southwest power pool, inc. project cost working … minutes...overlap between mod and scert...
TRANSCRIPT
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 5, 2019
AEP Office, 41st Floor
• AGENDA •
8:30 AM – 2:30 PM
1. Administrative Items ..................................................................................................................... (5 min)
a. Call to Order & Introductions ..................................................................... Tom Hestermann
Tom Hestermann called the meeting to order at 8:30 and asked the group for introductions.
b. Anti-trust Language ............................................................................................ John O’Dell
John O’Dell reviewed the anti-trust language with the group.
c. Receipt of Proxies .............................................................................................. John O’Dell
John O’Dell took receipt of proxies:
Teddy Hutchinson for David Insinger (OPPD)
d. Review of Agenda ..................................................................................... Tom Hestermann
2. Review of Past Action Items* .................................................................................. John O’Dell (10 min)
Action item 200-In progress-Agenda Item 12- Description is updated for clarity.
Brian Johnson presented at May, 2019 CAWG on differences between AACE guidelines for cost
estimate accuracy and accuracy required by SPP Business Practice 7060.
3. Consent Agenda (Approval Items)* .................................................................. Tom Hestermann (5 min)
a. Approval of Meeting Minutes – March 4, 2019
Tom Hestermann reviewed the consent agenda with the group.
Motion to approve March 2019 minutes with the following changes was made:
Add Attendance Roster
Update item 11 to reflect Business Practice 7060, not 760
The motion passed unanimously
4. NTC Withdrawal 200420 Pecos Interchange 230/115 kV Transformer* ................... John O’Dell (5 min)
Group reviews posted information. SPS states that no money has been spent.
5. NTC Withdrawal 200234 Renfrow Cap Bank* ........................................................... John O’Dell (5 min)
Group reviews posted information. NTC Issuance date Oct 28 2013.
6. NTC Withdrawal 200437 Heizer 115/69 kV Transformer* ........................................ John O’Dell (5 min)
Group reviews posted information. PCWG requests that NTC Issuance Date and Total
Expenditures to date are included in the slide presentation. NTC issuance date is Feb 8 2017.
Break: 9:09 – 9:20
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.
7. Line - Iatan - Stranger 345 kV Ckt 1 Voltage Conversion (Approval Item)* ....... Brenda Jessop (30 min)
PCWG reviews posted material on this rebuild.
Motion to accept is made and seconded.
The motion passed unanimously
8. Quarterly Report Review* (Approval Item) .............................................................. John O’Dell (30 min)
Group reviews posted information. Discussion ensues regarding Total Cost Estimate for > 300
Type in Executive Summary, Total cost and variance cost for ITP10 2012 in Appendix 2
Discussion ensues on why some Baseline estimates are more than the Study estimates.
Group discusses replacing Study estimate with original baseline estimate in Appendix 3. This
change will begin in Q4 2019. PCWG requests changing the order in the table of the estimate
columns. Discussion about Complete and In Service status and the difference between the 2
ensues. John states that we will cover this in more detail later in the day…
A motion to accept with changes as discussed is made and seconded
The motion passed unanimously
9. Action Item 195 Review Training Video (Approval Item) ......................................... John O’Dell (30 min)
John would like to push this to later in the day as he is having technical difficulties.
Video is reviewed after Item 13. There were comments regarding the video and audio quality. PCWG
requests this material to be posted as PowerPoint presentation with audio and script included for
each slide.
Break 10:11 – 10:26
10. Action Item 202 – MDSTF Member Availability* ..................................................... John O’Dell (10 min)
John leads the group on this item. Discussion ensues and action item 202 is marked complete.
11. Action Item 198 – BP 7060 Modification for Grandfathered Applicable Projects* (Approval
Item)…............................................................................................................... John O’Dell (30 min)
PCWG reviews posted material. Group modifies language. Discussion ensues on combining all
BP 7060 revisions to a single RR. .
Motion to accept with changes as discussed is made and seconded
The motion passed unanimously
Lunch break 11:11 – 11:40
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.
12. Action Item 200 – Discuss Close-Out Requirements* (Approval Item) ................... John O’Dell (30 min)
PCWG reviews posted material. Brenda questions, 2nd item…Do a non-planned upgrade receive
upgrades? Brian answers that yes they do. Intent of revision is not to require final SCERTs for
close-out, but language does not prohibit SPP from requesting a final SCERT if they wish.
Motion to accept as submitted is made and seconded
The motion passed unanimously
13. Action Item 204 – Update on Appendix C for BP 7060* (Approval Item) ................ John O’Dell (30 min)
PCWG reviews posted material. There are concerns on how the flow charts are structured. More
discussion again about bundling Agenda items11-13 into a single RR. Tom states we will table
Action item 204 until a future date. Items Agenda items11-12 will now be combined into a single RR.
14. Summary of Action Items .......................................................................................... John O’Dell (5 min)
Updates to minutes from previous meeting
Add Action Item 205 and roster to previous meeting minutes
Revisions to the report
Submit RR for action items 198 and 200
Edits to the charts in action item 204 will be continued in conjunction with page turn review of
Business Practice 7060
Close Action Item 202
15. Develop Agenda for Next Meeting .................................................................... Tom Hestermann (5 min)
Chair requests page turn of Business Practice 7060, but isn’t sure if we will meet next via conference
call or just wait until next face-to-face.
16. Future Meeting Dates and Locations ..................................................................................... All (30 min)
July 2019 meeting will be canceled
a. Discuss alternate locations for PCWG meetings
Denver, Kansas City, and remaining in Dallas were talked about. No one seemed that
interested in moving
Meeting adjourned at 1:05
Upcoming Meetings: July 2, 2019 Net Conference August 7, 2019 Net Conference September 4, 2019 AEP Dallas Office October 2, 2019 Net Conference November 6, 2019 Net Conference December 4, 2019 AEP Dallas Office
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.
January 8, 2020 Net Conference * Background Materials Included
Antitrust Statement
This memorandum is to inform you of a new process endorsed by the Oversight Committee on January 29, 2018 requiring that an antitrust notice be provided for all SPP stakeholder meetings
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.
1
Southwest Power Pool, Inc.
Project Cost Working Group
Pending Action Items Status Report
June 5, 2019, 8:30 AM to 2:30 PM
No Action Item Date
Originated Status Comments
13
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 7, 2012
Ongoing MOPC Action item complete. Ongoing project to identify improvements
195 Research creation of training
materials for new TAGIT-SCERT users
April 4, 2018
In Progress
Agenda Item 9
Staff will incorporate PCWG feedback into training video. Video will be revised upon implementation of action item 178. Staff to create final version of training video to include action item 178.
198
Investigate potential changes to BP 7060 that would designate future upgrades where an NTC is not issued by SPP but are base plan funding through inclusion in a Tariff attachment as “Applicable”.
June 6, 2018
In Progress
Agenda Item 11
Proposed RR draft included in meeting materials. Staff will research establishing baseline where no NTC is issued. Staff will research whether or not SPP can issue NTCs for Integration Projects. Staff proposed language change to Section 8.6 that would include “integrated” projects and not include GI projects. Research whether or not an NTC could be issued in future cases. Concern is that without language requiring NTC for such projects, there is no guarantee that an NTC would be issued. PCWG reviewed and agreed that changing Section 2.2 in BP 7060 would be more efficient than changing Tariff to issue NTCs for these projects.
No Action Item Date
Originated Status Comments
200
Create list of Upgrades with potential to be closed out. Identify outstanding items required for close-out process.
