30971 51358 SPS Cochran‐WhitefaceTap69kVCkt1Rebuild RegionalReliability 11/28/2018 6/1/2016 4/20/2016 DPA‐2013‐JUN‐342 Complete Rebuild4.5‐mile69kVlinefromCochrantoWhitefaceTapto115kVstandards(operatedat69kV). N Y Y

71349 102167 WAPA GraniteFalls115kVSubstationGEN‐2016‐036Interc GenerationInterconnection 12/6/2018

Complete

TransmissionOwner’sGraniteFalls115kVSubstation:Constructa115‐kVbayadditionincluding,theinstallationofone115‐kVcircuitbreaker(JY28A/2862),two115‐kVdisconnectswitches(WY28A/2863,YY28B/2865),one115‐kVdisconnectswitchwithgroundblades(YY28A/2861,ZY28A/2860),one115‐kVCCVT(VY28A1),equipmentsupports,steellatticebeamandsupports,115‐kVtake‐off/undergroundterminationstructure,controlboards,communicationequipment,andrelays.

N Y

200446 31186 51831 AEP IPC138kVCapBank RegionalReliability 12/13/2018 12/1/2018 5/12/2017 2017ITPNT Complete Install28.8‐MVARcapacitorbankatIPC138kV N Y Y200365 30991 51411 SPS NationalEnrichmentPlant‐Teague115kVCkt1Rebu RegionalReliability 12/14/2018 6/1/2018 1/12/2016 SPP‐2014‐AG1‐AFS‐6 Complete Rebuild6.8‐mile115kVlinefromNationalEnrichmentPlanttoTeague N Y Y200395 31008 51452 SPS ArtesiaCountryClubTap115kVLineTap RegionalReliability 12/17/2018 6/1/2017 5/17/2016 2016ITPNT Complete Tapthe115kVlinefromAtokatoEagleCreekandinstall3‐wayswitchattappoint N Y Y200386 30997 51433 AEP Sayre138kVCapBank RegionalReliability 12/19/2018 6/1/2017 5/17/2016 2016ITPNT Complete Installnew14.4‐MVARcapacitorbankatSayre138kV. N Y Y200386 31058 51561 AEP FortTowson‐KiamichiPumpTap69kVCkt1Rebuild RegionalReliability 12/21/2018 6/1/2018 5/17/2016 2016ITPNT Complete Rebuild9.0‐mile69kVlinefromFortTowsontoKiamichiPumpTap N Y Y200386 31058 51562 AEP KiamichiPumpTap‐Valliant69kVCkt1Rebuild RegionalReliability 12/21/2018 6/1/2018 5/17/2016 2016ITPNT Complete Rebuild4.8‐mileportionof69kVlinefromKiamichiPumpTaptoValliant N Y Y200395 30692 50920 SPS Seminole230/115kV#1Transformer RegionalReliability 12/28/2018 6/1/2017 5/17/2016 2016ITPNT Complete Replacefirstexisting230/115transformeratSeminole. N Y Y

200214 30451 50546 SPS Atoka‐EagleCreek115kVCkt1 RegionalReliability 12/31/2018 6/1/2015 2/20/2013 2013ITPNT Complete Buildnew12‐mile115kVlinefromAtokatoEagleCreekandinstallnecessaryterminalequipment. N Y

200384 30444 50539 SPS Cochran115kVCapBank RegionalReliability 12/31/2018 6/1/2016 4/20/2016 DPA‐2013‐JUN‐342 Complete Install28.8‐MVARcapacitorbankatCochran115kV(two14.4‐MVARstages). N Y Y

20130 1036 11372 SPS SoncyTap115kV‐NewSoncy115kV RegionalReliability 12/31/2018 6/1/2015 2/14/2011

2010STEP Complete

Convert1.04milesofZ33to115kVservicebytappingthe115kVlinefromSunsetSubstationtoCoulterInterchangeatI‐40&SoncyStreet.AtSoncySubsplittheconvertedZ33lineoffthe69kVbusandterminatetoanew115/13.2kVtransformertoservetheSoncydistributionload.Installnew115/13.2kVdistributiontransformer.Leave69kVundergroundcabletoLawrenceParktobefedbyY72outofCoulterInterchange.

N Y Y

200241 30440 50535 GRDA 412Sub‐KansasTap161kVCkt1TerminalUpgrade RegionalReliability 12/31/2018 6/1/2018 2/19/2014 2014ITPNT Complete Replace1200Ampswitchwitha2000AmpswitchatKansasTapsubstation161kVbus. N Y Y

200452 51236 71926 WAPA RobertsCounty115kVSubstation RegionalReliability 1/1/2019 6/1/2018 5/12/2017 2017ITPNT Complete Buildnew115kVsubstationatRobertsCountybetweentheFormanandSummitsubstations. N Y

200395 30844 51140 SPS Amoco‐Sundown230kVTerminalUpgrades RegionalReliability 2/20/2019 1/1/2019 5/17/2016 2016ITPNT Complete UpgradeswitchesandwavetrapsatSundownandAmocoandincreasethelineclearancetoincreasetheratingofthe230kVlinefromAmocotoSundown. N Y Y

200339 30762 51034 AEP EllerbeRoad‐Lucas69kVCkt1Rebuild RegionalReliability 2/27/2019 3/1/2019 3/17/2015 DPA‐2013‐MAR‐296 Complete Rebuildexisting3.2‐mile69kVlinefromEllerbeRoadtoLucas N Y Y

200339 30762 51035 AEP EllerbeRoad‐Lucas69kVTerminalUpgrades RegionalReliability 2/27/2019 3/1/2019 3/17/2015 DPA‐2013‐MAR‐296 Complete Replacejumpersat69kVsubstationsEllerbeRoadandLucas.ReplacerelaypanelatEllerbeRoad.ChangerelaysettingatLucas. N Y Y

200262 30766 51039 SPS YoakumCountyInterchange230/115kVCkt1Transf TransmissionService 3/15/2019 6/1/2019 4/9/2014 SPP‐2011‐AG3‐AFS‐11 Complete UpgradeYoakumCountyInterchangeCkt1230/115kVtransformerto250MVA N Y Y200446 41233 71945 AEP BrokenArrowNorth‐LynnLaneEast138kVCkt1Re RegionalReliability 3/19/2019 6/1/2018 5/12/2017 2017ITPNT Complete ReconductorBrokenArrow‐LynnLaneEast7.2‐mile138kVline N Y Y200360 30914 51250 SPS NationalEnrichmentPlant‐Targa115kVCkt1 RegionalReliability 3/20/2019 6/1/2015 12/7/2015 2015ITPNT Complete Rebuild4.3‐mile115kVlinefromNationalEnrichmentPlanttoTarga N Y Y200360 30914 50958 SPS IMC#1Tap‐IntrepidWest115kVCkt1Rebuild RegionalReliability 3/22/2019 6/1/2015 12/7/2015 2015ITPNT Complete Rebuild3.9‐mile115kVlinefromIntrepidWestTaptoIMC#2. N Y Y200360 30914 50957 SPS IntrepidWest‐PotashJunction115kVCkt1Rebuild RegionalReliability 3/22/2019 6/1/2015 12/7/2015 2015ITPNT Complete Rebuild1.5‐mile115kVlinefromIntrepidWestTaptoPotashJunction. N Y Y200360 30914 50952 SPS IMC#1Tap‐LivingstonRidge115kVCkt1Rebuild RegionalReliability 3/22/2019 6/1/2015 12/7/2015 2015ITPNT Complete Rebuild9.5‐mile115kVlinefromLivingstonRidgetoIMC#1Tap. N Y Y210491 51300 72066 AEP FigFive‐VBINorth69kVCkt1 RegionalReliability 4/11/2019 6/1/2019 8/17/2018 2018ITPNT Complete Rebuild4.2milesof69kVlinefromFigFivetoVBI. N Y Y

200418 31042 51569 OGE DeGrasse138kVSubstation(OGE) RegionalReliability 4/17/2019 6/1/2017 12/27/2016

2016ITPNT Complete

Taptheexisting138kVlinefromMoorelandtoRoseValleyandterminatebothendpointsintothenewDeGrassesubstation.OGEandWesternFarmersElectricCooperativeshalldecidewhoshallbuildhowmuchoftheseNetworkUpgradesandshallprovidesuchinformation,alongwithspecificcostestimatesforeachDTO'sportionoftheNetworkUpgrades,toSPPinitsresponsetothisNTC.

