BEFORE THE NEW MEXICO PUBLIC REGULATION COMMISSION
IN THE MATTER OF AN INVESTIGATION ) INTO THE PRUDENCE OF SOUTHWESTERN ) PUBLIC SERVICE COMPANY’S ) PARTICIPATION IN THE SOUTHWEST ) POWER POOL REGIONAL TRANSMISSION ) Case No. 07-00390-UT ORGANIZATION ) ) SOUTHWESTERN PUBLIC SERVICE COMPANY, ) ) Respondent. )
SOUTHWEST POWER POOL INC.’S FILING OF THE 2010 SPP TRANSMISSION EXPANSION PLAN REPORT IN ACCORDANCE WITH SECTION 15 OF THE UNCONTESTED STIPULATION
Southwest Power Pool, Inc. (“SPP”), by and through its attorneys, hereby submits a draft
of the 2010 SPP Transmission Expansion Plan Report (“STEP Report”), dated January 4, 2011,
in accordance with Section 15 of the Uncontested Stipulation (“Stipulation”), dated September
17, 2009 and approved by Final Order Approving Certification of Stipulation issued by the New
Mexico Public Regulation Commission (“Commission”) on February 2, 2010. In support
thereof, SPP states as follows:
1. Section 15 of the Stipulation requires that “[p]rior to SPP’s Board of Directors’
consideration and vote on SPP’s annual Transmission Expansion Plan (STEP), any Balanced
Portfolio proposals or any other similar regional multi-project transmission proposal, SPP will
provide the transmission plans to the Commission or its Staff and, upon request, will meet either
in person or via teleconference with the Commission or its Staff and other interested parties to
discuss the plans.”
2. The STEP Report summarizes 2010 activities that impact future development of
the SPP transmission grid. Seven distinct areas of transmission planning are discussed in this report, each of which are critical to meeting mandates of either the 2010 SPP Strategic Plan or the nine planning principles in FERC Order 890.
3. A draft of the STEP Report in the form presented and discussed at the Markets and Operations Policy Committee (“MOPC”) meeting on January 11, 2011, is attached hereto as
Exhibit A and may be accessed on SPP’s website within the MOPC Agenda and Background
Materials posted at: http://www.spp.org/section.asp?group=321&pageID=27.
4. The SPP Board of Directors (“SPP Board”) is scheduled to meet on January 25,
2011, and SPP anticipates that the SPP Board will consider and vote on the STEP Report at that time. The final version of the STEP Report to be considered by the SPP Board will be included with the SPP Board meeting materials, which will be posted approximately a week in advance of the January 25, 2010 SPP Board meeting on SPP’s website at: http://www.spp.org/section.asp?group=113&pageID=27.
Respectfully submitted,
ATTORNEY FOR SOUTHWEST POWER POOL, INC.
KANTER & GRUBESIC, P.A.
John T.L. Grubesic Post Office Box 25483 Albuquerque, New Mexico 87125-0483 (505) 247-1541
Page 2 of 6
Exhibit A
2010 SPP Transmission Expansion Plan Draft Report January 4, 2011
Page 3 of 6 2010 SPP T E P
A Report of the SPP Regional Transmission Organization
Table of Contents
1. Executive Summary ...... 2 1.1 What is the 2010 SPP Transmission Expansion Plan? ...... 2 1.2 Summary of 2011-2021 Network Upgrades ...... 4 2. Integrated Transmission Planning ...... 10 2.1 Priority Projects ...... 10 2.2 Integrated Transmission Plan ...... 10 3. RTO Regional Reliability Assessment 2011 – 2021 ...... 12 3.1 RTO Regional Reliability Assessment 2011 – 2021 Scope ...... 13 3.2 Load Forecast ...... 17 3.3 Stakeholder Process and Forums ...... 21 3.4 RTO Regional Reliability Results ...... 22 3.5 Loss of Load Expectation Analysis...... 30 4. Tariff Studies ...... 33 4.1 Transmission Service 2010 Overview ...... 33 4.2 Generation Interconnection 2010 Overview ...... 33 4.3 Area Generation Connection Task Force 2010 Overview ...... 34 4.4 Tariff Attachments AQ and AR ...... 34 5. Sub-regional (Local Area) Planning ...... 37 5.1 Stakeholders Process and Forums ...... 37 5.2 2010 Sub-regional Meetings ...... 38 5.3 2010 SPP Exxon-Mobil and TransCanada Load Study ...... 39 6. 2010 Transmission Congestion and Top Flowgates ...... 41 6.1 SPP 2010 Transmission Congestion...... 41 6.2 SPP Top Ten Flowgates ...... 42 7. Interregional Coordination ...... 54 7.1 SPP RTO and Entergy ICT ...... 54 7.2 AECI Interaction ...... 55 7.3 ITP Interaction ...... 57 7.4 MISO Cross Border Study Interaction ...... 57 7.5 WAPA- Basin Electric Interaction ...... 57 7.6 Eastern Interconnection Planning Collaborative ...... 58 8. Project Tracking ...... 60 8.1 NTC Letters Issued in 2010 ...... 60 8.2 Projects Completed in 2010 ...... 60
Appendix A: Complete List of Network Upgrades Appendix B: Reliability Network Upgrades Recommended for Notification to Construct Appendix C: Network Upgrade Diagrams Appendix D: AECI-SPP JCSP Network Upgrades
Priority Projects and Integrated Transmission Planning 1
1. Executive Summary
1.1 What is the 2010 SPP Transmission Expansion Plan?
The 2010 Southwest Power Pool, Inc. (SPP) Transmission Expansion Plan (STEP) summarizes 2010 activities that impact future development of the SPP transmission grid. Seven distinct areas of transmission planning are discussed in this paper, each of which are critical to meeting mandates of either the 2010 SPP Strategic Plan1 or the nine planning principles in FERC Order 890. As a Regional Transmission Organization (RTO) of the Federal Energy Regulatory Commission (FERC), SPP must meet requirements of FERC and the SPP Open Access Transmission Tariff (OATT or Tariff).
1. Regional reliability assessment (2011-2021): This assessment, which was developed with extensive stakeholder review and input, identifies foundational reliability projects needed in the next ten years for the SPP region, and finds upgrades to address possible problems in both normal and contingency conditions. The assessment identifies approximately $2 billion in reliability projects, a reduction of approximately $700 million from 2009 reliability project totals.
All upgrades included in the 2010 STEP total $5.1 billion. Projects included for the 10-year window are those needed for local and regional reliability, the Balanced Portfolio (approved in 2009), and Priority Projects (approved in 2010).
Three major issues impacted reliability assessment results: • The downturn in the economy resulted in a significant reduction in the load forecast. • Two new generating units were included in southwest Texas: Jones (190 MW) and Antelope (170 MW). • Associated Electric Cooperative, Inc. (AECI) participated in the 2010 reliability assessment as if they were a member of SPP, which resulted in considerably more reliability non-OATT upgrades.
2010 is the last year this reliability assessment will be conducted under the pre-Integrated Transmission Planning (ITP) Attachment O framework. Going forward, reliability assessments will be part of the ITP Near-Term Assessment.
2. Tariff studies: In 2010 transmission expansion projects identified as needed to meet Transmission Service Requests totaled $546 million, and projects needed to meet Generation Interconnection requests totaled $104 million. A wind integration study was issued in January 2010 to assess the operational and reliability impacts of integrating large amounts of wind into the SPP system.
3. Sub-regional and local area planning: Each year SPP holds a series of local planning meetings to discuss local transmission user needs. Through this process SPP facilitated a high priority study to analyze the impacts of additional load from ExxonMobil and the planned
1 SPP.org > About > 2010 Southwest Power Pool Strategic Plan
Priority Projects and Integrated Transmission Planning 2
TransCanada oil pipelines across the footprint; 10 new reliability projects were identified and considered in the STEP.
4. 2010 Transmission Congestion and Top Flowgates: SPP monitors congestion on the transmission grid and identifies the region’s top 10 congested flowgates. When projects from SPP’s study processes are built, the new facilities often lower production costs and reduce congestion. SPP provides a list of projects that are expected to provide some positive mitigation for the annual top 10 congested flowgates.
5. Interregional coordination: In addition to regional planning, SPP conducts interregional planning with neighboring systems. In 2010 SPP participated with the Midwest ISO and Western Area Power Administration in activities related to seams and flowgate congestion. SPP contacted neighboring parties to coordinate inputs and outputs for the 2010 ITP 20-Year Assessment. Through the Entergy/SPP Regional Planning Process, five regional economic studies were selected to be performed either in detail or at a high level. SPP is actively involved in the Eastern Interconnection Planning Collaborative model building process.
6. Integrated Transmission Planning and Priority Projects: In 2009 the SPP Board of Directors (Board) directed SPP to follow through on the Synergistic Planning Project Team’s recommendations2. The first recommendation was to identify a set of Priority Projects that will improve the SPP transmission system and benefit the region, specifically projects that will reduce grid congestion, improve the Generation Interconnection and Aggregate Study processes by facilitating interconnections and transmission service, and better integrate SPP’s west and east regions. During 2010 the Board approved six Priority Projects. Notifications To Construct (NTC) for these projects where sent in the summer of 2010.
The team’s second recommendation was to develop an ITP process that will maintain reliability and provide economic benefits to the SPP region in both the near and long-term, enabling SPP and its stakeholders to better facilitate the development of a robust transmission grid that will give regional customers improved access to the SPP region’s diverse resources. The first phase of this new process, the ITP 20-Year Assessment, was conducted in 2010. This study recommended a long-term transmission plan for a 20-year horizon, incorporating a proposed extra high voltage backbone supply system. The assessment identifies a versatile system capable of providing a cost-effective deliverability to market solution for a broad range of possible resource futures.
7. Project tracking: After the Board approves transmission expansion projects, or once appropriate agreements are filed with FERC, SPP issues Notification to Construct (NTC) letters to appropriate Transmission Owners. In 2010, SPP issued 43 NTC letters with estimated construction costs of $2.35 billion. SPP actively monitors the progress of approved projects by soliciting feedback from project owners. By the end of 2010, 94 projects were scheduled to be completed.
The SPP RTO acts independently of any single member, customer, market participant, or class of participants. It has sufficient scope and configuration to maintain electric reliability and effectively
2 SPP.org>Org Groups>Synergistic Planning Project Team> Documents>Report of the Synergistic Planning Project
Priority Projects and Integrated Transmission Planning 3
perform its functions. This includes Tariff administration and transmission planning, as well as support for efficient and non-discriminatory power markets.
SPP’s transmission planning process incorporates the SPP Value Proposition:
• Relationship-based • Member-driven • Independence through diversity • Evolutionary vs. revolutionary • Reliability and economics are inseparable
While SPP also serves as a Regional Entity (RE) of the North American Electric Reliability Corporation, the STEP tariff planning functions are independent of the SPP RE.
1.2 Summary of 2011-2021 Network Upgrades
The 2010 STEP summarizes transmission planning efforts including regional reliability, local reliability, Generation Interconnection, Transmission Service, Balanced Portfolio, and Priority Projects. This summary also includes information from previous STEP reports which identified projects that are currently in the project tracking stages. This summary includes Network Upgrades needed to address reliability or meet NERC Reliability Standards/SPP Criteria; Zonal Reliability Upgrades (compliance to Transmission Owner company-specific planning criteria); requests for Transmission Service under the Tariff with a FERC-filed Service Agreement; Generation Interconnections with a FERC-filed Generation Interconnection Agreement; Balanced Portfolio upgrades; and Priority Projects.
Cost (Billions) by Facility Type
$0B $1B $2B $3B $4B
New Lines Transformers Line Rebuilds Voltage Conversions Substation Upgrades Cap / Reactive Devices
Priority Projects and Integrated Transmission Planning 4
Project Cost by Type
Transformers 10% Line Rebuilds 9%
Voltage Conversions New Lines 6% 69% Substation Upgrades 5%
Cap / Reactive Devices 1%
Cost by Project Type
transmission transmission service 11% Balanced service 11% regional Portfolio reliability ‐ non 17% regional reliability non‐OATT 6% OATT 6% zonal ‐ sponsored regional zonal‐sponsored 6% 6% reliability 28% inter‐regional inter‐regional2% 2%
high priority GenerationGeneration Interconnection 2% 28% Interconnect Zonal Reliability Zonal Reliability0.1%2% 0.1%
The following table of categorized projects for the 2010 STEP provides a cost summary and comparison with the 2008 and 2009 STEP of all project types:
Priority Projects and Integrated Transmission Planning 5
(Dollars in Millions)
2010 STEP 2009 STEP 2008 STEP (Nearest (Nearest (Nearest 10 Upgrade Type 10 Million) 10 Million) Million)
$1,420 2010 Priority Projects $820 $770 2009 Balanced Portfolio Transmission Service Request and Generation $650 $540 $320 Interconnection Service Agreements $1,220 $1,690 $880 Reliability - Base Plan $540 $1,030 $520 Reliability - Other $320 $620 Sponsored Upgrades $4.65B $4.35B $2.3B SPP Subtotal $420 $100 $350 non-OATT upgrades $5.1B $4.45B $2.7B Appendix A - TOTAL
Has filed Service Agreement or is Board- approved (APPENDIX A includes a breakdown of projects in the 10-year horizon)
Major 345 kV projects in various stages of approval or sponsorship that were studied during the 2010 STEP process are listed below. These projects are also shown in the map following.
• American Electric Power to construct 33 miles of 345 kV transmission line from Turk in southwest Arkansas to Northwest Texarkana in northeast Texas
• American Electric Power to construct 76 miles of 345 kV transmission line from Northwest Texarkana to Valliant in southeast Oklahoma
• American Electric Power to construct 18 miles of 345 kV transmission line from Flint Creek to Shipe Road in northwest Arkansas
• American Electric Power to construct 55 miles of 345 kV transmission line from Shipe Road to Osage Creek (passing near East Rogers) in northwest Arkansas
• Associated Electric Cooperative to construct 113 miles of 345 kV transmission line from Blackberry in southwest Missouri to Sportsman to GRDA 1 in northeast Oklahoma
• KCP&L Greater Missouri Operation Company and Omaha Public Power District to construct 181 miles of 345 kV transmission line from Sibley to Maryville to Nebraska City in northwest Missouri and southeast Nebraska
Priority Projects and Integrated Transmission Planning 6
• ITC Great Plains to construct 19 miles of 345 kV transmission line from Hugo Power Station to Valliant in southeast Oklahoma
• ITC Great Plains to construct 90 miles of 345 kV transmission line from Spearville to Post Rock (Knoll) in west Kansas
• ITC Great Plains and Nebraska Public Power District to Construct 125 miles of 345 kV transmission line from Post Rock (Knoll) in west Kansas to Axtell in southern Nebraska
• Kansas City Power & Light to construct 30 miles of 345 kV transmission line from Iatan to Nashua in northwest Missouri
• Mid-Kansas Electric Company and Sunflower Electric Power Corporation to construct 55 miles 345 kV double circuit transmission line from Spearville to Comanche Co in southwest Kansas
• Mid-Kansas Electric Company to construct 55 miles of double circuit 345 kV transmission line from Comanche Co to Medicine Lodge in southwest Kansas
• Mid-Kansas Electric Company and Westar Energy to construct 75 miles double circuit 345 kV transmission line from Medicine Lodge to Wichita in south Kansas
• Mid-Kansas Electric Company and Oklahoma Gas and Electric Company to construct 108 miles of double circuit 345 kV transmission line from Medicine Lodge to Woodward EHV in northwest Oklahoma and southwest Kansas
• Oklahoma Gas and Electric and Westar Energy to construct 106 miles of 345 kV transmission line from Rose Hill in central Kansas to Sooner in central Oklahoma
• Oklahoma Gas and Electric to construct 36 miles of 345 kV transmission line from Sooner to Cleveland in central Oklahoma
• Oklahoma Gas and Electric to construct 120 miles of 345 kV transmission line from Hugo to Sunnyside in southern Oklahoma
• Oklahoma Gas and Electric to construct 100 miles of 345 kV transmission line from Seminole to Muskogee in central Oklahoma
• Oklahoma Gas and Electric and Southwestern Public Service Company to construct 250 miles of 345 kV transmission line from Woodward District EHV in west Oklahoma to Oklahoma/Texas Stateline to Tuco in west Texas
• Oklahoma Gas and Electric and Southwestern Public Service Company to construct 122 miles of double circuit 345 kV transmission line from Hitchland to Woodward EHV in northwest Oklahoma
Priority Projects and Integrated Transmission Planning 7
• Oklahoma Gas and Electric to construct 5 miles of 345 kV transmission line from Arcadia to Redbud in central Oklahoma
1.2.1 Appendices A and B Appendix A includes a comprehensive listing of transmission projects identified by the SPP RTO. Not all projects in Appendix A have been approved by the Board, but all Board-approved projects are included in the list. Appendix A also includes Tariff study projects, economic projects, zonal projects, and associated interregional projects.
Appendix B lists proposed transmission projects for which sponsors or RTO staff request action by the Board in the first quarter of 2011. The Appendix B list includes projects specifically needed for regional reliability that have a financial commitment lead-time inside the 2011-2014 four-year commitment window. Appendix B also includes projects for which withdrawals are being sought.
Projects in Appendices A and B are categorized in the column labeled “Project Type Exp” by the following designations:
Balanced Portfolio – Projects identified through the Balanced Portfolio process
Generation Interconnect – Projects associated with a FERC-filed Generation Interconnection Agreement
Priority Projects and Integrated Transmission Planning 8
Interregional – Projects developed with neighboring Transmission Providers (Appendix A only)
High priority – Projects identified in the high priority process
Regional reliability – Projects needed to meet regional reliability
Regional reliability – non-OATT – Projects to maintain reliability for SPP members not participating under the SPP OATT (Appendix A only)
Transmission service – Projects associated with a FERC-filed Service Agreement
Zonal Reliability – Projects identified to meet more stringent local Transmission Owner criteria
Zonal – sponsored – Projects sponsored by facility owner with no Project Sponsor Agreement
As transmission usage changes, proposed and approved projects are subject to evaluation. Appendix A projects can be re-evaluated by the SPP RTO for “best” regional and/or local area solutions. Even though many are approved, Network Upgrades listed in Appendix A are not considered beyond the scope of reevaluation. Transmission Network Upgrades approved for construction have the opportunity for additional review on a case-by-case basis. The goal of reevaluation is to investigate viable alternatives considering new information and then determine if a more regionally-beneficial solution exists. This also takes into account long-term strategy and regional reliability needs.
Appendix B includes only new proposed transmission projects that have SPP RTO support and for which sponsors or RTO staff are requesting action by the Board. This appendix does not include Network Upgrades identified by the SPP OATT Attachment Z Transmission Service Procedure or Attachment V Generation Interconnections. If approved, these Network Upgrades will be included in the SPP OATT Transmission Service study models. Transmission Network Upgrades authorized for construction have the opportunity for additional review on a case-by-case basis. The goal of such re-evaluation is to compare viable alternatives and then determine a cost-effective transmission solution while taking into consideration long-term strategy and regional reliability needs.
Included in Appendix B are withdrawal requests for projects that have an approved NTC. These projects are identified in the “BOD Action” column as “NTC – withdraw”. The reasons listed below explain why these projects are no longer required:
• Network Upgrade no longer required due alternate solution • Network Upgrade no longer required due to new load forecast • Network Upgrade no longer required due to model correction • Network Upgrade no longer required due to new generation
Priority Projects and Integrated Transmission Planning 9
2. Integrated Transmission Planning
2.1 Priority Projects
In April 2009, SPP was directed by the Board of Directors to implement the Synergistic Planning Project Team’s recommendations for creating a robust, flexible, and cost-effective transmission system for the region, large enough in both scale and geography to meet SPP’s future needs. Development of Priority Projects was the first step of the Integrated Transmission Planning (ITP) process. The ITP process was envisioned to improve and integrate SPP’s existing planning processes in concert with the new SPP highway/byway cost allocation methodology.
SPP was charged with identifying, evaluating, and recommending Priority Projects that will improve the SPP transmission system and benefit the region, specifically projects that will reduce grid congestion, improve the Generation Interconnection and Aggregate Study processes, and better integrate SPP’s east and west regions.
The SPP Board of Directors approved the Priority Project Phase II Final Report3 revision 1 in April 2010 with the identified projects rolling forward into the new Integrated Transmission Planning 20- Year study process.
2.2 Integrated Transmission Plan
The Integrated Transmission Planning (ITP) process concept, developed by the Synergistic Planning Project Team (SPPT), was approved by the Board to address gaps and conflicts in SPP’s transmission planning processes, including Generation Interconnection and Transmission Service. Its aim is to develop a holistic, proactive approach to planning that optimizes individual processes, and to position SPP to respond to national energy priorities. The ITP is based on the SPPT’s planning principles which emphasized the need to develop a transmission backbone large enough in both scale and geography to provide flexibility to meet SPP’s future needs.
The ITP is a three year study process which assesses the SPP region's transmission needs in the long and near-term planning horizon with the intention of creating a cost-effective, flexible, and robust transmission network that will improve access to the region’s diverse generating resources. Along with the recently approved Highway/Byway cost allocation methodology, the ITP process promotes transmission investment that will meet reliability, economic, and public policy needs.4 The ITP process is embodied in the new SPP Attachment O, which was approved by FERC in July 2010.
This is the first Integrated Transmission Plan looking into the future 20 years as required by OATT Attachment O Section III - 3. This is an expansion on the annual SPP Transmission Plan (STEP), the 10 year transmission expansion plan in place since 2006. SPP has had two previous EHV plans, which like this plan, provide a look into the future that help to form the near term plans. The concept
3 SPP.org>Engineering>Transmission Planning>Priority Projects>Priority Projects Phase II Final Report 4 The Highway/Byway cost allocation approving order is Sw. Power Pool, Inc., 131 FERC ¶ 61,252 (2010). The approving order for ITP is Sw. Power Pool, Inc., 132 FERC ¶ 61,042 (2010).
Priority Projects and Integrated Transmission Planning 10
for this 20 year look into the future arose from the 2009 Synergistic Project Planning Team, as a means to develop a flexible EHV backbone network. The process utilizes a diverse array of power system and economic analysis tools to identify cost-effective robust backbone projects which will provide the transmission system flexibility to reasonably accommodate possible changes characterized by the various futures (scenarios) depicted in the assessment. Projects identified in the ITP20 provide benefits to the region across multiple futures, and create flexibility for SPP to meet future needs. The ITP effort has been driven by numerous interactions with stakeholders and with significant support from the ESWG and TWG. This plan differs from the earlier EHV plans in the level of detail and effort that has gone into its preparation.
Several distinct generation expansion futures were considered to account for possible variations in system conditions over the assessment’s 20-year horizon. The futures were determined by the Strategic Planning Committee and further refined by the Economic Studies Working Group, incorporating data from a Cost Allocation Working Group renewable energy survey. The four futures are presented briefly below:
1. Business-As-Usual: This future assumed no major changes in policy from the present, and included renewable generation necessary to meet existing state renewable targets (approximately 10.6 GW of nameplate wind).
2. Renewable Electricity Standard: This future assumed a 20% federal Renewable Electricity Standard (RES). It included renewable resources necessary to meet that standard (approximately 16.5 GW of nameplate wind).
3. Carbon Mandate: This future assumed a carbon tax of $73/ton on CO2 emissions, and included renewable generation necessary to meet existing state renewable targets (approximately 10.6 GW of nameplate wind).
4. Renewable Electricity Standard + Carbon Mandate: This future combined the assumptions of Future 2 and Future 3 for a RES of 20% and a carbon tax of $73/ton. It included renewable resources necessary to meet the RES (approximately 16.5 GW of nameplate wind).
The analysis identified many projects and organized them first into a set of four least-cost5 preliminary designs; one per future. Projects from each of these designs were incorporated together in order for the system to be adaptable across all of the futures and provide a starting point for development of several robust portfolio designs. Robustness analysis was performed to determine how the transmission plan and various alternatives performed against a variety of metrics. Out of the robustness analysis, six portfolios were developed that met the study’s goals.
The complete ITP20 report can be found on SPP.org6
5For the purpose of this analysis, only upgrades at 345 kV and above were considered. 6 SPP.org > Engineering > Transmission Planning > Integrated Transmission Planning
Priority Projects and Integrated Transmission Planning 11
3. RTO Regional Reliability Assessment 2011 – 2021
The following table summarizes cost estimates for all reliability projects documented in the 2010 STEP.
2010 STEP 2009 STEP 2008 STEP Upgrade Type ($ Million) ($ Million) ($ Million)
Base Plan reliability – with NTC $1,222 $1,688 $881 Zonal Reliability – with NTC $3 $19 $25 Reliability – beyond financial approval window $241 $727 $285 Sub Total SPP Tariff reliability $1,466 $2,434 $1,191 Zonal – sponsored* $296 $282 $205 Reliability – non-OATT $316** $43 $285** Reliability Sub Total $2,078 $2,759 $1,681
* The projects sponsored directly by facility owners may be needed for local reliability but are not verified by SPP.
**In the 2008 STEP, this total included Nebraska entities’ projects. In 2009 the Nebraska entities became SPP members and transferred their facilities under the SPP OATT; many of the Nebraska projects are included in the other appropriate Reliability totals. In 2010, SPP conducted the STEP study with Associated Electric Cooperative’s (AECI) participation, identifying many AECI projects and causing a notable increase in total dollars but would not result in Board approval for construction.
Regional transmission planning is one of SPP’s integral functions. SPP has always taken a proactive stance on transmission planning. The SPP Open Access Transmission Tariff (OATT) contains procedures in Attachment O that describe the coordinated planning process. Support and oversight of the regional planning process is a key responsibility of the Transmission Working Group (TWG) and the Economic Studies Working Group (ESWG), which incorporates vital input from stakeholders throughout the planning process. The TWG and ESWG are composed of stakeholders from both Transmission Owning and Transmission Using members. Meetings are open, and agendas are posted on SPP.org. SPP stakeholders are encouraged to actively participate in the regional planning process to ensure that the recommended transmission projects are the best solutions for the footprint.
The 2011-2021 regional reliability assessment followed the same 12-month cycle as the 2006, 2007, 2008, and 2009 studies. SPP worked with stakeholders on expedited reliability needs that were reviewed during quarterly meetings of the Markets and Operations Policy Committee and Board of Directors (Board). Using an annual planning cycle synchronizes the SPP Aggregate Transmission Service Study process with the Attachment O regional reliability review process. The 2006 STEP used a two-year financial window to issue Notifications to Construct. The 2007 and 2008 STEP used a four-year financial window to issue Notifications to Construct. The 2009 STEP was changed to a two year financial window by the Board. The 2010 STEP used a four-year financial window to issue Notification to Construct (NTC) letters.
RTO Regional Reliability Assessment 2011 – 2021 12
Three major issues impacted reliability assessment results: • The downturn in the economy resulted in a significant reduction in the load forecast. • Two new generating units were included in southwest Texas: Jones (190 MW) and Antelope (170 MW). • AECI participated in the 2010 reliability assessment as if it were a member of SPP, which resulted in considerably more reliability non-OATT upgrades. AECI findings will be documented but not presented for approval to the Board.
The transmission grid’s dynamic usage and constantly changing needs require the need for quarterly transmission project review. At these quarterly reviews, local area issues may identify new transmission projects or require adjustments to the existing list of approved projects. If action by the Board is requested, these adjustments are reviewed on a quarterly basis with approvals or cancellations summarized in a newly-submitted Appendix B. Once Board approval has been acquired for Appendix B refinements, the transmission projects will be moved out of Appendix B and into Appendix A with the appropriate Tariff designation (i.e., Base Plan, Sponsored, Balanced Portfolio, etc.).
As load on the transmission system grows and new transmission service is sold, it is critical that approved transmission projects are tracked to ensure timely completion of upgrades needed for the security of the transmission system.
3.1 RTO Regional Reliability Assessment 2011 – 2021 Scope
The main objective of the ten-year regional reliability assessment is to create a reliable long-range transmission expansion plan for the SPP footprint. The assessment reviews normal conditions (no contingency) and single contingency outage conditions (N-1) scenarios using NERC Reliability Standards, SPP Criteria, and local planning criteria. It also coordinates appropriate mitigation plans to meet the SPP region’s reliability needs.
SPP’s compliance with NERC Reliability Standards is facilitated through the applicable Regional Entities, which are separate from the SPP RTO. The goal of this assessment is to meet the SPP RTO’s requirements under Attachment O of the OATT for planning a reliable transmission system that meets long-term transmission service needs. This process consists of the following steps:
• Identify reliability-based problems (NERC Reliability, SPP and local criteria)
• Comprehensively assessment of known mitigation plans
• Develop additional mitigation plans to meet the region’s needs and maintain SPP and local reliability/planning standards
The process is open and transparent, allowing for stakeholder input. Study results are coordinated with other entities and regions responsible for transmission assessment and planning.
RTO Regional Reliability Assessment 2011 – 2021 13
3.1.1 Reliability Planning Goals
• Meet NERC Reliability Standards
• Meet SPP criteria
• Meet SPP RTO-recognized local planning criteria, as requested by Transmission Owners
• Address additional regional needs
• Assess mitigation plans proposed by Transmission Owners (operating guides and/or new facilities)
• Track approved and planned system upgrades to ensure reliability projects are built in time to meet system needs. This is accomplished with SPP’s project tracking and quarterly reporting processes.
• Coordinate regional transmission plans with neighboring entities, regions, and ISOs/RTOs.
3.1.2 Load Flow Models SPP used the SPP Model Development Working Group’s (MDWG) 2010 series process to build the load flow cases. The reliability study cases in this analysis were: 2011 Summer Peak, 2011/12 Winter Peak for timing upgrades, 2012 Summer Peak, 2012/13 Winter Peak, 2016 Summer Peak, 2016/17 Winter Peak, and 2021 Summer Peak cases. Updates from nearby regions and entities were used for the contingency analysis. The cases were modified as follows to develop the appropriate study models for the reliability assessment. The load and capacity forecast for the flow cases have included the impact on load of the existing and planned demand response resources.
Treatment of Transmission Owner Zonal Reliability Upgrades SPP included Transmission Owner-initiated projects as determined by the Transmission Owner. Model on Demand (MOD) Type - Reliability MOD Status - STEP (w/ NTC) or Planned
Treatment of previous STEP projects SPP included upgrades that have either a Letter of Authorization (LOA) or Notification to Construct (NTC), except for those that have been requested to be removed and have been through stakeholder review. MOD Type - Reliability MOD Status - STEP (w/ NTC) or Transmission Owner Planned
Treatment of Balanced Portfolio projects SPP included the approved Balanced Portfolio projects.
RTO Regional Reliability Assessment 2011 – 2021 14
Treatment of Priority Projects SPP included the approved Priority Projects.
Treatment of SPP Aggregate Transmission Service Study (Attachment Z) Projects SPP included upgrades that have either a LOA or NTC, except for those that have been requested to be removed and have been through stakeholder review. MOD Type - Transmission Service Request (TSR) MOD Status - w/ NTC (Approved)
Treatment of interconnection facilities of new generation SPP included upgrades of interconnection facilities with executed agreements not on suspension. MOD Type - Large Generation Interconnection Procedures (LGIP) MOD Status - With executed Large Generator Interconnection Agreement not on suspension (w/LGIP)
Scenario cases SPP developed two scenario cases for each season for the steady state analysis:
1. The “Zero Case” has the same dispatch as the MDWG cases, except for generation without a FERC-filed Interconnection Agreement and generation without Transmission Service. An exception is in later years when generation, load, and interchange do not match creating a generation shortfall situation; then it is made up of in-service units.
2. The “All transactions” scenario 5 cases are the same as the Zero Case, but the dispatch was changed to include all transmission service commitments with ERCOTN HVDC tie North to South, ERCOTE HVDC tie East to West, and Southwestern Public Service Company importing/ exporting to the Lamar HVDC tie.
3.1.3 Steady State Analysis
• Monitoring of Facilities: SPP staff monitors all 69 kV and above facilities in the SPP footprint for near-term cases (2012 Summer Peak, 2012/13 Winter Peak, 2016 Summer Peak and 2016/17 Winter Peak). For the long-term cases in 2021, SPP monitoring will be increased to 100 kV and above. With the exception of Entergy (EES) and Associated Electric (AECI), SPP staff monitors all facilities 230 kV and above in first tier control areas. Within EES, facilities are monitored at 100 kV and above. Within AECI, facilities are monitored at 69 kV and above
• Normal condition and (N-1) contingency analysis: SPP performed normal conditions and contingency analysis on 2012 Summer Peak, 2012/13 Winter Peak, 2016 summer Peak, 2016/17 Winter Peak, and 2021 Summer Peak cases (including all transaction cases). The 2011 Summer Peak and 2011/12 Winter Peak were used for timing upgrades in the near term. The following system conditions were performed:
RTO Regional Reliability Assessment 2011 – 2021 15
o Normal conditions
o All (N-1) single-element contingencies 69 kV and above in SPP are evaluated. These contingencies do not include manual transfer of load or manual switching.
o All (N-1) single-element contingencies 69 kV and above in AECI, 100 kV and above in EES, and 230 kV and above on all other first-tier companies are evaluated.
o SPP verifies that all normal conditions and N-1 violations identified have corrective plans.
3.1.4 Use of Transmission Operating Guides Steady state analysis identifies all violations without the use of Transmission Operating Guides (TOGs). TOGs may be used as alternatives to planned projects. Load flow analysis is performed to determine the effectiveness of the TOG in alleviating the violation(s). With input from stakeholders, SPP staff determines reinforcements needed to eliminate TOGs used in alleviating violation(s).
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3.2 Load Forecast
The load forecast used in the reliability analysis study models was developed by each Load Serving Entity and provided to SPP during the model building process. The aggregated load represents SPP total load. Reliability analysis models had a total growth of 11.4 % for summer 2011 through summer 2021, or approximately 1.2% per year.
The economic downturn had a considerable impact on the load forecast. Overall growth rate for the 2010 STEP slowed compared to the 2009 STEP, which had a growth rate of 1.5% per year. The overall forecast is down considerably as demonstrated by the following graph.
Total Load
60,000MW
58,000MW
56,000MW
54,000MW
52,000MW
50,000MW 2011SP 2014SP 2016SP 2019SP 2021SP
2009 2010
3.2.1 Transmission Service Commitments Only Long-Term Firm Service commitments with FERC-filed Service Agreements were included in the study model, with two exceptions:
1) Generation that has a high probability of going into service and getting a FERC-filed Interconnection Agreement
2) Shortfall transactions to make generation and load match
SPP used two transaction scenarios to capture the effects of the Transmission Service. SPP built scenario models to minimize counter-balancing Transmission Service. The scope of the regional reliability assessment provides additional information on these scenario cases.