December 5, 2018
In Progress
Agenda Item 12
PCWG would like to defer action on staff recommendation in order to continue to address issues discussed and possible revision to BP 7060. PCWG agreed on language to revise BP 7060 Section 13 to remove final SCERT as a criteria for close out. Staff will research overlap between MOD and SCERT information to identify any gaps. Mod is a platform for submitting change to existing models. There is no data overlap between models and SCERT. Staff sees no issue with proceeding on this revision.
201
Staff to present history of Conceptual, Study, CPE, & NPE bandwidths to PCWG.
December 5, 2018
In Progress
Staff will discuss internally and report back with findings on potential for change.
202
Research availability of current MDSTF members
December 5, 2018
In Progress
Agenda Item
10Complete
Staff will provide additional Update in April, 2019.
203
SPP Staff will advise of Study Cost Estimate windows for 2020 ITP assessment.
March 2019 In
Progress
Rough Estimate from staff was 4-5 months before estimated study cost estimate windows will be available.
204
Research Revision to BP 7060 to clarify NTC-C reevaluation in Appendix C.
March 2019
In Progress
Agenda Item 13
If formal RR is required, draft staff will draft a recommendation. Revision of BP 7060 for Action Items 198, 200, & 204 should be handled in a single RR if possible.Table for inclusion with page turn of BP 7060
205
Create reference materials for ITP and non-ITP processes. Post materials to PCWG home page on SPP.org
March 2019 In
progress See Agenda Item 7 materials of March 2019, slides 8 & 9.
Withdrawal of NTC for Upgrades 51578, 51566, & 50626SPP Staff
6/5/2019
1
Background
2
Business Practice 7060, Section 7.1 states:
• If SPP confirms that an NTC/NTC-C Project is unnecessary, it will inform the TWG, PCWG, MOPC, and BOD of this fact at their next regularly scheduled meeting and request approval by the BOD, as necessary, to withdraw the NTC/NTC-C.
• After the BOD 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 BOD 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.
SPP NTC 200237 –Withdrawal
3
Transmission Owner: MIDW
Network Upgrade ID: 51578
Network Upgrade Name: Heizer 115/69 kV Ckt 4 Transformer
Network Upgrade Description: Upgrade the 115/69 kV transformer at Heizer (HEIZER T4) to achieve 44.8 MVA
RTO Determined Need Date: 6/1/2021
Baseline Including Escalation: $2,862,839
Current Estimate: $2,663,963
Cost Variance: -7%
Applicable Project: No
Reason for Change: Upgrade identified in SPP-2015-AG2-AFS-3. MIDW requested re-evaluation of this upgrade on 1/28/2019 via RMS. SPP staff determined that the upgrade is no longer required.
SPP NTC 200420 –Withdrawal
4
Transmission Owner: SPS
Network Upgrade ID: 51566
Network Upgrade Name: XFR - Pecos 230/115 kV Transformer Upgrade
Network Upgrade Description: Upgrade 230/115 kV transformer at Pecos
RTO Determined Need Date: 6/1/2021
Baseline Including Escalation: $3,596,726
Current Estimate: $3,681,706
Cost Variance: 3.6%
Applicable Project: No
Reason for Change: Upgrade identified in SPP-2015-AG1-AFS-6. SPS requested re-evaluation of this upgrade on 1/24/2019 via RMS. SPP staff determined that the upgrade is no longer required.
SPP NTC 200234 –Withdrawal
5
Transmission Owner: WFEC
Network Upgrade ID: 50626
Network Upgrade Name: Renfrow-Sandridge Capacitor 138 kV
Network Upgrade Description: Install new 138 kV 4.8-Mvar capacitor at Renfrow-Sandridge substation
RTO Determined Need Date: 6/1/2017
Baseline Including Escalation: $214,548
Current Estimate: $185,004
Cost Variance: -38.6%
Applicable Project: No
Reason for Change: Upgrade identified in DPAs-2012-MAR-151,154,161, JUL-218, SEP-243. WFEC requested re-evaluation of this upgrade on 1/22/2019 via RMS. SPP staff determined that the upgrade is no longer required.
Project Review: Line - Iatan - Stranger 345 kV Ckt 1 Voltage ConversionPCWG 6/5/2019
2
Line - Iatan - Stranger 345 kV Ckt 1 Voltage Conversion
3
INCORRECT MAP. This must be
replaced with CORRECT MAP
Project 30850 Cost History
4
Project Cost Overview
5
Upgrade ID Owner Upgrade Scope
51151 KCPLInstall any terminal upgrades required at Iatan to convert existing 18.2-mile 161 kV line from Iatan to Stranger Creek to 345 kV operation
51283 GMOConvert GMO's portion of the existing 18.2-mile 161 kV line from Iatan to Stranger Creek to 345 kV operation
51284 WRConvert WR's portion of the existing 18.2-mile 161 kV line from Iatan to Stranger Creek to 345 kV operation. Install any necessary terminal equipment at Stranger Creek
Upgrade ID OwnerBaseline Cost
Estimate(Adj. for Inflation)
Latest Variance Var. %
51151 KCPL $3,513,894 $3,005,339 ($508,555) -14.5%
51283 GMO $6,716,567 $6,582,841 ($133,726) -2.0%
51284 WR $30,163,706 $21,977,566 ($8,186,140) -27.1%
Total $40,394,167 $31,565,746 ($8,828,421) -21.9%
Project In-ServiceDate
6/1/2018
51151 - Iatan 345 kV Voltage Conversion
6
Future Projection (Confidence Level)
Low<50%
Medium50-80%
High>80%
Estimate the probability that final cost will be within +/- 20% of updated cost estimate.
x
Upgrade Cost Estimates
Baseline Cost Estimate ($) $3,513,894
Updated Cost Estimate from Quarterly Update ($) $3,005,339
Variance Amount (Updated less Baseline) ($) ($508,555)
51151 Major Factors Contributing to Variance Variance
Engineering Labor
($124,597)
Construction Labor
Replace 3 KCPL double circuit structures due to line terminal location move to south.
($379,454)
Material $652,542
Escalation ($250,894)
AFUDC ($68,152)Contingency ($338,000)
Total ($508,555)
51283 Iatan - Stranger Creek 345 kV Ckt 1 Voltage Conversion (GMO)
7
Future Projection (Confidence Level)
Low<50%
Medium50-80%
High>80%
Estimate the probability that final cost will be within +/-20% of updated cost estimate.
x
51283 Major Factors Contributing to Variance VarianceEngineering
Labor$173,330
Construction Labor
$719,042
Right-of-Way ($112,851)
Material $175,286
Escalation ($479,567)AFUDC ($101,966)
Contingency ($507,000)Total ($133,726)
Upgrade Cost Estimates
Baseline Cost Estimate ($) $6,716,567 Updated Cost Estimate from Quarterly Update ($) $6,582,841 Variance Amount (Updated less Baseline) ($) ($133,726)
51284 Iatan - Stranger Creek 345 kV Ckt 1 Voltage Conversion (WR)
8
Future Projection (Confidence Level)
Low<50%
Medium50-80%
High>80%
Estimate the probability that final cost will be within +/- 20% of updated cost estimate.
x
51284 Major Factors Contributing to Variance Variance
Engineering LaborRequired additional line engineering for tire land fill that was close to centerline.
$272,548
Construction LaborObtained favorable fixed firm price contract for line work and 2, 345kV breakers were replaced prior to project due to failures reducing labor costs.
($3,727,212)
Right-of-WayWas able to use existing ROW; only required to purchase additional footage on both sides.