N Y Y

200297 1139 11501 SPS AllenSubstation‐LubbockSouthInterchange115kV RegionalReliability 4/26/2019 6/1/2019 5/5/2015 SPP‐2012‐AG3‐AFS‐9 Complete Rebuild6‐mile115kVlinefromLubbockSouthInterchangetoAllensubstation N Y Y200262 30510 50637 SPS Mustang‐ShellCO2115kVCkt1 TransmissionService 4/29/2019 6/1/2015 4/9/2014 SPP‐2011‐AG3‐AFS‐11 Complete Constructnew7.7‐mile115kVlinefromMustangtoShellCO2 N Y Y200395 30692 50921 SPS Seminole230/115kV#2Transformer RegionalReliability 4/30/2019 6/1/2017 5/17/2016 2016ITPNT Complete Replacesecondexisting230/115transformeratSeminole. N Y Y

200282 30675 50988 SPS YesoHills115kVSubstation HighPriority 5/3/2019 6/1/2018 5/19/2014 HPILS Complete Constructnew115kVYesoHillssubstation.Installanynecessary115kVterminalequipment. N Y

200282 30675 50869 SPS ChinaDraw‐YesoHills115kVCkt1 HighPriority 5/3/2019 6/1/2018 5/19/2014 HPILS Complete Constructnew18.4‐mile115kVlinefromChinaDrawtonewYesoHillssubstation N Y

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200262 30766 51050 SPS YoakumCountyInterchange230/115kVCkt2Transf RegionalReliability 5/7/2019 6/1/2019 4/9/2014 SPP‐2011‐AG3‐AFS‐11 Complete UpgradeYoakumCountyInterchangeCkt2230/115kVtransformerto250MVA N Y Y200326 30888 51206 SPS LynnCounty115/69kVCkt1Transformer RegionalReliability 5/15/2019 6/1/2019 2/18/2015 2015ITPNT Complete Replace115/69kVtransformeratLynnCountysubstation. N Y Y

200326 30888 51270 SPS LynnCounty115kVTerminalUpgrades RegionalReliability 5/15/2019 6/1/2019 2/18/2015 2015ITPNT Complete Install115kVterminalequipmentatLynnCountysubstationnecessarytoreplace115/69kVtransformer. N Y Y

200395 30999 51436 SPS PotterCo.‐Harrington230kVTerminalUpgrades RegionalReliability 5/16/2019 6/1/2019 5/17/2016 2016ITPNT Complete UpgradeterminalequipmentatbothPotterCo.andHarrington230kVsubstations. N Y Y200395 31022 51481 SPS CanyonEastTap‐Randall115kVCkt1Rebuild RegionalReliability 5/16/2019 6/1/2017 5/17/2016 2016ITPNT Complete Rebuild3‐milesegmentof115kVlinefromCanyonEastTaptoRandall N Y Y200309 30376 50457 SPS Hobbs‐Yoakum345kVCkt1 HighPriority 5/30/2019 6/1/2020 12/3/2014 HPILS Complete Constructnew52‐mile345kVlinefromHobbstoYoakum N Y Y

81467 112299 SEPC MingoSubstationRelayGEN‐2015‐065(NU) GenerationInterconnection 5/30/2019 InService MingoSubstationrelaysettingmodification(NU N Y Y81467 112297 SEPC Mingo345kVSubstationGEN‐2015‐065(TOIF) GenerationInterconnection 5/30/2019 Complete Mingo345kVSubstation N Y Y81467 112298 SEPC Mingo345kVSubstationGEN‐2015‐065(NU) GenerationInterconnection 5/30/2019 Complete Mingo345kVSubstation(NU) N Y Y

210484 31068 50451 SPS Yoakum345/230kVCkt1Transformer RegionalReliability 5/31/2019 6/1/2017 4/27/2018 HPILS Complete Installnew345/230kV640MVAtransformeratYoakumsubstation.Installanynecessary230kVterminalequipment. N Y Y

200431 31131 51738 AEP SiloamSprings‐SiloamSpringsCity161kVCkt1Reb Economic 5/31/2019 1/1/2017 2/21/2017 2017ITP10 Complete Rebuild2.1‐mile161kVlinefromSiloamSprings(AEP)‐SiloamSpringsCity(GRDA)andupgradeterminalequipmentatSiloamSprings. N Y Y

200432 31131 51739 GRDA SiloamSprings‐SiloamSpringsCity161kVCkt1Reb Economic 5/31/2019 1/1/2017 2/21/2017 2017ITP10 Complete UpgradeterminalequipmentatSiloamSpringsCity(GRDA)toincreasetheratingofthelinebetweenSiloamSprings(AEP)andSiloamSpringsCity(GRDA)substations. N Y Y Y

200455 30755 50992 SPS Tuco230/115kVCkt1Transformer TransmissionService 6/15/2019 6/1/2018 5/12/2017 2017ITPNT Complete Upgrade230/115kVtransformeratTucoto273MVA. N Y Y

NTCID

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200454 51253 71961 NIPCO L‐10Southern69kVTerminalUpgrades RegionalReliability 7/1/2019 6/1/2018 5/12/2017 2017ITPNT Complete Install69kVbreakersneededtocloseintheL‐10SoutherntoNorthOakland69kVline N Y Y200454 51253 71962 NIPCO J1669kVSubstation RegionalReliability 7/1/2019 6/1/2018 5/12/2017 2017ITPNT Complete Buildnew69kVswitchingstationtoreplacetheK‐116switch N Y

200242 30584 50740 WR ElkJunction‐Sedan69kVCkt1Rebuild ZonalReliability 9/11/2019 6/1/2018 2/19/2014 2014ITPNT Complete Rebuild18.8‐mile69kVlinefromElkJunctiontoSedantoachievenewemergencyratingof72MVA. N Y Y Y

200376 30953 51333 SEPC LaneScott115kVCapBank RegionalReliability 9/19/2019 6/1/2017 7/12/2016 DPA‐2015‐MARCH‐494 Complete Install12‐MVARcapacitorbankatLaneScott115kV. N Y

200452 51236 71927 WAPA XFR‐RobertsCounty115/69kVTransformer RegionalReliability 9/30/2019 6/1/2018 5/12/2017 2017ITPNT Complete New115/69kVtransformeratRobertsCounty.Installnecessary69kVterminalequipmentatRobertsCountysubstation. N Y

30960 51341 OGE BeaverCountySubstation‐Add345kVterminalforGE GenerationInterconnection 10/28/2019Complete

BeaverCounty345kV:Convertfromringbustobreaker–and‐a‐halfconfigurationbyinstallingadditionalrungtotheexistingbuslayoutandinstallfive(5)345kV,3000Ampbreakers,linerelaying,disconnectswitches,andassociatedequipment.

N Y Y

30960 51609 OGE BeaverCountySubstation‐Add345kVterminalforGE GenerationInterconnection 10/28/2019Complete

BeaverCounty345kV:Addone(1)345kVlineterminalincludingdead‐endstructure,substationsteel,substationbus,interconnectionmetering,lineswitchandassociatedequipment.NoadditionalRight‐of‐Wayisincludedinthiscost.

N Y

210512 51339 82139 OGE Kildare‐WhiteEagle138kVCkt1Rebuild SponsoredUpgrade 10/29/2019 6/1/2019 4/3/2019 SUS‐004 Complete Rebuild11.2mile138kVlinefromKildare‐WhiteEagleandupgradeterminalequipment N Y Y Y

210542 81526 112396 WR GettyEast‐Skelly69kVCkt1TerminalUpgrades RegionalReliability 11/4/2019 4/1/2021 11/18/2019 2019ITP Complete UpgradeanynecessaryterminalequipmentatGettyEastand/orSkellytoincreasethesummeremergencylineratingto108MVA N y Y Y

51328 82116 WR EmporiaEnergyCenter345kVSubstationGEN‐2015‐ GenerationInterconnection 11/5/2019

InService

Constructone(1)345kVlineterminal,lineswitches,deadendstructure,linerelaying,communications,revenuemetering,linearrestorandallassociatedequipmentandfacilitiesnecessarytoaccepttransmissionlinefromInterconnectionCustomer’sGeneratingFacility.;AllowanceforFundsUsedDuringConstruction(AFUDC)

N Y Y

51328 82117 WR EmporiaEnergyCenter345kVSubstationGEN‐2015‐ GenerationInterconnection 11/5/2019

InService

ConstructOne(1)345kV3000continuousampacitybreakers,controlpanels,linerelaying,disconnectswitches,structures,foundations,conductors,insulators,andallotherassociatedworkandmaterials.Thefollowingareincludedinthiscostestimate:AllowanceforFundsUsedDuringConstruction(AFUDC)

N Y Y

200457 31176 51819 SPS HockleyCountyInterchange115kVTerminalUpgrad RegionalReliability 11/15/2019 6/1/2021 5/15/2017 SPP‐2016‐AG1‐AFS‐3 Complete ReplacewavetrapatHockleyCountyInterchangetoincreasethelinecapacityforHockleyCountyInterchange‐LambCountyInterchange115kVCkt1. N Y Y

210487 51278 72005 CPEC NorthBismarck115kVTerminalUpgrades SponsoredUpgrade 12/11/2019 11/1/2018 8/17/2018

SUS‐002CPECNorthBismarckBreaker Complete

SponsoredUpgrade‐CPECischangingtheoperationalstatusofthe115kVbreaker262withintheNorthBismarcksubstationfroma"normallyopen"devicetoa"normallyclosed"device.Thischangeinconfigurationresultsina115kVloopbetweenWAPA'sBismarckandWard230kVsubstations.