Guidelines for including service from new generation that has a high probability of going into service and getting a FERC-filed Interconnection Agreement are listed below:
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• A formal request is sent to SPP requesting the generation capacity be included in the study model • It must have a FERC-filed Interconnection Agreement that is not on suspension • Funding for major equipment must be acquired • It must be in an Aggregate Transmission Service Study and completed Facilities Study waiting for results without third-party impacts (this eliminates generators that may drop out as result of changes in study results) • Where applicable, air and environmental permits must be acquired, with major equipment awarded • Construction must be started
The following new generation in SPP was included in the regional reliability assessment models:
Generation Capacity with an Executed Transmission Service Agreement Net Capacity** In-Service Model Area Plant Name (MW) Date American Electric Power Stall 509 In-Service American Electric Power Turk 618 4/1/2012 City Utilities, Springfield Missouri Southwest 2 275 12/1/2010 Meridian Way Wind Farm Mid-Kansas Electric Company (Cloud County) 196* In-Service Central Plains Wind Sunflower Electric Power Corporation Farm 99* In-Service Mid-Kansas Electric Company Flat Ridge Wind Farm 100* In-Service Kansas City Power & Light Company Iatan # 2 850 In-Service Oklahoma Gas and Electric Company Redbud 300 In-Service Nebraska Public Power District Petersburg Wind Farm 80* In-Service Nebraska Public Power District Broken Bow Wind Farm 80* 11/1/2010 Nebraska Public Power District Whelan Energy Center 2 220 6/1/2012 Nebraska Public Power District Crofton Hills Wind Farm 42* 6/1/2011 Western Farmers Electric Cooperative Orme 150 In-Service Western Farmers Electric Cooperative Blue Canyon Wind Farm 152* In-Service *Firm transmission capacity reserved. **For wind farms, nameplate capacity is shown; for other generation, net summer capacity is shown.
A list of the Long-Term Firm Transmission Service agreements, including study models, is available on the SPP password-protected file server TrueShare. Access may be requested by emailing [email protected].
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3.2.2 Generation Generation Interconnection facilities were included in the regional reliability assessment load flow models when a FERC-filed Generation Interconnection Agreement was executed and not on suspension.
The following new generation in SPP was included in the regional reliability assessment models:
Generation Capacity without an Executed Transmission Service Agreement Net Summer In-Service Model Area Plant Name Capacity (MW) Date Oklahoma Gas and Electric Company Redbud Power Plant 155 In-Service Southwestern Public Service Company Antelope 170 12/1/2010 Southwestern Public Service Company Jones #3 243 6/1/2012
In later model years when there is a shortfall between interchange, generation, and load, the following process was used: 1. Exhaust the generation of the network customer 2. Exhaust the host Transmission Owner’s existing dispatchable generation 3. Exhaust the Independent Power Producer’s (IPP) existing dispatchable generation in the Host Transmission Owner’s modeling area. 4. Exhaust remaining existing available dispatchable generation in SPP on pro rata basis
The following table lists the IPP generation used for generation shortfall:
IPP Generation Capacity Used to Meet Shortfall of Generation and Interchange
MW available for In-Service Model Area Units used for shortfall Shortfall Date American Electric Power Green Country Energy LLC 778 In-Service American Electric Power Oneta Energy Center 1077 In-Service American Electric Power Eastman Cogeneration Facility 402 In-Service American Electric Power Harrison County Power Project 570 In-Service KCP&L Greater Missouri Operations Company Dogwood 481 In-Service
3.2.3 Criteria NERC Reliability Standards, SPP Criteria, and local Transmission Owner planning criteria were utilized in this analysis (whichever is most stringent). If a project was needed for more stringent local Transmission Owner’s planning criteria, these projects were identified as Zonal Reliability Upgrades.
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SPP Criteria is available on SPP.org > Engineering > Transmission Planning.
Transmission Owners’ planning criteria is available through SPP.org > Engineering > Transmission Planning > Local Area Planning and High Priority Studies.
3.2.4 Demand Response SPP is in the process of addressing demand response. The impacts of stakeholders’ demand response programs over the planning horizon were assumed to have been incorporated into their load forecasts.
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3.3 Stakeholder Process and Forums
All SPP transmission planning stakeholder meetings are open to the public. Minutes and materials from SPP organizational group meetings, such as meetings of the Transmission Working Group (TWG), are posted on the Org Groups pages of SPP.org. Materials from regional and sub-regional planning summits are also posted on SPP.org>Engineering> Transmission Planning. Due to Critical Energy Infrastructure Information (CEII) confidentiality requirements, data such as load flow models and SPP system maps are posted on a password-protected file server called TrueShare. Contact [email protected] for more information.
On November 4, 2009, SPP and the TWG developed and finalized the 2011-2021 reliability assessment study scope. SPP prepared a system assessment and shared it with the TWG and at an SPP planning workshop in May 2010. Stakeholder feedback was solicited to work toward solutions to problems identified in the assessment.
Taking into consideration the feedback received, SPP prepared a draft reliability plan for 100 kV and above facilities and shared it at an SPP planning workshop in August 2010. Further feedback was solicited from stakeholders. Then SPP prepared a draft plan for 69 kV facilities and changes to the 100 kV facilities which was presented during a net conference in October 2010.
Incorporating feedback received, SPP staff prepared the draft SPP regional reliability assessment, listing all Network Upgrades and any deferred or displaced upgrades. This information was shared with the TWG along with a request for more feedback. Feedback from the sub-regional meetings was taken into consideration and incorporated after each sub-regional meeting.
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3.4 RTO Regional Reliability Results
3.4.1 Summary of Violations The following charts summarize monitored facilities that had overloads and voltage violations as identified by the 2010 STEP scope. These charts also compare overload and voltage violations from the 2007, 2008, 2009, and 2010 STEP. The count is by number of elements in violation. Because the reinforcements without NTCs for later years were removed from the models, as expected, there are more violations in the later years.
Many of the voltage violations identified in the off-peak cases were due to high voltages resulting from the difficultly of modeling reactive sources so the system responds properly to all load levels. The models are predominately designed so they react correctly to conditions that would provide low voltage situations.
2010 STEP Overloads 200
150
100 Quantity 50
0
230 - 500 kV 115 - 161 kV 69 kV
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2010 STEP Voltage Violations
200
150
100 Quantity 50
0
230 - 500 kV 115 - 161 kV 69 kV
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Total Voltage Violations
1200 1110
1000
800 623 686 600 545 315 370 Quantity 259 400 289 336 52 57 20 150 200 77 9 62 26 139 26 3 198 5 0 131 129
3.4.2 Summary of 2010 STEP Network Upgrades The following figures summarize the January 2011 – December 2021 identified Network Upgrades including Network Upgrades required for executed Service Agreements, SPP RTO regional reliability, Transmission Owner local criteria, Priority Projects and economic upgrades identified in the Balanced Portfolio process.
The total estimated cost of Network Upgrades for this period is $5.1 billion and includes: reconductoring 947 miles of transmission lines; converting the operating voltages of 533 miles of transmission lines; and adding 3,295 miles of new transmission lines, 753 Mvars of new capacitors, and 104 new or upgraded transformers.
The summaries are somewhat characteristic of what one might expect due to future uncertainties, with the greater number of identifiable dollars being spent in the first five years and fewer in the last five years. These graphs include all Network Upgrades in SPP, not just the reliability-based upgrades. The early years include a greater number of Transmission Owner zonal, Transmission Service, Balanced Portfolio projects, and several new projects in the Southwestern Public Service
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Company area as a result of the large increase in load. The later years are predominantly regional reliability projects, for both SPP OATT participating members and non-OATT members. Also impacting the number of new projects this year is the integration of the AECI Joint Coordinated System Plan into the STEP. The following graphs provide additional information about the 2010 STEP:
Cost (Billions) by Facility Type
$0B $1B $2B $3B $4B
New Lines Transformers Line Rebuilds Voltage Conversions Substation Upgrades Cap / Reactive Devices
Costs of Line Upgrades
$1,200M
$1,000M
$800M
Cost $600M
$400M
$200M
$0M 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021
Year
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Miles of Line Upgrades
1500
1200
900 Miles 600
300
0 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 New Lines Line Rebuilds Voltage Conversions Year
Costs of Capacitors & Reactive Devices $14M
$12M
$10M
$8M
Cost $6M
$4M
$2M
$0M 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021
Year
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History of Total Miles 1400
1200
1000
800
Miles 600
400
200
0 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021
2008STEP 2009STEPYear 2010STEP
History of New Lines 1400
1200
1000
800
Miles 600
400
200
0 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021
2008STEP 2009STEPYear 2010STEP
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History of Rebuilds and Conversions 1400
1200
1000
800
Miles 600
400
200
0 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021
2008STEP 2009STEPYear 2010STEP
Identified criteria violations were shared during SPP’s planning summits to solicit stakeholder suggestions for Network Upgrades to address the violations. SPP staff created a pool of solutions using input received from stakeholders, solutions used in SPP’s Aggregate Studies, proposed Network Upgrades provided by stakeholders, and alternative solutions suggested by SPP staff.
SPP staff independently evaluated the alternatives and made recommendations from this pool of solutions for reliability Network Upgrades. SPP did not necessarily recommend the least-cost solution in all circumstances. Engineering judgment was sometimes applied and recommendations were developed to fit long-term strategy and plans. SPP recommends the best solution considering many factors beyond cost over the short-term five-year horizon. Externalities are reflected in SPP staff recommendations, which have been reviewed and revised as appropriate, based on stakeholder feedback. Appendix C contains diagrams of Network Upgrades providing their location, type, and projected in-service year.
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3.5 Loss of Load Expectation Analysis
3.5.1 Introduction SPP Criteria 4.3.5 states “SPP will use a probabilistic approach for Regional and sub-regional Generation Reliability assessments. These assessments will be performed by the SPP on a biennial basis. Generation Reliability assessments examine the regional ability to maintain a Loss of Load Expectation (LOLE) standard of 1 day in ten years. The SPP capacity margin Criteria requires each control area to maintain a minimum of 12% capacity margin for steam-based utilities and 9% for hydro-based utilities. Historical studies indicate that the LOLE of one day in ten years can be maintained with a 10% - 11% capacity margin.”
Though criteria requires SPP to conduct LOLE studies on a biennial basis, SPP plans to conduct LOLE assessments on an annual basis, rotating between near-term and long-term assessments each year.
The 2010 LOLE study investigates the expected number of days per year for which available generating capacity is insufficient to serve the daily peak demand. The LOLE is usually measured in days/year or hours/year. When given in days/year, it represents a comparison between daily peak values and available generation. When given in hours/year, it represents a comparison of hourly load to available generation. LOLE is sometimes referred to as Loss of Load Probability (LOLP), where LOLP is the proportion (probability) of days per year, hours per year, or events per season that available generating capacity/energy is insufficient to serve the daily peak or hourly demand. This analysis is generally performed for several years into the future and the typical standard metric is the LOLP of one day in ten years or 0.1 day/year. LOLE is a DC power flow study, so it does not address voltage or stability issues.
3.5.2 Objective The LOLE study has two purposes. It provides an assessment of whether currently installed generation capacity is adequate to serve the forecasted load, given a set of random generator outages. It also assesses whether the capacity margin requirement of 12% is adequate to maintain an LOLE of one day in ten years.
3.5.3 Background SPP performed an LOLE study in 2008 specifically for the Southwestern Public Service Company (SPS) area. The following suggestions were made in the conclusion of the report for near-term reliability support: ¾ Build a new 345 kV transmission line from Woodward to Tuco ¾ Increase the SPP-SPS flowgate limit to 1,134 MW ¾ Add new generation resources in SPS area These conclusions are addressed in this study. Specific assumptions in the SPS area were made as discussed in later sections.
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3.5.4 Study Assumptions
Study year: 2016
Powerflow base: 2010 MDWG 2016 Summer Peak
Transmission projects: Board of Directors-approved 2009 STEP Appendix B projects through 2016, Balanced Portfolio, 2010 Priority Projects
Forced Outage Rate: Based on Generation Availability Data System data, updated with ITP20 PROMOD data
Peak Demand: 52,460 MW (Summer Peak)
Installed Capacity: 65,612 MW (Capacity of all generators in SPP in the PROMOD model excluding wind) 69,274 MW (Capacity of all generators in SPP in the PROMOD model including wind)
3.5.5 Flowgate Assumptions In response to suggestions in the 2008 LOLE study, in this study the following flowgate assumption is made in the SPS area:
¾ SPP-SPS Interface Limits: 1,140 MW ¾ SPS North-South Limit: 800 MW The changes in import limits for this study were made based on the addition of the Tuco-Woodward 345 kV.7 In the 2008 study, the following assumption was made:
¾ SPP-SPS Interface Limits: 1,027 MW ¾ SPS North-South Limit: 800 MW
3.5.6 Conclusion Based on the results of 2010 study, the LOLE is zero after the inclusion of Priority Projects, and the LOLE standard of one day in ten years is maintained with a capacity margin of 9.25%8, which is below the SPP requirement of 12%.
7 The adjusted SPP-SPS interface limit assumption does not reflect the actual power flow limit after the addition of the Tuco- Woodward and Woodward-Hitchland lines.
8 The capacity margin calculation is based on the assumption of 0% capacity credit for wind farms. If a 5% capacity credit were considered, the capacity margin would be 9.51%
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System reliability increases due to the implementation of suggestions in the 2008 study. The system LOLE is about 0.28 hour/year before the inclusion of Priority Projects. All un-served load in the SPS area is caused by congestion on the SPP-SPS Interface.
In the 2008 LOLE study, three suggestions were made to improve the reliability of the system in the near-term. Those suggestions were: ¾ Build a new 345 kV transmission line from Woodward to Tuco ¾ Increase the SPP-SPS flowgate limit to 1,134 MW ¾ Add new generation resources in SPS area The Woodward-Tuco 345 kV line was approved as part of the Balanced Portfolio and is included in the base case models for this study. Due to the addition of this line, the SPP-SPS interface limit increased from 1,027 MW to 1,140 MW for the purpose of this study. The increase in the SPP-SPS interface limit contributes to a reduction in congestion of the SPP-SPS interface. The addition of the Hitchland-Woodward 345 kV line from the Priority Projects significantly reduces congestion on the SPP-SPS interface as well.
Additional wind farms, the Jones 3 generator, and Golden Spread Electric Cooperative’s Antelope Station were added to the base case. Additional resources in the SPS area also contribute to a reduction in imports across the SPP-SPS interface, which adds to the LOLE decrease.
The results of 2010 study confirm the results of the 2008 study. The 2008 study identified additional reinforcements in the SPS area that would be necessary to decrease the probability of lost load. Those suggestions were incorporated into this study, and the results show that additional transmission and generation capacity in the SPS region contributes to reducing the LOLE to zero under forecasted conditions in 2016.
3.5.7 Recommendation Based on the LOLE report results, which focus on future conditions, it is recommended that the SPP capacity margin requirement of 12% is maintained. The next near-term LOLE assessment may provide a better basis for assessing the capacity margin requirement for the SPP system.
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4. Tariff Studies
Following is a cost estimate summary of all Transmission Service Request (TSR) and Generation Interconnection (GI) projects with filed service agreements documented in the 2010 STEP report:
2010 STEP 2009 STEP 2008 STEP Upgrade Type ($ Million) ($ Million) ($ Million)
(TSR) transmission service* $550 $455 $235 (GI) Generation Interconnection $103 $81 $84 TSR/GI Sub Total $653 $536 $319 *Regional reliability upgrades associated with transmission service are included in the Reliability subtotal in this report
4.1 Transmission Service 2010 Overview
During 2009, SPP’s Tariff Studies staff posted Aggregate Facility Studies to meet 60-day study completion deadlines and posted Facilities Studies to meet FERC Order 890 metric requirements. Order 890 requires Transmission Providers to file notice with FERC if more than 20% of the System Impact and Facilities studies in any two consecutive calendar quarters are not completed in the 60- day study window. In 2010, the following percentages were late:
Quarter 1 – 0% Quarter 2 – 0% Quarter 3 – 0% Quarter 4 (still active) – 0%
SPP was not required to file with FERC, as there were no two consecutive quarters in which more than 20% of the studies were late, due in large part to the timely submission of documentation by Transmission Owners. As of December 29, 2010, SPP has posted 12 Aggregate Studies, down from 17 studies in 2009. SPP also posted four delivery point transfer screening studies.
4.2 Generation Interconnection 2010 Overview
As of October 30, 2010, SPP received 55 GI Requests, similar to the 50 received through the same period in 2009. As of that date, there were 116 active queue requests for 20,180MW under study.
During 2010, SPP Wind Generation Task Force (WITF) completed and issued its wind integration report. The study examined three wind penetration levels and compared each to current system conditions. Detailed analysis was completed on 10% and 20% wind levels by annual energy; limited analysis was completed on a 40% case. SPP wind generation resources are primarily located in the western part of the region, typically in sparsely-populated locations with little transmission and electricity demand. The study found that an increase in the wind penetration level causes changes in power flow patterns – particularly increased flow from the western to the eastern part of the region – requiring upgrades and/or reconfigurations to the transmission system. To accommodate the
Tariff Studies 33
increased west-to-east flows while meeting SPP’s electric reliability standards: For the 10% case, new transmission lines totaling 1,260 miles of 345 kV and 40 miles of 230 kV lines are needed. For the 20% case, an additional 485 miles of 765 kV, 766 miles of 345 kV, 205 miles of 230 kV, and 25 miles of 115 kV lines are needed. These findings are consistent with CRA’s 2008 analysis of SPP’s Extra High Voltage Overlay plans. Other significant study findings, assuming all needed transmission upgrades and an SPP Day- Ahead market is in place: Integrating the levels of wind studied in the 10% and 20% cases could be attained without adversely impacting SPP system reliability. Wind integration would be greatly facilitated by the creation of an SPP consolidated balancing authority, in which SPP would balance electricity supply and demand for the entire region. While a consolidated balancing authority should reduce overall needs for electric reserves and flexible resources, greater operational flexibility would be required to quickly respond to injections of wind to the grid. As wind generation increases or decreases, other sources of generation must quickly ramp up or back down to keep an uninterrupted power flow. Efficient wind integration requires a sophisticated process for determining what generating units are utilized throughout the region, explicitly addressing the uncertainty associated with wind forecast errors. The implementation of a centralized forecasting system would be advantageous. The study further identified the impact of wind penetration on the scope and level of required reserve energy and generation patterns.
4.3 Area Generation Connection Task Force 2010 Overview
In April 2010 the Markets and Operations Policy Committee (MOPC) created the Area Generation Connection Task Force (AGCTF) to develop policy to guide SPP staff in determining the optimum method of interconnecting generation, considering the many complex situations including multiple generation developers in a concentrated area that may or may not have nearby transmission lines. The AGCTF gave an update to the MOPC in October 2010 that included the following possible recommendations: 1) The designation of generation collector substations through the ITP process 2) More stringent interconnection requirements for customers that do not interconnect at a designated hub 3) Restrictions on building redundant substation facilities 4) Possible designation of a generation collection system for SPP.
No recommendations have been approved; the AGCTF will make another report in January 2011.
4.4 Tariff Attachments AQ and AR
During 2010, SPP Tariff attachments AQ and AR were approved by FERC. Attachment AQ became effective in May 2010. Attachment AQ is a process through which delivery point additions, modifications, or abandonments can be studied without having to go through the Aggregate Study process. Delivery points submitted through the process are examined in an initial assessment to determine if a project is likely to have a significant effect on the transmission system. If necessary, a full study is then performed on the requested delivery points to determine any necessary upgrades. As of December 1, 2010 twenty six delivery point requests have been made, of which two have required full studies that should be complete by early 2011.
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Flow chart diagram for AQ Studies
SPP Tariff attachment AR became effective in February 2010. Attachment AR is a screening process used to evaluate potential Long-Term Service request (LTSR) options or proposed Delivery Point Transfers (DPT). The LTSR option provides customers with a tool to determine which LTSR to pursue in the Aggregate Study process. The DPT option enables customers to implement a DPT via issuance of a service agreement more expediently pending the results of the screening. Both of these screening tools allow for a more streamlined aggregate study process by reducing the number of requests in the studies. As of December 1, 2010 five DPT requests have been made, of which four have been granted service. Thirteen LTSR requests have been made; results should be reported by early 2011.
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Flow Chart for AR process
Tariff Studies 36
5. Sub-regional (Local Area) Planning
Based on FERC Order 890 and Section III.2.b of Attachment O of the SPP Open Access Transmission Tariff (OATT), sub-regional areas were defined and local area planning meetings were held in conjunction with Transmission Working Group (TWG) meetings.
The purpose of local area planning meetings is to identify unresolved local issues and transmission solutions at a more granular level than can be accomplished at general regional planning meetings. Local area planning meetings provide stakeholders with local needs the opportunity to give advice and recommendations to the Transmission Provider and Transmission Owners. Local area planning meetings are open, coordinated, and transparent, providing a forum to review local area planning criteria as specified in Section II of the OATT, Attachment O. Feedback offered at each sub-regional meeting is taken into consideration by SPP staff when developing the regional reliability plan.
5.1 Stakeholders Process and Forums
Notices for the sub-regional meetings are posted on SPP.org and distributed to email distribution lists. Sub-regional planning meetings are open to all entities. Any regulatory agency having utility rates or services jurisdiction over an SPP member is invited and encouraged to fully participate.
The map above represents the SPP region broken into three local areas. Local Area 3 has two components (3 and 3a) – the SPP RTO and SPP Independent Coordinator of Transmission (Entergy) footprints.
Sub-Regional Planning 37
5.2 2010 Sub-regional Meetings
Area 3/3a: February 2 - Little Rock, AR 7 Transmission Owner presentations Area 1: May 11 – Amarillo, TX 3 Transmission Owner presentations Area 2: August 3 – Overland Park, KS 7 Transmission Owner presentations
Each sub-regional meeting featured the local area construction plans of both Transmission Owners and local stakeholders. When preparing for the sub-regional meetings, SPP staff asked Tier 1 neighbors to share their plans with the group. Most presenters discussed projects in their organizations’ areas. A question-and-answer period followed each presentation.
A variety of discussions took place during 2010. Topics focused on flowgates, interconnections, attachment AQ of the SPP OATT, NERC reliability and SPP transmission reliability criteria, the SPP reliability planning process, the various functions of the SPP Engineering department, and forecasting methods.
Meeting agendas, local area construction plan presentations (that were basically limited to 69 kV and above), and meeting notes were posted on SPP.org > Engineering > Transmission Planning > Local Area Planning and High Priority Studies.
On March 15, 2010 SPP held a web conference with representatives of Lincoln Electric System. Presentations were given by SPP staff on topics including local area planning, the STEP 10-year reliability assessment, and the ITP process. Questions pertaining to these topics were answered by SPP staff.
On July 14, 2010 SPP representatives attended an Associated Electric Cooperative (AECI) long- range plan stakeholder meeting in Springfield, Missouri. AECI provided presentations on their 2009- 2019 long-range plan, and discussed the status of their 2011 -2021 long range plan. AECI also discussed their coordination with other companies, including SPP.
On August 18, 2010 SPP representatives attended a local planning meeting hosted by Southwestern Public Service Company (SPS) in Amarillo, TX. SPS representatives provided several presentations which included updates on their construction plans and their process for complying with the new SPP OATT attachment AQ process. SPP and SPS representatives discussed attachment AQ at length.
Two meetings were held with the East Texas Electric Cooperative, Inc. in Douglasville, Texas on March 3, 2010 and Shreveport, Louisiana on October 6, 2010. The meetings were attended by the member cooperatives, American Electric Power, and SPP staff. Participants reviewed 2009 and 2010 STEP results as well as the status of the ITP20 analysis. Typical questions and answers focused on the STEP and ITP20 and their construction implications for the member cooperatives.
The 2010 SPP Exxon-Mobil and TransCanada Load Study evaluated the effects within the entire SPP footprint due to the additional loads being served to the new Exxon-Mobil and TransCanada pumping Stations, PS-37 & 38. A previous study, “2009 SPP TransCanada Pipeline Study” was completed by SPP staff in July 2009. However, the Exxon-Mobil 62 MW addition, in American Electric Power area, constituted a large load increase in a mainly rural area.
Sub-Regional Planning 38
5.3 2010 SPP Exxon-Mobil and TransCanada Load Study
The objective of this study was to determine the effects within the entire SPP footprint of the additional loads being served to the new Exxon-Mobil pumping station and TransCanada pumping stations PS-37 and 38. The study analyzed a total of 106 MW of load added to the SPP footprint.
The general area studied is shown in the map below. The Exxon-Mobil load is located near the Perdue substation. The TransCanada loads, PS-37 and 38, are shown north and south of that location. All three new loads are for electrically driven pumping stations and processes.
When the Exxon-Mobil load was analyzed on the SPP system, a number of voltage and thermal problems occurred in multiple areas in SPP. To relieve these violations, six reliability projects were identified. This information was considered in the 2010 STEP.
1. DIANA - PERDUE 138KV CKT 1 equipment upgrade by 2014 2. EXXONM 4 138.00 - PERDUE 138KV CKT 1 equipment adjustment by 2011 3. TEXAS EASTMAN - WHITNEY 138KV CKT 1 re-conductor 2.49 miles by 2014 4. BEN WHEELER_STARR CLOSE the OPEN TIE by 2017
Sub-Regional Planning 39
5. WELSH REC - WILKES 138KV CKT 1 equipment upgrade by 2019 6. WINNSBORO 28.8 MVAR new capacitor bank by 2019
When the PS-37 and PS-38 load additions were analyzed on the SPP system, a number of voltage problems occurred within SPP. To relieve these violations, four new reliability projects were identified. This information was considered in the 2010 STEP.
6. a. WINNSBORO 28.8 MVAR new capacitor bank by 2014 not 2019 as above in # 6 7. PETTY, 508310, 28.8 MVAR new capacitor bank by 2014 SP 8. EXXON-MOBIL, 508369, 28.8 MVAR new capacitor bank with 2 block steps by 2016 9. WELSH REC – CHAPEL HILL 138 kV CKT 1 equipment upgrade by 2019 10. DIANA – PERDUE 138 KV CKT 1 re-conductor 21.85 miles by 2019
The estimated project costs for the following owners are as follows:
Transmission Area 2014 2016 2019 Total
AEP $5,832,800 $1,166,400 $22,565,000 $29,564,200
Read the 2010 Exxon-Mobil Study, which is posted on SPP.org>Engineering>Tariff Studies>Assessments and Forecasts.
Sub-Regional Planning 40
6. 2010 Transmission Congestion and Top Flowgates
6.1 SPP 2010 Transmission Congestion
SPP staff identifies congested areas by monitoring flowgates and analyzing their causes and effects. The graphic below is a typical Energy Imbalance Services market price contour map for the SPP footprint. The map is from the September 2010 SPP Monthly State of the Market Report and shows the average Locational Imbalance Prices (LIPs) from October 2009 to September 2010. The regions with the brighter shades (red, orange, and yellow) have higher LIPs. The areas with transmission congestion, on this annual basis, occur at the points between different shades of colors. Note that market prices vary over time and that the graphic shows the average price at the nodes.
Congestion occurs for a variety of reasons in different parts of the SPP footprint depending on the time of year. One of the drivers for new and future congestion in the SPP footprint is wind generation. Wind currently represents about 4% of generation in the SPP region, and is continually developing. As wind farms in the western part of SPP continue to develop, the congestion in that region should increase until adequate transmission is in place. Factors causing congestion in the Greater Kansas City area included Heavy north – south flow from Nebraska into Kansas, high external impacts, high SPP market flow in the Kansas City load pocket and unit testing.
Transmission Congestion and Top Flowgates 41
Congestion in all parts of the footprint can sometimes be attributed to generation and line outages or general load growth.
6.2 SPP Top Ten Flowgates
SPP monitors over 250 flowgates. From these, the ten SPP flowgates with the highest “shadow price” over the previous twelve months are shown in the SPP EIS Monthly State of the Market Reports posted on SPP.org>Market>Market Reports. A shadow price is the amount of value, measured in dollars, of relieving a constraint by a small amount. The value of relieving a constraint is generally that lower-priced power can be used, so the value is reflected in the difference in Locational Imbalance Prices on either side of the constraint.
The table below shows the annual top ten flowgates from the September 2010 Monthly State of the Market Report. This table includes a list of projects that are expected to provide some positive mitigation to the flowgates. This list of projects is sorted by the estimated in-service date. As described by the upgrade type, the upgrades were planned to provide one or more benefits, such as reliability or regional economic enhancements, but not necessarily to directly solve all congestion on the particular flowgate listed. SPP has directed project owners to begin construction on the projects shown in this table via Notifications to Construct (NTCs). For more information about these projects, please refer to the Project Tracking & NTCs page on SPP.org.
Average Total % Projects Expected to Provide Some Hourly Intervals Positive Mitigation Region Flowgate Name Flowgate Location (kV) Shadow (Breached Price (Estimated In Service Date – or Binding) ($/MWh) Upgrade Type) 1. Tuco Int. – Woodward 345 kV line (May 2014 - Osage Switch - Canyon East [SPS] Balanced Portfolio) OSGCANBUSDEA [(115) ftlo Bushland - Deaf Smith $ 33.35 22.0% 2. Castro County Int. – Newhart 115 kV line (April [SPS] (230) 2015 - Regional reliability) 1. Rebuild Randall Co–Palo Duro 115 kV line (April 2014 - no NTC but is Sponsored) Randall County - Palo Duro (115) Texas 2. Tuco Int. – Woodward 345 kV line (May 2014 - RANPALAMASWI ftlo Amarillo – Swisher (230) Panhandle $ 9.18 3.4% Balanced Portfolio) [SPS] 3. Swisher Co. Int. – Newhart 230 kV line (April 2015 - Regional reliability) 1. Tuco Int. – Woodward 345 kV line (May 2014 - Shamrock XFR [CSWS] (115/69) Balanced Portfolio) SHAXFRTUCOKU ftlo Tuco – Oklaunion [SPS- $ 5.44 3.6% 2. Two Hitchland – Woodward 345 kV lines (June CSWS] (345) 2014 - Priority Projects) 1. Axtell–Post Rock–Spearville 345 kV line, two Spearville – Comanche – Woodward 345 kV lines, and two Comanche – Medicine Lodge – Wichita Lake Road – Alabama [GMOC] 345 kV lines (12/31/2014 - Balanced Kansas City LAKALASTJHAW (161) ftlo St. Joe – Hawthorn Portfolio/Priority Projects) Area $ 9.54 1.4% [GMOC] (345) 2. Iatan – Nashua 345 kV line (June 2015 - Balanced Portfolio) 3. Nebraska City – Maryville – Sibley 345 kV line (June 2017 - Priority Projects)
Transmission Congestion and Top Flowgates 42
1. Iatan – Nashua 345 kV line (June 2015 - Balanced Platte City – KCI (161)[GMOC] Portfolio) PLAKCISTRCRA ftlo Stranger Creek – Craig (115) $ 8.97 1.4% 2. Nebraska City – Maryville – Sibley 345 kV line [KCPL] (June 2017 - Priority Projects) Lake Road – Alabama [GMOC] LAKALAIATSTR (161) ftlo Iatan to Stranger Creek $ 8.67 2.1% Same as LAKALASTJHAW above [KCPL] (345) Lone Oak to Sardis [CSWS] (138) SE 1. Sunnyside – Hugo – Valliant 345 kV line (April LONSARPITVAL ftlo Pittsburg – Valliant [CSWS] Oklahoma $ 9.90 2.3% 2012 - Transmission Service) (345) 1. Rose Hill – Sooner 345 kV line (June 2012 - El Paso – Farber [WR] (138) ftlo Regional reliability) Wichita ELPFARWICWDR Wichita – Woodring [WR-OGE] 2. Two Woodward – Comanche Co. – Medicine Area $ 6.86 4.2% (345) Lodge – Wichita 345 kV lines (Dec 2014 - Priority Projects) Holcomb – Plymell Switch [SECI] 1. Rebuild Holcomb – Plymell Switch 115 kV line SW Kansas HOLPLYHOLSPE (115) ftlo Holcomb - Spearville $ 6.03 1.9% (Dec 2011 - Regional reliability) [SECI] (345) 1. Knob Hill – Steele City 115 kV line (Oct 2010 - Regional reliability) 2. Rebuild Kelly – Seneca 115 kV line (Dec 2010 - Kelly – S. Seneca [WR] (115) ftlo Regional reliability) NE Kansas KELSENEMACON E Manhattan – Concordia [WR- $ 4.86 2.9% 3. Axtell–Post Rock–Spearville 345 kV line, two SECI] (230) Spearville – Comanche – Medicine Lodge – Wichita 345 kV lines, and two Medicine Lodge – Woodward 345 kV lines (12/31/2014 - Balanced Portfolio/Priority Projects)
The annual top ten flowgates as of September 2010 are detailed below.
OSGCANBUSDEA – Located in the Texas Panhandle
The OSGCANBUSDEA flowgate monitors the 115 kV transmission line from Osage Switch to Canyon East for the loss of the 230 kV line from Bushland to Deaf Smith. The percentage of total intervals breached or binding over the last twelve months is 22%. This flowgate had the highest average shadow price at $33.35.
The Tuco to Woodward 345 kV line, a new link between Texas and Oklahoma that is part of the Balanced Portfolio, is expected to provide some positive mitigation for this congestion when it goes into service in 2014. Another project that is expected to provide some mitigation is the Castro County Interchange to Newhart 115 kV line in the southern part of the Texas Panhandle, a regional reliability project that should be in service in 2015.
Transmission Congestion and Top Flowgates 43
Transmission Congestion and Top Flowgates 44
RANPALAMASAWI – Located in the Texas Panhandle
The RANPALAMASAWI flowgate monitors the 115 kV transmission line from Randall County to Palo Duro for the loss of the 230 kV line from Amarillo to Swisher. The percentage of total intervals breached or binding over the last twelve months is 3.4%. This flowgate had an average shadow price of $9.18.
The Randall County to Palo Duro 115 kV line will be rebuilt with a larger conductor in 2014, which is expected to provide some positive mitigation for this congestion. Another project that is expected to provide some mitigation is the Tuco to Woodward 345 kV line, a new link between Texas and Oklahoma that is part of the Balanced Portfolio that should be in service in 2014. A third project expected to provide some mitigation is the Swisher County Interchange to Newhart 230 kV line in the southern part of the Texas Panhandle, a regional reliability upgrade that should be in service in 2015.