($1,183,582)
MaterialBreakers were replaced by maintenance due to failure prior to project construction.
($123,923)
Escalation ($2,153,706)
AFUDCProject was less than originally planned and done in a shorter window, therefore, reducing the AFUDC carrying costs.
($1,270,265)
ContingencyTotal ($8,186,140)
Upgrade Cost Estimates
Baseline Cost Estimate ($) $30,163,706
Updated Cost Estimate from Quarterly Update ($) $21,977,566
Variance Amount (Updated less Baseline) ($) ($8,186,140)
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.
9
PCWG QUARTERLY
REPORT June 5, 2019
Southwest Power Pool, Inc.
REVISION HISTORY
DATE OR
VERSION NUMBER AUTHOR
CHANGE
DESCRIPTION COMMENTS
06/05/2019 Staff Initial Draft
06/06/2019 Staff Revision 1 Revised as discussed at PCWG
meeting on 6/5/2019
Southwest Power Pool, Inc.
CONTENTS
Revision History ......................................................................................................................................................................... i
Executive Summary ................................................................................................................................................................ 1
Background ................................................................................................................................................................................ 2
Review Process ......................................................................................................................................................................... 3
Business Practice 7060 ........................................................................................................................................................................... 3
Process Changes ......................................................................................................................................................................................... 3
Projects Outside of Precision Bandwidth (+/-20%) .................................................................................................................. 4
Projects Currently +/- 10% of Baseline Estimate ....................................................................................................................... 5
Observed Trends ...................................................................................................................................................................... 6
Minimum Design Standards Task Force ........................................................................................................................ 7
Recommendations................................................................................................................................................................... 8
Appendix 1 ................................................................................................................................................................................. 9
Appendix 2 ............................................................................................................................................................................... 10
Appendix 3 ............................................................................................................................................................................... 11
Appendix 4 ............................................................................................................................................................................... 14
Southwest Power Pool, Inc.
PCWG Quarterly Report 1
EXECUTIVE SUMMARY
There are fifty-two (52) Applicable Projects and four (4) Projects that are not Applicable included in
this report. Of the fifty-two (52) Applicable Projects, fifteen (15) active Applicable Projects1 are 300 kV
and above and thirty-seven (37) 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). Four (4)
Projects in this report do not meet the criteria to be considered Applicable Projects, but are tracked
since they are specifically designated for cost allocation under Attachment J, Section III.A.2 of the SPP
Open Access Transmission Tariff (OATT) and have cost estimates greater than $20 million. Of the
Applicable Projects in Appendix 1, one (1) reported an updated cost estimate that is outside the
established precision bandwidth during this quarter.
The list of all active Projects subject to PCWG review is included in Appendix 1 to this report. Appendix
2 summarizes all reported Projects based on source study.
Table 1 below summarizes the cost estimates of active Applicable Projects in Appendix 1 with
established baseline estimates2. Table 2 below summarizes items not considered to be Applicable
Projects in Appendix 1.
Type No. of
Projects
Total Baseline Cost Estimate Amount (adj. for inflation)
Total Cost Estimate
Variance Var. %
> 300 15 $2,001,618,805
$1,909,425,197 ($92,193,608)
-4.6%
100 - 300
37 $1,422,401,632 $1,324,252,732 ($98,148,900) -6.9%
Total 52 $3,424,020,438 ($3,233,677,93)
($190,342,508)
-5.6%
Table 1: Active Applicable Project Cost Estimate Summary
Type No. of
Projects
Total Baseline Cost Estimate Amount (adj.
for inflation)
Total Cost Estimate
Variance Var. %
> 300 3 $365,184,438 $208,843,318 ($156,341,119) -42.8% 100 - 300
1 $42,993,512 $38,000,000 ($4,993,512) -11.6%
Total 4 $408,177,950 $246,843,318 ($161,334,631) -39.5% Table 2: Non-Applicable Project Cost Estimate Summary
1 Applicable Projects are defined in Business Practice 7060 as those that have an estimated cost greater than $20 million and a nominal operating voltage greater than 100 kV which SPP has authority to direct. 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.
Southwest Power Pool, Inc.
PCWG Quarterly Report 2
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 Scott Brunnert, OG&E, TO Randy Diede, WAPA, TO James Ging, KPP, TU Jamie Hajek NWE, TU Travis Hill, NPPD, TO David Insinger, OPPD, TO Brenda Jessop, KCP&L and Westar, Evergy Companies, TO Jonah Martin, Tri-State G&T, TU Kenny Munsell, SPS, TO David Sonntag, WFEC, TO Boyd Trester, Basin Electric, TO Shawnee Claiborn-Pinto, Public Utility Commission of Texas (CAWG Liaison) John O’Dell, SPP Staff Secretary
Southwest Power Pool, Inc.
PCWG Quarterly Report 3
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 fifty-two (52) Applicable Projects and four (4) Projects that are not Applicable included in
this report. Of the fifty-two (52) Applicable Projects, fifteen (15) active Applicable Projects3 are 300 kV
and above and thirty-seven (37) 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). Four (4)
Projects in this report do not meet the criteria to be considered Applicable Projects, but are tracked
since they are specifically designated for cost allocation under Attachment J, Section III.A.2 of the SPP
Open Access Transmission Tariff (OATT) and have cost estimates greater than $20 million. Of the
Applicable Projects in Appendix 1, one (1) reported an updated cost estimate that is outside the
established precision bandwidth during this quarter.
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.
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 are fifteen (15) Applicable Projects that were moved from the purview of Business Practice 7050
to Business Practice 7060, four (4) of which are still active and included in Appendix 1.
3 Applicable Projects are defined in Business Practice 7060 as those that have an estimated cost greater than $20 million and a nominal operating voltage greater than 100 kV which SPP has authority to direct.
Southwest Power Pool, Inc.
PCWG Quarterly Report 4
PROJECTS 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 this quarter.
Line - Iatan - Stranger 345 kV Ckt 1 Voltage Conversion SPP identified this Project as part of the Integrated Transmission Planning 10-Year ("ITP10") Assessment. On January 27, 2015, the SPP Board of Directors approved the Network Upgrade(s) listed below to be constructed per results 2015 ITP10. On February 25, 2015, SPP Issued Notification to Construct (NTC) 200328 to Kansas City Power and Light Company (KCPL). KCPL accepted NTC 200328 on May 18, 2015 and provided a cost estimate of $3,263,000 for their portion of the Project. On February 25, 2015, SPP Issued Notification to Construct (NTC) 200337 to Kansas City Power & Light Company, Greater Missouri Operations (KCPL GMO). KCPL GMO accepted NTC 200337 on May 18, 2015 and provided a cost estimate of $6,237,000 for their portion of the Project. On February 25, 2015, SPP Issued Notification to Construct (NTC) 200338 to Westar Energy, Inc. Westar accepted NTC 200338 on May 22, 2015 and provided a cost estimate of $28,010,000. At the time of issuance of NTCs 200328, 200337, and 200338, SPP estimated project costs totaled $15,726,289. Upon acceptance of NTCs above, the DTOs submitted cost estimates totaling $37,510,000. Line - Iatan - Stranger 345 kV Ckt 1 Voltage Conversion became an Applicable Project pursuant Section 2.2 of Business Practice 7060 at that time. On July 28, 2015, SPP Board of Directors approved suspension of activities and future expenditures related to NTCs 200327, 200337, and 200338. This decision was based on Section 6.1 of Business Practice 7060 to allow re-evaluation the project due to study cost estimates used in the 2015 ITP10 ($15.7 million) increasing 133% to ($37.5 million) after NTC issuance. In February, 2016, NTC for these upgrades was reinstated. Between May 1, 2019 and May 13, 2019, the following cost estimate updates were entered:
KCPL Upgrade ID 51151 - $1,885,731 KCPL GMO Upgrade ID 51283 - $7,688,424 Westar Upgrade ID 51284 - $21,977,566
Total cost for the Line - Iatan - Stranger 345 kV Ckt 1 Voltage Conversion project is $31,551,721, which
is a -21.9% variance to the escalated baseline amount.