N Y Y

200386 31057 51558 AEP ArmyAmmo‐McAlester69kVCkt1Rebuild ZonalReliability 12/18/2019 6/1/2017 5/17/2016 2016ITPNT Complete Rebuild9.9‐mile69kVlinefromArmyAmmotoMcAlester. N Y Y200462 41223 61894 CPEC EastRuthville‐SWMinot115kVNewLine RegionalReliability 12/19/2019 6/1/2018 8/2/2017 2017ITPNT Complete Constructnew24‐mile115kVlinefromEastRuthvilletoSWMinot. N Y Y200462 41223 61895 CPEC EastRuthville‐SWMinot115kVlineTerminalUpgra RegionalReliability 12/19/2019 6/1/2018 8/2/2017 2017ITPNT Complete InstallterminalupgradesneededforEastRuthville‐SWMinot24‐mile115kVline N Y Y200365 30987 51406 SPS Cunningham‐MonumentTap115kVCkt1Rebuild RegionalReliability 12/20/2019 6/1/2021 1/12/2016 SPP‐2014‐AG1‐AFS‐6 Complete Rebuild6.5‐mile115kVlinefromCunninghamtoMonumentTap N Y Y

200366 30988 51408 SPS EddyCo.230kVBusTie TransmissionService 12/20/2019 10/1/2017 1/12/2016 SPP‐2013‐AG3‐AFS‐6 Complete Reconfigure230kVbustieatEddyCo.substationtoconverttoadoublebusandbreakerscheme. N Y Y

200446 41202 61858 AEP TulsaSoutheast‐E.61st138kVRebuild RegionalReliability 12/20/2019 6/1/2018 5/12/2017 2017ITPNT Complete RebuildTulsaSoutheast‐E.61st3.5‐mile138kVline N Y Y

210496 41197 61850 SPS TerryCounty‐LGClauene115kVTerminalUpgrades RegionalReliability 12/31/2019 6/1/2019 8/17/2018 2018ITPNT Complete ReplaceterminalequipmentontheClauene‐Terry(circuitV55)lineandaddressanylineclearanceconcernstomeetorexceedtheline'sconductorrating. N Y Y

210493 51285 72037 CUS Brookline345kVReactor RegionalReliability 12/31/2019 6/1/2019 8/17/2018 2018ITPNT Complete Installnew50MVARreactoratBrookline345kV. N Y210493 51285 72038 CUS Brookline345kVSubstationExpansion RegionalReliability 12/31/2019 6/1/2019 8/17/2018 2018ITPNT Complete Brookline345kVSubstationexpansiontoaccommodatenew50MVARreactor. N Y

81467 112300 SEPC Mingo115kVSubstationGEN‐2015‐064(TOIF) GenerationInterconnection 1/20/2020

InService

TransmissionOwner’sMingo115kVSubstation:Constructone(1)115kVlineterminal,lineswitches,deadendstructure,linerelaying,communications,revenuemetering,linearrestorandallassociatedequipmentandfacilitiesnecessarytoaccepttransmissionlinefromInterconnectionCustomer’sGeneratingFacility.

N Y Y

81467 112301 SEPC Mingo115kVSubstationGEN‐2015‐064(NU) GenerationInterconnection 1/20/2020

InServiceTransmissionOwner’sMingo345kVSubstation:Constructfour(4)115kV3000continuousampacitybreakers,controlpanels,linerelaying,disconnectswitches,structures,foundations,conductors,insulators,andallotherassociatedworkandmaterials.

N Y Y

200483 51277 72004 OPPD S1255‐S1260161kVCkt1NewLine RegionalReliability 1/27/2020 1/1/2020 2/27/2018 DPA‐2017‐May‐746 Complete Buildnew5.3‐mile161kVlinefromS1255toS1260 N Y Y

200369 1142 11506 SPS CanyonEastSub‐RandallCountyInterchange115kV RegionalReliability 3/20/2020 2/1/2014 2/12/2016 SPP‐2011‐AG3‐AFS‐11 Complete Rebuild13.5‐mile4/0segmentof115kVlinefromCanyonEastSubtoRandallCountyInterchange. N Y

51241 71939 SEPC JohnsonCorner115kV‐GEN‐2015‐021Addition(TOI GenerationInterconnection 4/7/2020

InService115kVSubstationworkforone(1)newlineterminal,lineswitch,deadendstructure,linerelaying,one(1)2000Acircuitbreaker,communications,controlpanelreplacement,disconnectswitches,revenuemetering,andlinearrestor,substationbus,andassociatedequipment.

N Y

200296 30560 50698 WR SumnerCounty‐Viola138kVCkt1 ZonalReliability 5/11/2020 6/1/2019 9/2/2014 2014ITPNT InService Buildnew28‐mile138kVlinefromViolatoSumnerCounty N Y Y200397 31002 51445 WFEC Lincoln‐Meeker138kVCkt1NewLine(WFEC) RegionalReliability 7/31/2020 6/1/2017 5/17/2016 2016ITPNT Complete Constructnew8.5‐mile138kVlinefromLincolntoMeeker. N Y Y Y200365 30990 51410 SPS Jal‐Teague115kVCkt1Rebuild RegionalReliability 6/1/2021 1/12/2016 SPP‐2014‐AG1‐AFS‐6 Complete Rebuild10.3‐mile115kVlinefromJaltoTeague N Y Y Y

200444 31079 51623 SPS Tuco‐Stanton115kVTerminalUpgrades Economic 1/1/2017 2/22/2017 2017ITP10 InService UpgradeanynecessaryterminalequipmentatStantonand/orTucotoincreasetheratingofthe115kVlinebetweenthetwosubstations. N Y Y

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BP 7060 APPENDIX C UPDATE-PCWGACTION ITEMS 204 & 2106/3/2020

JOHN O’DELL

2

PCWG ACTION ITEMS 204 AND 210

ACTION ITEMDATE

ORIGINATEDSTATUS COMMENTS

204

Research Revision to

BP 7060 to clarify

NTC-C reevaluation in

Appendix C.

March 2019

In Progress

Agenda

Item 10

Tabled for inclusion

with page turn review

of BP 7060. Now

dependent on Action

Item 210.

210

Add deadlines/

timeframes to

Appendix C of BP

7060

December

2019

In Progress

Agenda

Item 10

3

EXISTING APPENDIX C

Applicable Project?

NTC Re-evaluation

Issue NTC

Board Action

SPP Task

TO Task Stakeholder Group Task

Continue to Quarterly

Process

Withdraw NTC

NO

YES

Issue NTC-CStudy

Completion

Is CPE bandwidth

within Study Estimate

bandwidth?

NPE (+/-20%)

CPE (+/-20%)

Issue NTC (Remove

Conditions)

NO

YES

NPE Review

SPP and/or TO TaskStudy Estimate (+/-30%)

Competitive Project?

NO

TO Selection Process

YES

RRE (+/-20%)

Issue NTC

Set Baseline Estimate

Suspend NTC

Set Baseline Estimate

Although not required by Business Practice 7060, Staff will compare the NPE for a project to the Study

Estimate and may recommend a re-evaluation of the project at its

discretion

4

REVISED APPENDIX C

Applicable

Project?

NTC Re-

evaluation

Board

Action

Continue to

Quarterly

Process

Withdraw

NTC

NO

YES

Study

Completion

Is CPE

bandwidth

within Study

Estimate

bandwidth?

NPE

(+/-20%)

Issue NTC (Remove

Conditions)

NO

YES

Study

Estimate

(+/-30%)

Competitive

Project?

TO

Selection

Process

YESRRE

(+/-20%)Issue NTC

Set Baseline

Estimate

Suspend

NTC

Set Baseline

Estimate

15 Days

90 Days

6 Months

15 Days

15 Days

NO

NTC-C Timeframe

NTC Timeframe

7 Days 1 Year Next Board Cycle

RFP Timeframe

Issue NTC NPE Review

CPE

(+/-20%)Issue NTC-C

Board

Approval

Although not required by Business

Practice 7060, Staff will compare

the NPE for a project to the Study

Estimate and may recommend a re-

evaluation of the project at its

discretion

Re-evaluation

occurs at the next

Board cycle

RFP Timeframe

5

CHANGES INCLUDE

Addition of NTC, NTC-C, & NTC-C timeframes

Removal of additional evaluation loop for clarification

Existing Revised

6

ACTION REQUESTED

Staff requests PCWG approval for these

changes to be included in upcoming BP 7060

RR.



AGING REPORT-PCWG ACTION ITEM 2096/3/2020

TAMMY BRIGHT

2


Aging Report - Add review of projects with no

change in cost compared to baseline as

ongoing quarterly Face to Face agenda.

• Projects must be within 24 months of

projected in service date to be included

• Projects that have been re-baselined that are

not in service will be included in this list.

3

AGING REPORT

PID Project NameProject

OwnerStatus

In-Service

Date

Meeting

Date

Baseline

Estimate

Variance

Pct. to

Baseline

Baseline

Estimate

Year

Escalated

Baseline

Estimate

Variance

Pct. To

Esc.