Transmission Congestion and Top Flowgates 45
SHAXFRTUCOKU – Located in the Texas Panhandle
The SHAXFRTUCOKU flowgate monitors the 115/69 kV transformer at the Shamrock substation for the loss of the 345 kV line from Tuco to Oklaunion. The percentage of total intervals breached or binding over the last twelve months is 3.6%. This flowgate had an average shadow price of $5.44.
The Tuco to Woodward 345 kV line, a new link between Texas and Oklahoma that is part of the Balanced Portfolio, is expected to provide some positive mitigation for this congestion when it goes into service in 2014. Other upgrades expected to provide some mitigation are the double-circuit 345 kV lines crossing the Oklahoma Panhandle from Hitchland to Woodward, an approved Priority Project which is estimated to be in service in 2014.
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LAKALASTJHAW – Located in the Kansas City Area
The LAKALASTJHAW flowgate monitors the 161 kV transmission line from Lake Road to Alabama for the loss of the 345 kV line from St. Joe to Hawthorn. The percentage of total intervals breached or binding over the last twelve months is 1.4%. This flowgate had an average shadow price of $9.54.
Some Balanced Portfolio and Priority Project upgrades spanning Nebraska, Kansas, and Oklahoma are expected to provide some positive mitigation for this congestion when all are in service in 2014, including the Axtell to Post Rock to Spearville 345 kV line, Spearville to Comanche County to Medicine Lodge to Wichita double-circuit 345 kV, and Medicine Lodge to Woodward double-circuit 345 kV lines. Another project that is expected to provide some mitigation is the Iatan to Nashua 345 kV line north of Kansas City, part of the Balanced Portfolio that should be in service in 2015. Other projects expected to provide some mitigation are the Nebraska City to Maryville to Sibley 345 kV lines running from southeastern Nebraska to northwestern Missouri, a Priority Project which is estimated to be in service by 2017.
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PLAKCISTRCRA – Located in the Kansas City Area
The PLAKCISTRCRA flowgate monitors the 161 kV transmission line from Platte City to KCI for the loss of the 345 kV line from Stranger Creek to Craig. The percentage of total intervals breached or binding over the last twelve months is 1.4%. This flowgate had an average shadow price of $8.97.
A project expected to provide some positive mitigation is the Iatan to Nashua 345 kV line north of Kansas City, part of the Balanced Portfolio that should be in service in 2015. Other projects expected to provide some mitigation are the Nebraska City to Maryville to Sibley 345 kV lines running from southeastern Nebraska to northwestern Missouri, a Priority Project which is estimated to be in service by 2017.
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LAKALAIATSTR – Located in the Kansas City Area
The LAKALAIATSTR flowgate monitors the 161 kV transmission line from Lake Road to Alabama for the loss of the 345 kV line from Iatan to Stranger Creek. The percentage of total intervals breached or binding over the last twelve months is 2.1%. This flowgate had an average shadow price of $8.67.
Some Balanced Portfolio and Priority Project upgrades spanning Nebraska, Kansas, and Oklahoma are expected to provide some positive mitigation for this congestion when all are in service in 2014, including the Axtell to Post Rock to Spearville 345 kV line, Spearville to Comanche County to Medicine Lodge to Wichita double-circuit 345 kV lines, and Medicine Lodge to Woodward double- circuit 345 kV lines. Another project expected to provide some mitigation is the Iatan to Nashua 345 kV line north of Kansas City, part of the Balanced Portfolio that should be in service in 2015. Other projects expected to provide some mitigation are the Nebraska City to Maryville to Sibley 345 kV lines running from southeastern Nebraska to northwestern Missouri, a Priority Project estimated to be in service by 2017.
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LONSARPITVAL – Located in Southeast Oklahoma
The LONSARPITVAL flowgate monitors the 138 kV transmission line from Lone Oak to Sardis for the loss of the 345 kV line from Pittsburg to Valliant. The percentage of total intervals breached or binding over the last twelve months is 2.3%. This flowgate had an average shadow price of $9.90.
The Sunnyside to Hugo to Valliant 345 kV lines, transmission service upgrades in Southern Oklahoma, are expected to provide some positive mitigation for this congestion when they go into service in 2012.
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ELPFARWICWDR – Located in the Wichita Area
The ELPFARWICWDR flowgate monitors the 138 kV transmission line from El Paso to Farber for the loss of the 345 kV line from Wichita to Woodring. The percentage of total intervals breached or binding over the last twelve months is 4.2%. This flowgate had an average shadow price of $6.86.
The Rose Hill to Sooner 345 kV line, a regional reliability upgrade that crosses the Kansas/Oklahoma border, is expected to provide some positive mitigation for this congestion when it goes into service in 2012. Other upgrades that are expected to provide some mitigation are the double-circuit 345 kV lines from Woodward to Medicine Lodge to Wichita in northwestern Oklahoma and southern Kansas, part of the Priority Project upgrades which are estimated to be in service by 2014.
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HOLPLYHOLSPE – Located in Southwest Kansas
The HOLPLYHOLSPE flowgate monitors the 115 kV transmission line from Holcomb to Plymell Switch for the loss of the 345 kV line from Holcomb to Spearville. The percentage of total intervals breached or binding over the last twelve months is 1.9%. This flowgate had an average shadow price of $6.03.
The Holcomb to Plymell Switch 115 kV line will be rebuilt with a larger conductor in 2011 for regional reliability, which is expected to provide some positive mitigation for this congestion.
Transmission Congestion and Top Flowgates 52
KELSENEMACON – Located in Northeast Kansas
The KELSENEMACON flowgate monitors the 115 kV transmission line from Kelly to South Seneca for the loss of the 230 kV line from East Manhattan to Concordia. The percentage of total intervals breached or binding over the last twelve months is 2.9%. This flowgate had an average shadow price of $4.86.
The Knob Hill to Steele City 115 line, a regional reliability upgrade crossing the Nebraska/Kansas border, is expected to provide some positive mitigation for this congestion when it goes into service in 2010. The Kelly to South Seneca 115 kV line in northern Kansas will be rebuilt with a larger conductor in 2010 for regional reliability, which is also expected to provide some positive mitigation for this congestion. Other upgrades expected to provide some mitigation include some Balanced Portfolio and Priority Projects spanning Nebraska, Kansas, and Oklahoma that expected to be in- service in 2014, including the Axtell to Post Rock to Spearville 345 kV line, Spearville to Comanche County to Medicine Lodge to Wichita double-circuit 345 kV, and Medicine Lodge to Woodward double-circuit 345 kV lines.
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7. Interregional Coordination
7.1 SPP RTO and Entergy ICT
As the Independent Coordinator of Transmission (ICT) for Entergy Services, Inc. (Entergy), SPP facilitates transmission planning for Entergy. The SPP RTO and ICT coordinate planning study conclusions and look for opportunities to collaborate on seams-related transmission improvements. These investigations include evaluation of third-party impacts identified from transmission service requests on both systems. The RTO and ICT continue to work closely on the Joint Coordinated System Plan study, and both groups are involved in the SERC Reliability Corporation’s planning processes.
7.1.1 Entergy/SPP Regional Planning Process
7.1.1.1 Introduction In accordance with FERC Order 890, SPP OATT Attachment O, and Entergy OATT Attachment K, the Entergy/SPP Regional Planning Process (ESRPP) was created to identify system enhancements that could relieve interregional congestion between Entergy and SPP, and to share system plans to ensure they are simultaneously feasible and otherwise use consistent assumptions and data.
Up to five high-level studies can be requested annually to provide screening to identify constraints and needed upgrades, and to approximate costs and timelines. Based on the results of these high- level studies, stakeholders may request a more detailed study to be undertaken in the following planning cycle which will provide detailed cost estimates and timelines.
7.1.1.2 2010 Activity In March 2010, the Joint Planning Committee (JPC) shared the results of the 2009 ESRPP study efforts. The JPC reviewed the 5 projects below:
• Turk – McNeil 345kV Line • Spadra – Russellville 161kV • Messick 500/230kV Transformer • Flint Creek – Chamber Springs – Fort Smith – ANO 345kV
The initial high-level transfer analysis results were presented along with project cost estimates. The ESRPP kicked-off its 2010 efforts in the late spring. In May, stakeholders chose the five regional economic studies to be performed in 2010 for either high-level studies or more detailed analyses:
Detailed Studies as a continuation from 2009 ESRPP; • Turk – McNeil 345 kV Line • Messick 500/230 kV Auto
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New High-level Studies • Transfer of 3,000 MW from Arkansas IPPs ( Hot Springs, Magnet Cove, and PUPP) to SPP South (AEP and OGE) • Transfer of 700 MW from AEP to Entergy Arkansas • Transfer of 700 MW from Entergy Arkansas to AEP
In the August ESRPP meeting, the JPC presented an overview of the initial results of the stakeholders’ regional 2010 economic studies. In the first quarter of 2011, it is expected that the ESRPP 2010 Report will be completed and presented at an ESRPP meeting.
7.1.2 2010 Cost-Benefit Analysis In 2009 FERC directed Entergy to consider membership in the SPP RTO. FERC funded a study to determine the benefit of Entergy joining the SPP RTO, and selected and Charles River and Associates (CRA) to conduct the study. SPP staff supported the effort, including providing generation, operational, and transmission information to CRA. For this study SPP built special power flow models that included SPP, Entergy, TVA, and Southern Company.
SPP conducted a reliability assessment on Entergy’s system using SPP criteria and Entergy- proposed upgrades and costs. These upgrades and cost estimates were used as the costs for Entergy to join SPP. SPP identified upgrades that would be required for Entergy to join SPP and costs that would qualify for cost allocation under the Highway/Byway methodology.
The Entergy SPP Cost Benefit study report and presentation was completed and presented to FERC in September 2010. CRA will complete various addendum studies, including an evaluation of Entergy Arkansas joining SPP, Entergy joining MISO, and CLECO joining SPP.
7.2 AECI Interaction
7.2.1 AECI-SPP JCSP
As part of a seams coordination effort, Associated Electric Cooperative (AECI) participated in the 2010 reliability assessment, Section 3, as if they were a member of SPP. AECI findings are documented as part of the reliability assessment but will not be presented for approval to the Board. Total dollars for AECI upgrades are shown below. See Appendix D for AECI project details.
AECI also participated in the 2010 ITP20 efforts, providing valuable feedback throughout the study process. These studies and their coordination together are considered the 2010 AECI-SPP Joint Coordinated System Plan, which meets all requirements of the AECI-SPP Joint Operating Agreement.
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AECI Upgrades Total Costs (in millions) Inter-regional $ 100 Regional reliability – non OATT $ 273 Total: 83 projects $ 373
7.2.2 AECI-SPP Joint Inter-regional Transmission Project in Ozark area As part of a coordination effort, AECI, City Utilities of Springfield, Empire District Electric, Southwest Power Administration, and SPP met in October and discussed a potential project in the Ozark area in southwest Missouri made up of 345 kV transmission facilities. These facilities would run between Springfield and Branson, continuing south from Branson to Osage Creek, and from Branson going eastward to Thayer. The group agreed to study the benefits of the projects. The study will be completed in the first quarter 2011. Once the study is complete the parties will begin discussing cost sharing.
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7.3 ITP Interaction
The 2010 ITP 20-Year Assessment considered seams impacts in accordance with FERC Order 890 principles. SPP contacted neighboring parties to coordinate the inputs and results of the analysis. SPP analyzed whether alternative interregional projects would more efficiently or effectively meet SPP’s needs as compared with projects developed entirely within the SPP or neighboring region’s boundaries. This analysis should help improve the coordination of proposed interregional upgrades, identify more efficient and cost-effective solutions along the seams, and potentially reduce the cost of transmission plans for both parties. SPP also considered projects which may have an impact on one or more of the SPP seams as shown in the table below.
Seams Project Area Ozark Plan AECI - SPP - EES ISES - Osage Creek 500kV EES - SPP NW Texarkana - Ft. Smith 345 kV EES - SPP Dolet Hills - Messick 345 kV EES - SPP Lacygne - Mariosa Delta 345 kV AECI - SPP Holt Co - Sioux City 345 kV MISO - SPP Turk - McNeil 345 kV EES - SPP Messick Transformer 500/230 kV EES - SPP Delaware - Afton 345 kV SPP - AECI Big Cajun 2 - Cocodrie 230kV EES - SPP Grand Island - Wheeler Co (Rebuild) 345 kV WAPA - SPP Tapping Grand Island - Ft Thompson 345 kV WAPA - SPP Table: Seams Projects
7.4 MISO Cross Border Study Interaction
MISO performed the Cross Border Top Congested Flowgates Study in 2010 to analyze the congested flowgates on the seams of MISO. The study identified transmission upgrades to relieve congestion on MISO seams, including in Iowa and Nebraska. SPP staff and members participated in the study by providing input model support and potential upgrades for the congestion corridors. The results of this study will be part of MISO’s 2010 Midwest ISO Transmission Expansion Plan scheduled for publication in December 2010.
7.5 WAPA- Basin Electric Interaction
In an effort to form seams agreements with its neighboring entities, SPP held discussions with Western Area Power Administration (WAPA) concerning operational and planning level coordination. Staff from SPP, WAPA, and Basin Electric (a neighboring entity to WAPA and SPP) established three sub-teams to meet and discuss tariff administration, transmission planning, and AFC coordination. In the spring of 2010, the parties began discussing transmission planning processes in both regions for educational purposes prior to writing a seams agreement. In summer 2010 the group was expanded to include Nebraska Public Power District as a party to the
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discussions. The group is working through a draft agreement Monthly calls are held to continue discussing the planning components of the seams agreement.
7.6 Eastern Interconnection Planning Collaborative
7.6.1 Background The Eastern Interconnection Planning Collaborative (EIPC) represents the entire Eastern Interconnection and was initiated by a coalition of NERC-registered regional Planning Authorities. The EIPC was founded to be a broad-based, transparent collaborative process among all interested stakeholders:
• State and federal policy makers • Consumer and environmental interests • Transmission Planning Authorities • Market participants within the Eastern Interconnection
The EIPC builds on the regional expansion plans developed each year by regional stakeholders in collaboration with their respective NERC Planning Authorities. This approach provides coordinated interregional analysis for the entire Eastern Interconnection guided by the consensus input of an open and transparent stakeholder process.
The EIPC represents a first-of-its-kind effort to involve Eastern Interconnection Planning Authorities in modeling the impact on the grid of various policy options determined to be of interest by state, provincial, and federal policy makers and other stakeholders. This work will build on, rather than replace, current local and regional transmission planning processes developed by the Planning Authorities and associated regional stakeholder groups within the Eastern Interconnection. Those processes will be informed by EIPC’s efforts, including the interconnection-wide review of existing regional plans and development of transmission options associated with the various policy options.
The EIPC will establish processes for aggregating the entire Eastern Interconnection’ s modeling and regional transmission plans and for performing interregional analyses to identify potential opportunities for efficiencies between regions in serving the needs of electrical customers. This interconnection-wide analysis will also serve as the reference case for modeling alternative grid expansions based on scenarios guided by stakeholder input and consensus recommendations of a multi-constituency stakeholder steering committee. The analysis will aid states and other stakeholders in assessing interregional options and policy decisions.
The project will benefit power system stakeholders by providing modeling and analysis considering the entire Eastern Interconnection, identifying potential opportunities for efficiencies between regional transmission plans, providing coordinated analysis of scenarios of interest to policy makers and stakeholders, and developing potential transmission expansion options and cost estimates to inform their decisions.
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7.6.2 SPP Engineering Involvement The SPP Engineering department is actively involved in the EIPC model building process through its participation in the Eastern Interconnection Planning and Steady State Modeling and Load Flow Working Group (SSMLFWG). The SSMLFWG’s focus during 2010 was the construction of a 2020 Summer Peak model. This model, which incorporates all SPP modeling data, is considered to be the base case and will be the foundation for all subsequent models. In 2011, SPP will remain involved in the modeling and planning processes and will contribute as required.
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8. Project Tracking
After the SPP Board of Directors (Board) approves a transmission project and a Notification to Construct (NTC) is issued, SPP tracks and monitors the projects to ensure they continue to provide the best regional transmission solutions and, where applicable, are following cost recovery requirements under the SPP Open Access Transmission Tariff (OATT). SPP provides quarterly project status updates to the Board on approved transmission projects.
8.1 NTC Letters Issued in 2010
The NTC, previously called a Letter of Authorization, informs transmission project owners of their responsibility for constructing Board-approved Network Upgrades. NTCs were requested by project owners to assist them in the regulatory and cost recovery process. In 2010, 50 NTCs were issued with current estimated engineering and construction costs of $2.37 billion. Of this $2.37 billion, approximately $810 million was identified for regional reliability, $140 million for transmission service, and $1.42 billion for Priority Projects.
8.2 Projects Completed in 2010
As of the third quarter of 2010, 63 upgrades had been completed, and another 31 were scheduled to be completed by the end of 2010. Of the upgrades completed in 2010, 30 were identified for regional reliability, three for zonal- sponsored needs, 14 for transmission service, eight for sponsored upgrades, and seven for Generation Interconnect agreements. The total estimated engineering and construction cost for upgrades completed in 2010 was $434 million, with $58 million for regional reliability, $27 million for transmission service, $12 million for zonal-sponsored upgrades, $20 million for Generation Interconnect agreements, and $317 million for sponsored upgrades.
Project Tracking 60 Appendix A - Complete List of Network Upgrades
Appendix A is a complete list of planned 2011 - 2021 SPP transmission Network Upgrades identified by the following seven sources:
Projects in appendices A and B are categorized in the column labeled “Project Type Exp” by the following designations:
Balanced Portfolio – Projects identified through the Balanced Portfolio process
Generation Interconnect – Projects associated with a FERC-filed Generation Interconnection Agreement
Interregional – Projects developed with neighboring Transmission Providers (Appendix A only)
High priority-Project- identified in the high priority process
Regional reliability – Projects needed to meet the reliability of the region
Regional reliability – non-OATT – Projects to maintain reliability for SPP members not participating under the SPP OATT (Appendix A only)
Transmission service – Projects associated with a FERC-filed Service Agreement ' Sponsored – Projects with an executed Project Sponsor Agreement or that have previously been identified as an economic projects to receive transmission revenue credits under the OATT attachment Z2.
Zonal Reliability – Projects identified to meet more stringent local Transmission Owner criteria
Zonal – sponsored – Projects sponsored by facility owner with no Project Sponsor Agreement
The complete Network Upgrade list includes three dates.
1. In-service: Date Transmission Owner has identified as the date the upgrade is planned to be in- service.
2. 2010 STEP Date: Date upgrade was identified as needed for reliability, based on the 2009STEP analysis.
M: Upgrade was in the base load flow model,
R: Upgrade was replaced by an alternate project
D: Project was deferred beyond 2021
The column titled “BOD Requested Action” lists the action for which sponsors or RTO staff are requesting of the SPP Board of Directors (BOD) and have SPP RTO support. The cost estimates highlighted in yellow were estimated by SPP.
Facility owner abbreviations used in Appendices A and B:
Abbreviation and Identification AECC Arkansas Electric Cooperatives AECI Associated Electric Cooperative, Incorporated AEP American Electric Power CRE Cap Rock Energy CUS City Utilities, Springfield Missouri DETEC Deep East Texas Electric Cooperative EDE Empire District Electric Company EES Entergy, Incorporated GMO KCP&L Greater Missouri Operations Company GRDA Grand River Dam Authority GRIS Grand Island Electric Department (GRIS) INDN City Power & Light, Independence, Missouri HU Hastings Utilities ITCGP ITC Great Plains KACY Board of Public Utilities, Kansas City, KS KCPL Kansas City Power and Light Company LEA Lea County Cooperative LES Lincoln Electric System NEO Northeast Oklahoma Electric Cooperative MIDW Midwest Energy, Incorporated MKEC Mid-Kansas Electric Company NPPD Nebraska Public Power District OGE Oklahoma Gas and Electric Company OMPA Oklahoma Municipal Power Authority OPPD Omaha Public Power District RCEC Rayburn Electric Cooperative SEPC Sunflower Electric Power Corporation SPS Southwestern Public Service Company SWPA Southwestern Power Administration TSGT Tri-State G & T Association WAPA Western Area Power Pool WFEC Western Farmers Electric Cooperative WR Westar Energy Appendix B - List of SPP Reliability Network Upgrades Recommended for Notification to Construct
Appendix B lists proposed transmission projects for which sponsors or RTO staff requested 1st quarter of 2011 BOD action and were subsequently approved for construction. These include projects specifically needed for regional reliability having a financial commitment lead time falling inside the 2011-2014 four-year commitment window.
Appendix A includes more than just regional reliability upgrades. For example, Appendix A may include economic projects through the economic Balanced Portfolio process or projects for which cancellation is being sought. Appendix B is a subset of the Network Upgrade list in Appendix A. These Network Upgrades are endorsed by the SPP RTO expansion planning staff (for approval by the SPP BOD to direct construction). They are specifically needed for reliability.
This list does not include Network Upgrades identified by the Transmission Service Procedure of the SPP OATT, Attachment Z, Sponsored, Generation Interconnections, Balanced Portfolio, TO and stakeholder-zonal-sponsored upgrades not identified for reliability. These Network Upgrades have a financial commitment lead time falling inside the 2011-2014 four-year commitment window. If approved, these Network Upgrades will be included in the SPP OATT Transmission Service study models.
Transmission Network Upgrades authorized for construction have the opportunity for additional review on a case-by-case basis. The goal of such re-evaluation is to evaluate and compare viable alternatives and determine a cost-effective transmission solution, while taking into consideration long-term strategy and regional reliability needs.
SPP is committed to performing necessary analysis to determine needs, costs, and benefits, while supporting its members’ state regulatory requirements necessary to substantiate funding of identified Network Upgrade costs. Appendix B has three dates:
1. In-service: Date Transmission Owner has identified as the date the upgrade is planned to be in-service.
2. 2010 STEP Date: Date upgrade was identified as needed for reliability, based on the 2010 STEP analysis.
M: Upgrade was in the base load flow model,
R: Upgrade was replaced by an alternate project
D: Project was deferred beyond 2019