Evergy (KCPL, GMO and Westar) noted the following reasons for cost Decreases:
Line Sub-Total - Obtained favorable construction contract and conversion of ROW was less
than if being built on new route
Station Sub-Total - Construction and Materials were significantly less than estimated as two
345kV breakers were replaced by Maintenance prior to Substation construction due to
failures
AFUDC - Project costs were less than originally planned and completed in a shorter window,
reducing AFUDC This project went into service on June 1, 2018.
Southwest Power Pool, Inc.
PCWG Quarterly Report 5
PROJECTS CURRENTLY +/- 10% OF BASELINE ESTIMATE Projects listed in Appendix 3 are within Business Practice 7060’s bandwidth of +/-20% but are over the
+/-10% threshold developed by the PCWG to raise attentiveness to the cost estimates related to these
projects. There are twenty-three (23) projects in the list this quarter.
Southwest Power Pool, Inc.
PCWG Quarterly Report 6
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.
Southwest Power Pool, Inc.
PCWG Quarterly Report 7
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.
Southwest Power Pool, Inc.
PCWG Quarterly Report 8
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.
Of the Applicable Projects presented in Appendix 1, one (1) reported updated cost estimates that were
outside the established precision bandwidth during this quarter.
Line - Iatan - Stranger 345 kV Ckt 1 Voltage Conversion PCWG recommends that the MOPC and Board accept the cost estimate deviation for Line - Iatan -
Stranger 345 kV Ckt 1 Voltage Conversion as reasonable and acceptable and reset the baseline used to
evaluate future cost estimate deviations.
Southwest Power Pool, Inc.
PCWG Quarterly Report 9
APPENDIX 1
{See accompanying list of active Applicable Projects}
Southwest Power Pool, Inc.
PCWG Quarterly Report 10
APPENDIX 2
Active Projects Summary by Source Study
Source Study No. of
Projects Total Study
Estimate
Total Baseline Estimate With
Escalation
Total Latest Cost
Variance Var. %
2012 ITP10 4 $774,735,922 $814,390,434 $802,849,274 ($11,541,160) -1.4%
2012 ITPNT 1 $9,132,270 $38,743,378 $38,607,163 ($136,215) -0.4%
2013 ITPNT 6 $232,482,551 $243,001,377 $212,796,439 ($30,204,938) -12.4%
2014 ITPNT 7 $331,564,915 $354,439,566 $332,058,251 ($22,381,315) -6.3%
2015 ITP10 1 $15,726,289 $40,394,167 $31,551,721 ($8,842,446) -21.9%
2015 ITPNT 4 $116,513,757 $144,182,784 $135,295,733 ($8,887,051) -6.2%
2016 ITPNT 5 $151,435,957 $155,466,869 $156,472,108 $1,005,239 0.6%
2016 ITPNT/HPILS
1 $133,612,272 $143,787,186 $128,605,777 ($15,181,409) -10.6%
2017 ITPNT 1 $21,780,000 $22,883,663 $21,781,000 ($1,102,663) -4.8%
Ag Studies 1 $11,000,000 $25,635,637 $22,598,424 ($3,037,213) -11.8%
DPA Studies 8 $375,563,007 $407,015,405 $401,586,736 ($5,428,669) -1.3%
HPILS 10 $416,425,485 $503,484,001 $454,474,823 ($49,009,178) -9.7%
IS Integration Study4
4 $383,400,000 $408,177,950 $246,843,318 ($161,334,631) -39.5%
Priority Projects 3 $535,191,250 $530,595,971 $495,000,480 ($35,595,491) -6.7%
Grand Total 56 $3,508,563,676 $3,832,198,387 $3,480,521,248 ($351,677,139) -9.2%
4 Projects associated with this study do not meet the criteria to be considered Applicable Projects, but are tracked since
they are specifically designated for cost allocation under Attachment J, Section III.A.2 of the SPP Open Access
Transmission Tariff (OATT) and have cost estimates greater than $20 million.
Southwest Power Pool, Inc.
PCWG Quarterly Report 11
APPENDIX 3
Projects Currently within +/- 20% but outside of +/- 10% Baseline Estimate
PID Project Name Project Owner
Voltage Class (kV)
Status Projected In-Service
Date
Study Estimate
Latest Cost Escalated Baseline Estimate
Variance Latest to Esc.
Baseline
Variance Pct. To
Esc. Baseline
772 Line - Carlisle -
Wolfforth 230 kV SPS
100 - 300
IN SERVICE 3/27/2018 $32,790,576 $29,400,000 $36,690,708 ($7,290,708) -19.9%
805 Multi - Bowers -
Howard 115 kV Ckt 1 SPS
100 - 300
COMPLETE 2/28/2016 $25,557,920 $42,796,163 $36,480,174 $6,315,989 17.3%
939 Line - Nebraska City - Mullin Creek 345 kV
(OPPD) OPPD > 300 COMPLETE 12/15/2016 $19,500,000 $59,170,665 $72,120,820 ($12,950,155) -18.0%
30364
Multi - Woodward District EHV - Tatonga
- Matthewson - Cimarron 345 kV
OGE > 300 COMPLETE 2/15/2018 $206,966,741 $159,885,990 $198,746,648 ($38,860,658) -19.6%
30375 Multi - Gentleman - Cherry Co. - Holt Co.
345 kV NPPD > 300 DELAYED 5/1/2021 $287,900,000 $408,565,094 $363,420,807 $45,144,287 12.4%
30376 Multi - Hobbs -
Yoakum 345/230 kV Ckt 1
SPS > 300 ON
SCHEDULE 6/1/2020 $69,907,711 $101,035,365 $120,424,792 ($19,389,427) -16.1%
30469
Multi - Kilgore Switch - South Portales -
Market St. - Portales 115 kV
SPS 100 - 300
COMPLETE 7/11/2018 $24,951,218 $24,573,313 $30,581,497 ($6,008,184) -19.6%
30484
Multi - Viola 345/138kV
Transformer and 138 kV Lines to Clearwater
and Gill
WR 100 - 300
IN SERVICE 11/16/2018 $78,162,713 $56,429,542 $68,743,648 ($12,314,106) -17.9%
30496
Multi - Bobcat Canyon 345/115 kV and Bobcat Canyon -
Scottsbluff 115 kV
BEPC/NPPD 100 - 300
COMPLETE 10/26/2017 $35,000,000 $33,458,264 $37,622,786 ($4,164,522) -11.1%
Southwest Power Pool, Inc.
PCWG Quarterly Report 12
PID Project Name Project Owner
Voltage Class (kV)
Status Projected In-Service
Date
Study Estimate
Latest Cost Escalated Baseline Estimate
Variance Latest to Esc.