Baseline

Latest Cost

30560Line - Sumner County - Viola 138 kV

Ckt 1WR DELAYED 6/1/20 6/3/2020 $34,432,188 0.0% 2019 $35,292,993 -2.4% $34,432,188

30946 Multi - Lower Brule - Witten 230 kV BEPC DELAYED 1/1/18 6/3/2020 $38,000,000 0.0% 2014 $41,944,890 -9.4% $38,000,000

30988 Sub - Eddy Co. 230 kV Bus Tie SPS COMPLETE 12/20/19 6/3/2020 $19,732,223 0.0% 2020 $19,732,223 0.0% $19,732,223

41223Line - New East Ruthville - SW

Minot 115 kV New LineCPEC COMPLETE 12/19/19 6/3/2020 $14,365,735 0.0% 2020 $14,365,735 0.0% $14,365,735




4


Project Owner

Number of Upgrades

Number of Upgrades Reviewed

Reviewed %In-Service Date

ChangesISD Change % Cost Changes Cost Change %

AECC 1 0 0% 0 0% 0 0%

AEP 57 56 98% 6 11% 2 4%

BEPC 23 8 35% 0 0% 7 30%

CBPC 1 0 0% 0 0% 0 0%

CPEC 3 3 100% 3 100% 2 67%

CUS 2 2 100% 0 0% 0 0%

EDE 3 0 0% 0 0% 0 0%

EREC 3 3 100% 1 33% 1 33%

GHP 1 0 0% 0 0% 0 0%

GMO 2 1 50% 0 0% 0 0%

GRDA 3 1 33% 0 0% 1 33%

KCPL 9 8 89% 2 22% 2 22%

KPP 1 0 0% 0 0% 0 0%

MIDW 5 5 100% 0 0% 0 0%

NIPCO 2 0 0% 0 0% 0 0%

NPPD 38 0 0% 0 0% 2 5%

NWE 2 0 0% 0 0% 0 0%

OGE 29 8 28% 6 21% 2 7%

OPPD 13 13 100% 0 0% 0 0%

SEPC 8 7 88% 2 25% 1 13%

SPS 173 173 100% 57 33% 70 40%

TBD 10 0 0% 0 0% 0 0%

TSMO 2 2 100% 0 0% 0 0%

WAPA 10 0 0% 0 0% 0 0%

WFEC 35 0 0% 0 0% 0 0%

WR 28 25 89% 1 4% 5 18%

Total 464 315 67.89% 78 16.81% 95 20.47%

*Reporting period was 11/1/2019-1/31/2020

5


0

20

40

60

80

100

120

140

160

180

200

AEC

C

AEP

BEP

C

CB

PC

CP

EC

CU

S

EDE

EREC

GH

P

GM

O

GR

DA

KC

PL

KP

P

MID

W

NIP

CO

NP

PD

NW

E

OG

E

OP

PD

SEP

C

SPS

TBD

TSM

O

WA

PA

WFE

C

WR

In-Service Date Changes No In-Service Date Change

0

20

40

60

80

100

120

140

160

180

200

AEC

C

AEP

BEP

C

CB

PC

CP

EC

CU

S

EDE

EREC

GH

P

GM

O

GR

DA

KC

PL

KP

P

MID

W

NIP

CO

NP

PD

NW

E

OG

E

OP

PD

SEP

C

SPS

TBD

TSM

O

WA

PA

WFE

C

WR

Cost Changes No Cost Change

6

PCWG ACTION

Does PCWG wish to request additional

information from Designated Transmission

Owners on projects listed on slide 1?

Revision Request Form

SPP STAFF TO COMPLETE THIS SECTION

RR #: Date:

RR Title: BP7060 – Clean-up

System Changes No Yes

Process Changes? No Yes

Impact Analysis Required? No Yes | If no, but system or process changes are expected please explain why an Impact

Analysis will not be performed (e.g. FERC Order, work included in another Impact Analysis for a related RR):

SUBMITTER INFORMATION

Name: Tammy Bright Company: SPP staff on behalf of PCWG

Email: [email protected] Phone: (501)688-1644

Only Qualified Entities may submit Revision Requests.

Please select at least one applicable option below, as it applies to the named submitter(s).

SPP Staff

SPP Market Participant

SPP Member

An entity designated by a Qualified Entity to submit

a Revision Request “on their behalf”

SPP Market Monitor

Staff of government authority with jurisdiction over

SPP/SPP member

Rostered individual of SPP Committee, Task Force or

Working Group

Transmission Customers or other entities that are parties to

transactions under the Tariff

REVISION REQUEST DETAILS

Requested Resolution Timing: Normal Expedited Urgent Action

Reason for Expedited/Urgent Resolution:

Type of Revision (select all that apply):

Correction (i.e., revising erroneous language or

language that needs clean-up for grammatical errors or

inconsistency across governing documents - no changes to

intent or policy)

Clarification (i.e., revising language to better

represent existing intent, no changes to functionality or

policy)

Enhancement (i.e., revising language to expand upon

existing intent or functionality)

New Protocol, Business Practice, Criteria, Tariff

(i.e, new language to accommodate new functionality or

policy not existing today)

NERC Standard Impact (Specifically state if

revision relates to/or impacts NERC Standards, list

standard(s))

FERC Mandate (List order number(s))

REVISION REQUEST RISK DRIVERS

Are there existing risks to one or more SPP Members or the BES driving the need for this RR? Yes No

If yes, provided details to explain the risk and timelines associated:

Compliance (Tariff, NERC, Other)

Reliability/Operations

Financial


SPP Documents Requiring Revision: Please select your primary intended document(s) as well as all others known that could be impacted by the requested revision (e.g.

a change to a protocol that would necessitate a criteria or business practice revision).

Market Protocols Section(s): Protocol Version:

Operating Criteria Section(s): Criteria Date:

Planning Criteria Section(s): Criteria Date:

Tariff (OATT) Section(s):

Business Practice Business Practice Number: 7060

Integrated Transmission Planning (ITP)

Manual Section(s):

Revision Request Process Section(s):

Minimum Transmission Design

Standards for Competitive Upgrades (MTDS) Section(s):

Reliability Coordinator and Balancing

Authority Data Specifications (RDS) Section(s):

SPP Communications Protocols Section(s):

OBJECTIVE OF REVISION

Objectives of Revision Request: Describe the problem/issue this revision request will resolve.

PCWG completed a review of BP 7060 and found multiple opportunities to clarify existing language, provide consistency, or

update to reflect current process. PCWG does not view these changes as substantive, but does feel that clarification does need to

be made in these cases.

Describe the benefits that will be realized from this revision.

With the language update of BP7060, members and staff will be provided clarification and consistency on what the govering

language has been created to accomplish.

REVISIONS TO SPP DOCUMENTS

In the appropriate sections below, please provide the language from the current document(s) for which you are requesting

revision(s), with all edits redlined.

SPP Business Practices

7060 Notification to Construct and Project Cost Estimating Processes Effective January 1, 2012

(return to TOC)

Business Practice

Contents 1. Notification to Construct 2. Notification to Construct with Conditions

3. Issuance of an NTC or NTC-C

4. Format of NTC/NTC-C Letters and Identification Numbers

5. Acceptance of an NTC-C or NTC

6. NTC/NTC-C Modification

7. NTC/NTC-C Withdrawal 8. Project Specification and Cost Estimation Process

9. Standardized Cost Estimate Reporting Template (SCERT)

Deleted:

Deleted:

10. PCWG Review Process for Applicable Projects

11. Projects Reviewed by PCWG

12. Project Reporting 13. NTC Project Close-out and Validation Process

14. Dispute Resolution

Appendix A. Sample NTC for A Non-Competitive Project

Appendix B. Sample NTC-C

Appendix C. Cost Estimation Process Flow Chart

Appendix D. Quarterly Project Tracking Flow Chart

1. Notification to Construct An SPP Notification to Construct (NTC) letter is a formal document directing the Designated Transmission Owner

(DTO) for the commencement of construction of Network Upgrades that have been approved or endorsed by the

SPP Board of Directors (Board) intended to meet the construction needs of the SPP Transmission Expansion Plan

(STEP), SPP Open Access Transmission Tariff (OATT), or Regional Transmission Organization (RTO).

3. Issuance of an NTC or NTC-C The authority for SPP to issue an NTC is derived from approval by the Board, a FERC filed Service Agreement

under the SPP OATT, an endorsed Economic or Sponsored Upgrade upon the execution of a contract that

financially commits a Project Sponsor to fund such upgrade, or when such upgrade is otherwise required pursuant to

the tariff. An NTC or NTC-C may be issued for projects originating from study processes described in Attachment

O of the OATT.