2011 NTC NTC 2010 Requested Board Action Appendix A - Complete List ofAppendix Upgrades Network List A-Complete 20048 454 10588 AEP transmission service $8,400,000 Rebuild approximately 8.5 miles of line with 1590 ACS to achieve aminimum achieve approximately to of miles Rebuild 1590ACS linewith 8.5 2000A $8,400,000 service transmission AEP 10588 10578 454 446 20048 20048 07 9 10511 10830 393 20050 634 20076 10730 20034 10644 352 10586 499 19970 452 19970 20027 11237 937 20096 00 9 11312 998 20106 10854 650 20034 00 0 10388 301 20001 20089 912 11209 MIDW transmission service $825,000 Tap the College - South Ellinwood 69 kV line and install anew Ellinwood Ellinwood North 69kV -South 69 lineandinstall College Tap the $825,000 service transmission MIDW 11209 50197 912 30190 20089 20078 50077 50078 30071 30072 20028 20028 00 00 03 KCtasiso evc 6,0 elc T n easa eadsbtto n tJh usain1/11 KC539 MKEC 11/01/10 John substation andSt Seward substation at andrelays CTs Replace $60,000 service transmission MKEC 50096 50338 30090 30300 20007 20107 00 08 50092 30086 20001 07 07 50184 30176 20078 NTC_ID 01 30356 30355 30312 30311 0611386 1046 1059 1058 1057 1056 1063 1062 1061 1060 1077 1076 1064 0711387 1047 8 10781 283 8 10916 283 8 10369 283 9 11311 997 8 10368 283 349 10367 283 9 11308 994 9 11 EIrgoa eiblt o AT$2,500,000 -nonOATT reliability regional AECI 11310 11268 996 954 5 10459 350 4 11263 949 5 11266 952 8 10373 287 0 10390 302 10370 284 10455 10452 10451 349 10447 349 349 349 11265 951 5 11267 953 9 11309 11269 995 955 394 10446 349 1 11215 915 3 13 E oa pnoe e OSMPI 1/25VTasomr0/11 522FLO&HL15k 532FLO&HL1. V111 1 kV 12.5 FOLSOM&PHIL 650342 115kV FOLSOM&PHIL 650242 M 05/31/11 New Transformer 115/12.5kV FOLSOM&PHIL zonal - sponsored LES 11230 11447 11218 930 11217 919 11216 918 917 916 1 08 EIrgoa eiblt o AT$,0,0 6/9k rnfre tLmr0/11 EI1 ots305 0745AA 69/ 1 5LAMAR 300794 300651 18months AECI M 06/01/11 Lamar kV at transformer 161/69 Lamar sub KAMO's to of Build21miles sub 161kV linefrom Clark Camp the $3,800,000 $9,833,000 -nonOATT reliability regional -nonOATT reliability regional AECI AECI 10783 10782 611 610 PID 10457 19 EIrgoa eiblt o ATMv odfo tge 9k o11k 60/10/11 ots558 tge 6 V50558 161kV Stigler 505588 6months Muskoge Sullivan 300909 Sullivan 300119 300119 18months 18months 06/01/11 18months 06/01/11 AECI AECI AECI 06/01/11 06/01/11 06/01/11 06/01/11 06/01/11 06/01/11 loadfrom Move 161kV 69kV to Stigler 100C rated 795ACSR linewith Rebuild $200,000 Upgrade Transformer 84MVA unit to Upgrade Transformer 84MVA -nonOATT unit to $2,800,000 reliability regional -nonOATT $2,800,000 reliability regional -nonOATT reliability regional AECI -nonOATT reliability regional AECI AECI AECI 11399 11398 11397 11396 10 EIrgoa eiblt o AT$,0,0 prd rnfre o8 V nt0/11 60/1AC 8mnh 018Gobbler Kingdom 300168 Kingdom 300090 300090 18months 18months 18months AECI AECI AECI 06/01/11 06/01/11 06/01/11 06/01/11 06/01/11 06/01/11 Upgrade Transformer 84MVA unit to Upgrade Transformer 56MVA unit to $2,000,000 Upgrade Transformer 56MVA unit to $2,500,000 Addnew 84MVA Transformer -nonOATT $2,500,000 reliability regional -nonOATT $2,700,000 reliability regional -nonOATT reliability regional AECI -nonOATT reliability regional AECI AECI AECI 11403 11402 11401 11400 10 EIrgoa eiblt o AT$,0,0 prd rnfre o8 V nt0/11 60/1AC 8mnh 018Gobbler 300168 18months AECI 06/01/11 06/01/11 Upgrade Transformer 84MVA unit to $2,000,000 -nonOATT reliability regional AECI 11417 11416 11404 10512 UID DETEC MIDW MIDW GRD GRD MKEC GRD GRD GRD IWrgoa eiblt $325,000 reliability regional MIDW MIDW GRD GRD GMO M einlrlaiiy$3,527,710 reliability regional GMO M einlrlaiiy$3,281,565 reliability regional GMO AECI AECI AECI AECI AECI A A A A A A A A A EIrgoa eiblt o AT$,0,0 eul eg rso 9k iet 15 V 60/10/11 EI2 ots300887 24months 3 18months AECI 06/01/11 AECI 06/01/11 06/01/11 06/01/11 MVA 51/51 lineto 69kv -Bristow Beggs Rebuild MVA -Seligman 70/70 69kV lineto Cassville Rebuild $2,506,500 $1,380,000 -nonOATT reliability regional -nonOATT reliability regional AECI AECI EIrgoa eiblt o AT$64,800 $48,600 -nonOATT reliability regional -nonOATT reliability regional AECI AECI EDE EDE A A A A A A AEPA EES AEP E einlrlaiiy$350,000 regionalreliability AEP AEP LES LES LES LES LES ECI ECI ECI ECI ECI ECI ECI ECI ECI EP EP EP EP EP EP EP Facility Owner A A A A A A A re re re re re re re re re g g g g g g g g g Generation Interconnect Generation Generation Interconnect Generation Interconnect Generation Interconnect Generation Interconnect Generation eeainInterconnect Generation G Generation Interconnect Generation ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit enera transmission service transmission transmission service transmission transmission service transmission service transmission zonal -sponsored zonal -sponsored zonal -sponsored zonal -sponsored zonal -sponsored zonal -sponsored zonal -sponsored re regional reliability einlrlaiiy$750,000 regional reliability regional reliability regional reliability regional reliability re re re regional reliability g g g g inter-regional inter-regional inter-regional inter-regional inter-regional inter-regional high priority ional reliabilit ional reliabilit ional reliabilit ional reliabilit ti on I n 2010 Project Type y y y y y y y y y t erconnec -nonOATT -nonOATT -nonOATT -nonOATT -nonOATT -nonOATT -nonOATT -nonOATT -nonOATT y y y y t $100,000,000 $100,000,000 $13,100,000 12/31/11 half breaker-and-a to station Patterson Convert 138kV. lineto lineandconvert Reconductor $11,431,000 $10,450,000 $11,250,000 $11,124,000 $11,299,000 Build 12 miles of 138 kV from Etoile - Chireno 06/01/11 97813 Etoile 138 k Etoile 97813 06/01/11 of Build12miles 138 kV from -Chireno Etoile $11,299,000 32600Cnet156 Vsaint 3-9k.12/31/11 138-69 kV. to 115-69kV station Convert $3,266,000 138kV andre lineto andconvert Reconductor $7,810,000 80900Ta $8,019,000 $3,000,000 Rebuild Ke Rebuild $3,000,000 North-Norwood- Central-Mansfield BuildMansfield $9,693,000 Transformer kV 56MV 2138/69 No. Fisher Install kV 56MV 2138/69 No. transformer Checotah Install $2,400,000 $2,400,000 20000Re $2,000,000 $2,500,000 $3,000,000 000 806 $7 $ $8,170,000 $6,000,000 40000Re $5,750,000 $4,000,000 2700Re $277,000 $872,000 rebuild the existin rebuildthe existin rebuildthe $872,000 $872,000 BuildScru BuildA $560,000 $560,000 1000Re $150,000 $960,895 $300,000 Install 5 Mvar ca 5Mvar Install $300,000 $380,000 $150,000 $100,000 $100,000 $380,000 $800,000 Install Install $374,000 $800,000 $800,000 $300,000 Install 5 Mvar Ca 5Mvar Install $300,000 7,806,000 Build Turk 138-115 kV station and relocate autotransformer autotransformer andrelocate 138-115kV BuildTurk station 7,806,000
Cost Estimate Sportsman Acres 345kV bus a 345/161 transformer 161 kV line connects to Chouteau 161kV sub. 161kV sub. Chouteau to 161kV transformer lineconnects a345/161 345kV bus Acres Sportsman the At 2gen). (GRDA 1bus GRDA to via a5mile 345kV circuit connects which 345kV bus Acres Sportsman to 108mile 345kV the lineconnects Blackberry From sub. Blackberry proposed the is border--This Kansas 345kV -Neosho linenearthe Morgan the to lineconnects The proposed Sportsman Acres 345kV bus a 345/161 transformer 161 kV line connects to Chouteau 161kV sub. 161kV sub. Chouteau to 161kV transformer lineconnects a345/161 345kV bus Acres Sportsman the At 2gen). (GRDA 1bus GRDA to via a5mile 345kV circuit connects which 345kV bus Acres Sportsman to 108mile 345kV the lineconnects Blackberry From sub. Blackberry proposed the is border--This Kansas 345kV -Neosho linenearthe Morgan the to lineconnects The proposed Sportsman Acres 345kV bus a 345/161 transformer 161 kV line connects to Chouteau 161kV sub. 161kV sub. Chouteau to 161kV transformer lineconnects a345/161 345kV bus Acres Sportsman the At 2gen). (GRDA 1bus GRDA to via a5mile 345kV circuit connects which 345kV bus Acres Sportsman to 108mile 345kV the lineconnects Blackberry From sub. Blackberry proposed the is border--This Kansas 345kV -Neosho linenearthe Morgan the to lineconnects The proposed Sportsman Acres 345kV bus a 345/161 transformer 161 kV line connects to Chouteau 161kV sub. 161kV sub. Chouteau to 161kV transformer lineconnects a345/161 345kV bus Acres Sportsman the At 2gen). (GRDA 1bus GRDA to via a5mile 345kV circuit connects which 345kV bus Acres Sportsman to 108mile 345kV the lineconnects Blackberry From sub. Blackberry proposed the is border--This Kansas 345kV -Neosho linenearthe Morgan the to lineconnects The proposed 345kV bus a 345/161 transformer connects to Chouteau 161kV sub. 161kV sub. Chouteau to connects transformer a345/161 345kV bus Chouteau the At 2gen). (GRDA 1bus GRDA to via a5mile 345kV circuit connects which kV bus 345 Chouteau to 108mile 345kV the lineconnects Blackberry From sub. Blackberry proposed the is border--This Kansas 345kV -Neosho linenearthe Morgan the to lineconnects The proposed a hlo o2t ines15k iea h e Wt laatHl u ocet new create to sub Hill Pleasant & SW7th new the at line kV 115 Pioneers & 115 kV linefrom FOLSOM&PHIL7 Sheldonto 20th to Sheldon Tap a oeyt 0h&Poer 1 Vln ttenwS7h&Pesn ilsbt raenew create to sub Hill Pleasant & new SW7th new create the to at sub line Hill kV Pleasant 115 & & Pioneers 20th SW7th & at new line 115 kV 20th linefrom Rokeby to FOLSOM&PHIL7 the the to at reterminate line Rokeby kV and kV Tap 115 sub 115 new Hill Pioneers Pleasant create & & to 115 kV &PIO linefrom 20th to FOLSOM&PHIL7 20th SW7th sub to new Hill Sheldon the Pleasant Tap at & line SW7th kV new 115 new 115kV the linefrom &PIO. create PIO 20th 2nd &N to to the N to at 2nd line Tap kV 115 N & line from FOLSOM&PHIL7 Sheldon to 2nd to Sheldon Tap Rebuild approximately 13 miles of line with 1590 ACSR to achieve aminimum achieve approximately to Rebuild of 13miles 2000Amp 1590ACSR line with Rebuild approximately 22 miles of line with 795 ACSR(NTC specifies rebuilding at 115 kV. GRDA GRDA 115kV. rebuildingat approximatelyRebuild specifies of 22miles 795ACSR(NTC linewith Install 21.8 Mvar capacitor at Jay 69kV Jay substation. at capacitor Mvar 21.8 Install A A thi t A A tt P f ) d ( f t t t l d ti t kV 115 138 k A T ild B A Add new kV Holden Xfmr 161/69 #2 Install 7.2Mvar capacitor bank at Texanna at bank 69kV capacitor 7.2Mvar Install of 15Mvar for existing total 9.6Mvar to 69kV inaddition Milan at of capacitor Add 5.4Mvar ieadrbidtev ie f15k iet kysaint 3 V 50AS,t omaTurk- a form to ACSR, 1590 kV, 138 kV to 115 station Okay-Hope Okay existing to the line to kV station 115 Turk of from miles section twelve line rebuild ACSR and 1590 line kV, 138 mile, two Build rnve,o h xsig11k iebtenTbeRc a n ueaSrnssubstation Springs Eureka and Dam Rock Table between line kV 161 anew substation. 161kV Grandview linebetween Creek existing Osage andthe and constructing existing the on Grandview, Replace one breaker andfour switches. onebreaker Replace 138 kV line. Power Tulsa flow limiting the Power Tulsa at onthe Station a2%reactor Station-Riverside Install a h otoe-LmVsa11k ieit CSuh11k usain hspoeti an is - project City This Martin and substation. East kV Spring 161 Blue - South Rd KC Duncan into the of Line project kV 161kVGrandview lines. reconductor East 161 the replace LomaVista to - alternative Montrose the Tap wavetrap. and replace @ Oronogo, settings CT change eodco ezr-Mlege 1k,Isal15k a tHie n paerlyn 06/01/12 relaying update and Heizer at bay kV 115 Install 115kV, Mullergren - Heizer Reconductor kV 161 new two it make and sub kV 161 Harper South into line kV 161 Harper. -South Harper Junction andArchie -South Stilwell sections: Junction Archie - Stilwell Tap neg lnighsietfe hspooe rjc sisaln e wthn station, switching new a installing as project proposed this identified has Planning Entergy d96Ma aaio tRsel15k.11/01/11 115kV. Russell at capacitor Mvar dd 9.6 69kV. Sallisaw at capacitor Mvar dd 7.2 Afton. 2at kVdd 50MVA Ckt transformer 161/69 Sallisaw kV at 75MVA 161/69 autotransformer dd second kV transforme 138/24 dd Turk dd new Thomas kV Hill Xfmr 345/161 2 p p p p p teGD -ln re 4 Vln n ul 4/6 rnfre.Te ul 6 Vln 1/11 GRD M 12/01/11 Then builda161kV transformer. 345kV line lineandbuilda345/161 Creek 1-Flint GRDA the lace the Colb the lace 36months EDE M 800am lace 06/01/11 dueto transformer Auto 150MVA 110with ORONOGO rated at transformer Auto lace 3310. breaker lace ( p 3 ache Flats-Scru ache ) 7.2 Mvar ca Mvar 7.2 gg y stone-Fisher Ta stone-Fisher s-Zion Ta s-Zion p p p y g g wavetra ctrbn tPwe 1 V 0/11 IW1 ots502 Pawnee 115k 530621 12months MIDW M 06/01/11 Pawnee at bank 115kV. acitor at Kinsle at 69/34.5 kV alar with transformer 69/34.5 Fredericktown 161kV ta Fredericktown 161kV ta Fredericktown p p acitors for a total of 21.6 Mvar at Afton 69kV Afton bus. at Mvar of 21.6 for atotal acitors 161kV line gg p s 161kV line s at Nashua with lar with Nashua at y p 15k.0/11 MIDW M 06/01/11 115kV. with 954 ACSR, 100C 954ACSR, with r Project Description/Comments Project ( cut A ( cut A p ache Flats-Zion Ta Flats-Zion ache p p t ni-n-u iewt 5 CRcnutr 11/01/11 11/01/11 conductor. 954ACSR linewith anin-and-out to conductor. 954ACSR linewith anin-and-out to g p p er am ache Flats-Zion Ta Flats-Zion ache aesice tAhonRC 06/01/11 REC. Ashdown at switches lace A Mt.Grove g A rui 0/11 P Colb SPP 06/01/11 er unit p acit y wavetra ( 6 vr6 06/01/11 161 over 69 and s p ; total len p p are p ; total len ) fo atro oti e 12/31/11 new this from to Patterson g th 7.14 miles 7.14 th g (hspoetwl e 60/1MAC 000309 LMR1112.3286/286 21.23 161 1 5LAMAR 300794 300070 AECI M 06/01/11 will be project (this th 1.9 miles 1.9 th kV substation. 01/01/11 MIDW North Ellinwood North 69kV MIDW 01/01/11 kV substation. peegny 60/1MAP2 ots509 atevleSuhat18k 136NrhBrlsil 3 V11883 280/287 8.37 138 1 138kV Bartlesville North 510386 138kV Southeast Bartlesville 510391 24months AEP M 06/01/11 mp emergency ) ) 02/01/11 02/01/11 02/01/11 02/01/11 06/01/12 05/31/11 05/31/11 05/31/11 05/31/11 05/31/11 06/01/11 60/1M 06/01/11 60/1MGRD M 06/01/11 12/31/11 12/31/11 06/01/11 06/01/11 12/31/11 06/01/11 06/01/11 10/01/11 11/01/11 06/01/11 06/01/11 60/1MGRD M 06/01/11 03/01/11 06/01/11 06/01/11 60/106/01/11 06/01/11 06/01/11 06/01/11 60/10/11 AECI 06/01/11 06/01/11 60/10/11 EI1 ots309 ais11k 014Mre 9k 6/984/84 161/69 3 69kV Maries 301184 161kV Maries 300096 18months AECI 06/01/11 06/01/11 60/10/11 AECI AECI 06/01/11 06/01/11 06/01/11 06/01/11
In Service 06/01/11 06/01/11 06/01/11 06/01/11 60/1GO6mnh 541203 6months GMO 06/01/11 60/1MD 2mnh ezr15k 368GetBn 1 V11500 165/178 0.03 115 1 Bend115kV Great 539678 Heizer 115kV 12months MIDW 06/01/11 MGRD M AEP 15 months 509788 Tulsa Power Tulsa 138kV Station 509788 15months AEP M M 8mnh 498Lm it 6 V 425K ot 6 V1114293/335 4 299/335 161 1 11.9 161 161kV South KC 1 541245 161kV Sub167-Riverton 547469 Loma 161kV Vista 542998 18 months 161kV Sub110-OronogoJct. GMO 547467 36months M EDE M M 8mnh 499Silel11k 427Aci 6 V11136293/335 3.6 161 1 161kV Archie 541207 161kV Stillwell 542969 18months GMO M P 428Sedn604 OSMPI 1 V11505240/240 0.5 115 1 115kV FOLSOM&PHIL 650242 Sheldon 640278 SPP M P 5202d&N603 0h&PO115139/155 348/390 348/390 139/155 0.5 115 115 115 1 1 115 1 2 &PIO 20th Rokeby 650238 115kV FOLSOM&PHIL 650290 &PIO 20th 650242 650238 115kV FOLSOM&PHIL 650242 115kV FOLSOM&PHIL 650242 2nd&N 650230 Sheldon 640278 SPP SPP M SPP M SPP M M M M M MKEC M M M M M M M M M E 60months AEP M AEP M 2010 STEP DATE GRD GRD GRD A A A A A A A A A AECI A A AEPA A A A A ECI ECI C 30 months 18 months ECI ECI ECI ECI ECI ECI ECI P24months EP EP EP EP EP EP EP Estimated Cost Source A A A A A A A 12 months 18 months 4mnh 170Siloam S 512750 512632 24 months 24 months 36 months 338099 Grandview 161 kV 338682 Osage 161 kV 1 161 5.34 247/247 247/247 5.34 161 1 161kV Osage 338682 Grandview 161kV 338099 36 months 60 months 60 months 60 months 60 months 4mnh 300145 505594 24 months 24 months 24 months 2mnh 162Sallisaw 512652 512633 12 months 18 months 18 months 24 months 24 months th 48 18 months 6 months 6 months mont Project Lead Time h s 071SotmnArs11k 009Cota 6 V111067/1067 161 161kV Chouteau 300069 161kV Acres Sportsman 300741 070SotmnArs35k 071SotmnArs11k 4/6 505/505 345/161 2 161kV Acres Sportsman 300741 345kV Acres Sportsman 300740 070SotmnArs35k 071SotmnArs11k 4/6 505/505 345/161 1 161kV Acres Sportsman 300741 345kV Acres Sportsman 300740 070SotmnArs35525 RA135k 4 977/977 5 345 1 1345kV GRDA 512650 345 Acres Sportsman 300740 507456 004Bann138k 508054 507456 512652 Sallisaw 69k Sallisaw 512652 508575 Whitney 138 508574 Whitney 69 Whitney 508574 138 Whitney 508575 539701 Russell 115k Russell 539701 547467 369Kinsle 530619 509416 Turk Coal 507454 Turk 138k Turk 507454 138k Bartlesville North 510386 Coal Turk 509416 69k Okay 507427 507402 507402 009Feeikon348 rdrctw E1161 1 UE Fredericktown Ta Wedeken 344586 345976 Thomas Hill Ke 300049 Fredericktown 505610 Fredericktown 300079 Mansfield 300079 Scru 300095 300617 344028 014Hle 6 V303 odn6 V2116 56/56 161/69 2 Holden 69kV 300336 Holden 161kV 300124 020Texanna 69kV 69kV Milan 300280 300280 170Ja Kerr161k 512720 512635 507428 Okay 138kV Okay 507428 67 lcbry35k 070SotmnArs35k 4 0 1369/1369 108 345 1 345kV Acres Sportsman 300740 345kV Blackberry 96272 01 asil 9k 084Slga 9k 99270/70 9.2 69 1 Seligman 69kV 300824 69kV Cassville 00819 From Bus Number used in SPP 9 EAD15k 366S-ON15k 1 80/88 115 1 ST-JOHN 115kV 539696 115kV SEWARD 692 MDWG bus Sub 110-Orono Nashua 161k Nashua Fisher 138k Fisher 138k Checotah eg 9k 089Bitw16 67 51/51 16.71 69 1 Bristow 300889 69kV Beggs A A kV 115 Turk T A A Ap ur fton 69k fton k fton161 138k (Millwood) REC shdown 138k (Millwood) REC shdown y ceFas301 Scru 300617 y Flats ache k Gr269k stone Dam 300131 Fisher Ta Fisher 300131 Dam stone
y gg 115 69k y s 344815 JC Zion Ta Zion JC 344815 s 115k 11k 012Slia 9k 6/984/84 84/84 161/69 161/69 2 1 Sullivan 69kV Sullivan 69kV 301152 301152 161kV 161kV nb11k 013GblrKo 9k 6/984/84 161/69 1 GobblerKnob69kV 300173 Knob 161kV nb11k 013GblrKo 9k 6/984/84 161/69 2 GobblerKnob69kV 300173 Knob 161kV
p wth6 V300 al rw 9k 913 122/122 1.32 69 1 Brown 69kV Sally 300905 69kV e Switch iy11k 057KndmCt 9k 6/956/56 56/56 161/69 161/69 3 2 69kV Kingdom City 69kV Kingdom City 300517 300517 161kV City 161kV City kV V rin V V V V V V V g V V V V s Ta V V V g o Jct. 161k o Jct. p 345k
V From Bus Name V V V V 300120 301128 507454 171Siloam S 512751 161k Sallisaw 512633 505550 69k Fisher 300931 300895 366Colb 530646 512654 Pensacola 161k Pensacola 512654 Smithville 161k 541204 69k SUB 110-OronogoJct. 547534 Coffeyville Tap 138k 510422 507454 138k Okay 138k Patterson 507428 138 k Okay 507431 507428 138k REC Springs Red 508075 To Bus Number used in SPP
tge 6 V161 161kV Stigler 8 MDWG bus hmsHl 4/6 625/625 345/161 2 Thomas Hill Mt. Grove Turk 138kV Turk Checotah 69k Checotah Chireno 138k Chireno kV 138 Turk T Afton 69k Afton ur k
gg y 138 34.5 k 34.5 6 1.4 161 1 s
p kV p rin V V p V V V g V p s Ta V V V V V V p 161k V To Bus Name V V V 1 &2 6 02286/286 20.2 161 1 3 22368/512 2 12 138 1 4/6 75/140 50/50 75/84 224/265 150/150 161 215/225 345/161 161/69 161/69 1 1 1 750/750 2 175/234 12.5 161 83/92 368/512 368/512 1 224/261 5 13.11 161/69 14.3 138 138 1 1 1 138/24 138/115 1 138/69 1 138 138 1 1 138 1 1 56/56 56/56 138/69 138/69 2 2 93. 25/28 69/34.5 3 3 .6274/274 1.4 4.26 138 161 1 161 1 1 Circuit 138/115 3/9140/170 138/69 138 /2539/39 5/12.5 115 115 115 69 7.2 Mvar 7.2 15Mvar 69 69 69 7.2 Mva 7.2 69 69 21.6 Mva 21.6 Mva 21.8 69 69 6 84/84 161 Voltages (kV)
Number of Reconductor 2.2 2.2 Number of New 22 Number of Voltage Conversion 1 9.6 Mva 9.6 286/284 286/285 175/234 194/194 287/287 191/191 230/264 5 MVa 5 Mva Summer Rating Normal/Emergency r r r r r r NTC 30303 50345 OGE regional reliability $352,350 Install 6 Mvar capacitor bank at Wells 69 kV 06/01/11 SPP 22 months 515202 Wells 69kV Wells 515202 22months 514991 22months SPP SPP 06/01/11 12/01/11 69kV Lake River Little at bank capacitor 6Mvar Install 69kV Wells at bank capacitor 6Mvar Install $352,350 $352,350 regionalreliability regionalreliability OGE OGE 50347 50345 30305 30303 NTC NTC NTC NTC 1085 11429 WFEC regional reliability $50,000 Upgrade relaying at OU Switchyard and Lindsay Switchyard; close the normally openCr normally the close Switchyard; andLindsay OU Switchyard at Upgrade relaying $50,000 regionalreliability WFEC 11429 1085 NTC NTC OGE 11439 1095 NTC NTC 156 11389 SPS regional reliability $1,181,400 Install 0.19 miles 115 kV line and install terminal equipment at Ochiltree andPerr Ochiltree at equipment terminal 115kV miles lineand install 0.19 Install $1,181,400 reliability regional SPS 11389 156 NTC 2010 Requested Board Action Appendix A - Complete List ofAppendix Upgrades Network List A-Complete 03 6 10349 266 20033 Build new 795ACSR. 115kV 35mile using -Channing Dallam reliability regional SPS 10704 554 20031 03 5 10326 156 20031 03 9 10757 590 20031 03 5 10705 554 20031 03 3 10823 632 20031 01 05 50166 30158 20017 00 3 10304 238 20003 01 5 10331 156 20111 95 5 10467 357 19951 10828 10827 10826 10825 633 10824 633 633 633 20031 632 20031 20031 20031 10330 20031 156 20111 50170 30162 20017 08 6 06 Rrgoa eiblt 69000Ta onadrbid78 ieGl lawtr18k.0/11 R1 ots53304 18months WR M 07/01/11 Tear 138kV. mile down Gill-Clearwater andrebuild7.88 $6,900,000 regionalreliability WR 10866 660 10303 20086 10305 11114 238 239 10311 10310 845 20003 10309 20030 243 243 20085 243 20003 20003 20003 10792&10793 50167 615 30159 20029 20017 03 3 10822 632 20031 03 3 10173 135 20030 08 07 50186 30178 20085 Ellinwood North MIDW M 01/01/11 06/01/11 115kV bus. Valentine substation at bank capacitor Mvar a9.0 Install $1,000,000 Ellinwood. North at transformer anew 69/34.5kV Install $530,000 regionalreliability service transmission NPPD MIDW 50211 11211 11210 30204 912 912 20080 20089 20089 08 0 10926 609 20082 08 0 10925 609 20082 08 0 10924 609 20082 20118 554 11321 SPS regional reliability Convert 30 mile Tascosa - Potter from -Potter 30mile 115kV 69kV Tascosa Convert 795ACSR. with to reliability regional SPS 11322 11321 554 554 20118 20118 00 04 50050 30044 20003 115 substation Corner Johnson at bank 115kV capacitor 12Mvar asecond Install $308,583 reliability regional SEPC 50247 30235 20083 08 03 50246 30234 20083 04 0 03 WFEC 10938 705 20044 04 0 04 OGE 10946 709 20041 NTC_ID 30292 50330 OGE zonal - sponsored $1,307,000 Install 70 MVAR Shunt Reactor at Johnston County 05/14/11 M SPP 12 months 514810 Johnston Cou Johnston 514810 12months SPP M 05/14/11 County Johnston at Reactor Shunt 70MVAR Install $1,307,000 zonal -sponsored OGE 50330 30292 01 05 P oa pnoe 12570Isal2sae f5MA n tgso 0MA eco tNro wthn tto 1 Station Switching Norton at of reactor 10MVAR of and2stages 5MVAR 2stages Install $1,275,750 zonal -sponsored SPS 50354 30310 0811388 1048 0411424 1084 08134SSznl-sosrd$24218Bid2. ie f15Vfo ee iesItrhn-al re usainMSP527711 SPP M substation of miles Creek 115kV Build21.1 from Interchang-Eagle Seven Rivers $12,462,188 zonal -sponsored SPS 11374 1038 1 10398 310 1 13 G oa pnoe 1000Cneso rm6k o11V0/11 P 138SotMuti 173SotMuti 6/454 161/34.5 1 Mountain Short 515783 Mountain Short 515358 SPP M 04/01/11 from Conversion 161kV 69kV to $150,000 zonal -sponsored OGE 10392 11336 310 310 1 10396 10394 10395 310 310 310 1 13 G oa pnoe 21760Cneso rm6k o11V0/11 P 137Rzrak554 uic a 6 .5313/335 31 7.25 5.49 161 161 1 1 10741 Tap Subiaco Mountain Short 515440 515358 580 Tap Subiaco Razorback 515440 515357 SPP SPP M M 04/01/11 04/01/11 10735 10733 10732 304 304 from Conversion 161kV 69kV to 304 from Conversion 161kV 69kV to $16,321,770 $2,157,600 zonal -sponsored zonal -sponsored OGE OGE 10393 10391 11335 11334 10400 310 310 310 310 310 0 10734 304 0 10731 304 6 10214 165 0 05 G aacdPrfloIsal1saeo 5Ma eco tGaeot1. V1/11 181Gracemont 515801 M 12/01/11 kV 13.8 Gracemont at of reactor 25Mvar 1 stage Install Portfolio Balanced OGE 50359 709 5 11001 758 0 50360 304 2 12 G oa pnoe 60800TasCnda ieiepm 20/11 P 103Csig550 upn tto 21187426 7.4 138 1 Pumping 32 Station 515401 Cushing 515033 SPP M 04/01/11 Pipeline Canadian Trans pump 32 will equipment Limiting be Three breakers. 2000Awith linewill terminal beupgradedto $6,068,000 $1,300,000 zonal -sponsored zonal -sponsored OGE OGE 11228 11190 928 895 0 02 G oa pnoe a h ilre oRset18k noteNwJhsnCut usain0/11 G 188Johnson 514808 OGE M 06/01/13 substation New the 138kV County Johnson into Russett to MillCreek Tap the zonal -sponsored OGE 10821 10820 304 304 8 04 G oa pnoe ntl emnleupett eoeTretria ie0/11 G 197Acda 3 V597 Garb 529272 51 138kV Arcadia 138kV Creek Cottonwood 514907 514827 OGE OGE M M 06/01/11 06/01/11 Terminal remove to equipment Three Install line terminal Terminal remove to equipment Three Install line terminal zonal -sponsored zonal -sponsored OGE OGE 10748 10747 582 582 9 18 G oa pnoe ntl elCwsbadascae ie,rmv hnlrsb0/01 107Wrik18k 139Be 515369 51 138kV Warwick 138kV West Keystone 515047 515048 M M 05/30/11 05/30/11 remove sub chandler lines, andassociated sub BellCow Install remove sub chandler lines, andassociated sub BellCow Install zonal -sponsored zonal -sponsored OGE OGE 11189 11188 896 896 PID
UID WFEC WFEC FCregionalreliability WFEC WFEC WFEC FCregionalreliability WFEC WFEC WFEC WFEC WFEC WFEC WFEC SWP MIDW PDregionalreliability regionalreliability OPPD OPPD PDregionalreliability OPPD OPPD SEPC SEPC OGE OGE OGE OGE OGE OGE OGE OGE OGE OGE OGE OGE OGE OGE OGE OGE G einlrlaiiy$5,404,250 regionalreliability OGE OGE OGE SPS SPS SPS regional reliability regional SPS SPS regional reliability regional SPS P einlrlaiiy$50,000 reliability regional SPS SPS regional reliability $3,375,000 Build new 6 mile 115 kV line from Doss Interchange - Legacy Interchange. -Legacy Buildnew 6mile Interchange 115kV linefrom Doss $3,375,000 reliability regional SPS SPS P einlrlaiiy$3,285,000 Interchange. -Legacy Interchange mile Buildnew 115kV 5.5 linefrom County Gaines $3,093,750 reliability regional SPS reliability regional SPS SPS SPS SPS SPS P einlrlaiiy$3,937,500 reliability regional SPS WR Facility Owner A re g ional reliabilit transmission service transmission transmission service transmission transmission service transmission service transmission transmission service transmission Balanced PortfolioBalanced Balanced PortfolioBalanced zonal -sponsored zonal -sponsored zonal -sponsored zonal -sponsored zonal -sponsored zonal -sponsored zonal -sponsored zonal -sponsored zonal -sponsored zonal -sponsored zonal -sponsored zonal -sponsored zonal -sponsored zonal -sponsored zonal -sponsored zonal -sponsored zonal -s re regional reliability re re regional reliability regional reliability re regional reliability re re re re re re re re re re re g g g g g g g g g g g g g g g ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit p
noe $264,000 onsored 2010 Project Type y -nonOATT y y y y y y y y y y y y y y y $15,000,000 $10,766,250 Buildnew Count 50mile Moore $16,094,371 $32,975,000 $26,043,761 $16,300,000 29300Cneso rm6k o11V 33/1MOE555 I 515355 OGE M 03/31/11 from Conversion 161kV. 69kV to $2,973,000 98672Buildnew 35mile Philli $9,846,782 31000Re $3,150,000 33300Buildnew 4mile AEP Sn $3,373,000 04/15/11 $6,243,750 Universit Oklahoma kV at transformer 138/69 Install 6mile Goldsb Convert $5,000,000 5mile Universit Oklahoma Convert $2,250,000 from Bradle ACSR 336.4 to ACSR of miles 1/0 6.9 Reconductor $2,753,800 $2,328,750 Buildnew 69kV. 3mile Rural 69kV South Town linefrom -Artesia Artesia $1,350,000 $5,846,295 of 8miles 115kV 69kV Convert Interchan from to Carlsbad $1,222,843 $1,900,000 $1,400,000 $2,000,000 'Install 2nd 112 MVA auto in 2nd112 MVA auto 'Install $2,000,000 $8,265,000 S Little 515319 OGE M 02/10/11 from Conversion 161k 69kV to $2,994,000 from Conversion 161kV. 69kV to $2,112,000 14600Cneso rm6k o11V 11/1MOE530 Fitzhu 503902 161k Mountain Short 515358 OGE OGE M 01/19/11 M 08/18/11 from Conversion 161kV. 69kV to $1,416,000 from Conversion 161kV. 69kV to $3,231,000 $2,900,000 $112,500 Replace relay in OGE's Alva substation inOGE's relay Replace $112,500 $200,000 Tap the existing WFEC Anadarko - Washita 138 kV line into the new Gracemont 345kV new substation. Gracemont the 138kV lineinto -Washita Anadarko existing Tap WFEC the $200,000 $225,000 mile Buildnew 115kV 0.5 linefrom new Nava mile Buildnew 115kV 0.5 linefrom new Nava $281,250 $281,250 $543,000 Conversion from Conversion 161k 69kV to $543,000 $522,000 Conversion from Conversion 161k 69kV to $522,000 6000Cneso rm6k o11V 22/1MOE515352 OGE M 02/28/11 $300,000 from Conversion 161kV. 69kV to $660,000 $240,000 $325,000 $922,000 $150,000 Install 3 Mvar 69kV 3Mvar ca Install $150,000 $617,166 $50,000