Baseline
Variance Pct. To
Esc. Baseline
30501 Multi - Renfrow -
Medford Tap - Chikaskia 138 kV
OGE/WFEC 100 - 300
COMPLETE 4/1/2016 $31,892,184 $21,832,236 $25,334,584 ($3,502,348) -13.8%
30560 Line - Sumner County -
Viola 138 kV Ckt 1 WR
100 - 300
DELAYED 6/1/2020 $51,513,963 $48,513,963 $58,283,321 ($9,769,358) -16.8%
30569 Multi - Potash Junction
- Road Runner 230/115 kV Ckt 1
SPS 100 - 300
COMPLETE 10/27/2015 $49,596,223 $62,043,951 $55,015,336 $7,028,615 12.8%
30619 Line - Darlington -
Roman Nose 138 kV Ckt 1
AEP/OGE 100 - 300
COMPLETE 6/29/2017 $26,416,440 $23,135,990 $25,892,128 ($2,756,138) -10.6%
30638 Multi - Kiowa - North Loving - China Draw
345/115 kV Ckt 1 SPS > 300 COMPLETE 5/30/2018 $62,619,690 $65,908,291 $74,636,957 ($8,728,666) -11.7%
30639
Multi - Potash Junction - Road Runner 345 kV
Conv. and Transformers at Kiowa and Road
Runner
SPS > 300 COMPLETE 4/27/2018 $21,560,659 $21,309,725 $25,585,269 ($4,275,544) -16.7%
30695 Multi - Livingston
Ridge - Sage Brush - Cardinal 115 kV
SPS 100 - 300
COMPLETE 11/30/2017 $26,257,165 $28,127,695 $33,671,134 ($5,543,439) -16.5%
30717 Line - Hopi Sub - North
Loving - China Draw 115 kV Ckt 1
SPS 100 - 300
COMPLETE 5/25/2015 $22,240,813 $21,154,466 $23,845,709 ($2,691,243) -11.3%
30732
Multi - Anthony - Bluff City - Caldwell -
Mayfield - Milan - Viola 138 kV Ckt 1
MKEC/WR 100 - 300
IN SERVICE 5/31/2018 $43,265,193 $41,787,223 $51,554,838 ($9,767,615) -18.9%
30850 Line - Iatan - Stranger 345 kV Ckt 1 Voltage
Conversion GMO/WR
100 - 300
COMPLETE 6/1/2018 $15,726,289 $32,574,155 $40,394,167 ($7,820,012) -19.4%
Southwest Power Pool, Inc.
PCWG Quarterly Report 13
PID Project Name Project Owner
Voltage Class (kV)
Status Projected In-Service
Date
Study Estimate
Latest Cost Escalated Baseline Estimate
Variance Latest to Esc.
Baseline
Variance Pct. To
Esc. Baseline
30914 Multi - Road Runner 115 kV Loop Rebuild
SPS 100 - 300
DELAYED 4/15/2019 $22,043,187 $18,815,589 $22,216,865 ($3,301,276) -14.9%
31032
Multi - Plaza 115 kV Substation and
Blaisdell - Plaza 115 kV New Line
BEPC 100 - 300
COMPLETE 2/1/2018 $19,042,308 $19,042,308 $21,225,300 ($2,182,992) -10.3%
31042
Multi - DeGrasse - Knob Hill 138 kV New
Line and DeGrasse 345/138 kV Transformer
OGE/WFEC 100 - 300
DELAYED 7/1/2020 $30,500,000 $34,458,334 $30,265,401 $4,192,933 13.9%
31068 Multi - Tuco - Yoakum
345/230 kV Ckt 1 SPS > 300 DELAYED 6/1/2020 $133,612,272 $128,605,777 $143,787,186 ($15,181,409) -10.6%
Southwest Power Pool, Inc.
PCWG Quarterly Report 14
APPENDIX 4
Quarter 3 2019 MAY Format Legend S M T W T F S
1 TOs submit updates 1 2 3 4
15 SPP staff notifies TOs & PCWG of cost estimates outside precision bandwidth of +/- 20%
5 6 7 8 9 10 11
12 13 14 15 16 17 18
19 20 21 22 23 24 25
17 TOs provide cost increase justifications
26 27 28 29 30 31
29 SPP staff prepares cost increase data for PCWG background Materials
31 SPP Staff prepares and submits Quarterly Project Tracking Report for MOPC
JUNE S M T W T F S
1
6 PCWG Face to Face 2 3 4 5 6 7 8
17 MOPC 9 10 11 12 13 14 15
30 RSC & BOD 16 17 18 19 20 21 22
23 24 25 26 27 28 29
30
JULY 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
Southwest Power Pool, Inc.
PCWG Quarterly Report 15
Quarter 4 2019 AUGUST Format Legend S M T W T F S
1 TOs submit updates 1 2 3
13 SPP staff notifies TOs & PCWG of cost estimates outside precision bandwidth of +/- 20%
4 5 6 7 8 9 10
11 12 13 14 15 16 17
18 19 20 21 22 23 24
15 TOs provide cost increase justifications
25 26 27 28 29 30 31
27 SPP staff prepares cost increase data for PCWG background Materials
29 SPP Staff prepares and submits Quarterly Project Tracking Report for MOPC
SEPTEMBER S M T W T F S
1 2 3 4 5 6 7
4 PCWG Face to Face 8 9 10 11 12 13 14
15 MOPC 15 16 17 18 19 20 21
28 RSC & BOD 22 23 24 25 26 27 28
29 30 31
OCTOBER
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
OwnerSource Study
Voltage
Class
(kV)
StatusIn-
ServiceComplete
Projected In-
Service DateStudy Estimate Latest Cost Baseline 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
Comment
461 Line - Curry - Bailey 115kV SPS 2012 ITPNT 100 - 300 COMPLETE Y Y 9/29/2016 $9,132,270 $38,607,163 $35,099,588 $3,507,575 10.0% 2012 $38,743,378 ($136,215) -0.4%
772 Line - Carlisle - Wolfforth 230 kV SPS 2013 ITPNT 100 - 300 COMPLETE Y Y 3/27/2018 $32,790,576 $29,400,000 $32,429,240 ($3,029,240) -9.3% 2013 $36,690,708 ($7,290,708) -19.9%
805 Multi - Bowers - Howard 115 kV Ckt 1 SPS DPA Studies 100 - 300 COMPLETE Y Y 2/28/2016 $25,557,920 $38,922,978 $33,951,078 $4,971,900 14.6% 2013 $36,480,174 $2,442,804 6.7%
936 Line - Valliant - NW Texarkana 345 kV AEP Priority Projects > 300 COMPLETE Y Y 12/16/2016 $131,451,250 $185,751,250 $185,751,250 $0 0.0% 2016 $185,751,250 $0 0.0%
938 Multi - Nebraska City - Mullin Creek - Sibley 345 kV (GMO) TSMO Priority Projects > 300 COMPLETE Y Y 12/15/2016 $384,240,000 $250,078,565 $266,072,098 ($15,993,533) -6.0% 2015 $272,723,900 ($22,645,335) -8.3%
939 Line - Nebraska City - Mullin Creek 345 kV (OPPD) OPPD Priority Projects > 300 COMPLETE Y Y 12/15/2016 $19,500,000 $59,170,665 $70,361,776 ($11,191,111) -15.9% 2015 $72,120,820 ($12,950,155) -18.0%
