Q3 2015 Quarterly Project Tracking Report
Transcript of Q3 2015 Quarterly Project Tracking Report
T h i r d Q u a r t e r l y P r o j e c t T r a c k i n g R e p o r t 2 0 1 5
July 2015
Southwest Power Pool, Inc.
Q3 2015 Project Tracking Report 1
Table of Contents
Executive Summary .....................................................................................................................................2
NTC Project Summary ................................................................................................................................4
NTC Issuance ...................................................................................................................................7
NTC Withdraw.................................................................................................................................8
Completed Projects ..........................................................................................................................8
Project Status Summary .................................................................................................................13
Balanced Portfolio ........................................................................................................................................14
Priority Projects ...........................................................................................................................................16
Out-of-Bandwidth Projects .........................................................................................................................17
Responsiveness Report ................................................................................................................................19
Appendix I ....................................................................................................................................................21
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Q3 2015 Project Tracking Report 2
Executive Summary
SPP actively monitors and supports the progress of transmission expansion projects, emphasizing the importance of maintaining accountability for areas such as grid regional reliability standards, firm transmission commitments and tariff cost recovery. Each quarter SPP staff solicits feedback from the project owners to determine the progress of each approved transmission project. This quarterly report charts the progress of all SPP Transmission Expansion Plan (STEP) projects approved either directly by the SPP Board of Directors (Board) or through a FERC filed service agreement under the SPP Open Access Transmission Tariff (OATT). The reporting period for this report is February 1, 2015 through April 30, 2015. Table 1 provides a summary of all projects in the current Project Tracking Portfolio (PTP), which includes all Network Upgrades in which construction activities are ongoing, or construction has completed but not all the close-out requirements have been fulfilled in accordance to Section 13 of Business Practice 7060. The PTP includes all active Network Upgrades including transmission lines, transformers, substations, and devices. Table 1 below summarizes the PTP for this quarter. Figures 1 reflects the percentage cost of each upgrade type in the PTP. Figure 2 shows the percentage cost of each project status in the PTP.
Upgrade Type No. of Upgrades Estimated Cost Miles of New
Miles of Rebuild
Miles of Voltage
Conversion Balanced Portfolio 4 $258,217,874 226.5 0.0 0.0 Economic 4 $37,914,101 0.0 0.0 28.8 High Priority 102 $2,215,684,294 1753.4 11.5 0.0 Regional Reliability 334 $3,156,305,363 1529.2 642.3 588.6 Transmission Service 23 $110,490,871 12.7 31.6 0.0 Zonal Reliability 9 $109,245,734 34.7 28.5 0.0
NTC Projects Subtotal 476 $5,887,858,237 3556.5 713.9 617.4 Generation Interconnection 35 $165,430,659 39.5 0.0 0.0 Regional Reliability - Non OATT 5 $23,567,090 0.0 11.8 0.0 TO - Sponsored 16 $92,968,646 12.0 0.0 46.0
Non-NTC Projects Subtotal 56 $281,966,395 51.5 11.8 46.0 Total 532 $6,169,824,632 3608.0 725.7 663.4
Table 1: Q2 2015 Portfolio Summary
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Figure 1: Percentage of Project Type on Cost Basis
4%
0.6%
3%
37%
52%
2% 2%
Balanced Portfolio
Economic
Generation Interconnection
High Priority
Regional Reliability
Transmission Service
Zonal Reliability
Figure 2: Percentage of Project Status on Cost Basis
27%
40%
6%
23%
0.1%1%
1% 0.3%1%
Complete
On Schedule < 4
On Schedule > 4
Delay - Mitigation
NTC Suspension
NTC - Commitment Window
NTC-C Project Estimate Window
RFP Response Window
Re-evaluation
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Q3 2015 Project Tracking Report 4
NTC Project Summary
In adherence to the OATT and Business Practice 7060, SPP issues Notifications to Construct (NTCs) to Designated Transmission Owners (DTOs) to commence the construction of Network Upgrades that have been approved or endorsed by the Board intended to meet the construction needs of the STEP, OATT, or Regional Transmission Organization (RTO). Figure 3 reflects project status within each source study, and Table 2 provides the supporting data. Figure 4 shows the amount of estimated cost by in-service year for all Network Upgrades that have been issued an NTC or NTC-C. Figure 5 shows the cost trend of all the Board-approved studies that have resulted in NTCs. Note: Figures 3, 4, and 5, and Table 2 provide data for all projects for which SPP has issued an NTC or NTC-C, regardless of completion date, and therefore include data from Network Upgrades no longer included in PTP.