Cost Estimate Install a 6 Mvar capacitor bank at Electra substation 69 kV bus for a total of 18 Mvar at this location. this of at 18Mvar for 69kV a total bus substation Electra at bank capacitor a6Mvar Install to Ellinwood North from ACSR 477 with line 34.5kV new of miles of Ellinwood. City nearthe 4.5 interconnect approximately Build a 6 Vln rmSb15 oSb10 n ot tit n u fnw11k usain u 08/01/11 08/01/11 Sub substation, kV 161 new Sub of substation, out kV and 161 into new it of route out and and 1305 into Sub it to route 1251 and Sub 1305 from Sub line kV to 161 1251 Tap Sub from line kV 161 Tap ul e 6 Vsbtto u 31 eoe00 ie f11k iefo u 21-Sb08/01/11 Sub - 1251 Sub from line kV 161 of miles 0.06 Remove 1341. Sub substation kV 161 new Build issues, not to address violations of reliability criteria. of reliability violations address to not issues, maintenance-related address to is project of The Sub902-98369kV. this purpose Rebuild Upgrade Snyder 69 kV CTs from 69kVUpgrade 600A. CTs Snyder 400Ato Rebuild 0.23 mile Circle - HEC GT -HEC 115kV mile line. Circle 0.23 Rebuild Rebuild 18.5-mile Alva 18.5-mile 69kV -Freedom Rebuild 556.5 linefrom to 3/0 A A A A Convert 15 mile Channing - Tascosa linefrom 115kV 69kV -Tascosa 15mile 795 ACSR. with to Channing Convert Install 230/115 kV 112/128 MVA XF in Potter substation and terminal equipment andterminal MVA kV XF 112/128 230/115 substation in Potter Install ntl 9k wthnrho ot live usainadsuho HPWFY pnnew Open LH-PLW&FNY. of south and Substation Plainview North of north switch switch kV 69 Install Replace 4.65 miles of miles 477AS33 linewith 4.65 Replace FCwl ul obecrut18k ie prxmtl . ie og rmAPsAtoka AEP's from long, miles 6.5 approximately line, kV 138 circuit double a Laneline. to Tupelo-Lane 138kV line-Atoka WFEC the andloopinginto south the to substation build will WFEC 115kV substation. Corner Johnson at bank capacitor 12Mvar Install and install Eagle Creek Substation and 115/69 kV transformer. and115/69 Substation EagleCreek and install Tap line69kV from Navajo line115kV 2-Navajo No. from tap 4, No. Navajo 3-Navajo No. 4, No. Uniroyal wavetrap 800Aat Replace a h ilre oRset18k noteNwJhsnCut usainadreconductor and substation County Johnson New the into kV 138 Russett to 795AS33 Subwith Russett to County Jonson MillCreek the Tap Relaying Differential Replace FCwl ul obecrut18k ie prxmtl . ie og rmAPsAtoka AEP's from long, miles 6.5 approximately line, kV 138 circuit double a Tupelo line. to Tupelo-Lane 138kV line-Atoka WFEC the andloopinginto south the to substation build will WFEC 12/31/11 345/138 a Install substation. build and Anadarko at line kV 345 Cimarron to Side East Lawton Tap transformer MVA 400 a Install line. Re Pittsburg to Sunnyside the in substation sub. EHV new County Johnson at inaringbus breakers and4-138kv inaringbus breakers 3-345kv with 345 new a Build of 25miles 138kV of 795AS33linefrom new Count Johnson the Construct Re new Legacy Interchange substation. Interchange new Legacy Tap linefrom -Boardman Tenneco Tap 69kV kV MVA andaddnew at transformer 115/69 75/75 equipment at Cottonwood Creek, completing loop from Crescent to Twin Lakes (WFEC). Twin to Lakes loop from completing Crescent Creek, Cottonwood at equipment terminal andinstall Creek Cottonwood to of miles 138kV 69kV 13.64 from to Convert Crescent d20k iefo icln oOhlte 4 V.12/01/11 dd 2-Windin -541MVA. dd 230kV Ochilltree linefrom to Hitchland ofdd 9Mvar emer Cane t p p p lace Paralace rela lace rela lace , and close switch 3811 at Plainview 3811at switch Cit andclose y Creek remove 2existin Creek y y g g s at Pittsbur at s Sunn at s udat rnfres1ad2wt 0MAuis 13/1MSP551 Para 505412 SPP M 11/30/11 70MVA 1and2with units. transformers ould auto 230/115 kV transformer at Ochilltree – 172.5 MV –172.5 Ochilltree kV at transformer 230/115 g enc y p p - Canadian Switch from Switch 138kV. 69kV -Canadian to y sbur acitor at G at acitor y 345k side y ca g der - WFEC Sn der -WFEC 345k g p p -Rods15k.06/01/11 115kV. -Rhoades arallel withexistin acitors V V V y -Hthad 3 Vrtda 4 V.06/01/11 541MVA. at 230kV rated -Hitchland g Project Description/Comments Project V line terminals to the north andex north the to lineterminals yp y V
( u.0/11 M 06/01/11 sum. OU ) Switch - Goldsb Switch y e 3 V 06/30/11 der 138kV. j j y o No. 5 substation -Nava 5substation o No. -Nava 5substation o No. to allow befed Plainview North to b to Substation g Ui 06/01/11 Unit y . y from 138kV. 69kV to g ctlo CnetOoil 06/01/11 Ocotillo Convert e -Ocotillo. y A to Rush S p n h 3 Vbsnrhit 0/11 G 110Cane 515150 OGE M 06/01/11 into north 138kV bus and the j j o usain15k.04/15/11 04/15/11 115kV. 3substation o No. 115kV. 4substation o No. y p sub to Cane to sub rin g s 69 kV. tnsbttos0/11 P 214Ohlre535 ertnItrhne11501 157/173 0.19 115 1 Interchange Perryton 523158 Ochiltree 523154 SPP M 06/01/11 substations yton kV bus. 11/01/11 M SEPC 12 months 531424 Johnson Corner 115kV Corner Johnson 531424 12months SEPC M 11/01/11 kV bus. 9A3 0/11 G 2mnh 180Soeal3 V547 eigo ak18k 3 268/308 138 1 Park 138kV Remington 514872 kV Stonewall138 514870 12months OGE M 04/01/11 795AS33 nr-Lnsy6 Vln 60/1WE ots506 rnr6 V507 ida 9k 972/89 69 1 69kV Lindsay 520977 69kV Criner 520868 6months WFEC 06/01/11 69kV line iner -Lindsay y Creek. 06/01/11 M OGE 514808 Johnson Count Johnson 514808 OGE M 06/01/11 Creek. y Cox 06/01/11 03/01/11 06/01/11 02/10/11 M OGE 515354 Noark 161k Noark I 515354 161k Carbon Lakes Great 515355 515353 OGE OGE OGE M M M 02/10/11 02/10/11 02/19/11 12/01/11 06/01/11 Count Johnson Sunn 515809 515136 OGE OGE M M 06/01/11 06/01/11 06/01/11 06/01/11 60/1MOE24months OGE M 06/01/11 04/15/11 06/01/11 12months OGE M 06/01/11 12/31/11 06/01/13 12months OGE M 06/01/11 06/01/11 06/01/11 06/01/11 60/1MSPP M 06/01/11 4.5 34.5 1 of Ellinwood City kV Ellinwood North 34.5 MIDW 01/01/11 30/1MOP 492SB926 V678 U 8 9k 96.48 69 1 SUB 98369kV 647983 SUB 90269kV 647902 OPPD M 03/01/11 06/01/11 60/1M 06/01/11 60/1M 06/01/11 60/1M 06/01/11 20/1M 12/01/11 60/1MWE 2mnh 217AoaEs 3 V506 ae(FC 3 V11865262/329 6.5 138 1 138kV Lane(WFEC) 520968 138kV East Atoka 521187 12 months WFEC M 06/01/11 115kV Corner Johnson 531424 18months SEPC M 11/01/11 60/1MWE 2mnh 218AoaWs 3 V550 ueo(FC 3 V11865262/329 6.5 138 1 138kV Tupelo (WFEC) 505600 138kV West Atoka 521188 12months WFEC M 06/01/11 0/01/11 M SPP 12 months 524502 Norton Switching Station Switching Norton 524502 12months SPP M 0/01/11 In Service 60/1SP24months SPP 06/01/11 60/1SP6mnh 229Lgtoe6 V555 ot live 9k 69 1 Plainview North 69kV 525256 69kV Lighthose 525249 6 months SPP 06/01/11 60/1SP6mnh 514792 6months SPP 06/01/11 M WR 18 months 533421 Hutchinson Gas Turbine Station 115 k Turbine Station Gas Hutchinson 533421 18months WR M G 188JhsnCut 3 V552 ust 3 V11829 287/287 2.99 138 1 138kV Russett 515120 138kV County Johnson 514808 OGE M G 4mnh 515800 24months OGE M G 189JhsnCut 4 V540 ono ony18k 4/3 400/400 345/138 1 138kV County Johnson 514808 345kV County Johnson 515809 OGE M G 8mnh 137Cecn 3 V542 otnodCek18k 3 36 84/104 13.64 138 1 138kV Creek Cottonwood 514827 138kV Crescent 515377 18months OGE M PD646341 646341 OPPD OPPD M M PD646341 OPPD M M M M OGE M M M M M M M M M 30months M 0mnh 228Dla onyItrhne15k 288Cann 1 V1153 246/271 35 115 1 115kV Channing 523868 115kV Interchange County Dallam 523228 30months M P 4mnh 230Ds necag 1 V527346 115kV Interchange Doss 527340 24months SPS M P 6mnh 270EgeCek6 V(e u)571 al re 1 V(e u)1156 40/46 115/69 1 115kV (new sub) EagleCreek 527711 527346 69kV (new sub) EagleCreek 527710 115kV Interchange County Gaines 527322 36months 24months SPS SPS M M M WFEC 515800 Anadarko (Gracemont) Tap 138kV (Gracemont) Anadarko 515800 WFEC M M SPS 24 months 527346 Legacy Interchange 115 kV (new interchange 115kV (new interchange Interchange Legacy 527346 24months SPS M 2010 STEP DATE FC1 ots520814 16months WFEC EC2 ots598 Philli 539685 24months SEPC PD2 ots609 Valentine 115kV 640392 24months NPPD P 6mnh 527747 36months SPS SPS SPS SPS 24 months 528160 Carlsbad Interchan Carlsbad 528160 24months SPS P 6mnh 272Nava Nava 527742 527743 36months 36months SPS SPS SPS P 2mnh 201Sn 521051 12months SPP P 6mnh 511435 16months SPP P 6mnh 294Goldsb 520924 16months SPP P 6mnh 214OU Switch 521104 16months SPP P 6mnh 214OU Switch 521104 16months SPP P 4mnh 289Bradle 520829 24months SPP SPS Estimated Cost Source 12 months 12 months 520894 Electra 69k Electra 520894 12 months 12 months 48 months 523095 Hitchland 230 k Hitchland 523095 48 months 48 months 523309 Moore Co 230k Co Moore 523309 48 months 24 months 523154 Ochilltree 115k Ochilltree 523154 24 months
Project Lead Time 113Ro 515163 515135 Sunnyside 138k Sunnyside 515135 515142 Dillard 138k Dillard 515142 520806 515158 Madill Industries 138k Industries Madill 515158 299G 520929 523868 285Tsoa15k 291Pte ony15k 1 0246/271 30 115 1 1 115kV County Potter 115kV County Potter 523951 523951 230kV County Potter 115kV Tascosa 523959 523875 From Bus Number used in SPP MDWG bus ilW 3 V533 lawtr18k 3 .8534/586 7.88 138 1 138kV Clearwater 533036 138kV W4 Gill 5 SUB 1341161kV SUB 1341161kV SUB 1341161kV Little River Lake 69kV Lake River Little Channing 115kV Channing A A A A A Alva 69kV (OGE) al re 204SvnRvr necag 1 11246/271 21.1 115 1 Interchange Seven Rivers 528094 Eagle Creek Gracemont 345kV Gracemont g g ltus 161k ltus EP Sn lva 69k 138k nadarko Town Sub69k rtesia yp o 161k o 161k y cky Point 69 k der 69k sum g p j j y y o No.5 Sub115kVo No.5 Sub115kVo No.5 ould 161k sbur g side 345k side y Creek 138k Creek p y h 161k 69k y adra 161k 138k Cut 3 V552 ilre 3 V118191/191 138 1 138kV Millcreek 515121 138kV County der 138k V V V g y y V 115k ard 138k ard 138k V V V V V nty V V y y V 6 VNrhElnod3. V169/34.5 1 kV Ellinwood North 34.5 69kV V V V V 345k 138k V V V V V V g V e 115k V V V V V V V From Bus Name ( ( new sub new sub V V ) ) V a 044Para 505414 Nava 527775 Nava 527720 527739 Sub69k Ocotillo 528131 115 k Rhoades 531373 Pittsbur Count Johnson 510907 514809 Cane 515150 Tap Healdton 138k 138k Uniroyal 515141 515137 515166 161k Carbon Lakes Great 161k Noark 515353 515354 515352 I Fitzhu 515355 Helber 503902 515327 161k Branch 161k Razorback 515316 515357 533413 Circle 115k Circle 533413 Sn WFEC 521052 Ti 521070 520810 OU Switch 138 k SW Canadian 521018 Goldsb 520842 S Rush 520924 521041 435SB10 6 V11103 558/558 558/558 0.34 0.41 161 161 1 1 SUB 1305161kV SUB 1251161kV 646305 646251 523875 239Bada a 9k 1/9 40/46 115/69 1 Boardman Tap 69kV 230k Ochilltree 527349 230k Ochilltree 523155 523155 230k Hitchland 523095 520915 286Av 9k WE)16 48/48 69 1 Alva 69kV (WFEC) 520806 182Gaeot18k 4/3 448/493 345/138 1 138kV Gracemont 515802 97Acda18k 3 268/287 138 1 138kV Arcadia 4907 39Bl o 3 V118268/287 138 1 138kV BellCow 5369 To Bus Number used in SPP MDWG bus acs 1 V1151 246/271 15 115 1 115kV Tascosa A A A A interchan 115kV (new Interchange Legacy Freedom 69k Freedom interchan 115kV (new Interchange Legacy g rtesia South Rural Sub69k Rural South rtesia rdmore 69k 161k ltus nadarko 69k nadarko p 6 V 6 7 161 1 o 161kV lCw18k 3 268/287 138 1 138kV ll Cow ton 69k ton g r18k 3 268/287 138 1 er 138kV j j y o No.3 Sub115k o No.3 Sub115k o No.4 ould 69k g Creek 138k Creek g y h 161k p g 161k 138k rin 345k g g y e andsub e andsub y V g V der 138k ard 69k V V s 69k s V V V V V V V V V V y V V V V 345k V V V V V V V ) ) V V
V To Bus Name V V V 6/970/70 161/69 1 &2 93179/197 179/197 179/197 157/173 90/99 3 0.5 0.5 54/54 5.5 69 6 115 8 115 1 1 115 1 115 1 1 115 165/198 1 35 115 1 25 345 345 2 1 138 1 10 138 2 313/359 1 2 1 313/335 5 313/335 11 10 1 1 161 1 161 161 1 1 161 1 161 1 161 1 161 1 1 1 115 0.23 223/245 223/245 118/154 53/65 72/89 224/224 0.23 112/112 183/228 115 183/228 53/65 4 6 1 4.9 18.5 138 69 69 138/69 1 6.9 1 138/69 1 138 2 138 69 1 1 1 1 138 1 1 1 1 Circuit 230/115 230/115 38-70 13.8 38-25 13.8 138 138 1 9Mvar 115 161 115 1 12Mvar 115 1 -30 115 3 9Mva 138 230 230 69 96Mvar 6Mvar 69 69 93Mva 69 69 Voltages (kV) 4.65 Number of Reconductor 35 50 Number of New
Number of Voltage Conversion 2 150/172.5 191/191 194/222 112/128 313/335 12 Mvar 313/335 313/335 313/335 313/335 492/541 492/541 6 Mva 72/72 57/57 2/42 8/308 3/335 Summer Rating Normal/Emergency r r r NTC -Modif 2012 T 02136W einlrlaiiyBidnwsbtto ih50V 4/1/44k he-idn rnfre t8t tet06/0 Street 87th kV at transformer three-winding 560MVA with 345/115/14.4 Buildnew substation regionalreliability WR 11346 1022 NTC T 02134W einlrlaiiyTpteSrne ri 4 Vln noanwsbtto t8t tet0/11 4mnh 532 24months 06/01/11 Street 87th at 345KV anew -Craig substation lineinto Stranger Tap the regionalreliability WR 11344 1022 NTC NTC NTC 2010 Requested Board Action y Sco Appendix A - Complete List ofAppendix Upgrades Network List A-Complete p e 01- 4 10456 349 20016-1 00 9 10509 391 20000 03 2 01 Rrgoa eiblt 25100Rbidte23 ieCihl ily6 Vln sn ige19. CR 07/01/ ACSR. 1192.5 single 69kV lineusing -Ripley mile Chisholm 2.37 the Rebuild $2,551,000 regionalreliability WR 10638 10813 493 625 20033 20033 00 1 10140 113 20000 50151 30143 20015 01 06 50173 30165 20018 20033 600 10767 WR regional reliability $3,750,000 Tear down and rebuild the 3.43 mile 27th & Croco - 41st & California 115 kV &California linea -41st &Croco mile Tear 27th 3.43 down andrebuildthe $3,750,000 regionalreliability WR 10767 600 20033 01 1 10405 313 20018 10460 351 20015 10808 618 20033 20000 113 10786 AEP regional reliability $11,988,400 Build new Caplis-McDade 138 kV, 1590 ACSR line 06/01/12 M AEP 24 months 507741 Mcdade Mcdade 507741 24months AEP M 06/01/12 33month 11323 AEP 1007 M 10406 20107 07/01/12 line 1590ACSR 138kV, Buildnew Caplis-McDade $11,988,400 314 regionalreliability 20018 Texarkana. Buildapproximately from NW of 33miles to Turk 2-954ACSR 10386 AEP 10385 10839 299 10786 299 10141 638 20021 service transmission 113 20021 10505 113 10510 20075 11155 10374 AEP 20000 387 20000 392 50150 875 50149 288 50148 20000 20027 30142 50160 20073 30142 20016 30142 50164 50165 20016 30152 20016 20016 30156 30157 20016 20016 20016 10461 351 20015 10806 10639 618 493 20033 20033 01 05 50163 30155 20016 08 03 04 PDrgoa eiblt 8000Isala3 vrcpctrbn tKanysbtto 1 Vbs 60/2MNP 2 NPPD 24mon M NPPD 06/01/12 M 06/01/12 115kV bus. substation Kearney at bank capacitor a36Mvar Install $800,000 rating. 100Degree to equipment andterminal conductor Uprate $1,000,000 regionalreliability regionalreliability NPPD 50248 11152 NPPD 11151 30236 11080 629 10986 629 20080 20080 818 749 20080 20080 20080 05 03 04 Rtasiso evc 6750Ad6 V1 vrCpbn tToa0/11 R1 ots534 Tioga 69kV 533646 12months WR M R 06/01/11 533837 Ne 18months 533021 WR 6 months M WR 07/01/11 M 06/01/11 Tioga at bank Add69kV Cap 15Mvar $607,500 service transmission Hill approximately Junction-Richland mile Rebuild Rose 5.5 $3,010,000 aminimum achieve to approximately 120 ACSR Rebuild of 5miles 954-KCM linewith NE andJumpers 138kV Parsons at bus substation Replace WR $3,437,498 $250,000 aminimum achieve to approximately Rebuild 6 ACSR of 3miles 954kcmil linewith Reliability Zonal aminimum achieve to 6 ACSR approximately of miles Rebuild 954-KCM linewith 8.5 $2,633,000 $6,343,247 service transmission 50244 service transmission service transmission service WR transmission 30233 WR WR WR 10810 20059 WR 50245 50241 50232 622 50239 30224 30230 30224 20059 30224 20091 20059 20091 20091 04 0 04,199ITCGP 10939 10940, 707 20046 06 1 10 E rnmsinsrie$,0,0 eul .0mlso 9 CRwt 50AS 60/2MAP523 Coffeyville Farmla 512734 KCPL AEP 50329 ITCGP 10934 M 30291 06/01/12 10941 702 20116 707 20042 GRDA 20046 50080 10927 30074 698 20028 1590ACSR with of miles 795ACSR 2.20 Rebuild Coff S. at 138kV lineswitch Replace 20040 1590ACSR. with of 6miles 556ACSR Rebuild $2,200,000 $6,000,000 service transmission service transmission AEP AEP 11208 11199 911 902 20066 20066 01 06140ME einlrlaiiy$0,0 elc T n easa rt usainadS onsbtto 60/2ME 5396 MKEC 06/01/12 John substation andSt substation Pratt at andrelays CTs Replace $100,000 regionalreliability MKEC 50104 11440 30098 1096 20007 20119 NTC_ID 07 50079 30073 1079 1078 1065 0111421 1081 0511446 1045 0211345 1022 07141W eeainItronc 68700Isaltrebekrrn u 4k n n diinl35k rae oiin12/1 ands foundation andallassociated structures turning 345kV two full tension Install $625,000 position 345kV 345kV breaker andoneadditional ringbus breaker three Install $6,867,000 Interconnect Generation Interconnect Generation WR WR 11445 11441 1097 1097 1053 11394 LES zonal - sponsored 120th & Alvo Substation and 115/12kV tapping the Waverly - Wagner 115 kV line 05/31/12 M 120th &Alvo 120th M 05/31/12 115kV line -Wagner Waverly the tapping and115/12kV & Alvo Substation 120th zonal -sponsored LES 11394 1053 6 17 EIrgoa eiblt o AT$5,000,000 -nonOATT reliability regional AECI 11275 961 6 17 EIrgoa eiblt o AT$2,880,000 $3,600,000 -nonOATT reliability regional -nonOATT reliability regional AECI AECI 11277 11276 963 962 8 19 EIrgoa eiblt o AT$,0,0 ovr rse odt 6 V 60/2MAC 056Dresden 300526 AECI M 06/01/12 161kV. loadto Dresden Convert $1,900,000 -nonOATT reliability regional AECI 10297 11295 232 981 3 10296 231 3 10840 639 $5,762,455 $939,000 -nonOATT reliability regional -nonOATT reliability regional AECI AECI 11272 11270 958 956 5 17 EIrgoa eiblt o AT$1,900,000 -nonOATT $3,821,545 reliability regional -nonOATT reliability regional AECI AECI 11273 11271 959 957 6 17 EIrgoa eiblt o AT$11,124,000 -nonOATT reliability regional AECI 11274 960 636 10834 DETEC zonal - sponsored $7,617,000 Install new 138 kV line from Chireno to Martinsville 06/01/12 Chireno 138 kV Martinsville Martinsville 138kV Chireno 06/01/12 10491 new 138kV Martinsville linefrom to Install Chireno 378 $7,617,000 zonal -sponsored DETEC 10834 636 10448 349 1 10954 717 3 10969 732 3 10975 738 2 18 E einlrlaiiy-nnOT 10000Nwsbtto n rnfre 1/9k 4MA0/11 P 4mnh 232 527362 24months SPP M 06/01/12 New Line69kV New Line69kV $1,000,000 kV 44MVA 115/69 andtransformer New substation $1,000,000 $1,000,000 -nonOATT reliability regional -nonOATT reliability regional -nonOATT reliability regional LEA LEA LEA 11088 11087 11086 823 823 823 1 10956 10955 719 718 PID 11405 AECI regional reliability - non OATT $5,349,000 Add new 161/69 kV substation at Steele tied to Entergy Hayti and Blytheville andBlytheville Hayti Entergy to tied Steele at kV Addnew substation 161/69 $5,349,000 -nonOATT reliability regional AECI 11419 11418 11405 UID ITCGP ITCGP ITCGP MKEC GRDA GRD GRD MKEC A A A NPPD NPPD NPPD PDrgoa eiblt 17000Urt odco n emnleupett 0 erertn.0/11 PD24months NPPD M 06/01/12 rating. 100Degree to equipment andterminal conductor Uprate regional reliability $1,700,000 regionalreliability regionalreliability NPPD NPPD NPPD KCPL KCPL RSrgoa eiblt o AT$200,000 $3,937,500 -nonOATT regionalreliability -nonOATT regionalreliability GRIS GRIS INDN A EIrgoa eiblt o AT$13000Bidnw11k iefo aa oCrhg 60/20/11 EI3 ots558 Ca 505488 36months AECI 24 06/01/12 06/01/12 AECI 06/01/12 06/01/12 161 loadto Dresden Move 161kV line; BuildGeorgetown-Dresden $750,000 Buildnew 161kV linefrom Carthage Lamar to $11,360,000 -nonOATT reliability regional -nonOATT reliability regional AECI AECI NEO EDE A A A A A A A A A A A A A A A A A A WR Rregionalreliability WR Rregionalreliability WR Rrgoa eiblt $22,092,717 regionalreliability WR WR ECC ECC ECC ECI EP EP EP EP EP EP EP EP EP EP EP EP EP EP EP EP EP EP Facility Owner A A re re g g Generation Interconnect Generation Interconnect Generation Interconnect Generation ional reliabilit ional reliabilit transmission service transmission service transmission service transmission service transmission service transmission service transmission service transmission service transmission transmission service transmission service transmission service transmission transmission service transmission transmission service transmission transmission service transmission transmission service transmission Balanced PortfolioBalanced Balanced PortfolioBalanced PortfolioBalanced PortfolioBalanced zonal -sponsored oa pnoe $16,031,250 zonal -sponsored zonal -sponsored zonal -sponsored zonal -s re re re re re re re re re re re re regional reliability re einlrlaiiy$1,500,000 regional reliability g g g g g g g g g g g g g ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit p
onsored $300,000 Install Install $300,000 onsored 2010 Project Type y y -nonOATT -nonOATT y y y y y y y y y y y y y $106,662,000 2,9,0 ul e 4ml uk-S eakn 3 Vln n d ETxraa18k emnl 07/01/12 Buildnew 34mile -SETexarkana Turk 138kV lineandaddSETexarkana 138kV terminal. $25,590,000 Buildnew 24mile -Su Turk $18,427,000 $19,482,000 Convert Hau Convert $19,482,000 $19,234,000 $48,580,000 $10,355,000 Install new 345/138 kV new transforme 345/138 Install $10,355,000 $19,687,500 $33,000,000 $11,250,000 $26,825,000 $2,171,096 $3,840,000 Install 345kV e terminal Install $3,840,000 $7,310,000 115kV Buildnew line McNab-Turk $8,193,000 $1,773,000 $1,512,000 Reconductor line to 1590 ACSR the Ho the 1590ACSR lineto Reconductor $1,512,000 26500Buildnew 161kV linefrom BlueValle $2,625,000 U $2,500,000 $1,700,000 Reconductor line to 1590 ACSR, A = 347, B = 403. $255K/mile $255K/mile 403. B= 347, A= 1590ACSR, lineto Reconductor $255K/mile 403. B= 347, A= 1590ACSR, lineto Reconductor $1,700,000 $4,212,500 andu -Sedalia69kV mile 556ACSR with Nichols 8.92 Reconductor $3,520,000 Point-Hau Red Convert Ta Ordinance -Lone Star Hooks 1.68-mile Rebuild $9,480,000 $2,100,000 of miles Howell 3.49 Rebuild -Kil $3,986,000 Stran Rebuild Jarbalo -Stran Rebuild $4,600,000 $4,581,000 $7,141,000 $1,806,000 Install terminal equipment at Cleveland Substation Cleveland at equipment terminal Install $1,806,000 50000New Louisbur North $5,000,000 $5,625,000 $3,994,000 $456,000 $128,000 4000U $440,000 $165,000 1000Re $100,000 $674,280 Re Re $300,000 $125,000 $150,000 $779,000 Install (3) 7.2 Mvar capacitors for a total of 21.6 Mvar at Tahlequah West 69kV. Tahlequah West at Mvar of 21.6 for atotal capacitors Mvar (3)7.2 Install $779,000 $80,000
Cost Estimate Replace 138 kV breaker, switches, and jumpers at Linwood. Replace circuit switcher at Powell at switcher circuit Replace Linwood. at andjumpers switches, 138kV breaker, Replace 69kV switches. Replace Texarkana at jumpers 500Cu Plant. the out Change CTs andreset jumpers, 69KV switches, Replace 795ACSR. with of miles 266ACSR 5.92 Rebuild a eta iy-Sle re 1 Va lrs ul e 1 Vln rmCak eta City Central - Clarks from line kV 115 new Build Clarks. at kV 115 Creek Silver XL project. 115kV Keystone linefor Radial TransCanada . North - City Central Tap Upgrades to McNab Substation McNab to Upgrades ul e iefo nilt e TAT7 ail15k iefrTasaaaKytn XL Keystone TransCanada for line kV 115 Radial STUARTS7. new to Oneill project. from line new Build Construct approximately gen Bend(Mullergren) linefrom onemile Great of the 115-kV transmission Construct ul e iefo eesugt e RCO7 ail15k iefrTasaaaKeystone TransCanada for line kV 115 Radial ERICSON7. new to Petersburg XL project. from line new Build ul e . ie15k k rmTi hrht e ot iu iysbtto.Rebuild substation. City Sioux South new Rebuild to Church substation. Twin City from Sioux 2 South Ckt new kV to 115 substation. Sioux andnew South Church City substation Twin Church mile Twin 5.5 from new 1 Build Ckt kV 115 substation. Sioux andnew South City substation Twin Church mile 5.5 new Build A A A A Build Holman-Rogersville mi 161kV line-7.2 miles 1619.0 Way Build Holman-Cross BuildJasper-Lamar 161kV to line) change 161kV will line(This likely Build Blackberry-Lamar substation. kV 230/115 230kV Manhattan lineandbuild new Northwest Manhattan -East Concordia Tap the a h 5h&Wvry-Mniel 1 Vln nonw8t tetsbtto.Ta onand down Tear substation. Street 87th new into line KV 115 Monticello - Waverly newrebuild existing doublecircuit. lineas & 95th the Tap Install new linefrom ValliantInstall Hugo 345kV Power to Plant of 19miles with bundled1590ACSR ul e 4 Vln rmKolt necpinpito pavlet nl ie pae for Updated line. Knoll to Spearville of point interception to Knoll 345kV Swissvale-Stillwell line to cut-in Gardner345kV bus from West line kV 345 new 06/01/12 Build 345kV with transformer kV a600MVA ringbus auto 345/230 include to substation Rock Build Post Manhattan. Northwest 115kV into Tap KSU -Wildcat Must upgrade Stilwell terminal equipment to 2000amps to equipment terminal upgradeStilwell Must under NOT is that Facility Transmission Owned is Island that Grand Facility of Transmission Owned City Island Grand MVA. of 179 OATT. SPP City to line Libory. Upgrade - F Sub from NOT underSPP OATT line kV 115 Adding Install 20 Mvar ca 20Mvar Install (total ACSR 1192 to ACSR 477 161 load to Cabool Convert from line V 161kV 69k lineto Springs Cabool-Willow Convert kV 161 Louis-Enon Convert Mt.Grove-C St. Dardenne-Lake Reconductor Build Blackberry 345/161 kV sub (this will likely change to build Jasper 345/161 sub between Blackb between sub 345/161 buildJasper to change will likely (this kV sub 345/161 Build Blackberry d35k emnla WTxraa07/01/12 345KVdd 345KV of 345KV linefrom Install linefrom OKGEinterception Hugo to Sunnyside. kV transforme 345/138 dd Turk Turk. dd 345kV at terminal Texarkana NW dd 345kV at terminal pg pg p p p rade Ashervill transformer to No. 1 to 56MV 1to No. to transformer rade Ashervill Switchin rade Fulton lace 138kV wavetralace lace wave tra 11985and1033AAC 69kV switch lace ( 2 ) 3.6 Mvar ca Mvar 3.6 g g hton-McDade to 138 kV, 1590 ACSR 1590ACSR 138kV, to hton-McDade er - Northwest Leavenworth 6.5 miles of miles Leavenworth 115kV 6.5 er -Northwest andta p p at Okmul at acitor bank at Plainville at bank 115kV. acitor g abool 69 k V 161kVabool 69k lineto -Middle Creek 161kV line 06/01/12 M KCPL 24 months 543058 North Louisbur North 543058 24months KCPL M 06/01/12 161kV line Creek -Middle p g acitors at P at acitors g q er Ckt 2 7.1 miles of miles 115kV 27.1 andta er Ckt p hton to 138 kV, 1590 ACSR 1590ACSR 138kV, to hton g ui s at both ends. Reset CTs at Lone Star South. Reset rela Reset South. LoneStar at CTs Reset ends. both at s Sain0/11 M 04/01/12 Station p g eta alatSbtto 04/01/12 g Valliant Substation at ment ar Hill 138kV lineandaddSu e 06/01/12 ee. r g Project Description/Comments Project r r 9k / CRwt 9 CR 06/01/12 795ACSR. with ACSR ore 69kV 4/0 y ai onr 9k u.0/11 GRD 06/01/12 69kV bus. ramid Corners y Patt u ih75AS samnmmad19 sa 60/2MSP2 ots548807 24months SPP M 06/01/12 aminimum as a and1192as 795ACSR with SubM Plant to p e-Fulton line. Build at 138ando Buildat line. e-Fulton j um A p ers at Su at ers p ( 69 kV line. Re 69kV line. includes McDade station conversion station McDade includes ( includes Red Point &Hau terminal Red includes g g rHl.0/11 M 04/01/12 ar Hill. 04/30/12 ar Hill 138kV terminal. p the existin the @ @ 42m.0/11 GRD GRD M M 06/01/12 06/01/12 mi. 4.2 mi. 8.8 p aesic 06a oeSa 06/01/13 LoneStar 6006at switch lace pg p existin aeCs 60/2MEE1 ots547542 18months EDE M 06/01/12 rade CTs. g p Jrao-Nrhet 00/1MW 5mnh 324Jarbalo 115k 533244 15months WR M 10/01/11 Jarbalo -Northwest erate at 115k at erate ot 60/20/11 EI1 ots305 tee11k 079Sel 9k 161/69 1 69kV Steele 300769 161kV Steele 300756 18months AECI 06/01/12 06/01/12 North g Jrao-Nrhet 60/1MW 5mnh 328Stran 533268 15months WR M 06/01/11 Jarbalo -Northwest igecrut 51/1MW 4mnh 3182T rc ucin15K 3104S aiona15K 1 .3223/240 3.43 115 1 41ST 115KV &California 533160 115KV Junction 27TH &Croco 533188 24months WR M 05/15/11 circuit. asingle s 0ap 60/1MW 8mnh 363Ahn wthn tto 9k 362OlCek6 V16 .372/72 2.93 69 1 69KV Owl Creek 533642 69kV Station Switching Athens 533623 18months WR M 06/01/11 00 amp ite work 12/15/11 560120 Caney River Substation River Caney 560120 12/15/11 work ite y s at Pittsbur at s 0ap 23/1MW 8mnh 368Lhg a 9k 362OlCek6 V16 .772/72 8.47 69 1 69KV Owl Creek 533642 LehighTap 69kV 533638 18months WR M 12/31/11 00 amp yil a.0/11 E 142CfevleTp507 ot ofyil iy1186368/512 6 138 1 Coffeyville City South 510378 Coffeyville Tap 510422 AEP M 06/01/12 Tap. eyville m 0/01 R1 ots533 ofyCut N.4Vro 9k 363Ahn wthn tto 9k 951 116/128 5.17 69 1 69kV Station Switching Athens 533623 4Vernon No. 69kV County Coffey 533631 18months WR M 04/30/11 0 amp V g ) hton 06/01/12 hton 06/01/12 . g 06/01/12 . e e 06/01/12 04/01/12 07/01/12 07/01/12 11/01/12 04/01/12 11/01/12 40/2MWFEC M 04/01/12 07/01/12 11/01/12 06/01/12 06/01/12 06/01/12 60/206/01/12 M 06/01/12 04/01/12 60/2MAC 079Baker 017Baker 4/6 392/392 Heizer 115k 530601 18months MKEC 06/01/11 06/01/12 WFEC 345/161 M 1 04/01/12 Blackberry 300127 07/01/12 Blackberry 300739 AECI M 06/01/12 60/2MAC 019Hla 002Cosa 6 286/286 286/286 286/286 7.2 9 20 161 161 161 1 1 1 Rogersville Crossway 300832 300062 Lamar 300794 Holman Holman 301160 Blackberry 301159 300127 AECI AECI AECI M M M 06/01/12 06/01/12 06/01/12 40/2MWFEC M 04/01/12 60/2MSP576 EEF6 V587 e onyRCGie 941/54 41/54 69 69 1 1 REC-Gaines LeaCounty Tap REC-Ancell LeaCounty 528776 528772 69kV LE_ERF 69kV LE_ERF 527361 527361 SPP SPP M M 06/01/12 06/01/12 06/01/12 07/01/12 12/31/12 12/01/11 60/2KP 6months KCPL 06/01/12 04/01/12 12/01/12 60/2MAC 097Cbo 012Wlo pig 6 43 286/286 372/372 14.34 1.1 161 161 1 1 Springs Willow 300122 Louis St Lake 300602 Cabool Cabool 300917 300917 Dardenne 301128 300596 AECI AECI AECI AECI M M M 06/01/12 M 06/01/12 06/01/12 06/01/12 40/2M 04/01/12 60/2MICP531469 ITCGP M 06/01/12