30160 XFR - Ft Smith 500/161 kV Ckt 3 OGE Ag Studies 100 - 300 COMPLETE Y Y 11/10/2017 $11,000,000 $22,598,424 $25,635,637 ($3,037,213) -11.9% 2017 $25,635,637 ($3,037,213) -11.8%
30361 Multi - Chisholm - Gracemont 345 kV AEP/OGE 2012 ITP10 > 300 COMPLETE Y Y 3/1/2018 $175,061,392 $121,366,069 $127,678,129 ($6,312,060) -4.9% 2017 $128,774,467 ($7,408,398) -5.8%
30364Multi - Woodward District EHV - Tatonga - Matthewson -
Cimarron 345 kVOGE 2012 ITP10 > 300 COMPLETE Y Y 2/15/2018 $206,966,741 $159,875,026 $178,212,300 ($18,337,274) -10.3% 2013 $198,746,648 ($38,871,622) -19.6%
30367 Multi - Elm Creek - Summit 345 kV ITCGP/WR 2012 ITP10 > 300 COMPLETE Y Y 3/1/2018 $104,807,789 $113,043,085 $113,049,038 ($5,953) 0.0% 2013 $123,448,513 ($10,405,428) -8.4%
30374 Multi - Hoskins - Neligh 345 kV NPPD 2014 ITPNT > 300 COMPLETE Y Y 6/8/2018 $98,697,720 $82,139,513 $81,544,517 $594,996 0.7% 2017 $80,053,595 $2,085,918 2.6%
30375 Multi - Gentleman - Cherry Co. - Holt Co. 345 kV NPPD 2012 ITP10 > 300 DELAYED N N 5/1/2021 $287,900,000 $408,565,094 $313,376,623 $95,188,471 30.4% 2013 $363,420,807 $45,144,287 12.4%
30376 Multi - Hobbs - Yoakum 345/230 kV Ckt 1 SPS HPILS > 300 ON SCHEDULE N N 6/1/2020 $69,907,711 $101,035,365 $106,833,199 ($5,797,834) -5.4% 2014 $120,424,792 ($19,389,427) -16.1%
30437Multi - Geary County 345/115 kV and Geary - Chapman 115
kVWR 2014 ITPNT 100 - 300 IN SERVICE Y N 12/13/2018 $64,658,982 $67,493,875 $64,658,982 $2,834,893 4.4% 2014 $71,371,418 ($3,877,543) -5.4%
30449 Line - 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 $25,060,655 $0 0.0% 2013 $26,987,585 ($1,926,929) -7.1%
30451 Line - Atoka - Eagle Creek 115 kV Ckt 1 SPS 2013 ITPNT 100 - 300 DELAYED N N 12/31/2018 $19,639,618 $22,500,000 $20,808,304 $1,691,696 8.1% 2013 $24,131,253 ($1,631,253) -6.8%
30469Multi - Kilgore Switch - South Portales - Market St. - Portales
115 kVSPS 2013 ITPNT 100 - 300 COMPLETE Y Y 7/11/2018 $24,951,218 $24,573,313 $27,029,587 ($2,456,274) -9.1% 2013 $30,581,497 ($6,008,184) -19.6%
30484Multi - Viola 345/138kV Transformer and 138 kV Lines to
Clearwater and GillWR 2013 ITPNT 100 - 300 IN SERVICE Y N 11/16/2018 $78,162,713 $56,198,001 $67,066,974 ($10,868,974) -16.2% 2017 $68,743,648 ($12,545,648) -18.2%
30488 Multi - Renfrow - Wakita - Noel Switch 138 kV WFEC DPA Studies 100 - 300 COMPLETE Y Y 4/30/2014 $28,722,401 $31,303,754 $30,722,401 $581,353 1.9% 2013 $30,772,401 $531,353 1.7%
30495 Sub - Messick 500/230 kV AEP 2013 ITPNT 100 - 300 COMPLETE Y Y 4/29/2016 $51,877,771 $55,064,470 $51,877,771 $3,186,699 6.1% 2013 $55,866,685 ($802,215) -1.4%
30496Multi - Bobcat Canyon 345/115 kV and Bobcat Canyon -
Scottsbluff 115 kVBEPC/NPPD 2014 ITPNT 100 - 300 COMPLETE Y Y 10/26/2017 $35,000,000 $33,461,003 $36,705,157 ($3,244,154) -8.8% 2016 $37,622,786 ($4,161,783) -11.1%
30501 Multi - Renfrow - Medford Tap - Chikaskia 138 kV OGE/WFEC DPA Studies 100 - 300 COMPLETE Y Y 4/1/2016 $31,892,184 $21,832,236 $25,246,084 ($3,413,848) -13.5% 2015 $25,007,557 ($3,175,321) -12.7%
30560 Line - Sumner County - Viola 138 kV Ckt 1 WR 2014 ITPNT 100 - 300 DELAYED N N 6/1/2020 $51,513,963 $48,513,963 $51,513,963 ($3,000,000) -5.8% 2014 $58,283,321 ($9,769,358) -16.8%
30569 Multi - Potash Junction - Road Runner 230/115 kV Ckt 1 SPS HPILS 100 - 300 COMPLETE Y Y 10/27/2015 $49,596,223 $59,848,300 $53,673,499 $6,174,801 11.5% 2014 $55,015,336 $4,832,964 8.8%
30578 Multi - Bailey Co. - Lamb Co. 115 kV SPS 2014 ITPNT 100 - 300 DELAYED N N 3/15/2022 $28,122,150 $52,657,687 $49,643,005 $3,014,682 6.1% 2016 $55,992,727 ($3,335,040) -6.0%
30581Line - Park Lane - Ahloso - Harden City - Frisco - Lula 69/138
kV Ckt 1 OGE 2014 ITPNT 100 - 300 COMPLETE Y Y 9/1/2016 $20,998,500 $23,661,107 $21,492,965 $2,168,142 10.1% 2014 $22,581,046 $1,080,061 4.8%
30588 Multi - Fremont - S991 E 161/69 kV Ckt 1 OPPD 2015 ITPNT 100 - 300 COMPLETE Y Y 4/30/2019 $35,091,946 $27,497,485 $27,497,485 $0 0.0% 2018 $28,184,922 ($687,437) -2.4%
30596 Multi - Broken Bow Wind - Ord 115 kV Ckt 1 NPPD 2014 ITPNT 100 - 300 COMPLETE Y Y 6/1/2018 $32,573,600 $24,131,103 $28,534,673 ($4,403,570) -15.4% 2018 $28,534,673 ($4,403,570) -15.4%
30619 Line - Darlington - Roman Nose 138 kV Ckt 1 AEP/OGE HPILS 100 - 300 COMPLETE Y Y 6/29/2017 $26,416,440 $23,135,990 $24,353,198 ($1,217,208) -5.0% 2014 $25,892,128 ($2,756,138) -10.6%
30622Multi - Knipe - SW Station - Linwood & Warwick Tap 138 kV
Ckt 1OGE HPILS 100 - 300 COMPLETE Y Y 5/11/2018 $28,572,000 $31,794,580 $30,884,580 $910,000 3.0% 2014 $34,090,798 ($2,296,218) -6.7%
30637 Multi - Hobbs - Kiowa 345 kV Ckt 1 SPS HPILS > 300 COMPLETE Y Y 3/24/2018 $65,989,591 $59,199,211 $58,767,041 $432,170 0.7% 2018 $58,767,041 $432,170 0.7%
30638 Multi - Kiowa - North Loving - China Draw 345/115 kV Ckt 1 SPS HPILS > 300 COMPLETE Y Y 5/30/2018 $62,619,690 $65,908,291 $67,617,399 ($1,709,108) -2.5% 2014 $74,636,957 ($8,728,666) -11.7%
30639Multi - Potash Junction - Road Runner 345 kV Conv. and
Transformers at Kiowa and Road RunnerSPS HPILS > 300 COMPLETE Y Y 4/27/2018 $21,560,659 $21,309,725 $23,178,991 ($1,869,266) -8.1% 2014 $25,585,269 ($4,275,544) -16.7%