Figure 3: Project Status by NTC Source Study
$0
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Suspended
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Complete
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Source Study Complete Delayed Suspended On Schedule Total
2006 STEP $230,534,912 $0 $0 $0 $230,534,912 2007 STEP $413,650,905 $28,719,000 $0 $0 $442,369,905 2008 STEP $416,912,051 $3,543,000 $0 $0 $420,455,051 Balanced Portfolio $803,531,390 $0 $0 $0 $803,531,390 2009 STEP $556,245,220 $15,049,555 $0 $0 $571,294,775 Priority Projects $847,352,680 $127,995,000 $0 $407,791,450 $1,383,139,130 2010 STEP $115,237,966 $22,570,306 $0 $27,149,017 $164,957,289 2012 ITPNT $142,718,959 $56,400,374 $0 $6,300,000 $205,419,334 2012 ITP10 $0 $0 $0 $770,463,719 $770,463,719 2013 ITPNT $121,849,435 $320,334,183 $0 $76,524,777 $518,708,394 2014 ITPNT $3,804,467 $390,988,996 $0 $265,090,771 $659,884,234 HPILS $53,858,906 $201,339,804 $0 $574,122,201 $829,320,911 2015 ITPNT $0 $153,245,705 $0 $142,860,151 $296,105,855 2015 ITP10 $0 $0 $0 $91,510,843 $91,510,843 Ag Studies $721,294,405 $87,979,996 $0 $68,157,416 $877,431,817 DPA Studies $109,182,972 $71,102,077 $0 $12,367,550 $192,652,599 GI Studies $359,171,590 $42,448,492 $10,588,285 $88,569,631 $500,777,998
Total $4,895,345,859 $1,521,716,488 $10,588,285 $2,530,907,525 $8,958,558,158 Table 2: Project Status by NTC Source Study
Figure 4: Estimated Cost for NTC Projects per In-Service Year
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New Q2 2015 NTC
IS Integration Projects
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Figure 5: Cost Trend per Board-Approved Study
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2007 2008 2009 2010 2011 2012 2013 2014 2015
2006 STEP
2007 STEP
2008 STEP
Balanced Portfolio
2009 STEP
Priority Projects
2010 STEP
2012 ITP10
2012 ITPNT
2013 ITPNT
2014 ITPNT
HPILS
$ M
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Southwest Power Pool, Inc.
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NTC Issuance Six NTCs were issued since the last quarterly report for approved projects with a total cost estimate of the included Network Upgrades totaling $48.7 million. One NTC was issued to Southwestern Public Service Company (SPS) as a result of the completion of Aggregate Study, SPP-2012-AG3-AFS-9. The total estimated cost of the Network Upgrades listed in the NTC is $15.5 million. One NTC was issued to Oklahoma Gas & Electric Co (OGE) after SPP was notified that an additional Network Upgrade was required on the OGE system to fully address issues identified in the 2013 Integrated Transmission Planning Near-Term Assessment (ITPNT). The total estimated cost of the Network Upgrade is $12,000. Three NTCs were issued as a result of the Board in June approving the Short-Term Reliability Projects identified in the 2015 ITPNT. The total estimated cost of the Network Upgrades listed in these NTCs is $32.5 million. One NTC was issued to Mid-Kansas Electric Company (MKEC) as the incumbent TO to construct the portion of the Competitive Project identified in the 2015 Integrated Transmission Planning 10-Year Assessment determined to be ineligible for the Transmission Owner Selection Process (TOSP). The total estimated cost of the Network Upgrade described in this NTC is $689 thousand. SPP issued a Request for Proposal (RFP) for the portion of the Competitive Project eligible for the TOSP on May 5, 2015. Table 3 summarizes the NTC activity from April 1, 2015 through June 30, 2015. NTC ID values in bold font indicate NTC-Cs.