/1529 esa520 ahm 345 1 Lathams 532800 Neosha 532793 5/11 In Service 1MW 8mnh 376Cihl 9k 382Rpe 9k 923 134/147 2.37 69 1 69kV Ripley 533832 69kV Chisholm 533786 18months WR M 11 60/12 ots537 5h&Wvry538 otclo1215223/245 115 1&2 Monticello 533281 &Waverly 95th 533278 24months 06/01/11 P 18months SPP M RA540 onr35k 164Ceead35k 4 1195/1195 345 1 Gardner345kV 345kV Cleveland West 542965 512694 KCPL M Sooner345kV 514803 GRDA M MWR M M M M M PD4 ots603 lrs15k 444CnrlCt ot 1 V1151 174/174 10 115 1 115kV North City Central 640434 115kV Clarks 640436 48months NPPD M M PD4 ots600 nil15k 441Surs15k 1 85174/174 28.5 115 1 115kV Stuarts 640441 Oneill115kV 640305 48months NPPD M M M PD4 ots601 eesug15k 447Eisn15k 1 5174/174 35 115 1 115kV Ericson 640437 115kV Petersburg 640318 48months NPPD M PD4 ots608 wnCuc 1 V602 ot iu iy15k 1 . 266/266 266/266 5.5 5.5 115 115 2 1 115kV Sioux South City 640424 115kV Sioux South City 640424 115kV Twin Church 640387 115kV Twin Church 640387 48months 48months NPPD NPPD M M MKEC M M M M M M M M M TG 353Ps ok4 V508 otRc 3 V13520480/600 345/230 1 230kV Rock Post 530584 kV Rock345 Post 530583 ITCGP M M GRDA 12 months 300971 Tahlequah West 69kV Tahlequah West 300971 12months GRDA M P 406SBH15k 402SBE15k 1 179/179 160/160 7 115 115 1 1 SUB E115kV 642072 7115kV ST.LIB 640353 SUB H 115kV 642066 115kV SUB-F 642073 SPP SPP M M /13 ots527 7h538 7h13515560/616 345/115 1 87th 533283 87th 532775 30months 1/11 2010 STEP DATE A A A A A A A A A A A A A A A A A A A A A A WR ECC 503912 Fulton 115k Fulton 115k Fulton 503912 503912 ECC ECC ECC ECI EP 21 months 508057 Hooks 508063 Lone Star Ordinance Ta Ordinance Lone Star 508063 Hau 507741 Hooks 507736 138k South LoneStar 508057 24months 508297 Howell 69k 24months 21months 508545 15months EP 15months EP 18months EP EP EP EP EP EP EP EP EP 12months 9months EP EP EP EP EP EP EP Estimated Cost Source A A A 12 months 24 months 24 months 512642 W Siloam S W Ta Kansas 512642 512714 24 months 24 months 24 months 6mnh 217Hugo 345k 521157 36 months 33 months 507455 Turk 345k Turk 345k Turk 12 months 507455 24 months 507455 60 months Powell 138k Street 33 months 33 months 507748 Texarkana Plant 69k 48 months 15 months 508086 24 months 60 months 48 months 4mnh 300056 24 months 12 months 4mnh 333KUCmu 1 V534 ida 1 V1 115kV Wildcat 533345 115KV KSU Campus 533333 24 months 4 months 640250 Kearney 115kV Kearney 640250 4 months mnh 002Gogtw 6 V302 rse 6 V11125286/286 2.5 161 1 161kV Dresden 300526 161kV Georgetown 300082 months Project Lead Time h 429Lu iy15k 424NrhLu 1 V115137/137 115 1 Loup115kV North 640284 115kV LoupCity 640259 ths 045Tr 4 V587 WTxraa 4 V1353 1336/1915 33 345 1 Texarkana 345kV NW 508072 345kV Turk 507455 s 217Hu 521157 507427 Okay 69k Okay SETexarkana 69k 507427 508077 507456 Turk 115 504122 McNab REC 115k REC McNab 504122 115 Turk 507456 299Hu 520929 217Hu 521157 425Mlny15k 427NrhPat 1 V1 115kV Platte North 640287 115kV Maloney 640265 366Plainville 115k 539686 509783 Riverside Station 138k Station Riverside 509783 SugarHill 138k 508080 138k Turk 507454 138k Turk 507454 115k REC McNab 504122 138k Turk 507454 174P 512724 368Cnoda20k 381Es ahta 3 V1 230kV Manhattan East 532861 230kV Concordia 539658 542965 West Gardner 345 kV 542968 Stilwell 345kV Stilwell 542968 Gardner345kV West 542965 From Bus Number used in SPP 7 tagrCek527 ri 4 1099/1195 345 1 Craig 542977 Creek Stranger 772
7Pat15k 366S-ON15k 1 79.7/87.6 115 1 ST-JOHN 115kV 539696 115kV Pratt 87 MDWG bus Blue Valle SUB 170 - Nichols ST. 69k ST. SUB 170-Nichols Mcdade 138k Mcdade A Spearville 345kV Mt. Grove EEF15k 231L_R 9k 1/944/44 115/69 1 69kV LE_ERF 527361 115kV LE_ERF y sherville 161k sherville s ilJnto 9k 350Rcln 9k 954 72/72 5.43 69 1 69kV Richland 533550 69kV Hill Junction ose ramid Corners 69k ramid Corners g g g so18k 305NrhatPros18k 3 215/215 138 1 138kV Parsons Northeast 533005 138kV osho tae11k 074Lmr11k 6 84286/286 28.4 161 1 Lamar 161kV 300794 161kV rthage oe ln 4 298Hu 520948 345k valliant 510911 o Power Plant 345 o Power Plant 345 g o Power Plant 345k hton 138k hton g er Creek 115 533259 NW Leavenworth 115k NW 533259 115 er Creek 3 V579 als18k 3 0368/512 10 138 1 138kV Caplis 507791 138 kV y V V V V V V p Plant V V p 161k V V V Sbtto 1 V608 2t loSbtto 2k 1/239/39 115/12 1 12kV &Alvo Substation 120th 650380 115kV Substation rin V V g V g V V V 161k s 161k s d507 ot ofyil iy11822433/433 2.2 138 1 Coffeyville City South 510378 nd V V V V V V V V V From Bus Name V V V 484SbM1115353/441 5 161 1 SubM 548814 543129 Middle Creek 161k Creek Middle 543129 345k Sunnyside 515136 Siloam Cit Siloam S W 512643 512642 Sedalia69k 547529 Hau Point 138k Red 507736 507751 Pittsbur Okmul 508313 Kil 510898 508546 Valliant 345k 510911 Linwood 138k 69k Tollette 507738 Texarkana Plant 69k 507415 Texarkana 69k South REC 508086 504117 507456 301194 507453 Stran 533268 539678 Great Bend115k Great 539678 097Cbo 6 .1286/286 9.51 161 1 Cabool 300917 009SugarHill 69k 508079 345k Turk Texarkana 345k NW 507455 Texarkana 345k NW 508072 508072 SETexarkana 138k 508078 SugarHill 138k 508080 353Ps ok4 V1359 1792/1792 90 345 1 kV Rock345 Post 530583 To Bus Number used in SPP MDWG bus Turk 115k Turk Ho A sherville 69k sherville g g p ore 69k oPower Plant 138k g e 115k hton 138k hton g g er Creek 115k er Creek g ee 138k 138k y V V 161k V p V 3 V11895215/225 9.5 138 1 138 kV V V V rin V V V V V g V V V V s 161k s V V V V V V V V V V
V To Bus Name V p V 69k V V 161 1 1 161 12 293/335 293/335 500/500 913/1140 12 19 347/403 347/403 161 54/65 345/138 1 368/512 345 368/512 1 280/331 143/143 202/235 11.3 3.2 1 52/69 1 4.2 138/154 913/1140 8.8 1336/1915 8.92 675/675 161 1336/1915 161 368/512 69 1 1.68 1 138 1 138 3.49 150/174 69 138 1 138 34 368/512 69 1 1 138/69 1 345 1 345/138 1 345 1.5 1 345 1 1 138 24 1 1 1 1 115 1 56/56 1 1 138 1 245/301 1 3.61 161/69 115 1 1 1 223/240 223/240 6.5 7.1 115 115 1 2 1 165/178 1 115 1 161 1 345 1 4 1000/1136 345 1 Circuit 345 138 115 115 1 36Mvar 115 115 230 115 115 345 69 69 69 915Mvar 69 69 21.6 Mvar 21.6 69 69 7.2 Mva 7.2 69 Voltages (kV) 5.92 Number of Reconductor
Number of New
Number of Voltage Conversion 3 1195/1195 260/304 114/143 155/155 280/308 223/223 20 Mva 90/121 71/96 Summer Rating Normal/Emergency r r T oiySoe20831850156 30148 20048 Scope NTC -Modify 2013 T 09133SSrgoa eiblt 1000CnetLn onySbtto o15k evc 60/30/11 P 2mnh 266Ly 526656 12months SPP 06/01/12 06/01/13 115kV service to Substation County Lynn Convert $100,000 reliability regional SPS 11353 1029 NTC NTC NTC 2010 Requested Board Action Appendix A - Complete List ofAppendix Upgrades Network List A-Complete 05 8 10231 182 20059 00 7 10221 10602 172 463 20006 20033 05 2 10668 523 20055 08 8 13 P einlrlaiiy$,9,4 eodco .6ml adxSain-Mnmn 1 VCt1wt 9 CR 05/31/ Tap conduc 115kV -Brasher 397kcmil with interchange mile Roswell .27 Reconductor 115kV mile MVA linefor Maddox 6.15 226/239 Station -SangerSwitching Reconductor $173,324 $608,240 795ACSR. 1with 115kV mile Ckt -Monument Maddox 3.36 Station Reconductor $1,098,248 reliability regional reliability regional reliability regional 10829 SPS SPS SPS 696 11038 11029 11036 20031 789 779 786 20084 20084 20084 20033 621 10809 WR regional reliability $19,307,000 Uprate JEC- E. Manhattan 230 kV line to 100 deg C operation by raising structures raising by operation 100degC 230kV lineto Manhattan E. JEC- Uprate $19,307,000 regionalreliability WR 10809 621 20033 06 7 11 E einlrlaiiy$,0,0 eul .5mlso 9 CRwt 50AS n ee eas 0/11 E 12mo AEP M 06/01/13 relays. andreset 1590ACSR with of miles 795ACSR 2.45 Rebuild $2,500,000 regionalreliability AEP 11011 11015 767 770 20073 20064 08 6 10351 267 20086 00 4 11262 948 20105 05 2 10674 10352 529 267 20059 20086 10794 10174 10521 616 10520 10799 136 401 20030 400 135 20003 20003 20003 20030 10480 10215 367 10876 166 10701 20014 50171 670 20007 50169 551 30163 20110 30161 20081 20017 20017 20034 646 10847 GMO regional reliability $6,320,000 Replace Clinton 161/69 kV transformer #1 with new 100/125 MVA to match transforme kV match MVA new #1with transformer 161/69 to 100/125 Clinton Replace $6,320,000 reliability regional GMO 10952 10847 715 11184 11183 646 11012 20077 767 767 20034 767 20073 20073 20073 10837 551 20081 02 4 10575 443 20027 08 6 10350 10417 267 321 20086 20006 20091 30224 50228 WR transmission service $4,900,000 Rebuild approximately 6 miles of line with 954-KCM ACSR to achieve aminimum achieve to approximately 600 ACSR Rebuild of 6miles 954-KCM linewith $4,900,000 service transmission WR 50228 30224 20091 08 00 01 PDrgoa eiblt $700,000 regionalreliability NPPD 50210 30203 20080 08 00 50209 30202 20080 08 00 00 PDrgoa eiblt 7000Ada1 vrcpctrbn tCak usain15k u.1/11 PD24mon NPPD M 11/01/12 115kV bus. substation Clarks at bank capacitor Adda18Mvar $700,000 regionalreliability NPPD 50208 30201 20080 00 09 50099 50047 24 30093 NPPD 30041 20003 M 19985 11/01/12 115kV bus. substation Petersburg at bank capacitor Adda15Mvar $600,000 regionalreliability NPPD 50207 30200 20080 08 00 01 PDrgoa eiblt 7000Isala9Ma aaio aka odnsbtto 1 Vbs 60/2MNP 24 NPPD M 06/01/12 115kV bus. Gordonsubstation at bank capacitor a9Mvar Install $700,000 regionalreliability NPPD 50213 30206 20080 20059 30225 50229 WR transmission service $607,500 Add 15 Mvar Cap bank at Allen at bank Cap Add15Mvar $607,500 service transmission WR 50284 50229 30271 30225 20068 20059 01 0411348 1024 20112 20063 664 10870 WR regional reliability $1,720,000 Tear down and rebuild 1.8 mile Gill Energy Center West - Waco 138kV bundled with -Waco West Tear Center mile down GillEnergy andrebuild1.8 $1,720,000 regionalreliability WR 06/0 11204 10870 908 664 ACSR. 69kV 336.4 linefrom to 1/0 SW -ElReno mile ElReno 6.5 Reconductor 20068 $1,950,000 20063 regionalreliability WFEC 50085 10878 30079 672 20003 20085 So at equipment terminal Buildnew 345kV Install linefrom Cleveland. Soonerto $69,000,000 Portfolio Balanced OGE 10929 699 20041 01 0311347 1023 20112 NTC_ID 09 00 PDznl-sosrd$6,0 d n vrcpa nil6 V1/11 P 4mnh 436Oneill69kV 640306 24months SPP M 11/01/12 Oneill69kV at cap Addone9Mvar $364,500 zonal -sponsored NPPD 50206 30199 07 50311 30277 09 03 G rnmsinsrie$,0,0 ntl tgso 5Ma eco tSnyie0/11 P 2mnh 145Sunnyside 515405 12months SPP M 04/01/12 Sunnyside at of reactor 25Mvar 2stages Install $1,000,000 service transmission OGE 50331 30291 1092 1091 1090 1089 1088 1087 1086 0511319 1005 09136KP oa pnoe 21294Rbid42ml lte-Sizr11Vln.0/11 CL1 ots533 LTE11K 5 OLATHE 161KV 543036 543069 18months 36months KCPL SPP M M 06/01/13 06/01/13 mile Buildnew Paola 12.5 161kV -Hillsdale line -Switzer mile 161kV Olathe 4.2 line. Rebuild $11,390,625 $2,182,904 zonal -sponsored zonal -sponsored KCPL KCPL 11377 11376 1040 1039 7 18 EIrgoa eiblt o AT$,0,0 ul todWrik18k ie0/11 60/2AC 6mnh 094Sru 3 Stroud 300914 36months AECI 06/01/12 06/01/13 138kV line BuildStroud-Warwick $4,800,000 -nonOATT reliability regional AECI 11288 974 6 17 EIrgoa eiblt o AT$95879BidMaiCsvle11oe 90/11 60/1AC 8mnh 161Miami 512631 3006 AECI 48months 48months 06/01/11 AECI 06/01/13 AECI 06/01/11 06/01/13 06/01/11 06/01/13 161, Creek BuildSimmons Mt-Bear 161, Mt BuildNotch-Simmons $1,005,750 $2,402,000 Spring161over 69 Build Cassville-Reeds -nonOATT reliability regional $16,391,231 161over 69 Build Miami-Cassville -nonOATT reliability regional $29,508,769 -nonOATT reliability regional AECI -nonOATT reliability regional AECI AECI AECI 11281 11280 11279 11278 967 966 965 964 412 3 10430 333 10539 413 10865 659 414 10541 KCPL zonal - sponsored $1,385,000 New Quarry-Clare 161kV New Line Quarry-Clare $1,385,000 zonal -sponsored KCPL 10541 414 7 19 EIrgoa eiblt o AT$3,900,000 $2,240,000 -nonOATT reliability regional -nonOATT reliability regional AECI AECI 11290 11289 976 975 973 11287 AECI regional reliability - non OATT $1,900,000 Convert Stroud load to 138kV loadto Stroud Convert $1,900,000 -nonOATT reliability regional AECI 11287 973 7 18 EIrgoa eiblt o AT$,9,1 ul rso-ys 3 Vln; 60/30/11 EI3 ots303 Bristo Gy 300137 300916 36months 36months AECI AECI 06/01/12 06/01/12 06/01/13 06/01/13 138kV loadto Gypsy Convert 138kV line; City BuildGypsy-Stroud $1,900,000 138kV line; BuildBristow-Gypsy $7,107,090 -nonOATT $3,692,910 reliability regional -nonOATT reliability regional -nonOATT reliability regional AECI AECI AECI 11286 11285 11284 972 971 970 6 18 EIrgoa eiblt o AT$1,900,000 -nonOATT reliability regional AECI 11283 969 6 18 EIrgoa eiblt o AT$,0,0 move 161 Simmons loadto $1,900,000 -nonOATT reliability regional AECI 11282 968 0 10835 102 2 12 P einlrlaiiy$,0,0 e ie15k a oJhsDa ewe ansadTyo wth0/11 P 12month SPP M 06/01/12 Switch andTaylor New Gaines between Draw Johns to Line115kV tap $4,500,000 reliability regional SPS 11128 823 5 11002 759 1 10948 711 PID 11436 11435 11434 11433 11432 11431 11430 10538 UID WFEC WFEC WFEC WFEC WFEC WFEC WFEC WFEC WFEC SWP OMP OPPD NPPD SEPC SEPC GMO GMO EIrgoa eiblt o ATRbidln s6 Vudr11k n es 3 CR0/11 EI302 ekn 9k 061F 3006 300671 BearCreek Cassville 69kV Creek Flat 300713 Sweetwate 69kV Jenkins 300819 (E Neosho 300671 300758 (E Neosho 300821 300748 300748 AECI AECI AECI AECI AECI AECI M AECI M M M M 06/01/13 M 06/01/13 M 06/01/13 06/01/13 06/01/13 06/01/13 06/01/13 MVA 122/122 69kV lineto -Simmons Mountain BearCreek Rebuild 336ACSR with 69kV under161kV lineas andreconductor Rebuild 336ACSR with 69kV under161kV lineas andreconductor Rebuild 336ACSR with 69kV under161kV lineas andreconductor Rebuild 336ACSR with 69kV under161kV lineas andreconductor Rebuild 69kV 336ACSR under161kV lineas andreuse Rebuild 69kV 336ACSR under161kV lineas andreuse Rebuild -nonOATT reliability regional -nonOATT reliability regional -nonOATT reliability regional AECI -nonOATT reliability regional AECI -nonOATT reliability regional AECI -nonOATT reliability regional AECI -nonOATT reliability regional AECI AECI AECI A OGE OGE OGE OGE OGE OGE A A A A A A P einlrlaiiy$4,716,600 reliability regional SPS A A P einlrlaiiy$945,000 reliability regional SPS LES Rrgoa eiblt $4,674,000 $6,066,000 regionalreliability regionalreliability WR WR WR WR WR WR WR WR WR WR Rrgoa eiblt $4,230,000 $1,770,000 regionalreliability regionalreliability WR WR C re ECI EP EP EP EP EP EP EP transmission service $2,800,000 Rebuild 2.49 miles with 1590 ACSR. Replace wavetrap and jumpers at Whitney. Replace metering metering Replace Whitney. wavetrap at andjumpers Replace 1590 ACSR. with miles 2.49 Rebuild 1272ACSR with ACSR of miles 397.5 7.11 Rebuild $2,800,000 $7,200,000 service transmission service transmission EP EP Facility Owner A A re g g ional reliabilit ional reliabilit transmission service transmission transmission service $50,200 Replace the 69 kV bus and jumpers on the Oatville-Mac Arthur 69kV line Arthur Oatville-Mac onthe andjumpers 69kV bus the Replace $50,200 service transmission transmission service transmission service transmission service transmission transmission service transmission zona oa sponsored zonal zonal -sponsored zonal -sponsored zonal -sponsored zonal -sponsored regional reliability re regional reliability regional reliability regional reliability re re re re re re re re re re re re regional reliability re re re re re re re re g g g g g g g g g g g g g g g g g g g g g ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit l -sponsore
2010 Project Type y y - non OATT $440,000 Install 40 Mvar ca 40Mvar Install $440,000 -nonOATT -nonOATT y y y y y y y y y y y y y y y y y y y y y d $200,000,000 $68,375,000 New 345 kV line from Oklahoma/Kansas Stateline or the interface with the OG&E line segment to to OG&Elinesegment the with interface orthe New Stateline 345kV linefrom Oklahoma/Kansas $68,375,000 $24,965,000 Convert 17 mile Canadian River - McAlester Cit -McAlester River 17 mile Canadian Convert $24,965,000 $71,000,000 1,0,0 ntl hr rai 4/3 Vattasomr 06/01/12 kV autotransformer. 345/138 Arcadia third Install $13,500,000 $10,000,000 $11,250,000 $2,415,000 $6,600,000 15500U $1,575,000 $4,096,000 Rebuild McAlester Cit McAlester Rebuild Cit McAlester Rebuild $4,096,000 Ta $4,096,000 $9,513,000 Ta $2,000,000 -Newton Re 69kV Junction mile line. Mid-American 3.9 Rebuild $2,380,000 $5,765,600 $1,971,000 $6,674,000 from Lindsa ACSR 556.5 to ACSR of miles 1/0 3.7 Reconductor $1,248,750 15mile Holcomb Rebuild -Pioneer Ta 12mile Holcomb Rebuild -Pl $5,534,364 $3,986,076 $6,200,000 130000 300 $1 12500Dearin $1,215,000 $600,000 Rebuild 1.0 mile Mud Creek Junction - Mid-American Junction 69 kV line. Re 69kV line. Junction -Mid-American Junction Creek mile Mud 1.0 Rebuild $600,000 $225,000 $800,000 Reconductor GMO GMO Reconductor $800,000 $680,000 Rebuild Eastborou Rebuild $680,000 $675,523 $302,795 161kV Richfield Ta 161kV Richfield $302,795 $350,000 Install 12 Mvar ca 12Mvar Install $324,000 $350,000 $324,000 Install 12 Mvar ca 12Mvar Install $324,000 3,0 Re $30,000 5,0 Re $50,000 $50,000 , 300 Cost Estimate , 000 Convert Warwick load to 138 load to Warwick Convert for 138) built already Tap-Warwick 138Kv line (Warwick Build Warwick-Luther Expand existing 9 MVAR bank to 15 Mvar capacitor bank at Ainsworth substation 115kV bus. substation Ainsworth at bank Expand capacitor 15Mvar to existing bank 9MVAR h atMnatnMDwl 1 Vi ul sa20k iebti prtda 1 kV. 115 at operated is but line kV 230 a as built is kV 115 230kV operation.. lineto will work this beperformed have convert to inorderto Substation Manhattan-McDowell East The aminimum achieve to rating. 600amp emergency conductor copper existing 2/0 Replace 69kV line. Junction -White approximately Chase miles Rebuild 7.5 move Bear Creek load to 161 loadto move BearCreek Install 12 Mvar capacitor at Latta Junction 138kV. Junction Latta at capacitor 12Mvar Install Rebuild Bann - Lone Star Ordinance 69 kV with 1272 ACSR (5.4 miles). Replace jumpers, upgrade jumpers, Replace miles). (5.4 69kV 1272ACSR with Ordinance Bann-LoneStar Rebuild WFEC will upgrade 800 A CTs, new Pharaoh. will limit CT will be1200Aat upgrade800ACTs, WFEC New 345 kV line from Sooner to Oklahoma/Kansas Stateline or the interface with the Westar Westar the with interface orthe New Stateline 345kV linefrom Oklahoma/Kansas Soonerto Convert 11 mile Dover Southwest - Dover from 69 kV to 138 kV and install terminal equipment at Do -Dover from at equipment terminal 11mile 138kV 69kV Dover Southwest Convert andinstall to 138kV. 69kV lineto Switchyard -Twin 7-mile Reeding Convert Lakes equipment. terminal -HammettBuild new 138kV 10mile andinstall Meeker Convert TEC-Midland from TEC-Midland 115k 161kVConvert to eul 4h-Mnea6 Vln.0/11 R1 ots531 inh c ot 382Sixt 533842 South Jct Minneha 533819 18months WR M 06/01/12 li kV 69 h Mi 64th ild b 69kV line. -Minneha 64th R Rebuild 161k Johnson 515293 24months OGE M completed be will conversion the 06/01/12 161kV. 69kV lineto mile -Massard Johnson 5.6 Convert ofBuild 2miles e terminal 161kV Park from andinstall Oak to Johnson A A A og aia owl.SSpoie iiainwsvrfe ySPsafutl1/02when 12/2012 REC-Pine Valley until Central staff - SPP Price by - verified County was Chaves mitigation from SPS-provided kV 115 Roswell. to - line Capitan kV - 69 Lodge of miles 11.8 Convert elc aerp,Csadjmesa ohWlfrt n uasbttossc htterminal that such substations Yuma and Wolffordth both at jumpers 115kV of 192MVA lineT72 the rating the constrain not does equipment and CTs wavetraps, Replace d W8hHlrg 4/1k rnfre 2 rvnb ECCtgr TL03 prior - (TPL-003) C Category NERC by Driven #2. Transformer transformer. 345/115kV of followed of asecond anoutage transformer, one345/115kV outage by 345/115kV Holdrege NW68th Add Replace terminal equipment so that the overall facility rating is 352MVA. is rating overall facility the that so equipment terminal Replace erdw n eul .-ieHlta u re 9k ie elc 3. ci ACSR kcmil 336.4 Replace line. kV 69 Creek Mud - Halstead conductor 7.3-mile ACSR rebuild substations. at equipment terminal kcmil andreplace conductor ACSR 954kcmil with conductor 477 and replacing down line Tear kV 69 Oliver - Oaklawn undergroundcable. CU would Limit 750kcmil be0.2-mile conductor. ACSR 954kcmil with of 1.91-miles down/rebuild Tear dd 2nd 345/138KV Auto Transformedd 2nd345/138KV Auto of 345KV 345KV linefrom interception Install Hugo, dd 345KV WFEC to linefrom Sunnyside locati this of at 36Mvar for atotal Oneill115 kV substation at bank capacitor 18Mvar dd asecond pg p p p p Pittsbur S South the rade Nixa 70MV to #2transformer lace CT Russell at WFEC LineSwitches lace g 138kV Ca 20MVAR g - Musko p rin p p p g p acitor at Comanche 138 kV bus. 06/01/12 M WFEC 12 months 520864 Comanche 138 k Comanche 520864 12months WFEC 161k Cabool at acitor M 06/01/12 SPP M 06/01/12 138kV bus. Comanche at acitor of 24Mvar. total at makes which Jct Carter at acitor p inh 9k ie R1 ots539 Eastborou 533792 18months WR M - 69kV line. h -Minneha of Hallmark Sible to g ortion of Glenare-Libert ortion dale-East Fa dale-East y y g Ta Ta ee 345 kV about 33 miles north of the Pittsbur of the north 33miles ee 345kV about p p , doublecircuitin , Cit McAlester 'T' at the andeliminate y p mell 115kV. ctrAdto 60/2MWR M 06/01/12 Addition acitor Project Description/Comments Project y teil 6 Vln n ul . ie f11k onw 06/01/13 of miles 161kV new 161kV lineandbuild 1.5 etteville to r p A 115kV. y V V g existin y 69kV MVA for ratin 70/79 y ln rm6 Vt 3 V 06/01/13 linefrom 138kV. 69kV to g line, eliminate the 'T' at McAlester Cit McAlester 'T' at the eliminate line, y p y to Lindsa to lace 336.4 kcmil ACSR conductor conductor ACSR kcmil 336.4 lace North Ta North g station andste station q ui g p . y ment at Oak Park. 06/01/12 M OGE 24 months 515315 Oak Park 161k Oak 515315 24months OGE M 06/01/12 Park. Oak at ment p Suhet6 V 06/30/12 69kV. Southwest p 06/01/13 . lace 336.4 kcmil kcmil 336.4 lace nr1/11 G 2mnh 183Soe 4 V529 lvln 4 V1353 1195/1195 36 345 1 345kV Cleveland 512694 Sooner345kV 514803 32months OGE M 12/31/12 oner P 4mnh 381E ahta 3 V525 E 3 V120446/490 230 1 230kV JEC 532852 230 kV Manhattan E. 532861 24months SPP M . ap 60/2MW 2mnh 361Aln6 V533 eihTp6 V16 .972/72 5.69 69 1 LehighTap 69kV 533638 Allen69kV 533621 12months WR M 06/01/12 amp 125AS 0/11 R1 ots534 ilEeg etrWs 3 V537 ao18k 3 . 534/586 1.8 138 1 138kV Waco 533072 138kV West Center GillEnergy 533045 12months WR M 06/01/12 ACSR 1192.5 p 2 60/3MGO1-8mnh 433Citn6 V515 lno 6 V16/6 100/125 69/161 1 161kV Clinton 541352 69kV Clinton 541303 12-18months GMO M 06/01/13 r #2. dw o 06/01/13 down to o.0/11 P 2mnh 254RselItrhne15k 254BahrTp15k 1 .7160/160 0.27 115 1 Tap 115kV Brasher 527534 115kV Interchange Roswell 527564 12months SPS M 06/01/12 tor. aig 53/2MSP1 ots585 adxSain15k 243Sne wthn tto 1 V11561 146/161 6.15 115 1 115kV Station SangerSwitching 528463 115kV Maddox Station 528355 18months SPP M 05/31/12 rating. y Nrh 06/01/13 North C o v 60/30/11 EI2 ots301 awc 015Lte 3 .1228/228 5.61 138 1 Luther 300135 Warwick 300915 Warwick 300915 24months AECI AECI 06/01/12 06/01/12 06/01/13 06/01/13 60/30/11 EI301 Stroud 300914 AECI 06/01/12 06/01/13 60/30/11 EI301 Gypsy 300916 AECI 06/01/12 06/01/13 12/01/12 M WR 12 months 533588 Chase 69 kV 533605 White Junction 69 kV 1 69 7.3 72/72 72/72 7.3 69 1 69kV Junction White 533605 69kV Chase 533588 12months WR M 06/01/12 12/01/12 60/30/11 EI303 BearCreek 300933 AECI 06/01/11 06/01/13 60/30/11 EI300 Simmons Mt 300903 AECI 06/01/11 06/01/13 60/30/11 AECI 06/01/11 06/01/13 60/306/01/13 06/01/13 06/01/13 06/01/12 60/2MOGE M 06/01/12 12/01/12 40/2MOGE M 04/01/12 06/01/12 OMP 06/01/12 40/2MOE24months OGE M 04/01/12 06/01/13 M GMO 12-18 months 541346 Ritchfield 161k Ritchfield 541346 12-18 months GMO M 06/01/13 06/01/13 06/01/12 WR M 06/01/12 12/31/12 60/2MWERE M 06/01/12 05/31/13 11/10/12 06/01/13 M KCPL 18 months 543037 Quarry 161 kV #N/A Clare 161 kV 1 161 4.5 293/335 293/335 4.5 161 1 161kV Clare #N/A 161kV Quarry 543037 18months KCPL M 06/01/13 06/01/12 M WR 12 months 533824 Oaklawn 69 kV 533826 Oliver 69 kV 1 69 2.11 116/128 116/128 2.11 69 1 Oliver 69kV 533826 69kV Oaklawn 533824 12months WR M 06/01/12 10/2M 11/01/12 60/2MSP12months SPP M 06/01/12 06/15/12 03/01/12 03/01/12 04/01/12 06/01/13 04/01/12 10/2MNP 4mnh 435Oneill115kV 640305 24months NPPD M 11/01/12 06/01/13 M 06/30/12 60/2MW 2mnh 361Allen69kV 533621 12months WR M 06/01/12 60/20/11 P ots562 ofodhItrhne15k 245Ym necag15k 1 192/192 115 1 115kV Yuma Interchang 526475 115kV Interchange Wolffordth 526524 6 months SPP 06/01/12 06/01/12 04/01/12 M WR 12 months 533736 Halstead 69 kV 533744 Mud Creek Junction 69 kV 1 69 7.3 116/128 116/128 7.3 69 1 69kV Junction Creek Mud 533744 69kV Halstead 533736 12months WR M 04/01/12
/2MWE 8mnh 282E eo6 V509 lRn W6 V16 . 36/36 6.5 69 1 69kV SW ElReno 520899 69kV ElReno 520892 18months WFEC M 1/12 In Service 2MSP1 ots585 adxSain15k 241Mnmn u 1 V11533 246/270 3.36 115 1 Sub115kV Monument 528491 115kV Maddox Station 528355 18months SPP M 12 60/2WE 12months WFEC 06/01/12 60/6SPP 06/01/16 06/01/20 R1 ots526 atMnatn20V532861 230kV Manhattan East 532862 12months WR M R3 ots540 Sooner345k 514803 36months WR M EC2 ots519 Pl 531393 24months SEPC M EC1 ots514 Holcomb 115k 531448 18months SEPC M M WR 12 months 533741 Mid-American Junction 69k Junction Mid-American 533741 12months WR M CL2 ots538 Glenare69k 543081 24months KCPL M M WR 12 months 533744 Mud Creek Junction 69k Junction Creek Mud 533744 12months WR M M M M M M M M M M M P 242Cae onyItrhne15k 254RselItrhne15k 1 11 120/154 11.18 115 1 115kV Interchange Roswell 527564 115kV Interchange County Chaves 527482 SPP M OPPD M 2010 STEP DATE WFEC 6 months 521043 WFEC Russell 138k Russell WFEC 521043 6months WFEC NPPD A G 0mnh 514908 30months OGE A A A A A A A A P ots559 Pharoah 138k 505592 6 months SPP SPP P 4mnh 297Lindsa 520977 24months SPP SPP P 524N 8&Hlrde15k 514N6 ODIG 4 V13515336/420 345/115 1 345kV &HOLDRIDGE NW68 650114 68& Holdridge 115kV NW 650214 SPP WR ECI EP 36 months 510908 McAlester Cit McAlester Cit McAlester 510908 345k River Canadian 510908 138k River Canadian 515422 36months 510946 36months EP 36months EP 36months EP EP EP EP EP EP Estimated Cost Source A 10 months 12 months 24 months 24 months 8th 18 24 months 24 months 24 months 42 months 2mnh 217Hugo 345k 521157 42 months 18 months 24 months 1mnh 003Bann69k 508053 21 months 12 months 6 months 533180 Tecumseh Energy Center 115k Center Energy Tecumseh 533180 6 months months 640318 Petersburg 115kV Petersburg 640318 months ots609 Gordon138kV 640192 months
ts542 sdw 3 V509 ri ucin18k 3 .5265/287 2.45 138 1 138kV Junction Craig 510890 138kV Ashdown 504124 nths Project Lead Time ths 640436 Clarks 115kV Clarks 640436 ths 232Gie 232JhsnDa 1 159/160 115 1 Draw Johnson 527362 Gaines 527322 s 040Nth300 imn t111605286/286 6.005 161 1 Simmons Mt 300903 Notch 300490 093SmosM 093Ba re 6 .3286/286 2.23 161 1 BearCreek 300933 Simmons Mt 300903 520994 Meeker 138k Meeker 520994 515136 Sunnyside 345k Sunnyside 515136 520882 Dover SW 138k SW Dover 520882 046Nixa 161k 505496 506979 533819 640051 Ainsworth 115kV Ainsworth 640051 520971 Latta Junction 138k Junction Latta 520971 183Sooner345k 514803 521037 520846 Carter 69k Carter 520846 302Dearin 533002 508575 Whitney 138k Whitney 138k Shreveport Southwest 508575 507759 097Cabool 300917 514907 383Mcrhr532 Oatville 533825 Macarthur 533813 421SB12 6 V665 15 6 V1 S1255161kV 646255 SUB 1221 161kV 646221 From Bus Number used in SPP
2Csvle11k 442ResSrn 6 V1113 286/286 36 161 1 Spring 161 kV Reeds 547492 161kV Cassville 82 MDWG bus PAOLA 161KV Reedin Osbourne 161k Osbourne A A ihJtSth S t J h Mi cda 4 514907 138k RCADIA 345 rcadia y nn County Interchange 115kV Interchange nn County s 176Sru iy1181 245/245 16 138 1 City Stroud 512706 psy mell 115k 096Gpy1181.8 245/245 11.085 138 1 Gypsy 300916 w 11k 062Csvle11k 6 48 286/286 64.81 161 1 161kV Cassville 300682 161kV g y g 69k 138k 6 V302 hao Bry 9k 91 70/70 12 69 1 69kV (Barry) Wheaton 300826 69kV V g V E 9k 078Setae 9k 91.570/70 70/70 11.55 3.75 69 69 1 1 69kV Sweetwater 69kV (AECI) Neosho 300758 300750 69kV DE) 69kV DE) 9k 079Wna6 V16 . 70/70 4.5 69 1 69kV Wanda 300759 r 69kV V 6 V309 imn onan6 V16 .3 122/122 2.235 69 1 69kV Simmons Mountain 300792 69kV h 533819 Minneha Jct South 1 69 0.61 116/128 116/128 0.61 69 1 South Jct Minneha 533819 h V V V V V V y y V V V V V 138k 138k V V V V V V V V V V V V V V From Bus Name V V V V 533842 Newton 69k 532794 69k Junction Mid-American 533745 533741 138k Dover 520879 Hammett 138k 520951 138k Weleetka 511448 Lindsa 521026 Nixa 69k 520979 505501 Pioneer Ta Pl 531392 531393 161k Massard 161k Johnson 515343 k Sunnyside138 515293 345k Sunnyside 515135 515136 422Libert 541262 Cit McAlester 138k Dustin 510909 138k River Canadian 510921 Cit McAlester 510946 510908 Ta Osbourne Tap 69k Ordinance LoneStar 506980 508063 533252 Midland 115k Midland 533252 520847 138k OMLARCA 529272 Hill 345k Rose 532794 543121 Eastex 138 k 138k Springridge REC 508582 507757 01 awc 3 2245/245 12 138 1 Warwick 00915 34 WTE 6 V11142558/558 4.2 161 1 161KV SWITZER 43045 To Bus Number used in SPP