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 $54,843,257 $0 0.0% 2015 $56,214,338 ($1,371,081) -2.4%
30695 Multi - Livingston Ridge - Sage Brush - Cardinal 115 kV SPS HPILS 100 - 300 COMPLETE Y Y 11/30/2017 $26,257,165 $28,127,695 $32,370,314 ($4,242,619) -13.1% 2016 $33,671,134 ($5,543,439) -16.5%
30717 Line - Hopi Sub - North Loving - China Draw 115 kV Ckt 1 SPS HPILS 100 - 300 COMPLETE Y Y 5/25/2015 $22,240,813 $21,154,466 $23,264,106 ($2,109,640) -9.1% 2014 $23,845,709 ($2,691,243) -11.3%
30732Multi - Anthony - Bluff City - Caldwell - Mayfield - Milan - Viola
138 kV Ckt 1MKEC/WR HPILS 100 - 300 IN SERVICE Y N 5/31/2018 $43,265,193 $42,961,200 $49,070,637 ($6,109,437) -12.5% 2016 $51,554,838 ($8,593,638) -16.7%
30817Line - Canyon West - Dawn - Panda - Deaf Smith 115 kV Ckt 1
RebuildSPS 2016 ITPNT 100 - 300 DELAYED N N 12/15/2018 $17,686,344 $12,411,424 $12,787,234 ($375,810) -2.9% 2018 $12,838,627 ($427,203) -3.3%
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 $31,551,721 $37,510,000 ($5,958,279) -15.9% 2015 $40,394,167 ($8,842,446) -21.9%
30912 Multi - Walkemeyer Tap - Walkemeyer 345/115 kV SEPC/SPS 2015 ITPNT 100 - 300 COMPLETE Y Y 6/30/2018 $20,965,055 $34,139,402 $35,090,177 ($950,775) -2.7% 2017 $37,626,062 ($3,486,660) -9.3%
30914 Multi - Road Runner 115 kV Loop Rebuild SPS 2015 ITPNT 100 - 300 DELAYED N N 4/15/2019 $22,043,187 $18,815,589 $21,866,137 ($3,050,548) -14.0% 2018 $22,157,461 ($3,341,872) -15.1%
30943 Multi - AVS - Charlie Creek 345 kV BEPC IS Integration Study > 300 COMPLETE Y Y 6/1/2016 $108,000,000 $58,376,741 $108,000,000 ($49,623,259) -46.0% 2014 $113,467,500 ($55,090,759) -48.6% Reviewed 3Q 2018
30944 Multi - Charlie Creek - Judson - Williston 345/230 kV BEPC IS Integration Study > 300 COMPLETE Y Y 1/1/2016 $126,400,000 $61,893,823 $126,400,000 ($64,506,177) -51.0% 2014 $132,260,875 ($70,367,052) -53.2% Reviewed 3Q 2018
30945 Multi - Judson - Tande - Neset 345/230 kV BEPC IS Integration Study > 300 COMPLETE Y Y 11/11/2017 $111,000,000 $88,572,754 $111,000,000 ($22,427,246) -20.2% 2014 $119,456,063 ($30,883,309) -25.9% Reviewed 2Q 2018
30946 Multi - Lower Brule - Witten 230 kV BEPC IS Integration Study 100 - 300 DELAYED N N 1/1/2018 $38,000,000 $38,000,000 $38,000,000 $0 0.0% 2014 $42,993,512 ($4,993,512) -11.6%
31021 Line - Mustang - Seminole 115 kV Ckt 1 New Line SPS 2016 ITPNT 100 - 300 DELAYED N N 9/15/2020 $14,323,305 $20,136,042 $19,736,026 $400,016 2.0% 2016 $21,253,541 ($1,117,499) -5.3%
31031Multi - Kummer Ridge - Roundup 345 kV New Line and Patent
Gate and Roundup 345/115 kV SubstationsBEPC 2016 ITPNT 100 - 300 COMPLETE Y Y 9/1/2016 $69,884,000 $70,424,000 $69,884,000 $540,000 0.8% 2016 $69,884,000 $540,000 0.8%
31032Multi - Plaza 115 kV Substation and Blaisdell - Plaza 115 kV
New LineBEPC 2016 ITPNT 100 - 300 COMPLETE Y Y 2/1/2018 $19,042,308 $19,042,308 $20,202,546 ($1,160,238) -5.7% 2016 $21,225,300 ($2,182,992) -10.3%
31042Multi - DeGrasse - Knob Hill 138 kV New Line and DeGrasse
345/138 kV TransformerOGE/WFEC 2016 ITPNT 100 - 300 DELAYED N N 7/1/2020 $30,500,000 $34,458,334 $28,807,044 $5,651,290 19.6% 2017 $30,265,401 $4,192,933 13.9%
31068 Multi - Tuco - Yoakum 345/230 kV Ckt 1 SPS 2016 ITPNT/HPILS > 300 DELAYED N N 6/1/2020 $133,612,272 $128,605,777 $133,520,696 ($4,914,919) -3.7% 2016 $143,787,186 ($15,181,409) -10.6%
41223 Line - New East Ruthville - SW Minot 115 kV New Line CPEC 2017 ITPNT 100 - 300 DELAYED N N 12/31/2019 $21,780,000 $21,781,000 $21,781,000 $0 0.0% 2017 $22,883,663 ($1,102,663) -4.8%
51254 Multi - Sheldon - Monolith 115 kV NPPD DPA Studies 100 - 300 DELAYED N N 1/1/2021 $39,300,207 $39,300,207 $39,300,207 $0 0.0% 2018 $40,282,712 ($982,505) -2.4%
51282 Multi - Park Community - Sunshine 138 kV WFEC DPA Studies 100 - 300 DELAYED N N 3/1/2021 $78,900,000 $85,750,000 $85,200,000 $550,000 0.7% 2018 $89,217,500 ($3,467,500) -3.9%
51327 Line - Cogar - OU SW 138 kV WFEC DPA Studies 100 - 300 ON SCHEDULE N N 3/1/2021 $31,100,000 $31,100,000 $31,100,000 $0 0.0% 2018 $31,877,500 ($777,500) -2.4%
61347 Multi - China Draw - Road Runner 345 kV SPS DPA Studies > 300 DELAYED N N 4/15/2020 $91,074,869 $89,647,302 $89,647,302 $0 0.0% 2019 $89,647,302 $0 0.0%
71347 Line - Eddy+B2:B57 County - Kiowa 345 kV New Line SPS DPA Studies > 300 ON SCHEDULE N N 6/1/2024 $49,015,426 $63,730,259 $63,730,259 $0 0.0% 2019 $63,730,259 $0 0.0%
Action Item 202 –MDSTF Member AvailabilityJune 5, 2019
John O’Dell
1
BackgroundAction Item 202 – Added December, 2018
Action Item: Research availability of current MDSTF members
Update provided in March, 2018
• Not all members had responded
2
MDSTF Member Availability
3
MDSTF Position Company Availability Comment
Jeff Stebbins Chair Tri County Not Available Not available
David
ParrishVice-Chair AEP Available
Doug
Bowman
Staff
SecretarySPP Available
Jay Dring Member NPPDLimited
Availability
Garrett
GraybillMember OGE Available
Erin Keeler Member ITCGP Not Available
Mark
KuhnenegelMember OPPD Available
Kenny
MunsellMember Xcel Available
Paul
SedlacekMember Evergy Not Available
Resigned upon Evergy merger.