NTC ID DTO NTC Issue
Date Upgrade Type Source Study
No. of Upgrades
Estimated Cost of New
Upgrades
Estimated Cost of
Previously Approved Upgrades
200297 SPS 5/5/2015
Transmission Service/Regional
Reliability SPP-2012-AG3-AFS-9 3 $15,486,751 $0
200340 OGE 5/7/2015 Regional Reliability 2013 ITPNT 1 $12,000 $0 200342 MKEC 6/30/2015 Regional Reliability 2015 ITP10 1 $689,063 $0 200343 SPS 6/30/2015 Regional Reliability 2015 ITPNT 4 $18,609,838 $0 200344 SEPC 6/30/2015 Regional Reliability 2015 ITPNT 2 $4,331,457 $0 200345 WR 6/30/2015 Regional Reliability 2015 ITPNT 1 $9,536,211 $0
Total 12 $48,665,321 $0 Table 3: Q2 2015 NTC Issuance Summary
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NTC Withdraw One NTC previously issued to MKEC was withdrawn since the last quarterly report. The NTC included Network Upgrades that were requested to be restudied by the DTO, and were determined to be no longer needed through the Aggregate Study process. Table 4 lists the NTC Withdraw activity from April 1, 2015 through June 30, 2015. NTC ID values in bold font indicate NTC-Cs.
NTC ID DTO NTC
Withdraw Date
Upgrade Type Original Source Study No. of Upgrades
Estimated Cost of Withdrawn
Upgrades 200341 MKEC 5/12/2015 Regional Reliability SPP-2011-AG3-AFS-11 2 $18,616,980
Total 2 $18,616,980 Table 4: Q2 2015 NTC Withdraw Summary
Completed Projects Twenty-two Network Upgrades with NTCs and two Generation Interconnection Network Upgrades were completed during the reporting period, totaling an estimated $138 million. Transource Missouri (TSMO) notified SPP that the new 30-mile 345 kV line from Iatan to Nashua in northwest Missouri was completed and placed into service on April 30, 2015. The project was identified and studied as part of the Balanced Portfolio report that was approved by the Board in April 2009. The project scope also included a new 345/161 kV transformer at Nashua. The original NTCs were issued to Kansas City Power & Light (KCPL) and Kansas City Power & Light Greater Missouri Operations Company (GMO) before the project in its entirety was novated to TSMO in October 2013. The projected is projected to cost $65.3 million. Table 5 lists the Network Upgrades completed during the reporting period. Table 6 summarizes the completed projects over the previous year. Figure 6 reflects the completed projects by upgrade type on a cost basis for the current year and the following year based on current projected in-service dates. Tables 7 and 8 summarize all Network Upgrades that include construction of transmission lines, both for the current year and the following year. Note: Previous quarter’s updated results are listed as the Transmission Owners may make adjustments to final costs and status of projects completed during the year.
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Q3 2015 Project Tracking Report 9
UID Network Upgrade Name Owner NTC Source
Study Cost Estimate 10401 ACME - FRANKLIN SW 138KV CKT 1 WFEC 2007 STEP $2,065,000 10402 ACME - WEST NORMAN 138KV CKT 1 WFEC 2007 STEP $1,601,000 10403 OU SW - WEST NORMAN 138KV CKT 1 WFEC 2007 STEP $1,577,000 10425 Moundridge 138/115 kV Transformer Ckt 2 WR 2013 ITPNT $13,540,579 10519 LINDSAY SW - WALLVILLE 69KV CKT 1 WFEC 2007 STEP $1,347,000 10522 GRANDFIELD - INDIAHOMA 138KV CKT 1 WFEC 2007 STEP $1,125,000 10523 CACHE - INDIAHOMA 138KV CKT 1 WFEC 2007 STEP $7,306,000 10524 GRANDFIELD 138/69KV TRANSFORMER CKT 1 WFEC 2007 STEP $5,000,000 10629 Chaves County 230/115 kV Transformer Ckt 2 SPS 2013 ITPNT $2,917,118 10935 Iatan - Nashua 345 kV Ckt 1 (KCPL) TSMO Balanced Portfolio $6,675,931 10945 NASHUA 345/161KV TRANSFORMER CKT 1 TSMO Balanced Portfolio $2,617,433 11023 EAST PLANT INTERCHANGE - HASTINGS SUB 115KV CKT 1 SPS 2009 STEP $5,374,736 11067 Bowers Interchange 115/69 kV Transformer Ckt 2 SPS DPA Studies $3,100,001 11353 Lynn County Interchange 115 kV SPS 2010 STEP $5,342,685 11355 Crosby County Interchange 115/69 kV Transformer Ckt 1 SPS 2013 ITPNT $2,378,798 11507 Lubbock South 230/115/13.2 kV Transformer Ckt 2 SPS 2013 ITPNT $4,063,897 50499 Iatan - Nashua 345 kV Ckt 1 (GMO) TSMO Balanced Portfolio $56,048,696 50523 Floyd 115 kV Capacitor SPS 2013 ITPNT $1,731,323 50574 915 Tap South - Sub 915 T2 69 kV Ckt 1 OPPD 2013 ITPNT $260,590 50598 White Horse 69 kV Capacitor WFEC DPA Studies $237,000 50599 Fairview 69 kV Capacitor WFEC DPA Studies $237,000 50600 Hazelton 69 kV Capacitor WFEC DPA Studies $237,000 51064 Tap on Wolf Creek - LaCygne 345kV Ckt 1 WR GI Studies $13,197,769 51065 Tap on Wolf Creek - LaCygne 345kV Ckt 1 GEN-2010-003 Addition WR GI Studies $478,861