2Cp ar6 V16 . 51/51 3.6 69 1 69kV Fair Cape 62 MDWG bus HILLSDALE KV 161 McDowell 230kV McDowell Rose Hill 345k Rose itFt 6t)6 kV 69 (64th) th F t Si A A Cashion 138k Cashion a re 9k 91. 51/51 10.9 69 1 69kV Creek lat cda 3 4/3 493/493 EP Altus Jct Ta 345/138 3 138 rcadia y mell 115k y -Fourth -Fourth y y 69k SW 69k SW V p V 115k V V V ( V p V 64th y y V 161k V V North Ta North 138k V V V V V V p V V V ) 138k V 69k V V V
V To Bus Name V p V 138k V V V 3 56 358/358 15.65 230 1 161 1 1 69 1.99 116/128 116/128 1611/1743 116/128 116/128 1.99 53 69 3.9 1.0 1 345 69 69 144/179 144/179 1 219/235 1 143/143 11 1 223/228 7 72/89 10 138 138 138 3.7 1 230/276 138 1 230/276 138 69 1 70/70 161/69 1 1 313/335 313/335 1 2 5.6 956/1052 14.87 11.96 2 115 115 138 53 1 1 161 1 161 1 1 345 2 1 1 970/79 223/245 380 96/105 88/107 450/495 321/443 17 5.73 69 2.49 161 5.73 1.5 138 1 1 138 138 1 345/138 1 138 1 1 161 1 1 1 1 138 1 138 1 138 1 161 1 980/80 69 1 1 6 25293/335 12.5 161 1 Circuit 345/138 38-50 13.8 345 3 .1287 7.11 138 1 9Mvar 115 1 18Mvar 115 1 15Mvar 115 1 9Mvar 115 1 18Mvar 115 6 40Mva 161 115 3 20Mva 138 12Mva 138 138 161 1 19.33 115 69 69 99Mvar 69 915Mvar 69 912Mva 69 Voltages (kV) 199 5.4 Number of Reconductor 120 Number of New
Number of Voltage Conversion 4 1195/1195 240/240 116/128 428/636 12 Mva 352/352 117/117 90/121 Summer Rating Normal/Emergency r r r r r 2014 NTC T 03144W einlrlaiiyNw116 Vtasomra rnln0/11 R537 rnln11k 398Faki 9k 161 1 69kV Franklin 532938 161kV Franklin 533876 WR M 06/01/13 New Franklin kV at transformer 161/69 regionalreliability WR 11444 1073 NTC NTC NTC 1073 11413 WR regional reliability Tap Litchfield - Marmaton 161 kV line at new Franklin substation 06/01/13 M WR 533876 Franklin 161 Franklin 533876 WR M 06/01/13 substation new 161kV Franklin lineat -Marmaton Tap Litchfield regionalreliability WR 11413 1073 NTC T 9 14 P einlrlaiiy$,0,0 eodco .-ieCniga tto uky a 1 Vln ih75AS 06/0 Tap 115kV 795ACSR linewith -Buckeye Station Cunningham 8.5-mile Reconductor $3,607,000 reliability regional SPS 11046 792 NTC NTC T 7 00 D einlrlaiiy$,5,0 eodco .5mlso / Uwt 5 CR0/11 60/4EE1 ots573 SUB 547438 12months EDE 06/01/14 06/01/14 556ACSR with CU of miles 1/0 2.85 Reconductor $1,550,000 1272A to linefrom Hill 336ACSR -Carthage Rock 11.4-mile orreconductor Rebuild reliability regional $13,500,000 regionalreliability EDE 10608 AEP 472 11171 882 NTC NTC 2010 Requested Board Action Appendix A - Complete List ofAppendix Upgrades Network List A-Complete 07 5 10858 653 20079 09 4 11241 940 20099 09 3 11236 936 20096 00 5 10584 450 20000 02 4 10853 649 20027 08 6 10603 467 20086 00 0 10522 402 20003 96 7 10488 375 19964 20084 774 11021 SPS regional reliability $5,062,500 Convert Hastings Sub from 69 kV to 115 kV 03/31/13 M SPP 30 months 524136 Hastings Sub Hastings 524136 30months Ch 524010 SPP 20months M SPS 03/31/13 2 M 03/31/13 SPS M 06/01/13 Subfrom 115kV 69kV Hastings to Convert Substation. Cherry New at kV Autotransformer 230/115 $5,062,500 sub Cherry andbring230kV into Cherry 230kV lineat Tap West -Harrington Potter $8,515,623 $679,000 Kingsmill. MVA at 75/86 kV rated transformer 115/69 asecond Install $4,428,144 reliability regional reliability regional reliability regional reliability regional SPS SPS SPS SPS 11021 11020 11019 11096 774 774 774 829 20084 20084 20084 20084 02 4 10843 642 20029 03 4 04 Rrgoa eiblt 46000TpteNoh wnVle ieit laot 60/3MW 8mnh 308Twin Val 533008 18months WR M 06/01/13 10582 450 20000 -Twin Neosho Tap the Altamont. Valley lineinto $4,640,000 regionalreliability WR 11082 10678 10846 10844 819 533 10797 645 10796 643 10795 20086 10179 20086 10402 616 20063 10176 616 20033 10524 616 10523 140 311 20030 138 20030 402 20030 402 19985 20003 20003 20003 20003 10300 235 20081 11200 903 20067 00 4 11260 11255 11254 11253 11252 945 11251 945 11250 945 11249 945 11248 945 20102 11247 944 20102 11246 944 20102 11245 943 20102 11244 943 20102 11243 942 20101 942 20101 941 20120 941 20120 940 20121 20121 20100 20100 20099 10585 450 20000 09 4 11242 940 20099 08 9 11182 892 20081 04 0 04 ITCGP 10943 707 20046 04 0 03 OGE 10932 701 20041 04 0 03 OGE 10933 701 20041 08 9 15 P einlrlaiiy$48542Bidnw1 iePesn il-Oss20k ie 53/3MSS2 ots547 P 524770 24months 30mont SPS SPS M 05/31/13 M 05/31/13 East Harrington wavetrap at Replace 230kV line. County Buildnew -Roosevelt -Draw 26mile Frio $20,612,670 $500,000 Buildnew 230kV 16mile line. Hill Pleasant -Oasis $14,805,472 reliability regional service transmission reliability regional SPS SPS SPS 11349 11054 11053 1025 795 795 20113 20084 20084 20084 834 11101 SPS regional reliability $3,576,231 Convert existing 3 mile Portales Interchange - Zodiac 69 kV line to operate at 11 at operate 69kV lineto -Zodiac existing 3mile Convert Interchange Portales $3,576,231 reliability regional SPS 11052 11101 795 834 20084 20084 08 7 12 P einlrlaiiy$,0,0 ul e . ieHsig atPat15Vln.0/11 P ots543 Has 524136 4months SPP M 03/31/13 Plant 115kV line. -East mile Buildnew Hastings 3.7 $1,700,000 reliability regional SPS 11023 774 20084 08 1 17 PDrgoa eiblt 10000Urt odco n usaineupett 0 erertn.0/11 PD24m NPPD M 06/01/13 WVT DISC, (PCB, equipment andupgradeterminal C 100Deg to clearances Increase rating. 100Degree to equipment andsubstation conductor Uprate $3,500,000 $1,000,000 regionalreliability regionalreliability NPPD NPPD 11438 11079 1094 817 20117 20080 04 0 04 NPPD 10942 708 20047 06 01 10994 30211 20067 06 0 11203 906 20067 06 0 11202 905 20067 00 00132ME rnmsinsrie$,8,4 eul wesi f2. ie 60/3ME 4mnh 365Genef15k 53333 a minimum achieve to approximately Rebuild 600am ACSR 1mile of 954-KCM linewith $901,000 aminimum achieve to approximately Rebuild 1 ACSR of 4miles 954kcmil linewith aminimum achieve to approximately Rebuild 1 ACSR of 7miles 954kcmil linewith $2,752,000 $2,000,000 50231 service transmission service transmission service Greenleaf 115kV transmission SW Upgrade Terminal Altus at Equipment 30227 539665 $150,000 WR WR 24months 20059 WR 10713 service transmission MKEC 50240 50234 50233 563 WFEC 30224 30224 30224 20063 06/01/13 20091 11350 20091 20091 1026 20114 miles of Ownership 20.9 Rebuild $5,887,242 service transmission MKEC 11201 11342 904 1020 20067 20107 04 0 03 OGE 10930 700 20041 NTC_ID 03 50249 30237 1066 1067 1080 0311412 1073 1052 11393 LES zonal - sponsored 84th & Leighton 115/12kV #2 115/12kV &Leighton 84th zonal -sponsored LES 11393 1052 0311411 1073 1049 11390 SPS zonal - sponsored $4,632,000 Uprate Deaf Smith Auto for DS-24 mitigation 06/01/13 M SPP 524623 Deaf Smith County Interchan County Smith Deaf 524623 SPP M 06/01/13 mitigation for DS-24 Auto Smith Deaf Uprate $4,632,000 zonal -sponsored SPS 11390 1049 7 19 EIrgoa eiblt o AT$6,500,000 -nonOATT reliability regional AECI 11291 977 7 19 EIrgoa eiblt o AT$,4,9 ul tFacsDde 6 Vln 60/4MAC 015S rni 080Dudl 300820 Francis St 300115 AECI M 06/01/14 161kV line Francis-Dudley BuildSt $8,040,890 -nonOATT reliability regional AECI 11292 979 978 4 10852 10851 10850 10849 648 648 648 648 9 19 G oa pnoe e itiuinSb-W ipr 60/4M548 Ripr 3 V542 enyvna18k 3 233/26 233/2 138 138 1 1 Pennsylvania 138kV 514925 138kV WRAirport 514889 138kV WRAirport 138kV 36&Meridian 514889 514888 M M 06/01/14 06/01/14 Airport Sub-WR New Distribution Airport Sub-WR New Distribution zonal -sponsored zonal -sponsored OGE OGE 11192 11191 897 897 1 17 PDrgoa eiblt 10000Urt odco n usaineupett 0 erertn.0/11 PD24months NPPD M 06/01/14 rating. 100Degree to equipment andsubstation conductor Uprate $1,000,000 regional reliability NPPD 11078 816 6 10714 563 7 11378 774 PID 10 EIrgoa eiblt o AT$,0,0 Upgrade Transformer 84MVA unit to $2,000,000 -nonOATT reliability regional AECI 11406 11293 10 EIrgoa eiblt o AT$,0,0 Upgrade Transformer 84MVA unit to $2,000,000 -nonOATT reliability regional AECI 11407 11420 UID DETEC DETEC DETEC DETEC WFEC WFEC WFEC WFEC WFEC WFEC WFEC WFEC WFEC MKEC MKEC MKEC MKEC MKEC MKEC MKEC MKEC MKEC MKEC MKEC MKEC MKEC SEPC SEPC NPPD AECI regional reliability - non OATT $8,730,110 Build Dudley-Essex 161 kV line BuildDudley-Essex $8,730,110 -nonOATT reliability regional AECI EIrgoa eiblt o AT$7,0 eul reve & 9k ie0/11 60/4AC 8mnh 077Greenview 69kV 300777 18months AECI 06/01/14 06/01/14 Greenview Rebuild -J&7 69kV line $772,500 -non OATT reliability regional AECI OGE G einlrlaiiy$2,500,000 regionalreliability OGE OGE OGE OGE OGE OGE SPS A A A A AEP P einlrlaiiy$19,349,122 $1,771,875 reliability regional reliability regional SPS SPS SPS SPS Rregional reliability WR WR Rregionalreliability WR WR WR WR WR WR WR WR WR EP EP EP EP Facility Owner transmission service transmission rnmsinsrie$,6,1 Upgrade transformer $5,864,617 service transmission transmission service $9,875,072 Rebuild 26mile line Rebuild $9,875,072 service transmission transmission service $10,853,305 Rebuild 24.15 mile line 24.15 Rebuild $10,853,305 service transmission transmission service $5,250,000 Rebuild 8.05 mile line 8.05 Rebuild $5,250,000 $5,887,242 service transmission service transmission transmission service transmission Balanced PortfolioBalanced Balanced PortfolioBalanced Balanced PortfolioBalanced Balanced PortfolioBalanced Balanced PortfolioBalanced zonal -sponsored zonal -sponsored zonal -sponsored zonal -sponsored re re re re re re re re re re re regional reliability re re re re re re re re re re re g g g g g g g g g g g g g g g g g g g g g g high priority high priority high priority high priority high priority high priority high priority high priority high priority high priority high priority high priority high priority high priority high priority high priority high priority ional reliabilit ional reliabilit ional reliabilit ional reliabilit bili li ional reliabilit l i ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit
2010 Project Type y y y y y y y y y y y y y y y y y y y y y y $105,000,000 Build new 345 kV line from Woodward EHV Buildnew 345kV Border linefrom to Woodward $105,000,000 $127,995,000 $150,911,395 $144,911,395 $134,382,759 $178,633,333 110000Buildnew 345kV linefrom Muskogee Seminole to $131,000,000 $15,000,000 Install 2nd 345/138 kV transformer at Woodward EHV Woodward kV at transformer 2nd345/138 Install $15,000,000 $13,418,922 3,8,0 ntl 8mlso e 4 V -5 CRln.06/01/14 $11,962,000 line. of 18miles new 2-954ACSR 345kV, Install $34,085,000 $13,104,000 $12,622,500 $60,590,000 $38,790,727 $76,000,000 $26,221,860 Convert from Convert 138k 69kV to $26,221,860 $92,200,000 $8,883,760 21000Rcnutr21 iescino 1 Vln ih75AS.06/01/14 of 115kV 795ACSR. linewith mile section 2.15 Reconductor $2,150,000 $2,400,000 $3,937,500 $3,164,000 $5,315,700 $1,601,000 Grandfield kV new at transformer 138/69 Install $1,050,000 Ta $5,000,000 of 3miles 138kV 69kV Convert from to Grandfield. to Indiahoma $7,306,000 $1,125,000 345kV River e terminal Canadian Install $5,500,000 $8,100,000 Install 3rd Rose Hill 345/138 kV TRANSFORMER. 06/15/13 M WR 24 months 532794 Rose Hill 345k Rose 532794 24months WR M 06/15/13 kV Hill TRANSFORMER. 345/138 3rdRose Install $8,100,000 $4,379,000 from Convert 138k 69kV to from Convert 138k 69kV to $1,100,000 $3,127,600 from Convert 138k 69 kV to $8,837,000 $7,347,754 $8,750,767 $3,000,000 $1,000,000 $912,000 Reconductor 3.8 miles from 3/0 ACSR to 795 ACSR. Rate A=81MVA, Rate B=106MV Rate A=81MVA, Rate 795ACSR. to from miles ACSR 3.8 3/0 Reconductor $912,000 $150,000 6750Ad1 vrCpbn tAhn 60/3MWR M 06/01/13 Athens at bank Cap Add15Mvar $607,500 $76,000 $85,500 Remove wavetra $10,000
Cost Estimate ul e 4 Vln rmWl oitreto on fAtl oWl ie(assBre) 06/01/13 Border). (Kansas line Wolf to Axtell of point interception to Wolf from line kV 345 new Build Add 2nd Huben 345/161 kVAdd 2ndHuben transformer 345/161 Install a second 345/230 kV transformer at Hitchland substation. Hitchland kV at transformer 345/230 asecond Install Replace 69 kV disconnect switches at Aquarius with aminimum with Aquarius at rating 600amp emergency switches 69kV disconnect Replace Install 9 miles of 9miles 161kV fromInstall new Shi ShipeRoad. kV at transformer 345/161 Install kV transformer. 230/115 AuburnRoad second Install Re Build new 7 mile WFEC Twin Lakes - OG&E Crescent 138kV. -OG&ECrescent Twin Lakes Build new 7mile WFEC from mile 138kV. 69kV -Cashion Twin 7.5 to Convert Lakes mile from -Twin Dover 12.6 Convert 138kV. 69kV Lakes to Norman from -Acme 138kV. 69kV to 4mile West Convert new rat 795ACSR; to from ACSR 336.4 1200Aandreconductor to sub Woodward Upgrade WFEC Rebuild 5.56 mile Gill Energy Center East - MacArthur 60 kV line. Replace substation bus andjump bus substation Replace 60kV line. -MacArthur East Center mile GillEnergy 5.56 Rebuild Rebuild 21.9 mile St. John - Pratt 115 kV line with 795 ACSR conductor. John 115kV -Pratt mile 795ACSR linewith St. 21.9 Rebuild Re line, tapping line and connecting to Sheffield. to lineandconnecting tapping line, Build A Upgrade the Valliant and NW Texarkana substations with the necessary breakers and terminal andterminal breakers necessary the with Texarkana substations ValliantUpgrade andNW the ul ie fdul ici 9k iefo e rnlnsbtto oMler hfil 9kV 69 Sheffield - Mulberry to substation Franklin new from line kV 69 circuit Mulberry. to lineandconnecting tapping double line, of miles 6 Build Install a 18 Mvar capacitor bank at Holdrege substation 115kV bus. Holdrege substation at bank capacitor a18Mvar Install to the OGE interception point from the Woodward District EHV substation. Upgrade the Hitchland Hitchland Upgrade the EHV substation. District from Woodward point the OGEinterception the to substation from Hitchland the 3000Acapacity least 345kV at linewith Build 30mile doublecircuit osrc prxmtl . ie f15k iefo hrySre usaint Hastings to substation MVA kV 2 CKT 84/96 115/69 Add 2ndtransformer Street Cherry from line kV 115 of miles 3.5 substation approximately Construct ul e 4 Vln rmAtl oitreto on fAtl oWl ie(assBre) 06/01/13 Border). (Kansas line Wolf to Axtell of point interception to Axtell from line kV 345 new Build Rebuild 14.4 miles 14.4 Rebuild Install a 400 MVA 345/138 kV transformer at the new 345 kV Medicine Lodgesubstation. new 345kV the kV a400MVA Medicine at transformer 345/138 Install Build anew 345kV substation substation. County new Comanche the to Lodge 345kV substation from Medicine the 3000Acapacity least 345kV at linewith Build anew 55mile doublecircuit Buildthe from Spearville substation. the SEPC interception the to substation County Comanche from new the 3000Acapacity least 345kV at linewith mileBuild anew doublecircuit 27.5 substation. from County new point Comanche the interception MKEC the to substation from Spearville the 3000Acapacity least 345kV at linewith mileBuild anew doublecircuit 27.5 EHV District Woodward the bordertowards state Kansas/Oklahoma the to Lodge substation from Medicine the 3000Acapacity least 345kV at linewith mileBuild anew doublecircuit 28.6 Lodge Medicine the bordertowards state Kansas/Oklahoma the to EHV substation District from Woodward the 3000Acapacity least 345kV at linewith Build anew 79mile doublecircuit Upgrade the substation. from Hitchland SPS the the interception to EHV substation District from Woodward the 3000Acapacity least 345kV at linewith Build anew 92mile doublecircuit eodco . ie fFr mt ooy11k iet 50kmlAS n hneterminal change and ACSR kcmil 1590 to line kV 161 Colony - Smith 2000A. to substations Fort andColony Smith Ft. at equipment of miles 2.2 Reconductor dscn rnfre n1t tetsbtto.0/11 R2 ots533064 24months WR M 06/01/13 substation. Street in17th transformer dd second p p p Cache to Paradise 138 kV and install 13.7 miles of miles Indiahoma. 138kV 13.7 Paradise to from 138kV to andinstall Cache Cache lace wavetra A at switches 69kV disconnect lace 6 miles of double p p at VBI. s on Gill - Interstate 138kV linefor anew ratin onGill-Interstate s circuit V V V V 69 Project Description/Comments Project kV line p e Road Substation to East Centerton Substation. Centerton East to Substation e Road q q from ui ais SPP M uarius. p ment at new Canadian River substation ta substation River new Canadian at ment new Franklin substation g of 232/256 MVA. of 232/256 to Mulberry V 60/3MSS1 ots542 otlsItrhne15k 295Zda 1 V1153157/173 3 115 1 115kV Zodiac 524935 115kV Interchange Portales 524924 18months SPS M 06/01/13 5 kV. 0 m 0/11 R2 ots532 ulntnJnto 9k 363Wl re 6 V16 . 134/147 134/147 4.1 69 1 7.2 69 1 69kV Creek Wolf 69kV 3Westphalia No. County Coffye 533653 533630 69kV Junction Burlington 69kV Junction Burlington 533626 533626 24months 24months WR WR M M 01/01/13 07/01/13 200 amp 200 amp - tto.0/11 P 0mnh 200Cer u 3 V535 otrCut necag 3 V12001218/239 0.1 230 1 230kV Interchange County Potter 523959 Sub230kV Cherry 524010 20months SPS M 03/31/13 station. S n 0/11 E 4mnh 002Rc il6 V595 atae6 V16 14123/143 11.4 69 1 69kV Carthage 509056 Hill 69kV Rock 509082 24months AEP 06/01/14 and CSR Sheffield A pp P T 0/11 PD2 ots600 AAA 1 V605 eigo 1 V115137/137 115 1 Lexington 115kV 640256 115kV CANADAY 640103 24months NPPD 06/01/13 CT, RP, 1/11 R1 ots533 eihTp6 V535 ntdN.9Cne 9k 909 134/147 0.91 69 1 69 kV 9Conger No. United 533651 Lehigh Tap 69kV 533638 12months WR M 11/01/13 p in g the the 69 kV e 05/31/13 M 650567 84th & Leighton 12kV &Leighton 84th 650567 M 05/31/13 60/4MAC 002Hbn308 ue 4/6 392/392 345/161 2 Huben 300088 Huben 300042 AECI M 06/01/14 60/4MAC 080Dde 005Esx1111. 286/286 15.2 161 1 Essex 300075 Dudley 300820 AECI M 06/01/14 05/19/14 05/19/14 63/4MSS523097 SPS M 06/30/14 06/01/14 06/01/13 60/3MOE9mnh 135Kil 515335 9months OGE M 06/01/13 06/01/14 10/01/14 06/01/14 SPP Fitze 138k Fitze Shad SPP SPP SPP 06/01/14 06/01/14 06/01/14 06/01/14 60/3SPP 06/01/13 23/4M M 12/31/14 12/31/14 06/01/13 60/3MMKEC M 06/01/13 60/3MMKEC M 06/01/13 60/3MME 24 months MKEC M 06/01/13 60/3MMKEC M 06/01/13 60/3WFEC 06/01/13 60/3MME 24 months MKEC M 06/01/13 12/31/14 M PW Medicine Lod Medicine Lod Medicine Lod Medicine Lod Medicine 523097 523097 523097 M M PW M PW 12/31/14 M 12/31/14 OGE 12/31/14 OGE 12/31/14 M OGE M OGE SPS M 12/31/14 M 12/31/14 M 12/31/14 M 12/31/14 M 06/30/14 06/30/14 06/30/14 23/4M 12/31/14 63/4MSS523097 SPS M 06/30/14 06/01/13 12/31/13 06/01/13 23/3M M M 12/31/13 12/31/13 M 12/31/13 M 12/31/13 12/01/13 06/01/13 06/01/13 M WR 532938 Franklin 69k Franklin 532938 WR M 06/01/13 60/3M 06/01/13 60/3M M 06/01/13 06/01/13 06/01/13 02/15/13 06/01/13 06/01/13 M 12/01/13 60/3MW 398Faki 9k 377Mler 9672/72 6 69 1 Mulberry 533767 69kV Franklin 532938 WR M 06/01/13 60/4M 06/01/14 53/3M 05/31/13
/30/11 P 8mnh 284Cniga tto 1 V584 uky a 1 V11585 226/249 8.55 115 1 Tap 115kV Buckeye 528348 115kV Station Cunningham 527864 18months SPP 06/01/13 1/13 In Service 60/4AC 8mnh 023Ferctw 9k 009Ferctw 6 V1116 84/84 161/69 1 161kV Fredricktown 300079 69kV Fredricktown 301283 18months AECI 06/01/14 60/4AC 8mnh 023Ferctw 9k 009Ferctw 6 V2116 84/84 161/69 2 161kV Fredricktown 300079 69kV Fredricktown 301283 18months AECI 06/01/14 G 4mnh 136Wowr H 3 V557 odadEV35v23518448/493 345/138 2 EHV 345kv Woodward 515375 EHV 138kV Woodward 515376 24months 40months OGE OGE M M MWR M MKEC 24 months 539696 St. John 115k St. 539696 24months MKEC M E 1mnh 191Vlin 4 V587 WTxraa35k 4 76.25 345 1 Texarkana 345kV NW 508072 Valliant 345kV 510911 51months AEP M R1 ots534 GillEner 533044 18months WR M M OGE 30 months 515422 Canadian River 345k River Canadian 515422 30months OGE M M M G 4mnh 130Fr mt 6 V554 ooy11k 6 . 472/542 2.2 161 1 161kV Colony 515345 161kV Smith Fort 515300 24months OGE M G 0mnh 105Smnl 4 V552 ukge35k 4 0 1200/1200 100 345 1 345kV Muskogee 515224 Seminole 345kV 515045 40months OGE M TG 405Atl 4 V508 otRc 4 V1358 1792/1792 80 345 1 345kV Rock Post 530583 Axtell 345kV 640065 ITCGP M M M M M M P 2mnh 209Cer 1 V543 atns15k 1 . 174/192 3.5 115 1 115kV Hastings 524136 115kV Cherry 524009 12months SPP M PD4 ots606 xel35k 353Ps ok35k 4 51792/1792 45 345 1 345kV Rock Post 530583 Axtell 345kV 640065 48months NPPD M 2010 STEP DATE FC8mnh 520802 8months WFEC ITCGP ITCGP ITCGP Comanche Co 345k Co Comanche 345k Co Comanche ITCGP ITCGP ITCGP ITCGP ITCGP NPPD A A A A SPP 12 months 514782 OGE Woodward 69k OGEWoodward 514782 SPP SPP 12months SPP SPP SPP SPP 24 months 520954 Indiahoma 138k Indiahoma 520954 24months SPP P 4mnh 214Grandfield 138k 521194 Grandfield 138k 521194 24months 12months SPP SPP SPS R3 ots532851 36months WR WR WR P6 ots506935 24months 60months EP EP EP EP Estimated Cost Source 12 months 24 months 24 months 24 months 12 months 8mnh 375GillEner 533795 18 months 60 months 48 months 24 months 24 months 12 months ots531 igml 9k 272Knsil15k 1/975/86 115/69 2 115kV Kingsmill 523712 69kV Kingsmill 523711 4 months
nh 404Abo 1 V604 plig15k 1 174/174 115 1 Spalding 115kV 640347 Albion115kV 640054 onths Project Lead Time s547 laatHl 299RoeetCut necag 3 V1202 492/541 26 230 1 230kV Interchange County Roosevelt 524909 Hill Pleasant 524770 hs 521073 Twin Lakes 138k Twin Lakes 138k Twin Lakes 521073 138k Dover 521073 520879 520802 507001 507002 531469 531469 531469 531469 525835 Stateline 345kV Stateline 525835 533765 374Hdo ucin533756 Junction Hudson 533764 510399 532938 200Cer 297Hrigo et2 West Harrington 523977 Cherry 524010 424Holdrege 115k 640224 270Pesn il546 laatHl 1k 1 Hill Pleasant 115kV 524768 Hill Pleasant 524770 539674 Medicine Lodge 539673 Medicine Lodge Medicine 539673 Lodge Medicine 539674 363Mdcn og 367Pratt 539687 Lodge Medicine 539673 368Fa ig usain596 Harper 539668 Substation Ridge Flat 539638 539638 Flat Ridge Substation 539674 Medicine Lodge Medicine 539674 Substation Ridge Flat 539638 533623 Athens 69kV Athens 533623 520805 NAVAJO 269.000 521009 539656 404Abo 1 V608 eo 1 V115137/137 115 1 Genoa115 kV 640181 Albion115kV 640054 From Bus Number used in SPP MDWG bus Hitchland 345k Hitchland Litchfield 69k Litchfield 17TH Street 4138k 17TH Street Central Hie Central 138k Martinsville Lone Star 115k Lone Star 345k Creek Flint Shi Shi Fkli69kV A A A S S lfo 365Greenlea 539665 Clifton Hitchland 345k Hitchland 345k Hitchland 345k Hitchland S S Medicine Lod Medicine 345k Hitchland esn il547 ai necag 3 V1201 492/541 16 230 1 230kV Interchange Oasis 524875 Hill leasant p p p p uburn 230k 69k CME 138k CME g earville 345k earville 345k earville 345k earville 345k rySb20k 209Cer u 1 V12015218/239 230/115 1 Sub115kV Cherry 524009 Sub230kV erry p p ore 69k ig u 1 212Es ln necag 1 V11537157/173 3.7 115 1 115kV Plant Interchange East 524162 Sub115 tings e Road 161k e Road 345k e Road EPOE PIGCT A 452SB39-JPI OTWS 928 54/65 2.85 69 1 SUB 389-JOPLIN SOUTHWEST 547592 EXPLORER TAP SPRING CITY y Grove 138k e o aly18k 301Noh 3 V118191/210 138 1 138kV Neosho 533021 1Valley No. 138kV ley gy gy Center East 138k East Center 69 k East Center V g V V V kV hts 138k hts V V V g g g g g V 115 V e 345k e 345k e 345k e 345k e 345k V V V V V V V V V V V V V V V V V V V V V V V V V V V V V V V V V From Bus Name V e542 efSihCut necag 3/1 168/193 230/115 1 Interchange County Smith Deaf 524622 ge V 5330840 079J76 V16 .570/70 5.15 69 1 J&7 69kV 300779 099Es etro 6 V 6 9 161 1 Grove 115k Locust 161kV Centerton East 510423 Shi 506929 Shi 507001 507002 138k Interstate 533051 69k Macarthur 533813 533151 Hill 138k Rose 533062 138k Crescent 138k Cashion 515377 138k Twin Lakes 520847 Norman 69k W 521073 Norman 138k West 69k 521095 Woodward WFEC 521095 Grandfield 69k 521096 138k SW Cache 520926 138k Indiahoma 521193 520954 VBI 69k 515336 115k Pratt 539687 539674 Medicine Lod Medicine 539674 EHV 345k Woodward EHV 345k Woodward 515375 EHV 345k Woodward 515375 EHV 345k Woodward 515375 EHV 345k Woodward 515375 EHV 345k Woodward 515375 EHV 345k Woodward 515375 EHV 345k Woodward 515375 230k Hitchland 515375 523095 135Wowr H 4k 4 2 1475/1623 125 345 1 EHV 345kv Woodward 515375 374Sefed16 72/72 6 69 1 Sheffield 533774 533756 To Bus Number used in SPP
nbHl 1 V1152. 239/239 20.9 115 1 Hill Knob 115kV 2 MDWG bus 17TH Street 269k 17TH Street Tem 138k Fitze Hie Central Shad ld ffi Sh Aq Aq A A Medicine Lod Medicine Lod Medicine 345k Co Comanche 345k Co Comanche 345k Co Comanche 345k Co Comanche uburn 115k 69.000 LTUSSW2 ais16 80/80 69 1 uarius 69k uarius p p p e Road 345k e Road 161k e Road y1111 286/286 14 161 1 ey y son 138k son Grove 138k V f V V g hts 138k hts V g g g V V e 138k e 345k e 345k V V V V V V V V V V V V V V V V V V V V V V V V V V V V V V V V V V To Bus Name 6 65 169 3 . 215/225 215/225 215/225 3.7 215/225 10.52 120/129 8.82 9.58 1336/1915 18 138 138 2.15 138 232/232 138 1 1 115 1 1 345 345/161 1 1 1 134/147 280/308 150/165 138 144/179 1 144/179 81/106 144/179 183/228 91/114 7.5 5.56 70/70 12.6 183/228 3.8 183/228 7 69 3 230/115 138/69 1 400/440 2 345/138 3.8 13.7 1 138 138 3.5 3 138 69 1 138 69 1 1 138/69 1 138 1 138 1 1 1 72/72 1 217/261 165/198 69 1 14.4 21.9 115 115 1 1 4 55 55 27.5 27.5 27.5 27.5 28.6 28.6 345/138 345 79 345 79 345 92 1 345 92 2 345 30 1 345 30 2 345 1 345 2 345 1 345 2 345 1 345 2 345 1 345 2 345/230 1 2 1 2 1/239/39 115/12 1 3/1 200/250 138/115 1 1 6165/198 26 115 1 3 41 261/314 24.15 138 1 3 .5261/314 8.05 138 1 980/80 1 69 1 Circuit 230/115 4 1095/1095 345 6 211/211 161 230 115 1 18Mva 115 915Mvar 69 69
6 100/110 /69 Voltages (kV)
Number of Reconductor
6 Number of New
Number of Voltage Conversion 5 1330/1940 1792/1792 1792/1792 1792/1792 1792/1792 1792/1792 1792/1792 1792/1792 1792/1792 1792/1792 1792/1792 1792/1792 1792/1792 1792/1792 1792/1792 675/743 400/400 560/560 520/729 250/250 72/72 502 Summer Rating