Dan Slaven is Evergy rep. Paul
wishes to be considered for future
task forces of similar nature.
Dan Slaven Member Evergy Available
Clarence
SuppesMember SEPC Available
Conclusion• One member did not respond upon follow-
up
• 11 members listed
• 7 are available now and in future, if needed
• 1 has limited availability
• 3 not available
4
Recommendations• Maintain contact with available members
• Remove members who are not available from MDSTF web page
• PCWG Chair may solicit new members per Section 3.1 of the Bylaws
The Chair of any Organizational Group may appoint any ad hoc task forces as necessary to fulfill its mission. Task force appointments shall be made with due consideration of the various types and expertise of Members and their geographic locations.
5
Page 1 of 3
Revision Request Form
SPP STAFF TO COMPLETE THIS SECTION
RR #: Date:
RR Title: Grandfathered Applicable Projects
System Changes No Yes
Process Changes? No Yes
Impact Analysis Required? No Yes
SUBMITTER INFORMATION
Name: Company:
Email: Phone:
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
Clarification
Design Enhancement
New Protocol, Business Practice, Criteria, Tariff
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
Page 2 of 3
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.
BP 7060 defines “Applicable Projects” as construction projects, including Legacy Projects that SPP has the authority to direct
construction of, has a nominal operating voltage of 100 kV or above, and has a Study Estimate in excess of $20 million. There are
a limited number of cases where SPP funds projects that were not directed by SPP. Although PCWG can review cost changes for
these projects, current BP language does not consider these projects “Applicable” and does not require the same PCWG
recommendation for MOPC and Board as it does for other base plan funded upgrades. The objective of this RR is to allow all
future upgrades that are cost allocated in accordance with Attachment J, greater than 100 kV, and have estimates of $20 million or
more to be reviewed using the same methodology and decision structure as those currently defined as “Applicable” whether SPP
issues an NTC for the project or not.
Describe the benefits that will be realized from this revision.
This revision will allow upgrades that SPP did not direct construction of to be held to the same review standards for the Project
Cost Working Group as upgrades that SPP directs.
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.
Market Protocols
SPP Tariff (OATT)
SPP Operating Criteria
SPP Planning Criteria
Page 3 of 3
SPP Business Practices
2.2. Applicable Projects
Applicable Projects are construction projects, including Legacy Projects, that meet all of the following criteria:
Approved for construction under the Tariff or identified in the Tariff as a Base Plan Upgrade, except upgrades identified
through the Generator Interconnection process under Attachment V
Have a nominal operating voltage of 100 kV or above
Have a Study Estimate in excess of $20 million
A single Applicable Project may consist of multiple upgrades or multiple projects assigned to multiple DTOs. A non-Applicable
Project with a nominal operating voltage of 100 kV or above that has been issued an NTC will become an Applicable Project if either
its NTC Project Estimate (NPE) or any subsequent cost estimate exceeds $20 million. Applicable Projects will continue to be
Applicable Projects even if their subsequent cost estimates fall below $20 million.
For projects which did not receive an NTC from SPP, the initial cost estimate received from the project owner and reported in
Quarterly Project Tracking 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.
10. PCWG Review Process for Applicable Projects
The Project Cost Working Group (PCWG) process applies to approved Applicable Projects when the project exceeds the stated
bandwidths as described in Section 5.1.
Integrated Transmission Planning (ITP) Manual
Minimum Transmission Design Standards for Competitive Upgrades (MTDS)
Reliability Coordinator and Balancing Authority Data Specifications (RDS)
SPP Communications Protocols
Revision Request Process
Page 1 of 4
Revision Request Form
SPP STAFF TO COMPLETE THIS SECTION
RR #: Date:
RR Title: Modification of Close Out requirements
System Changes No Yes
Process Changes? No Yes
Impact Analysis Required? No Yes
SUBMITTER INFORMATION
Name: John O’Dell on behalf of Project Cost Working
Group Company: SPP
Email: [email protected] Phone: 501-688-8285
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
Clarification
Design Enhancement
New Protocol, Business Practice, Criteria, Tariff
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
Page 2 of 4
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: This revision will remove requirement for Transmission Owners to provide a final SCERT that includes as-built equipment
specifications before an upgrade can be closed out.
TOs will benefit by saving time that their staff has spent entering this information in the past.
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.
Market Protocols
SPP Tariff (OATT)
SPP Operating Criteria
SPP Planning Criteria
Page 3 of 4
SPP Business Practices
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:
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;
o Final SCERT that includes as-built equipment specifications; and
All pertinent Geographical Information Systems (GIS) data to the SPP Engineering Department through
the TruShare appropriate file sharing system (only applicable to Network Upgrades that include greenfield
transmission lines).
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.
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.
SPP staff will report to the MOPC, RSC, and BOD 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 BOD if the updated actual cost of the project deviates +/-20% from
the established baseline cost.
Integrated Transmission Planning (ITP) Manual
Formatted
Page 4 of 4
Minimum Transmission Design Standards for Competitive Upgrades (MTDS)
Reliability Coordinator and Balancing Authority Data Specifications (RDS)
SPP Communications Protocols
Revision Request Process
Page 1 of 4
Revision Request Form
SPP STAFF TO COMPLETE THIS SECTION
RR #: Date:
RR Title:
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: John O’Dell on behalf of PCWG Company: SPP
Email: [email protected] Phone: 501-688-8285
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
Page 2 of 4
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:
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:
This change will clarify Business Practice 7060 Appendix C where baseline estimates are set in the NTC-C process per Section 5.1
of that Business Practice.
This change will provide consistency in representation for establishing baselines for NTCs and NTC-Cs.
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.
Market Protocols
SPP Tariff (OATT)
SPP Operating Criteria
SPP Planning Criteria
Page 3 of 4
SPP Business Practices
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
Integrated Transmission Planning (ITP) Manual
Minimum Transmission Design Standards for Competitive Upgrades (MTDS)
Revision Request Process
Commented [JO1]: “Set Baseline Estimate” added for NTC-C
process
Page 4 of 4
Reliability Coordinator and Balancing Authority Data Specifications (RDS)
SPP Communications Protocols
Meeting Rooms and LogisticsJohn O’Dell 6/5/2019
1
Meeting Rooms & Logistics
Booking Process
Budgeting Process
Cost Saving Opportunities
Meeting Registration
2
Booking Process for Meetings
3
Meeting Form
• Provides all details and meeting specifics
• Plan ahead and send form as soon as possible
Booking
• Meeting is formally booked and confirmed
Posted on SPP.org
• Announcement to the group
Budgeting Process
4
Budgeting
Begins*
Budget Numbers
Must Be Turned In
* Information requested:
Months you plan to meet
City or Cities
Location (hotel, member company, SPP, AEP)
Expected number of attendees
Duration of meeting
Any major changes to your normal meeting set-up, catering, AV, etc.
• Meeting Locations:
Downtown Dallas (50 people)
Member companies
SPP offices
Certain cities/locations are more cost effective than others
Certain cities/locations are more expensive than others
5
Cost Saving Opportunities
• Don’t provide breakfast if meeting starts after 8:00 am or hotel provides free breakfast
• Hold lunch dessert for afternoon snack or no afternoon snack
• Take SPP owned AV equipment when possible
6
MORE Cost Saving Opportunities
Meeting Registration
Please encourage your groups to
REGISTER
REGISTER
REGISTER!…………..and
unregister if needed.
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8