Total $138,460,417 Table 5: Q2 2015 Completed Network Upgrades
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Upgrade Type Q2 2014 Q3 2014 Q4 2014 Q1 2015 Total
Regional Reliability 28 5 23 19 75
$148,998,816 $18,181,820 $182,810,361 $59,441,727 $409,432,724
Transmission Service
5 0 2 0 7
$23,399,683 $0 $335,319 $0 $23,735,002
Balanced Portfolio 4 1 0 3 8
$127,550,762 $192,875,814 $0 $65,342,060 $385,768,636
High Priority 8 2 16 0 26
$351,643,677 $2,248,743 $514,748,573 $0 $868,640,993
Economic 0 0 0 0 0
$0 $0 $0 $0 $0
Zonal Reliability 0 0 0 0 0
$0 $0 $0 $0 $0
Generation Interconnection
3 5 6 2 16
$4,159,087 $34,643,128 $18,243,711 $13,676,630 $70,722,556
Table 6: Completed Project Summary through 2nd Quarter 2015
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Voltage Class
Number of Upgrades
Miles of New
Miles of Rebuild/ Reconductor
Miles of Voltage
Conversion Estimated Cost
69 12 14.0 42.8 0.0 $51,955,268 115 7 63.7 47.9 0.0 $77,683,919 138 21 62.9 22.0 108.3 $125,880,130 161 3 0.0 14.0 0.0 $12,050,087 230 3 61.0 0.0 0.0 $48,834,393 345 19 1183.7 0.0 0.0 $1,134,954,911
Total 65 1385.3 126.8 108.3 $1,451,358,708 Table 7: Line Upgrade Summary for Previous 12 Months
Figure 6: Completed Projects by Upgrade Type
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Q3 2014 Q4 2014 Q1 2015 Q2 2015 Q3 2015Projected
Q4 2015Projected
Q1 2016Projected
Q2 2016Projected
Generation Interconnection
Zonal Reliability
Economic
High Priority
Balanced Portfolio
Transmission Service
Regional Reliability$ M
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Southwest Power Pool, Inc.
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Voltage Class
Number of Upgrades
Miles of New
Miles of Rebuild/ Reconductor
Miles of Voltage
Conversion Estimated Cost
69 19 44.1 106.2 0.0 $139,676,743 115 13 138.1 17.0 4.5 $127,297,724 138 7 29.0 20.0 2.0 $39,387,811 161 0 0.0 0.0 0.0 $0 230 4 42.4 0.0 122.0 $63,103,827 345 2 128.0 0.0 0.0 $182,000,000
Total 45 381.59 143.17 128.5 $551,466,105 Table 8: Line Upgrade Projections for Next 12 Months
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Project Status Summary SPP assigns a project status to all Network Upgrades based on the projected in-service dates provided by the DTOs relative to the Need Date determined for the project. Project status definitions are provided below:
• Complete: Construction complete and in-service • On Schedule < 4: On Schedule within 4-year horizon • On Schedule > 4: On Schedule beyond 4-year horizon • Delayed: Projected In-Service Date beyond Need Date; interim mitigation provided or
project may change but time permits the implementation of project • Within NTC Commitment Window: NTC/NTC-C issued, still within the 90-day written
commitment to construct window and no commitment received • Within NTC-C Project Estimate Window: Within the NTC-C Project Estimate (CPE)
window • Within RFP Response Window: RFP issued for the project • Re-evaluation: NTC/NTC-C active; pending re-evaluation • NTC Suspension: NTC/NTC-C suspended; pending re-evaluation
Figure 7 reflects a summary of project status by upgrade type on a cost basis.
Figure 7: Project Status Summary on a Cost Basis
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RegionalReliability
TransmissionService
BalancedPortfolio
High Priority Economic GenerationInterconnection
NTC Suspension
Re-evaluation
RFP Response Window
Within NTC-C Project Estimate Window
Within NTC Commitment Window
Delayed
On Schedule > 4
On Schedule < 4
Complete
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Southwest Power Pool, Inc.