3.1. Approved Network Upgrades from ITP/High Priority Studies

Unless previously issued, SPP staff will issue NTC(s) or NTC-C(s) for all Network Upgrades approved by the Board

for which financial commitment is required prior to the approval of the next update of the STEP. Additionally if

authorized by the Board, SPP staff will issue an NTC/NTC-C for each Network Upgrade for which a financial

commitment is needed within the next four years or other time period as designated by the Board. For a non-

Competitive Project, such an NTC/NTC-C will be issued within 15 business days from the time the SPP Board

approves the project. For a Competitive Project, an NTC will be issued to the Selected RFP Respondent in accordance

with Attachment Y of the OATT.

3.4. Network Upgrades related to Generation Interconnection requests

Unless previously issued, SPP staff will issue NTCs for identified project(s) associated with Generation

Interconnection Agreements (GIA) to an affected Transmission Owner (TO) who is not a party to the GIA within 15

business days from the Effective Date of the GIA. SPP will not issue NTCs for identified project(s) associated with

Generation Interconnection Agreements where the affected TO is a party to the GIA.

4.2. Project Information

Projects are assigned a unique Project Identification Number (PID).

Project ID# convention, XXXXXXX

Example: -123456

Projects consist of one or more Network Upgrades.

The Project name will generally describe the Network Upgrades associated with the Project.

Project Information will include an Estimated Cost and a Project Schedule, which will include, at a

minimum, the Need Date.

4.3. Network Upgrade Information

Network Upgrades are assigned a unique Upgrade Identification Number (UID)

Network Upgrade ID# convention, YYYYYYY

Example: 1234567

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Deleted: SPP-PID-#

Deleted: SPP-PID

Deleted: SPP-UID-#

Deleted: SPP-UID-1

The Network Upgrade Description will provide a brief scope of the Network Upgrade

Documentation of Network Upgrade Owner

SPP Member/facility owner(s) and Contact Information

Markets and Operations Policy Committee (MOPC) Representative

TWG Representative, if applicable

Categorization

Economic as a part of a Balanced Portfolio

Integrated Transmission Planning Process

Sponsored Upgrade

Service Upgrade

Zonal Reliability Upgrade

Other

Upgrad e Specifications

Upgrade Type: Reconductor, Rebuild, New Construction, etc.

Voltage levels

Estimated Line Length and minimum required summer and winter rating

Transformer, minimum required summer and winter rating

Associated terminal equipment, minimum required summer and winter rating

Any other static equipment

Network Upgrade Justification

NERC Reliability Compliance

Regional Study reliability Zonal criteria

Transmission service request – List Aggregate study number with reference to posted

facility log

Economic

Other

Need Date

Network Upgrade cost estimate in present day dollars, date of cost estimate, and origination of

cost estimate.

Cost recovery for Network Upgrade

Base Plan Allocated

Direct Assignment

Project Sponsor

Zonal

Regional

Other

4.4. Documentation of Approvals

Board approval or endorsement date or reference to approved motion

Service Agreement information

Commitment details of Sponsored Upgrades

5. Acceptance of an NTC-C or NTC

5.1. For all Applicable Projects that have been issued an NTC-C

The DTO shall provide to SPP, within 90 days of the date of the NTC-C letter, a written commitment that it has

accepted to construct the Network Upgrade(s) and that it shall provide SPP with an NTC-C Project Estimate (CPE),

Deleted: OD

Deleted: number

as described in Section 8.4, on or before the due date requested by SPP in the NTC-C letter. The DTO shall advise

SPP of any inability to provide the CPE by the SPP requested date as soon as the inability becomes apparent to the

DTO.

If the CPE variance bandwidth of -20% to +20% does not exceed the Study Estimate variance bandwidth of -30% to

+30%, as discussed in Section 8, the Applicable Project’s cost variance will be deemed acceptable and SPP staff

will remove the conditions in the NTC-C and SPP staff will notify the DTO in writing within 5 business days that

the conditions have been removed and issue a new NTC to the DTO, pursuant to Section 5.2.1 below. This will be

the authorization for the DTO to proceed with the construction of the Applicable Project. In other words, if the CPE

is not greater than 1.0833 times the Study Estimate and is not less than 0.875 times the Study Estimate, an NTC will

be issued with no further review.

If the CPE variance bandwidth exceeds the variance bandwidth of -30% to +30% of the Study Estimate, SPP staff

will re-evaluate this Applicable Project using the new cost estimate data provided by the DTO, and will make a

recommendation to the Board at its next regularly scheduled meeting. In other words, if the CPE is greater than

1.0833 times the Study Estimate or is less than 0.875 times the Study Estimate SPP staff will re-evaluate the project.

The CPE received from the DTO will be used as the established baseline cost estimate for reporting all future cost

estimate changes during the Project Tracking process for the project and will be the basis for determining project

cost variances. If a CPE has been provided in response to a NTC-C, an NTC Project Estimate will not be required

upon issuance of an NTC.

5.2. For all projects that have been issued an NTC

5.2.1. Non-Competitive

Projects

If the DTO accepts the NTC for a non-Competitive Project, it shall respond as prescribed in the NTC letter and

provide SPP with a refined Study Estimate as applicable. This estimate is referred to as the NTC Project Estimate

(NPE), as described in Section 8.4.

The NPE received from the DTO for these projects will be used as the established baseline cost estimate for

reporting all future cost estimate changes during the Project Tracking process and will be the basis for determining

project cost variances

The baseline cost estimate for a Legacy Project shall be established as the value submitted in Project Tracking as of

January 31, 2014, listed on the 2014 Quarter 2 SPP Project Tracking Report and approved by the Board.

5.2.2. Competitive

Projects

If the Selected RFP Respondent accepts the NTC for a Competitive Project, it shall respond within seven (7)

calendar days of receiving the notice as described in Attachment Y of the SPP OATT. Once the conditions listed in

Attachment Y are met, the Selected RFP Respondent will become the DTO.

The cost estimate provided in the response to the RFP by the DTO for a Competitive Project will be used as the

established baseline cost estimate for reporting all future cost estimate changes during the Project Tracking process

and will be the basis for determining project cost variances. This estimate is referred to as the RFP Response

Estimate (RRE), as described in Section 8.5.

Where a Competitive Project is required to interconnect with an existing facility, the DTO for the Competitive

Project and the incumbent TO of the existing facility shall negotiate in good faith the parameters of that

interconnection consistent with the obligations of the Membership Agreement.

6.3. Stakeholder Request for Project Re-Study

Deleted: OD

Deleted: ¶

Deleted: .

Deleted: OD

A stakeholder wishing to have an NTC/NTC-C Project restudied must provide SPP with the necessary model changes

needed to study the modification of the Project in the appropriate models. If SPP determines that a change has occurred

that could cause an NTC/NTC-C for a Project to be modified, SPP will perform the necessary analysis to determine if

the Project modification meets the Network Upgrade Justification of the original Project as described in Section 4.3.

For a Project modification to be deemed reasonable, it must meet or exceed the Network Upgrade Justification of

the original Project.

6.4. Notifications if NTC/NTC-C is Modified

If SPP determines that an NTC/NTC-C Project modification is reasonable, it will inform the TWG, MOPC, and

Board of this fact at their next regularly scheduled quarterly meeting and request the Board approval or endorsement,

as necessary, to issue an NTC/NTC-C modification.

After the Board approves or endorses the NTC/NTC-C modification, SPP will issue a modified NTC/NTC-C, as

needed.

7.1. Stakeholder Request for Project Re-studied for Withdrawal

A stakeholder wishing to have an NTC/NTC-C Project re-studied for withdrawal must provide SPP with the necessary

information needed to study the removal of the Project from the appropriate models. If SPP determines that changes

have occurred that could render an NTC/NTC-C for an approved Project unnecessary, SPP will perform any

necessary analysis and will, in consultation with stakeholders, determine if the Project is still required. Consideration

of NTC/NTC-C withdrawal will take into account the stage of development of the Project and discussion with the

DTO.

If SPP confirms that an NTC/NTC-C Project is unnecessary, it will inform the TWG, PCWG, MOPC, and Board of

this fact at their next regularly scheduled meeting and request approval by the Board, as necessary, to withdraw the

NTC/NTC-C.

After the Board approves the withdrawal of an NTC/NTC-C, SPP will notify the DTO that the NTC/NTC-C has been

withdrawn. If the NTC/NTC-C was due to a Service Agreement, then the NTC/NTC-C withdrawal shall not need

TWG, MOPC, or Board approval but shall be addressed by SPP staff. SPP staff will work in coordination with the

DTO to properly and safely stop all activities on the Project.

7.3 NTC Suspension

An NTC Suspension is a directive from the Board to suspend all activities and future expenditures for the suspended

Project for a time period specified by the Board and until the Board takes further action on the NTC. The Board may

suspend an NTC for any Project being restudied by SPP. If the Board suspends an NTC, SPP will issue a notice of

the suspension to the DTO within 15 business days of the Board approval to suspend the NTC. The notice will

provide the timeframe of the restudy for the Project. SPP will work in coordination with the DTO to properly and

safely suspend all activities on the Project.