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Balanced Portfolio
Approved in April 2009, the Balanced Portfolio was an initiative to develop a group of economic transmission upgrades that benefit the entire SPP region, and to allocate those project costs regionally. The projects that were issued NTCs as a result of the study include a diverse group of projects, estimated to add approximately 702 miles of new 345 kV transmission line to the SPP system. The total cost estimate of $822.2 million for the projects making up the Balanced Portfolio did not change from the previous quarter’s cost estimate total. The last Balanced Portfolio project still under construction was placed into service on April 30, 2015, when TSMO energized the 30-mile 345 kV line from Iatan to Nashua in northwest Missouri. Figure 8 below depicts a historical view of the total estimated cost of the Balanced Portfolio. Table 9 provides a project summary of the projects making up the Balanced Portfolio.
$ M
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Figure 8: Balanced Portfolio Cost Estimate Trend
$691.2
$832.3
$903.0
$810.5 $822.2
$650.0
$700.0
$750.0
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$850.0
$900.0
$950.0
FERC Filing $896.7
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Project ID(s)
Project Owner(s) Project Name
Est. Line
Length
BP Report Estimates (6/2009)
Q1 2015 Cost Estimates
Q2 2015 Cost Estimates
Variance %
705/709 WFEC/OGE Gracemont Substation 345 kV N/A $8,000,000 $15,091,100 $15,091,100 0.0%
707/708 ITCGP/NPPD Spearville - Post Rock - Axtell 345 kV 226.9 $236,557,015 $203,776,145 $203,776,145 0.0%
698/699 OGE/GRDA Sooner - Cleveland 345 kV 36.0 $33,530,000 $49,718,139 $49,718,139 0.0%
702 KCPL Swissvale - Stilwell Tap 345 kV N/A $2,000,000 $2,866,604 $2,866,604 0.0%
700 OGE Seminole - Muskogee 345 kV 118.0 $129,000,000 $165,000,000 $165,000,000 0.0%
701/704 SPS/OGE Tuco – Woodward 345 kV 290.1 $227,727,500 $320,426,576 $320,426,576 0.0%
703 TSMO Iatan – Nashua 345 kV 30.9 $54,444,000 $65,342,060 $65,342,060 0.0%
Total 701.9 $691,258,515 $822,220,624 $822,220,624 0.0%
Table 9: Balanced Portfolio Summary
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Q3 2015 Project Tracking Report 16
Priority Projects
In April 2010 the SPP Board of Directors and Members Committee approved for construction a group of "priority" high voltage electric transmission projects estimated to bring benefits of at least $3.7 billion to the SPP region over 40 years. The projects issued NTCs as a result of the study are estimated to add 291 miles of new single circuit 345 kV transmission line and 431 miles of double circuit 345 kV transmission to the SPP region. In October 2010 the SPP Board of Directors approved an overall cost increase for the Priority Projects due to line rerouting and addition costs for reactive compensation. The total cost estimate for the Priority Projects after the variances were approved was $1.42 billion. The current total cost estimate of $1.39 billion for the projects making up the Priority Projects indicates a slight decrease of 0.1% from the previous quarter’s total amount. Figure 9 below depicts a historical view of the total estimated cost of the Priority Projects. Table 10 provides a project summary of the projects making up the Priority Projects.
Figure 9: Priority Projects Cost Estimate Trend
$1,144.9
$1,449.7
$1,388.2 $1,389.2
$1,100.0
$1,150.0
$1,200.0
$1,250.0
$1,300.0
$1,350.0
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$ M
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Additional Costs Approved by Board
$1,416.3
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Table 11 lists construction status updates for the Priority Projects not yet completed.
Project ID(s)
Project Owner(s) Project
Est. Line
Length
Board Approved Estimates (10/2010)
Q1 2015 Cost Estimates
Q2 2015 Cost Estimates
Var. %
937 AEP Tulsa Power Station 138 kV Reactor N/A $842,847 $960,895 $960,895 0.0%
940/941 SPS/OGE Hitchland – Woodward District 345 kV Dbl Ckt
122.0 $221,572,283 $229,203,065 $231,203,065 0.9%
942/943 PW/OGE Thistle – Woodward District 345 kV Dbl Ckt 109.4 $201,940,759 $187,260,000 $190,471,326 1.7%
945 ITCGP Spearville – Ironwood – Clark Co. – Thistle 345 kV Dbl Ckt
122.5 $293,235,000 $309,000,001 $309,000,001 0.0%
946 PW/WR Thistle – Wichita 345 kV Dbl Ckt 77.5 $163,488,000 $127,026,938 $120,440,612 -5.2%
936 AEP Valliant – NW Texarkana 345 kV 76.3 $131,451,250 $127,995,000 $127,995,000 0.0%
938/939 OPPD/TSMO Nebraska City – Mullin Creek – Sibley 345 kV 215.0 $403,740,000 $407,791,450 $407,791,450 0.0%
Total 722.7 $1,416,270,139 $1,389,237,349 $1,387,862,349 -0.1%
Table 10: Priority Projects Summary
Proj
ect I
D
Proj
ect N
ame
Proj
ecte
d In
-Ser
vice
D
ate
Engi
neer
ing
Siti
ng a
nd R
outi
ng
Envi
ronm
enta
l Stu
dies
Perm
its
Mat
eria
l Pro
cure
men
t
Cons
truc
tion
C Complete
936 Valliant – NW Texarkana 345 kV 10/1/2016 C C C IP IP IP
IP In Progress
938 Nebraska City – Mullin Creek – Sibley 345 kV (TSMO) 12/31/2016 IP IP IP IP IP NS
NS Not Started
939 Nebraska City – Mullin Creek – Sibley 345 kV (OPPD) 12/31/2016 IP C IP IP IP NS
N/A Not Applicable
Table 11: Priority Projects Construction Status
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Out-of-Bandwidth Projects
In adherence to the Business Practice 7060, SPP reports projects that have updated cost values that exceed their established baseline values based upon a ±20% bandwidth. Variances are determined by total project cost. One project with a cost estimate greater than $5 million was identified as having exceeded the ±20% bandwidth requirement during the reporting period. Table 12 provides summary information and Table 13 lists the cost detail for the out-of-bandwidth project for Q2 2015.
PID Project Name Owner NTC Source
Study Upgrade Type In-Service Date
30369 Moundridge 138/115 kV Transformer Ckt 2 Westar 2013 ITPNT Regional Reliability 4/7/2015
Table 12: Out-of-Bandwidth Project Summary
Table 13: Out-of-Bandwidth Project Cost Detail
PID Baseline Cost Estimate
Baseline Cost Estimate Year
Baseline Cost Estimate with
Escalation
Latest Estimate or Final Cost
Variance Variance %
30369 $19,770,066 2013 $20,770,926 $13,540,579 ($7,230,347) -34.8
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Responsiveness Report
Table 14 and Figures 10 and 11 provide insight into the responsiveness of DTOs constructing Network Upgrades within SPP in the Quarterly Project Tracking Report for Q2 2015. Note: Network Upgrades with statuses of “NTC Suspension”, “Re-evaluation”, “Within NTC Commitment Window”, “Within NTC-C Project Estimate Window”, and “Within RFP Response Window” were excluded from this analysis.
Project Owner
Number of Upgrades
Number of Upgrades Reviewed
Reviewed %
Number of ISD
Changes
ISD Change %
Number of Cost
Changes
Cost Change
%
AEP 57 57 100% 4 7.0% 7 12.3% BEPC 15 15 100% 0 0.0% 0 0.0% GMO 5 5 100% 0 0.0% 1 20.0%
GRDA 7 3 43% 0 0.0% 3 42.9% ITCGP 15 5 33% 1 6.7% 5 33.3% KCPL 5 5 100% 0 0.0% 3 60.0% LES 1 1 100% 0 0.0% 0 0.0%
MIDW 11 0 0% 0 0.0% 0 0.0% MKEC 16 14 88% 14 87.5% 7 43.8% NPPD 26 9 35% 0 0.0% 8 30.8% OGE 48 27 56% 1 2.1% 19 39.6%
OPPD 15 11 73% 4 26.7% 4 26.7% PW 4 4 100% 0 0.0% 4 100.0% SPS 142 54 38% 17 12.0% 29 20.4%
TSMO 5 5 100% 5 100.0% 0 0.0% WFEC 43 1 2% 1 2.3% 0 0.0%
WR 51 8 16% 2 3.9% 6 11.8% Total 470 226 48% 49 10.4% 98 20.9%
Table 14: Responsiveness Summary by Project Owner
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Q3 2015 Project Tracking Report 20
Figure 10: In-Service Date Changes by Project Owner
Figure 11: Cost Changes by Project Owner
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Appendix I
See accompanying list of Network Upgrades