8.1. Conceptual Estimate Stage

The Conceptual Estimate is the estimate prepared by SPP staff based on historical cost information in an SPP

database and updated information provided by the TO(s). It is to be used as a screening tool to determine if a project

is cost-effective and whether it should be pursued in meeting a determined system need. This estimate would not

attempt to address detailed environmental, geography, terrain or other issues.

In this first stage, SPP staff will develop the initial project scope and Conceptual Estimate using a cost estimate tool

(database platform) that will be developed in conjunction with the TO(s). The cost estimating tool will include

historical SPP cost data such as construction costs per mile for specific voltage levels, substation construction cost

estimates, and construction cost modifiers for other relevant factors such as differences in region, terrain,

urban/rural, etc. This will allow cost estimates to be developed to more readily accommodate the screening of large

numbers of potential projects and selecting suitable candidates for further study.

The output of the cost estimate tool will be a table providing the total cost estimate for each project under

consideration, as well as all of the supporting information for each cost estimate. This will provide an easy-to-use

reference for the Conceptual Estimates and the ability to determine variations between them. SPP staff, in conjunction

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with the Transmission Owners, will update the cost data used in the cost estimate tool on an annual basis. To support

these updates, SPP staff will provide an aggregate summary of final cost data collected in the Project Tracking

process. This will ensure the cost estimate tool is kept up-to-date for Conceptual Estimates and will help refine the

tool to reflect a better estimate of actual costs.

The Study Estimate (including escalation) is expected to be within a -50% to +100% variance from

the final project cost.

8.3. NTC-C Project Estimate Stage

The NTC-C Project Estimate (CPE) is the estimate prepared by a DTO for an Applicable Project after the receipt

of an NTC-C. This estimate will include any cost estimate analysis, as described in Section 2. The CPE will be

used as the established baseline for reporting all cost estimate changes during the Project Tracking process and will

be the basis for determining project variance. The NTC-C Project Cost Estimate (CPE) provided is expected to be

within a +/- 20% precision bandwidth of the final project cost.

The CPE shall be submitted to SPP by the DTO on or before the date stated in the NTC-C letter.

For Applicable Projects originating outside the ITP process, the CPE shall be due four months prior to the start of

the next ITP Assessment (note: ITP Assessment described in Attachment O of the SPP OATT).

For Applicable Projects originating from a non-ITP Assessment, the CPE shall be due 6 months after the date in

which the NTC-C is issued.

If the CPE variance bandwidth of -20% to +20% does not exceed the Study Estimate variance bandwidth of -30% to

+30%, as described in Section 5.1, the project’s cost variance will be deemed acceptable and the conditions, as

described in Section 2, on the NTC will be removed by SPP staff. SPP staff will issue a revised NTC letter to the

DTO removing the conditions from the NTC. This will be the authorization for the DTO to proceed with the

project.

If the CPE variance bandwidth exceeds the variance bandwidth of -30% to +30%, as described in Section 5.1, of the

Study Estimate, SPP staff will re-evaluate this project using the new cost estimate data, and will make a

recommendation to the Board at its next scheduled quarterly meeting.

SPP staff’s recommendation could be, but is not limited to, one of the following actions:

a. Accept the cost estimate variance and approve the Applicable Project as described in the NTC-C letter and

remove the NTC’s conditions;

b. Modify the existing Applicable Project with input from TWG;

c. Replace the Applicable Project with an alternative solution with input from TWG; or

d. Cancel the Applicable Project.

If the cost estimate variation of the CPE is accepted by the Board, the CPE will be used as a final baseline cost

estimate for reporting all future cost estimate changes during the Project Tracking process and will be the basis for

determining project cost variances.

8.4. NTC Project Estimate Stage

The NTC Project Estimate (NPE) is provided by the DTO after receipt of an NTC for a non-Applicable, non-

Competitive Project. It includes any additional cost or project information that is known at the time that the DTO is

required to provide its response to the SPP. The NPE will be used as the established baseline for reporting all cost

estimate changes during the Project Tracking process and will be the basis for determining project variance. The

NPE (including escalation) is expected to be within a -20% to + 20% variance from the final project cost.

This stage begins after a non-Applicable, non-Competitive Project has been issued an NTC. The DTO has 90 days

to respond to the NTC by committing to a project as required by the NTC or proposing a different project schedule

or project specifications to be considered by SPP. If the DTO accepts the NTC, it shall respond as prescribed in the

Deleted: final project cost

Deleted: Study Estimate

Deleted: OD

Deleted: OD


Deleted: NPE

SPP NTC letter with a written commitment to construct letter and a NPE both submitted to SPP within the 90-day

response period.

NTCs provided as result of NTC-C are not required to submit an NPE since baseline estimate was set upon

acceptance of CPE.

Although not required by Business Practice 7060,Staff will compare the NPE for a project to the Study Estimate

and may recommend a reevaluation of the project at their discretion.

8.5. RFP Response Estimate Stage

The RFP Response Estimate (RRE) is the cost estimate provided by the DTO included in its response to an RFP

for a Competitive Project. The RRE will be used as the established baseline for reporting all cost estimate changes

during the Project Tracking process and will be the basis for determining project variance. The RRE is expected to

be within a -20% to + 20% variance from the final project cost.

8.6. Baseline Cost Escalation

The established baseline is the version of a cost estimate that can only be changed through formal change control

procedures and is used as a basis for comparison.

All cost estimates established as baselines will be escalated annually. SPP will escalate any cost estimate for an

Upgrade that is considered a baseline estimate at the escalation rate assumed in the source study that originated the

need for the Upgrade. The new escalated baseline cost estimate will be used for comparison with any updated cost

estimate submitted in the same calendar year to measure cost estimate variance.

Baseline cost escalation for an upgrade will cease upon the DTO providing SPP one of the following:

x Letter of commercial operation

x SCERT update listing the upgrade as “in-service”

x SCERT update listing the upgrade as “complete”

8.7. Design and Construction Estimate Stage

Design and Construction Estimates (DCE) are provided by the DTO to SPP while the DTO engineering and

construction are being completed, including any environmental, routing or siting requirements, and that has a known

route. This would include but not be limited to any known material and labor costs and condemnation costs. The

final project cost is expected to be within a -20% to + 20% variance from the applicable CPE, NPE, or RRE.

This stage covers the period between the start of design engineering to the final project closeout and the subsequent

submittal of actual project costs to SPP through the Project Tracking process. All line-item cost differences between

the cost estimate being used as an established baseline and these updated cost estimates must be accompanied by a

detailed explanation from the DTO and updated SCERT.

Table 1: Cost Estimate Stage Definition Overview

Estimate Name Stage End Usage Precision

Bandwidth

Non-Competitive Projects Competitive

Projects

Projects >

100 kV& >

$20 Million

All other Board

Approved

Projects

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Formatted Table

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Conceptual (SPP Prepared)

1 1 1

Concept

screening for

ITP

Assessmen

t

-50% to + 100%

Study 2 2

2

Study of

feasibility and

plan

development for

ITP Assessment

-30% to +30%

NTC-C

Issued NTC Issued RFP Issued

NTC-C

Project

(CPE)

3 N/A N/A Established

baseline

(NTC-C)*

-20% to +20%

New NTC

Issued

NTC

Project

(NPE)

N/A

3

N/A

Established

baseline

(NTC)*

-20% to +20%

RFP

Response

(RRE)

N/A

N/A

3

Established

baseline

(RFP

Response)*

-20% to +20%

NTC Issued

Design &

Construction

(DCE)

4 4 4

Design after

NTC issued to

build the project

-20% to +20%**

*Board approval required to reset the baseline. **Final cost is expected to be within +/-20% of established baseline estimate.

9. Standardized Cost Estimate Reporting Template (SCERT) SPP will request the completion of a Standardized Cost Estimate Reporting Template (SCERT) for all project cost

estimates and applicable monthly/quarterly updates. The SCERT template is located on the SPP website on the

Project Cost Working Group webpage. The SCERT will:

a. Provide a consistent format among all estimates

b. Facilitate the Project Tracking process

c. Ensure the required level of detail is provided

d. Facilitate the transition of a completed project into the proper Annual Transmission Revenue

Requirement (ATRR) recovery process through SPP’s OATT

For each Legacy Project, the DTO authorized to construct the Legacy Project will populate a SCERT if the cost

estimate of the project increases 10% or greater than the established baseline cost estimate.

For a Competitive Project, the RRE shall be submitted through the RFP response form. After a commitment to

construct is accepted by SPP for a Competitive Project, the DTO shall submit all subsequent cost estimates through

the completion of a SCERT.

All information requested to be sent to SPP in this section shall be submitted to [email protected].

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9.1. Study Estimate Design Guide

For the Study Estimate, all estimate providers shall develop estimates based on the Study Estimate Design Guide. The

SCERT information provides a transparent process on what is provided in the cost estimate, including the

assumptions made on unknowns at the time the cost estimate was prepared.

10. PCWG Review Process for Applicable Projects The Project Cost Working Group (PCWG) review process applies to approved Applicable Projects once a

DTO has received an NTC from SPP and the project exceeds the stated bandwidths as described in Section 5.1.

All information requested to be sent to SPP in this section shall be submitted to [email protected].

If an Applicable Project deviates or is expected to deviate +/- 10% from its established baseline cost estimate, the

DTO shall provide all relevant data and information to SPP with an updated SCERT within 45 calendar days when

the DTO became aware of the deviation. SPP staff will then notify the PCWG. The PCWG may require the DTO to

provide monthly Project Tracking data after this notice from the DTO.

If an Applicable Project deviates or is expected to deviate +/-20% from its established baseline cost estimate the

DTO, within 45 calendar days when the DTO became aware of the deviation, notify SPP staff detailing the cost

estimate variances with an updated SCERT along with comments and explanations regarding the variances.

The PCWG will receive the updated scope and SCERT provided to SPP by the DTO including any Project Tracking

data updates, any comments from the DTO related to cost estimate variances, and any applicable input from SPP staff.

The DTO’s comments should include relevant information regarding any sunk costs, an explanation for the cost

estimate variances, and comments regarding whether construction of the project should continue. The PCWG will

oversee all reports to be submitted to the MOPC, RSC, and Board prior to their regularly scheduled meetings.

11. Projects Reviewed by PCWG

The PCWG will provide recommendations to the MOPC and Board regarding any Applicable Project whose cost

estimate exceeded the +/-20% bandwidth of the established baseline (including escalation as described in Secton 8.6)

cost estimate. Recommended action(s) may include any of the following:

i. Accept the cost estimate deviation as reasonable and acceptable and reestablish the baseline

used to evaluate future cost estimate deviations.

ii. Identify all or a portion of the costs related to the variances and recommend any changes to the

NTC that would reduce the cost or avoid the issues that may be causing the increase.

iii. Issue an NTC Suspension on the project while SPP restudies the project to determine

appropriate changes to the NTC, possible withdrawal of the NTC or whether an alternative project

should replace the project.

The Board will make the final determination on whether to accept the PCWG recommendation(s) or to choose an

alternative action.

If the Board determines to reestablish the baseline cost estimate, the previous baseline cost estimate will be retained

in the monitoring tool.

The PCWG will notify MOPC if a trend appears to be developing whereby the information provided in the SCERTs

is deviating from the Study Estimate Design Guide. The MOPC will then determine if a review of the SCERT

indicates changes in the Study Estimate Design Guide are required.

12. Project Reporting

12.1. SPP Staff

On a quarterly basis the SPP staff shall post:

the status of the upgrades identified in the STEP on the SPP website

any NTC/NTC-C(s) issued during the quarter

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any NTC/NTC-C withdrawal(s) issued during the quarter

any NTC(s) modifications issued during the quarter

At least quarterly, SPP staff will submit a Project Tracking report to the PCWG detailing all Applicable Project

cost estimates.

12.2. Project Reporting Responsibility.

DTOs constructing a Project(s) with an approved RRE, NPE, or CPE shall submit Project Tracking updates to SPP

staff on a quarterly basis, unless the bandwidth is exceeded as denoted in (a) or (b) below, in which case the DTO

will notify SPP within 45 calendar days with the information as follows:

a. If an Applicable Project cost estimate deviates +/-10% from its escalated baseline cost estimate,

the PCWG may request additional information from the DTO detailing the cost estimate variances

along with comments and explanations regarding the variances. PCWG will monitor these projects

and take appropriate action if necessary.

b. If an Applicable Project cost estimate deviates +/-20% from its escalated baseline cost estimate,

the DTO will notify SPP staff detailing the cost estimate variances with an updated SCERT along

with comments and explanations regarding the variances. SPP staff will provide the updated

information to the PCWG. The PCWG will review and provide recommendations to the MOPC and

Board. The PCWG will also provide an update to the RSC. The PCWG may request monthly

updates regarding project cost estimates and other relevant information from a DTO until Board action

is taken.

13. NTC Project Close-out and Validation Process

For SPP to validate a Network Upgrade has been constructed and placed into service pursuant to the NTC, the DTO

shall provide the following to SPP in addition to the reporting requirements described in Section 12.2:

Indication of Commercial Operation submitted in Quarterly Project Reporting updates

All pertinent modeling information to the SPP Engineering Department through the Models On Demand

(MOD) system; Actual cost amount to-date of Network Upgrade as reflected through one of the following methods:

o Base Plan Funded Network Upgrades – submitted through formula rate updates. Amount to-date costs

submitted through quarterly project tracking may be used if formula rate information is not yet available. o Non-Base Plan Funded Network Upgrades – submitted through the Project Tracking update process and;

All pertinent Geographical Information Systems (GIS) data to the SPP Engineering Department through an

appropriate file sharing platform (only applicable to Network Upgrades that include greenfield

transmission projects).

Once all the required information has been provided to, and validated by SPP staff, the status of the Network Upgrade

will be marked as “Closed-out” on the next quarterly Project Tracking report, and will not appear on subsequent

quarterly reports.

On a quarterly basis, SPP staff will notify DTOs of projects that have been in service 18 months or more and are not

closed out. Notification will indicate items required to close out the project.

If a DTO does not provide the requirements listed above for a Network Upgrade within two calendar years after the

in-service date reported in Project Tracking, SPP staff will provide a report to the following organizational groups, in

escalation based on the length of time the information is delinquent:

i. Level 1 – Report provided to PCWG after 2-year delinquency is identified. PCWG may determine that

delinquency is justified. If so, PCWG would review delinquency on a quarterly basis prior to Level 2 escalation.

ii. Level 2 – Report provided to MOPC and RSC at their next regularly scheduled meetings

iii. Level 3 – Report provided to Board at its next regularly scheduled meeting if delinquent three months

after Level 2 report. Subsequently, reports provided to Board each regularly scheduled meeting until

delinquency is resolved.

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RRE, NPE, or CPE

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with no corrective action expected. SPP staff

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¶

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SPP staff will report to the MOPC, RSC, and Board if an actual cost reveals a deviation of +/-20% of the established

baseline cost.

Actual costs will continue to be tracked for all Network Upgrades after they are closed-out, as there could be additional

costs identified by the DTO and submitted to SPP. SPP staff will report the updated actual costs of a closed-out

project to the MOPC, RSC, and Board if the updated actual cost of the project deviates +/-20% from the established

baseline cost.

APPENDIX A: Sample NTC for A Non-Competitive Project

SPP Notification to Construct

201 Worthen Drive SPP-NTC-#

Little Rock, AR 72223-4936

501-614-3220 • Fax: (501) 666-0376

[SPP CONTACT]

[SPP CONTACT TITLE]

[DATE]

[DESIGNATED TRANSMISSION OWNER]

[ADDRESS]

RE: Notification to Construct [Approved Reliability Network Upgrades/Network Upgrades Pursuant to

Transmission Service Request]

Dear [DESIGNATED TRANSMISSION OWNER],

Pursuant to Section 3.3 of the Southwest Power Pool, Inc. (“SPP”) Membership Agreement and Attachments O and

Y of the SPP Open Access Transmission Tariff (“OATT”), SPP provides this Notification to Construct (“NTC”)

directing [DESIGNATED TRANSMISSION OWNER], as the Designated Transmission Owner, to construct the

Network Upgrade[s].

On [DATE], the Southwest Power Pool (“SPP”) [Board of Directors approved the Network Upgrade(s) listed

below to be constructed] OR [concluded that the Project is required on the [DESIGNATED

TRANSMISSION OWNER] system to fulfill Transmission Service Requests as detailed in Aggregate Facility

Study SPP-200#-AG#-AFS-##] OR [Insert the appropriate reason to construct the Project if different than listed above].

Project ID: PID #

Project Name: Project Name

Need Date for Project: DATE

Estimated Cost for Project: $###,###

Date of Estimated Cost: MM/DD/YYYY

Estimated Cost Source: Estimated Cost Source

Network Upgrade ID: UID #

Network Upgrade Name: Network Upgrade Name

Network Upgrade Description: Network Upgrade Description

Network Upgrade Owner: Owner Information

MOPC Representative: Representative Information

TWG Representative: Representative Information

Categorization: Regional Reliability / Zonal Reliability / Economic / Service

Network Upgrade Specifications: Network Upgrade Specifications

Network Upgrade Justification: Network Upgrade Justifications

Estimated Cost for Network Upgrade (currrent day dollars): $###,###

Cost Allocation of the Network Upgrade: Base Plan Funded / Direct Assigned to Customer / Sponsored

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Deleted: Estimated In-Service Date for Project: IN-

SERVICE DATE PROVIDED BY NETWORK UPGRADE

OWNER DURING AGGREGATE STUDY¶

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Deleted: Need Date for Network Upgrade:

Network Upgrade Need Date

Network Upgrade / Other Estimated Cost Source: Network Upgrade Owner / Network Upgrade Sponsor/ SPP


[In the event the NTC is a modification to or withdrawal of an existing NTC, the following will be listed in

addition to or instead of the above: Previous NTC number, Previous NTC Issue Date, and Reason for Change.]

Commitment to Construct

Please provide to SPP a written commitment to construct the Network Upgrade(s) no later than (NTC letter date + 90 days) MM/DD/YYYY, in addition to providing a construction schedule and an updated and an updated ±20% cost estimate in the Standardized Cost Estimate Reporting Template for the Network Upgrade(s). Failure to provide a sufficient written commitment to construct as required by the SPP OATT could result in the Network Upgrade(s) being assigned to another entity.

Mitigation Plan The Need Date the timing required for the Network Upgrade(s) to address the identified need. Your prompt attention

is required for formulation and approval of any necessary mitigation plans for the Network Upgrade(s) if the Need

Date is not feasible. Additionally, if it is anticipated that the completion of any Network Upgrade will be delayed

past the Need Date OR Estimated In- Service Date, SPP requires a mitigation plan, including an idev file, be filed

within 60 days of the determination of expected delays.

Notification of Commercial Operation Please submit a notification of commercial operation for each listed Network Upgrade to SPP the Network Upgrade is complete and in-service. The DTO must provide SPP with the actual costs of these Network Upgrades

as soon as possible after completion of construction. Timely cost notification will facilitate the timely billing by

SPP based on actual costs.

Notification of Progress On an ongoing basis, please keep SPP advised of any inability on [DESIGNATED TRANSMISSION OWNER]’s part to complete the approved Network Upgrade(s). For project tracking, SPP requires [DESIGNATED

TRANSMISSION OWNER] to submit status updates of the Network Upgrade(s) quarterly in conjunction with the

SPP Board of Directors meetings. However, [DESIGNATED TRANSMISSION OWNER] shall also advise SPP

of any inability to comply with the Project Schedule as soon as the inability becomes apparent.

All terms and conditions of the SPP OATT and the SPP Membership Agreement shall apply to this Project, and

nothing in this NTC shall vary such terms and conditions.

Don't hesitate to contact me if you have questions or comments regarding these instructions. Thank you for the

important role that you play in maintaining the reliability of our electric grid.

Sincerely,

[SPP CONTACT SIGNATURE]

[SPP CONTACT TITLE]

cc: SPP COO, SPP Vice President of Engineering, SPP Director, Transmission Services, SPP Director,

Planning, [MOPC REPRESENTATIVE(S)], [email protected], [TWG REPRESENTATIVE(S)].

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Deleted: <object>

Deleted: The DTO must provide to SPP a written commitment to

construct the Network Upgrade(s) within 90 days of the date of

this Notification to Construct, in addition to providing a

construction schedule for the Network Upgrade(s).¶

Failure to provide a written commitment to construct as required

by the SPP OATT could result in the Network¶

Upgrade(s) being assigned to another entity.¶

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calendar days after

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APPENDIX B: Sample NTC-C

SPP

Notification To Construct with Conditions

201 Worthen Drive

Little Rock, AR 72223-4936

501-614-3220 • Fax: (501) 666-0376

[SPP CONTACT]

[SPP CONTACT TITLE]

SPP-NTC-#

[DATE]

[DESIGNATED TRANSMISSION OWNER]

[ADDRESS]

RE: Notification to Construct with Conditions [Approved Reliability Network Upgrades/Network Upgrades

Pursuant toTransmission Service Request/Generation Interconnection Upgades]

Dear [DESIGNATED TRANSMISSION OWNER],

Pursuant to Section 3.3 of the Southwest Power Pool, Inc. (“SPP”) Membership Agreement and Attachments O and

Y of the SPP Open Access Transmission Tariff (“OATT”), SPP provides this Notification to Construct (“NTC”)

directing [DESIGNATED TRANSMISSION OWNER], as the Designated Transmission Owner, to construct the

Network Upgrade[s]. This NTC is Conditioned upon the [DESIGNATED TRANSMISSION OWNER] not

ordering materials or beginning construction until:

(1) the DTO submits a refined project cost estimate (CPE) to SPP staff that has a variance bandwidth of -20% to

+20% that does not exceed the Study Estimate variance bandwidth of -30% to +30% as provided for in SPP’s

Business Practices; or

(2) the SPP Board of Directors considers SPP Staff’s re-evaluation of a project that has a refined project cost

estimate (CPE) from the DTO that exceeds the Study Estimate variance bandwidth of -30% to +30% as provided for

in SPP’s Business Practices.

On [DATE], the Southwest Power Pool (“SPP”) [Board of Directors approved the Network Upgrade(s) listed

below to be constructed] OR [concluded that the Project is required on the [DESIGNATED

TRANSMISSION OWNER] system to fulfill Transmission Service Requests as detailed in Aggregate Facility

Study SPP-200#-AG#-AFS-##] OR [Insert the appropriate reason to construct the Project if different than listed above].

Project ID: PID #

Project Name: Project Name

Need Date for Project: DATE

Estimated Cost for Project: $###,###

Network Upgrade ID: UID #

Network Upgrade Name: Network Upgrade Name

Network Upgrade Description: Network Upgrade Description

Network Upgrade Owner: Owner Information

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Deleted: Estimated In-Service Date for Project: IN-

SERVICE DATE PROVIDED BY NETWORK UPGRADE


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MOPC Representative: Representative Information

TWG Representative: Representative Information

Categorization: Regional Reliability / Zonal Reliability / Economic / Service Network Upgrade Specifications: Network Upgrade Specifications

Network Upgrade Justification: Network Upgrade Justifications

Need Date for Network Upgrade: Network Upgrade Need Date

Estimated Cost for Network Upgrade (current day dollars): $###,###

Cost Allocation of the Network Upgrade: Base Plan Funded / Direct Assigned to Customer / Sponsored

Network Upgrade / Other

Estimated Cost Source: Network Upgrade Owner / Network Upgrade Sponsor/ SPP


[In the event the NTC-C is a modification to or withdrawal of an existing NTC-C, the following will be listed

in addition to or instead of the above: Previous NTC–C number, Previous NTC-C Issue Date, and Reason for

Change.]

Commitment to Construct The DTO shall provide to SPP a written commitment to construct the Network Upgrade(s) no later than (NTC Date + 90 days) MM/DD/YYYY. Failure to provide a written commitment to construct could result in the Network Upgrade(s) being assigned to another entity.

NTC-C Project Estimate (CPE) Also, the DTO shall provide SPP a CPE by [DATE] as described in SPP’s Business Practice No. 7060 regarding Notification to Construct with Conditions. [DESIGNATED TRANSMISSION OWNER] shall advise SPP of any

inability to provide the CPE by [DATE] as soon as the inability becomes apparent.

Removal of Conditions Upon notice by SPP staff of removal of the conditions contained in this NTC, SPP staff will issue the DTO a new NTC and the following will be applicable:

Mitigation Plan The Need Date represents the timing required for the Network Upgrade(s) to address the identified need. Your

prompt attention is required for formulation and approval of any necessary mitigation

plans for the Network Upgrade(s) if the Need Date is not feasible. Additionally, if it is anticipated that the completion

of any Network Upgrade will be delayed past the Need Date, SPP requires a mitigation, including ide file, plan be

filed within 60 days of the determination of expected delays.

Notification of Commercial Operation Please submit a notification of commercial operation for each listed Network Upgrade to SPP as soon as the Network Upgrade is complete and in-service. Please provide SPP with the actual costs of these Network Upgrades

as soon as possible after completion of construction.

Notification of Progress On an ongoing basis, please keep SPP advised of any inability on [DESIGNATED TRANSMISSION OWNER]’s

part to complete the approved Network Upgrade(s). For project tracking, SPP requires [DESIGNATED

TRANSMISSION OWNER] to submit status updates of the Network Upgrade(s) quarterly in conjunction with the

SPP Board of Directors meetings. However, [DESIGNATED TRANSMISSION OWNER] shall also advise SPP

of any inability to comply with the Project Schedule as soon as the inability becomes apparent.

All terms and conditions of the SPP OATT and the SPP Membership Agreement shall apply to this Project, and

nothing in this NTC shall vary such terms and conditions.

Don't hesitate to contact me if you have questions or comments regarding these instructions. Thank you for the

important role that you play in maintaining the reliability of our electric grid.

Sincerely,

[SPP CONTACT SIGNATURE]

[SPP CONTACT TITLE]

Deleted: Estimated In-Service Date for Network Upgrade:

IN-SERVICE DATE PROVIDED BY NETWORK UPGRADE


Deleted: Cost

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Deleted: within 90

Deleted: days of the¶

date of this Notification to Construct.

Deleted: ¶



Deleted: OR Estimated In- Service Date

Deleted: This will facilitate the timely billing by SPP based on

actual costs.

cc: SPP COO, SPP Vice President of Engineering, SPP Director, Transmission Services, SPP Director,

Planning, [MOPC REPRESENTATIVE(S)], [email protected], [TWG REPRESENTATIVE(S)].


of 18

APPENDIX C: Cost Estimation Process


of 18

APPENDIX D: Quarterly Project Tracking Process