67 Normal/Emergency 7 r NTC - Modify TimingNTC -Modify 2016 2015 T 09 50336 30298 NTC NTC NTC NTC NTC NTC NTC NTC NTC NTC T 08 02 PDrgoa eiblt 80000Adscn aall3wnigtasomra tgl 60/5NP 8mnh 526S 659206 48months NPPD 06/01/15 Stegall parallel3-winding at transformer Addsecond $8,000,000 regionalreliability NPPD 50320 30286 NTC NTC NTC 1034 11359 SPS regional reliability $2,362,500 Convert Hereford Interchange - NE-Hereford Interchange 69 kV line Z72 to 115kV se to 69kV -NE-Hereford lineZ72 Hereford Convert Interchange Interchange $2,362,500 reliability regional SPS 11359 1034 NTC T 4 11 FCrgoa eiblt 11500Rbid2ml lnhr USicyr 9k iea 3 V 60/2SP12months SPP 06/01/12 138kV. 69kV lineas -OU 2-mile Switchyard Blanchard Rebuild $1,125,000 regionalreliability WFEC 11116 846 NTC NTC NTC NTC NTC NTC T 09 50334 30296 NTC T 6 10 P einlrlaiiy$,9,0 prd ap ony156 VTasomr# o8/6MA0/11 60/2SP28mon 28mon SPP SPP 06/01/12 06/01/12 06/01/14 06/01/14 kV MVA Transformer 115/69 84/96 #2to Upgrade County Happy kV MVA Transformer 115/69 84/96 #1to Upgrade County Happy $1,890,000 $1,890,000 reliability regional reliability regional SPS SPS 11009 11007 764 764 NTC NTC T 7 07 FCrgoa eiblt 37250Rcnutr1 ie f10wt 3. CR0/11 P 4mnh 289Baly520979 Bradley 520829 24months SPP 06/01/15 ACSR 336.4 with of 11miles 1/0 Reconductor $3,712,500 regionalreliability WFEC 10879 673 NTC 2010 Requested Board Action Appendix A - Complete List ofAppendix Upgrades Network List A-Complete 00 4 11256 945 20102 00 4 16 AEP 11261 947 10600 20104 463 20108 03 2 10548 422 20036 20084 791 11042 SPS regional reliability $9,229,154 New 18 mile Kress - Newhart 115 kV line. 04/30/15 06/01/11 SPP 36 months 525192 Kress I Kress 525192 36months SPP 06/01/11 36 04/30/15 3 SPP SPP 06/01/11 04/30/15 06/01/11 04/30/15 04/30/1 -Newhart 115kV line. Interchange County New 24mile Castro New -Newhart 115kV 18mile line. Kress $3,008,180 -Newhart 230kV line. Interchange New 19mile County Swisher $9,229,154 $6,532,144 115kV line. Substation Industrial -Hart New 15mile Interchange Lampton $10,180,762 reliability regional reliability regional reliability regional reliability regional SPS SPS SPS SPS 11043 11042 11041 11045 791 791 791 791 20084 20084 20084 20084 00 9 10519 10403 399 311 20003 20003 10679 10175 10401 534 10308 10307 137 311 20086 242 241 20003 20003 20003 20003 11259 11258 11257 946 946 945 20103 20103 20102 00 1 10660 10659 10656 511 511 511 20000 20000 20000 -Plant 230kV X linefor new Station Interchange Potter Tap Newhart the Substati $9,683,496 reliability regional SPS 11040 791 20084 08 8 13 P einlrlaiiy$,0,7 ntl eod2015k rnfre nRnalsbtto.0/11 P 20months 12mo SPP SPP M M 04/01/14 04/30/14 existing 230kV 800AHarrington wave Replace 1200Aunit. with trap $27,144 substation. kV inRandall transformer 230/115 second Install $8,502,375 reliability regional reliability regional SPS SPS 11121 11033 851 783 20084 20084 20088 835 11102 SPS regional reliability $2,500,000 Move load from 69 kV bus to 115 kV bus 06/01/14 M SPS 36 months 524772 EST Clovis 69k EST Clovis 524772 36months SPS M 06/01/14 loadfrom Move 115kV bus to 69kV bus $2,500,000 reliability regional SPS 11102 835 20088 00 6 10471 361 20003 08 9 14 P einlrlaiiy$,0,3 ul e ieHr nutilSbtto ehr usain15k ie 04/3 115kV line. -Newhart Substation Substation Buildnew 4mile Industrial Hart $5,204,131 reliability regional SPS 11044 791 20084 08 4 10 P einlrlaiiy$,4,8 ul e . ieCx-Paniw15k ieui.0/11 P 6mnh 236Co 525326 36months SPS M 36m 06/01/15 SPS M M 06/01/15 06/01/15 mile Buildnew Cox 9.8 -Plainview 115kV lineunit. MVA Addnew ratings. kV Plainview 44/50.6 with transformer 115/69 County $5,949,482 $4,590,367 -Plainview 115kV. Interchange County mile Buildnew Kress 22.2 $14,126,005 reliability regional reliability regional reliability regional SPS SPS SPS 11109 11108 11107 840 839 839 20084 20084 20084 01 08 01 PDrgoa eiblt 50000Rpae17V glaatasomrwt 3MAOall rnfre 60/406 06/01/14 187MVA 336MVA with Ogallalatransformer Ogallalatransformer Replace $5,000,000 regionalreliability NPPD 50319 30285 20117 20114 1027 11351 WFEC transmission service $150,000 Replace CTs Replace $150,000 service transmission WFEC 11351 69kV East Altoona 533673 1027 18months 20114 WR M 06/01/14 11085 704 20084 KCPL KCPL East Altoona at bank Cap Add6Mvar 10945 $607,500 aminimum achieve to approximately Rebuild 1 ACSR of 9miles 954kcmil linewith 10935 $6,025,000 703 service transmission 703 service transmission 20042 20042 WR WR 50230 50236 30226 50045 30224 20059 30039 20091 20003 20085 04 0 03 SPS 10937 704 20043 08 8 17 P einlrlaiiy$09725Bidnw2 ieRnalC mrloSuh20k ie 43/4MSP3 ots5 36months SPP M 04/30/14 230kV -Amarillo Buildnew line. South Co 20mile Randall $20,907,295 reliability regional SPS SPS 10936 11177 704 888 20043 20084 NTC_ID 03 50136 30130 08 50315 30281 50313 30279 08 50314 30280 07 50312 30278 1068 0611372 1036 0011354 1030 0311384 1043 0211383 1042 0111392 1051 1041 11382 SPS zonal - sponsored $4,562,580 Reconductor Randall - Kress 115 kV with 795 ACSR 04/01/14 M SPP 525179 Tulia Tap 525192 Kress I Kress 525192 Ha 525154 52517 Tulia Tap Interchange Happy 525179 Palo Sub Duro 525154 Interch County Randall 524530 524364 SPP SPP SPP SPP M M M 04/01/14 M 04/01/14 04/01/14 04/01/14 115kV 795ACSR with -Kress Randall Reconductor 115kV 795ACSR with -Kress Randall Reconductor $4,562,580 $3,277,970 115kV 795ACSR with -Kress Randall Reconductor 115kV 795ACSR with -Kress Randall Reconductor $10,498,360 $5,094,140 zonal -sponsored zonal -sponsored zonal -sponsored zonal -sponsored SPS SPS SPS SPS 11382 11381 11380 11379 1041 1041 1041 1041 7 10616 479 11134 858 7 10361 278 11133 858 $1,900,000 -nonOATT reliability regional AECI 11296 982 3 03 M oa pnoe 70642Rda ieFo rewo oanwdsrbto u tLn ak0/11 M 24-36months GMO M 06/01/15 LoneJack at sub anew Greenwood LineFrom distribution to Radial $7,096,402 zonal -sponsored GMO 10540 10431 414 334 9 10836 694 5 11129 858 4 10576 444 11132 11131 11130 858 858 858 4 10698 549 10648 503 5 10856 651 2 50352 50348 422 422 7 10492 379 3 11100 833 4 11 FCrgoa eiblt 1,3,0 eul 52ml ndro-Bacad6 Vln s18k.0/11 60/2SP36mo SPP 06/01/12 06/01/15 138kV. 69kV lineas -Blanchard Anadarko 25.2-mile Rebuild $14,737,500 regionalreliability WFEC 11115 846 PID 11408 AECI regional reliability - non OATT $1,998,000 Rebuild line to 70/70MVA rating 70/70MVA line to Rebuild $1,998,000 -nonOATT reliability regional AECI 11408 UID WFEC WFEC WFEC WFEC WFEC WFEC WFEC WFEC SWP SWP SWP MKEC GRD MKEC KCPL KCPL GMO A A A A OGE OGE OGE OGE OGE OGE CUS D einlrlaiiy$7,0 eodco .5mlso 9k / ubtenSb#5 n u 39wt 5 CR0/11 06/01/ 06/01/15 06/0 06/01/15 556ACSR Sub#451and#359with between of miles Cu 69kV 1.55 1/0 Reconductor $476,500 556ACSR Sub#345and#451with between of miles Cu 69kV 3.58 1/0 Reconductor $1,100,500 reliability regional reliability regional EDE EDE D einlrlaiiy$,7,0 eodco .5mlso 9k / ubtenSb#7 n u 35wt 5 CR0/11 D 2 EDE 06/01/15 556ACSR Sub#170and#345with between of miles Cu 69kV 9.85 1/0 Reconductor $2,973,000 reliability regional EDE A A A A A P einlrlaiiy$500,000 reliability regional SPS P einlrlaiiy$150,000 reliability regional SPS P einlrlaiiy$150,000 reliability regional SPS P einlrlaiiy$2,126,250 reliability regional SPS P einlrlaiiy$1,890,000 reliability regional SPS SPS A A LES WR WR WR WR C re re ECI ECI re re ECI ECI EP EP EP EP EP EP EP Facility Owner A A A A re re re g g g g g g g ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit transmission service transmission transmission service transmission Balanced PortfolioBalanced PortfolioBalanced Balanced PortfolioBalanced Balanced PortfolioBalanced Balanced PortfolioBalanced zonal -sponsored zonal -sponsored zonal -sponsored zonal -sponsored re regional reliability re re re re re regional reliability regional reliability re reliability regional reg re re re re re re re regional reliability re re re re re g g g g g g g g g g g g g g g g g g g high priority high priority high priority high priority ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit i ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ona l re 2010 Project Type y y y y y y y li - non OATT $165,000 Install 15 Mvar ca 15Mvar Install ca 27Mvar Install $165,000 $297,000 -nonOATT -nonOATT -nonOATT -nonOATT ca 24Mvar Install ca 15Mvar Install $264,000 $165,000 -nonOATT -nonOATT -nonOATT a bilit y y y y y y y y y y y y y y y y y y y y 125750Buildnew 345kV linefrom Border to Tuco $122,597,500 $163,488,000 $49,824,000 $32,000,000 $65,500,000 $24,500,000 $11,000,000 $14,500,000 $16,000,000 $14,880,000 Build midpoint reactor station at interception point of Woodward to Tuco line. Tuco to of Woodward point interception at station reactor Buildmidpoint $14,880,000 1,5,0 d eod3520k uoItrhne5550MAtasomr 13/5M 11/30/15 MVA transformer. 515/560 kV Interchange Tuco 345/230 Addsecond $11,250,000 $1,650,000 $4,620,000 Install new 345/161 kV transformer at Nashua kV new at transformer 345/161 Install $4,620,000 44000Rbid43 o 9 CRwt 50AS. 60/5AP 20months AEPW 06/01/15 1590ACSR. with of 795ACSR 4.33 Rebuild $4,400,000 $3,756,500 New Cedar Niles-Clare 161 kV Line & Clare substation 06/01/15 M KCPL 24 months 543054 Cedar Niles 161k Niles Cedar 543054 24months KCPL M 06/01/15 substation 161kV New Line&Clare Niles-Clare Cedar $3,756,500 $4,500,000 Reconductor to 229/335 MVA. 229/335 to Reconductor $4,500,000 $5,625,000 13700U $1,347,000 $1,577,000 $8,000,000 miles. -10.8 336ACSR Elmore to -Paoli 3/0 Rebuild $2,065,000 -Geor 2mile Anadarko Rebuild $3,240,000 U $2,000,000 $2,000,000 54870New ringbus. Niles 161kV Niles LineandCedar -Cedar Hillsdale $5,418,700 $1,166,400 Install 28.8 MVAR ca MVAR 28.8 Install ca MVAR anew 28.8 Install $1,166,400 $1,166,400 8388161kV Ta Samson $893,868 $660,000 Reconductor the 2.2 mi 795ACSR. linewith 2.2 the Reconductor $660,000 $370,530 Reconductor 69 kV Line to 795 ACSR andre 795ACSR 69kV Lineto Reconductor $370,530 Re $750,000 $750,000 Install 30 MVAR ca 30MVAR Install $750,000 $243,000
Cost Estimate Rebuild existing line to 345kV operated as 230k as 345kV existing operated lineto Rebuild Install new 345/161 kV transformer at Cassville kV new at transformer 345/161 Install Replace both Carthage auto transformers with largerunits. with transformers auto Carthage both Replace u n emnt oanw151. Vtasomrt ev h oc itiuinla.Install be load. to Park distribution Lawrence Soncy to the kV cable 69 serve underground the to to kV off Substation 69 transformer line Sunset Z33 Leave kV from converted transformer. 115/13.2 Interchange. line of Coulter Y72out fed the by distribution kV new split kV 115 Sub a 115/13.2 the Soncy to new At tapping terminate Street. by Soncy and service & kV bus I-40 115 at to Interchange Z33 Coulter of miles 1.04 Convert Install 32 miles of 345 kV line from East Rogers to Osage Creek Osage to of 32miles 345kV Rogers linefromInstall East Rogers of 9miles 345kV East linefrom to Install ShipeRoad Creek Osage kV new at transformer 345/161 Install 1272ACSR 138kV to linefrom Georgia Pacific of miles -Keatchie the 12.63 795ACSR Rebuild Convert 8 mile OU - West Norman from 138kV. 69kV to 8mile OUConvert -West for new rati ACSR 336.4 to 69kV -Hazelton from Junction ACSR 1/0 mile Wakita 18.9 Reconductor from 5mile 138kV. 69kV -Franklin Acme Convert to Re Ta kV transformer. 138/69 with substation TaTap S 8.7-mile Convert 3-mile S Convert -S 6-mile Stillwater Convert -Cushin 14-mile Mehan Convert a h rs live iy15k iewt rs ua.CnetKesRrlsbtto o115 to substation Rural Kress Convert Rural. Kress with line kV 115 City Plainview kV. - Kress the Tap a h rs live iy15k iewt ot live usain ovr ot Planview North Convert substation. Plainview North with line kV 115 City 115kV. to Plainview substation - Kress the Tap substation to the MKEC interception from the new Medicine Lodge 345 kV substation. Upgrade the Upgrade the Lodge345kV from substation. new Medicine the interception MKEC the to substation from Wichita the 3000Acapacity least 345kV at linewith Build anew 35mile doublecircuit substation. from Wichita the interception WR the to Lodge 345kV substation from new Medicine the 3000Acapacity least 345kV at linewith Build anew 35mile doublecircuit osrc prxmtl ie f15k iefo uoItrhnet PAentySubstation. SP-Abernathy to Interchange Tuco from line kV 115 of 115kV service. to Substation SP-Abernathy Convert miles 6 approximately Construct d 6h&Ksbtto n 1/2Vtasomr hs15Vsbtto asteexisting the taps substation 115kV This transformer. 115/12kV and substation K 115kV line. &F SW27th &Holdrege to NW68th & 56th Add a aha35Vbsi aton-S.Jsp 4 Vln.Bidnw35k iefo aa o06/01/15 to Iatan from line kV 345 new Build line. kV 345 Joseph St. - Hawthorn in bus 345kV Nashua Tap kV 115 two terminals, transformer two accept to Interchange NE-Hereford at MVA kV transformer. 84/96 Add2nd115/69 115kV andonefuture lineterminal. line terminals, bus kV 115 Construct Install 6 Mvar capacitor at Esquandale 69kV. Esquandale at capacitor 6Mvar Install pg pg p p p p existin aeln rm10t 3.,48 ie 06/01/15 miles 4.85 336.4, rade linefrom to 1/0 69kV. Junction Marlow to SW from Fletcher 795ACSR to rade 7miles lace two breakers and breakers two lace 138k South Halstead 533012 24months WR M 06/01/14 MVA kV unit. 100/110 with transformer 138/69 Halstead lace existinexisting g g Oak Grove -Hw Oak CushinCushing p p p p p rin p p acitor at Shawnee Bend161k at acitor 161k Dresden at acitor Pea at Rid acitor 161k Cassville at acitor p of Lon rin g g acitor at Twin Oaks Substation 06/01/15 M CUS 24 months 549933 Twin Oaks 69k Twin Oaks 549933 24months CUS M 06/01/15 Substation Twin at Oaks acitor p Valle rso 3 k 138 Bristow - g acitor bank at Lo at bank acitor Valle Bristow g j y um iwt rnve atln 60/6MGO1-8mnh 514 Sam 541345 12-18months GMO M 06/01/16 view line Grandview to East p p - Mehan 69 kV line to 138k 69kV lineto -Mehan y ctrbn tWnsoo18k usain 06/01/16 138kV substation. Winnsboro at bank acitor y rin 99Ta -Kni p g g r tPru. 06/01/16 Perdue. at ers 138 g ia 138kV linefrom 1113ACSR. 556to Valle Project Description/Comments Project 69 kV line to 138k 69kV lineto p g p kV e 69 kV line to 138k e 69kV lineto e 161k 69 kV circuit into new Greenwood into substation 69kV circuit V y g 69 kV line to 138k 69kV lineto ieit e rewo usain ul e Greenwood new Build substation. Greenwood new into line ans V V p into V p r 3 Vsbtto. 06/01/16 138kV substation. ort lace 600A switch with 1200Aswitch. with 600Aswitch lace V new V V Greenwood V V V substation. Build on and install 230/ on andinstall 0 m 0/11 R2 ots533 re 9k 360Cfy onyN.3Wspai 9k 992 116/128 9.22 69 1 69kV 3 Westphalia No. County Coffye 533630 Green69kV 533636 24months WR M 04/01/14 200 amp new vc 60/40/11 P 8mnh 266Hrfr necag 1 V524567 115kV Hereford Interchange 524606 18months SPP 06/01/11 06/01/14 rvice Greenwood 1 12/31/14 M PW Medicine Lod Medicine PW M 12/31/14 60/50/11 EI2 ots308 asil 6 V301 asil 9k 6/956/56 161/69 1 69kV Cassville 300819 161kV Cassville 300682 24months AECI 06/01/11 06/01/15 06/01/15 06/01/16 06/01/16 06/01/16 12/01/14 06/01/15 06/01/19 WR 24 months 532861 East Manhattan 230k Manhattan East 532861 24months WR 06/01/19 12/31/14 M PW Medicine Lod Medicine Lod Medicine PW PW M M 12/31/14 12/31/14 06/01/14 05/31/15 06/01/15 06/01/15 06/01/14 12/31/14 M PW Medicine Lod Medicine PW M 12/31/14 05/19/14 05/19/14 23/5M 12/31/15 M 12/31/14 20/4M 12/02/14 60/4M 06/01/14 60/5M 06/01/15 20/4M 12/01/14 43/50/11 P 4mnh 241Nwat20k 240Nwat15k 3/1 250/250 230/115 1 06/01/16 06/01/16 Newhart 115kV 525460 Newhart 230kV 525461 24months SPP 06/01/11 04/30/15 06/01/15 06/01/15 60/4MSPP M 06/01/14
/50/11 P 5mnh 214Hr nutil15k 240Nwat15k 1 157/173 4 115 1 Newhart 115kV 525460 115kV Industrial Hart 525124 15months SPP 06/01/11 0/15 In Service 60/1SP3 ots551 atnItrhne15k 214Hr nutil15k 1 5157/173 15 115 1 115kV Industrial Hart 525124 115kV Interchange Lamton 525414 36months SPP 06/01/11 5 06/01/16 60/1SPP 06/01/11 60/6AC 4mnh 082Etrrs 9k 087Silr6 V16 33 70/70 13.32 69 1 69kV Stigler 300877 69kV Enterprise 300862 24months AECI 06/01/16 06/01/15 60/5SPP 06/01/15 06/01/15 06/01/16 06/01/15 06/01/15 06/01/15 06/01/15 06/01/15 06/01/11 0/6NP 6mnh 512Oall 1k 432Oall 3k 3/1 336/336 230/115 1 Ogallala230kV 640302 Ogallala115kV 659132 36months NPPD /01/16 MSWP M KCPL 24 months 543121 Hillsdale 161 kV 543054 Cedar Niles 161 kV 1 161 8 293/335 293/335 8 161 1 161kV Niles Cedar 543054 161kV Hillsdale 543121 24months KCPL M CL528 aa 4 V528 aha35k 1353 2546/2546 30 345 1 345kV Nashua 542980 345kV Iatan 542982 KCPL M CL528 aha35k 543028 345kV Nashua 542980 KCPL M M M M M M SPP 525225 Kress Rural 115lV Rural Kress 525225 SPP M M M 650310 SW56K 12kV SW56K 650310 M MSPS M SPS 525832 Tuco Interchange 345kV Interchange Tuco 525832 SPS M /5EE2 ots577 U 4 EULCNRHAT574 U 5 eulc16 .872/72 3.58 69 1 SUB 451-Republic 547443 SUB NORTHEAST 345-REPUBLIC 547576 24 months EDE 1/15 2010 STEP DATE 5EE2 ots574 U 5 eulc578 U 5 EULCES 915 72/72 1.55 69 1 SUB EAST 359-REPUBLIC 547580 SUB 451-Republic 547443 24months EDE 15 WFEC WFEC 16 months 520911 Fletcher 69k Fletcher 520911 16months WFEC FC1 ots520814 12months WFEC WFEC GRD A A A A OGE 515021 OakGrove 69k OakGrove 515021 OGE G 152S S 515512 138k Stillwater 515512 138k Mehan 515011 515513 OGE OGE OGE OGE OGE A A A A A P Cartha SPP SPP SPP SPP P 2mnh 288Elmore 69k 520898 12months SPP P 2mnh 299Lindsa 520979 12months SPP P 0mnh 220PaiiwC 9k 221PaniwCY15k 1/944/50.6 115/69 1 Plainview 115kV CTY 525271 Planiview 69kV Co 525270 30months SPS A A SPP SPP SPP ECI ECI ECI ECI P15months EP 24months EP EP EP EP P1 ots597 Lo 138k Winnsboro 509071 508317 18months 18months EP EP Estimated Cost Source A A 12 months 12 months 10 months 12 months 12 months 512626 Maid 69k Maid 512626 12 months 36 months 24 months 525832 Tuco Interchange 345 kV 525830 Tuco Interchange 230kV Interchange Tuco 525830 345kV Interchange Tuco 525832 24 months 18 months 60 months 60 months 60 months 24 months 12 months 12 months 12 months 12 months 0mnh 257N eeod15k 253NE Hereford 69kV 524573 NE Hereford 115kV 524567 30 months 12 months 24 months ots574 U 7 IHL T 456SB35-RPBI OTES 998 72/72 9.85 69 1 SUB NORTHEAST 345-REPUBLIC 547576 SUB ST. 170-NICHOLS 547542 4 months ots556 ehr 3 V551 wse onyItrhne20k 3 9492/541 19 230 1 230kV Interchange County Swisher 525213 Newhart 230kV 525461 6 months mnh 276Csr onyItrhne15k 240Nwat15k 1 4157/173 24 115 1 Newhart 115kV 525460 115kV Interchange County Castro 524746 months nh 212KesIt15k 221PaniwCY15k 1 22157/173 22.2 115 1 Plainview 115kV CTY 525271 115kV Int Kress 525192 onths ts501 ndro 3 V502 lnhr 3 V1182. 212/264 25.2 138 1 138kV Blanchard 520828 138kV Anadarko 520814 nths ts537 arntnMd 3 V546 adl o20k 3 798/798 230 1 230kV Co Randall 524365 230kV Mid Harrington 523978 nths Project Lead Time h 214HpyItrhne15k 213HpyItrhne6 V2156 84/96 84/96 115/69 115/69 2 1 69kV Interchange Happy 69kV Interchange Happy 525153 525153 115kV Interchange Happy 115kV Interchange Happy 525154 525154 ths ths 541316 Lone Jack 161 kV 541218 Greenwood 161 kV 1 161 4 223/245 223/245 4 161 1 Greenwood 161kV 541218 161kV LoneJack 541316 505501 521095 West Norman 138k West 521095 69k Wakita 138k SW Franklin 521085 520917 215SnyTp15k 221NwSny15k 1 .4157/173 1.04 115 1 115kV New Soncy 524201 Tap 115kV Soncy 524195 515033 300056 288Tc 1 V553 P brah 1 V1156157/173 6 115 1 115kV SP- Abernathy 525732 115kV Tuco 525828 509806 Oneta 138 kV 509786 Broken Arrow North South Tap Arrow 138kV South North Broken 509786 138kV Oneta 509806 525257 North Plainview North 115kV 525257 507001 Perdue 138k Georgia-Pacific 138k 508351 509064 056Shawnee Bend Dresden 300566 300526 Pea Rid Cassville 301144 300682 294Es 520904 288Bacad18k 214O wthad18k 3 212/264 2 138 1 138kV OU Switchyard 521104 138kV Blanchard 520828 525835 Stateline 345kV Stateline 525835 235RnalCut necag 3 V2027RnalCut necag 1 V22015 250/287 230/115 2 115kV Interchange County Randall 250/287 230kV Interchange County Randall 524365 270G30 a 3 V512 Paradise 138kV 521024 G03-05Tap 138kV 520750 90001 90002 46 adl o20k 245Aail ot 3 V1202 492/541 20 230 1 230kV Amarillo South 524415 230 kV Co Randall 24365 From Bus Number used in SPP MDWG bus Nixa 69k E Ro Shi Osa A A kV 138 Cushing C nadarko 138k nadarko sherville 161k sherville p p eal20V693 tgl 4k 4/3 400/400 345/230 2 345kV Stegall 659135 230kV tegall us g q rin rin 1 V557 live T 1 V11598157/173 9.8 115 1 Plainview 115kV CTY 525271 x 115kV p ans uandale 69k hi g e Road 345k e Road p g g g e Creek 345k e Creek son 161k son ng ers 345k ers Valle Valle y g trhne15k 240Nwat15k 1 8157/173 18 115 1 Newhart 115kV 525460 115kV nterchange p 69k g e 161k ort 138k ort 138 e V V y y V V
V V 138k 138k V kV V g g g g e 345k e 345k e 345k e 345k V V V V V V V V 285ECoi 1 V1115 1 115kV EClovis 524835 V V V V V V V V V V V V V V V V V V
ne543 aoDr u 1 156246/271 11.516 115 1 Palo Sub Duro 524530 ange From Bus Name 521104 OU SW 138k OU SW Nixa 69k DT 521104 Po 505541 505438 Hw 515019 Kni 515035 138k Mehan 515514 S 515513 Cushin 515512 515033 69k Halstead 230k JEC 533736 532852 Hazelton 69k 520938 Paola 69k 520802 Geor 521022 69k Jct Marlow 520923 520990 345k Wichita 345k Wichita 532796 345k Wichita 532796 345k Wichita 532796 532796 161Pr 512681 69k Wallville 521087 508831 Diana 138k Diana 138k REC Keatchie 508831 509050 525835 Stateline 345kV Stateline 525835 93 Osa 99832 90001 E Rogers 345k ERogers 90002 90001 #N/ To Bus Number used in SPP A MDWG bus ui a 1 .7 246/271 7.475 115 1 Tulia Tap 9 Northeast Hereford Interchange kV 115 rso 3 kV 138 Bristow B 161k Clare A Cartha Osa Nashua 161kV Nashua ida W16 153/65 11 69 1 SW Lindsay r p 138k CME y i p s rin p necag 1 37 246/271 23.73 115 1 Interchange ppy y p or Foundr lar Bluff 161k t g g 99Ta e 138k ow g g e Creek 345k e Creek 161k e Creek ia 138k Valle g g trhne1151.1 246/271 10.317 115 1 nterchange 138 e 69k 138k V V p V
69k V y V kV V V V y 138k V V V V V V V V V V South 69k South V V V V V V V V V To Bus Name V 6/9125/125 161/69 1 &2 3 .3287/316 4.33 138 1 3 . 182/228 72/72 299/335 8.3 2.2 11.84 138 69 161 1 1 1 52/66 72/72 268/286 194/222 194/222 8.69 3 5.98 14 69 293/335 138 1 138 138 1 138 1 1 4.5 1 1 892/892 161 53/65 47/61 131.7/162.54 212/264 1 91/114 4.9 27 18.9 100/110 138/69 230 10.8 2 7 69 1 138 69 1 138 69 1 1 1 1 1 40 40 35 35 345 345 345 345 2 1 2 1 91497/112 223/245 1336/1915 1336/1915 261/303 400/440 287/287 1.4 32 9 69 161 53/65 1 345 1 12.63 345 345/161 138 1 138 1 1 1 1 4.85 69 1 3 163 138 1 1/239/39 115/12 1 4/6 400/440 345/161 1 2 2 4 2 1792/1792 125 345 1 1 246/270 4 115 1 Circuit 4/3 515/560 345/230 1/984/96 115/69 138 115 115 6 15Mva 27Mva 161 161 15Mva 161 3 24Mva 138 138 28.8 Mva 28.8 Mva 28.8 138 138 345 96Mvar 69 930Mva 6Mva 69 69 Voltages (kV)
Number of Reconductor
Number of New
Number of Voltage Conversion 6 1792/1792 1792/1792 1792/1792 1792/1792 120/120 Summer Rating Normal/Emergency r r r r r r r r NTC -Modif NTC -Withdraw NTC -Withdraw Withdraw 2021 2020 2019 2018 2017 NTC NTC 11315 1001 NTC T 02136SSrgoa eiblt 2533RcnutrSne wth-OYPrin15k iewt 9. CR0/11 60/6S 06/01/16 06/01/16 -OXY SangerSwitch Permian ACSR 115kV Reconductor 397.5 linewith $295,313 reliability regional SPS 11316 1002 NTC NTC NTC NTC NTC NTC 24mo SPP 06/01/16 06/01/16 Upgrade 252MVA kV existing to transformer 230/115 Swisher NTC $5,953,500 reliability regional SPS 11318 1004 NTC NTC NTC NTC 2010 Requested Board Action y Timin Appendix A - Complete List ofAppendix Upgrades Network List A-Complete g 07 3 10685 537 20075 01 01133OEtasiso evc 1,0,0 d r 4k iefo rai oRdu 60/9OE540 rai 199Rdu 3 3 Redbud 514909 Arcadia 514908 OGE 06/01/19 Add3rd345kV Redbud linefrom to Arcadia $18,000,000 service transmission OGE 11207 11343 910 1021 20110 20110 09 3 11240 939 20098 07 4 10695 10696&10697 546 546 20073 20073 01 06 50172 30164 20017 10663 518 20002 20097 938 11239 GMO high priority $152,640,000 Build a new 345 kV substation at Maryville with a ring bus and necessary terminal equi terminal andnecessary aringbus with Maryville at Buildanew 345kV substation $152,640,000 anew from Ma to Sibley 3000Acapacity Buildanew 105mile least 345kV at linewith $231,600,000 high priority high priority GMO GMO 50168 11239 11238 30160 938 938 20017 20097 20097 20108 30290 50328 WR transmission service $700,000 Replace disconnect switches, wavetrap and CT 06/01/19 M WR 533012 Halstead South 138kV South Halstead 533012 WR M 06/01/19 wavetrap andCT switches, disconnect Replace $700,000 $700,000 service transmission service transmission WR WR 50328 50327 30290 30289 20108 20108 00 09 03 KCtasiso evc 1000RpaeCsadrly tJwl usainadSihCne usain0/11 M 06/01/18 substation Center andSmith Jewell at substation andrelays CTs Replace $150,000 service transmission MKEC 50337 30299 20107 NTC_ID 00 50346 30302 00 04 G einlrlaiiy$12000IsalnwFlsCekSbo 3 orpae6 VPie al u 60/8OE36m OGE 06/01/18 Sub 69kV Falls Prices replace Subon138to Creek new Falls Install $11,250,000 regionalreliability OGE 50349 30304 09 50332 50317 30294 30283 08 50361 30282 08 01 PDrgoa eiblt 1,0,0 d e 00ml ie15Vfo eta iyNrht ulro 60/0SP48mon SPP 06/01/20 Fullerton to North mile Addnew line115kV 10.0 City from Central $19,000,000 regional reliability NPPD 50318 30284 06 07 P einlrlaiiy$9,0 ntl . vrcpctrbn tCnda usain6 Vbs 60/8SP12month SPP 06/01/18 69kV bus. substation Canadian at bank capacitor Mvar a7.2 Install $291,600 reliability regional SPS 50275 30262 08 50321 30287 0411385 1044 0311358 1033 0911341 1019 0711339 1017 03137SSrgoa eiblt $4,473,000 reliability regional SPS 11317 11360 11423 1003 1035 1083 00134SSrgoa eiblt $542,000 reliability regional SPS 11314 1000 1009 11328 AEP regional reliability $500,000 Upgrade CT ratio at Perdue. at Upgrade ratio CT $500,000 regionalreliability AEP 11328 1009 1082 11422 AEP regional reliability $2,500,000 Replace Sugar Hill 138/69 kV SugarHill transformer 138/69 Replace Street. Trichel at jumpers Replace $2,500,000 $100,000 regional reliability regionalreliability AEP AEP 11422 11332 1082 1013 1012 11331 AEP regional reliability $24,000,000 Rebuild 21.85 mile Diana-Perdue 138 kV line. Replace switches, wave traps andjumpe wave traps switches, mile Diana-Perdue 21.85 Replace 138kV Rebuild line. $24,000,000 regionalreliability AEP 11331 1012 08132SSrgoa eiblt 1000TpteCsr ot e at15k ieit e imtsbtto 60/6SP12month SPP 06/01/16 New to new 115kV Hart Co substation Dimmit lineinto Castro Tap the $100,000 reliability regional SPS 11352 1028 1037 11373 SPS regional reliability $480,700 Build of new 8.14 miles of 69 kV to 115 kV from Bushland to Waterfield and covert Water andcovert Buildof of miles new 115kV 69kV 8.14 Waterfield from to to Bushland $480,700 reliability regional SPS 11373 1037 02137SSrgoa eiblt 7800Rcnutr15mlsfo ubc at-lnesSb6 V0/11 P 8mnh 227Lu 526297 18months 24months 24months SPP SPP SPP 06/01/19 06/01/19 06/01/19 substati CarGill to Co. from Casto of miles contuctor 115kV 24.25 477ACSS Construct MVA 84/96 kV 2to No. traansformer 116/69 Coutnty Crosby Upgrades $4,252,500 MVA 84/96 kV 1to No. traansformer 116/69 Coutnty Crosby Upgrades $1,984,500 Sub69kV -Planters East from miles 1.5 Lubbock Reconductor $1,984,500 $708,000 reliability regional reliability regional reliability regional reliability regional SPS SPS SPS SPS 11320 11356 11355 11357 1006 1031 1031 1032 Upgrad bus. andtransfer main bus to andjumpers breaker Upgrade to jumpers $475,000 -nonOATT regionalreliability SWPA 11437 1093 11391 1050 5 10583 451 $7,000,000 -nonOATT reliability regional AECI 11304 990 $1,632,000 10619 -nonOATT reliability regional 481 AECI 11297 983 10699 550 8 10 EIrgoa eiblt o AT$1,900,000 $200,000 -nonOATT $2,535,035 reliability regional -nonOATT $2,864,965 reliability regional -nonOATT reliability regional AECI -nonOATT reliability regional AECI AECI AECI 11301 11300 11299 11298 987 986 985 984 8 10 EIrgoa eiblt o AT$1,900,000 -nonOATT reliability regional AECI 11302 988 8 10 EIrgoa eiblt o AT$1,900,000 -nonOATT reliability regional AECI 11303 989 7 10891 677 0 11425 909 4 10313 245 50325 50324 50323 50322 10894 677 677 677 677 677 11205 10645 909 500 10624 10621 10620 481 481 481 11117 847 10544 418 0 11428 11427 11426 909 909 909 3 10819 631 7 10896 679 9 11 P einlrlaiiy$7,441,878 reliability regional SPS 11313 999 1 17 U oa pnoe 9600Rbid ot iha 5t ust6 V0/11 U 4mnh 497Sne 9k 498South 549908 549 69kV Sunset 549907 James 69 River 24months 549904 CUS 24months CUS M 06/01/18 M 06/01/18 69kV Sunset Highway 65to South Rebuild $956,000 Highway 6569kV South James to River Rebuild $1,750,000 zonal -sponsored zonal -sponsored CUS CUS 11077 11076 815 814 8 11174 885 3 50326 537 2 18 Rrgoa eiblt 16750Ta onadrbid1t aran-Ida il 1k k 60/6SP1 ots533 12months SPP 06/01/16 1 115kV Hills Tear Ckt -Indian &Fairlawn down andrebuild17th $1,687,500 regionalreliability WR 11083 820 901 11198 SPS regional reliability $450,000 Replace NICHOLS Line Trap with 1200 Amp B unit 230 kV M SPP 6 months 524044 Nichols Station 2 Station Nichols 524044 6months SPP M LineTrap NICHOLS 230kV 1200Amp with Bunit Replace $450,000 reliability regional SPS 11198 901 50316 537 3 50353 50350 537 537 PID
UID WFEC WFEC WFEC WFEC WFEC WFEC SWP SWP SWP SWP GRD OPPD KCPL A A A OGE OGE OGE OGE OGE OGE EDE EDE EDE EDE EDE EDE EDE A A A A A A A SPS regional reliability regional SPS SPS D re EDE P einlrlaiiy$1,680,000 reliability regional SPS SPS SPS SPS $19,500,000 regionalreliability AEP D re EDE D re re EDE EDE A LES ECI C re ECI re ECI EP EP EP EP EP EP EP EP Facility Owner A A A A A re re re re re g g gy g g g g g ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit transmission service transmission transmission service transmission transmission service transmission zonal -sponsored zonal -sponsored re re re re re re re re re regional reliability re re re re re re re re re re re regional reliability re re re re re re re g g g g g g g g g g g g g g g g g g g g g g g g g g g g g g g high priority ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit
2010 Project Type y y y y y y y -nonOATT ca 15Mvar Install $165,000 -nonOATT -nonOATT -nonOATT -nonOATT ca 15Mvar Install $165,000 -nonOATT -nonOATT y y y y y y y y y y y y y y y y y y y y y y y y y y y y y y y $12,993,350 Add 2nd transformer Carlise 230-115kV 2 CKT Carlise Add2ndtransformer $12,993,350 $15,030,000 MVA. 229/335 to Reconductor $10,095,750 $10,654,759 New 115 kV circuit from Bushland to NE Hereford construction w/795ACSR 06/01/19 SPS 30 months 524266 Bushland Interchan Bushland 524266 30months SPS Re 138kV line. -Wilkes Reserve mile Welsh 23.74 Reconductor $26,500,000 06/01/19 $16,000,000 $28,500,000 mile S Chamber 11.1 andreconductor Rebuild $12,500,000 w/795ACSR NE from New Hereford to Bushland 115kV construction circuit $10,654,759 $19,796,666 $11,000,000 22000U Re $2,250,000 Re $2,250,000 $2,250,000 18000U $1,890,000 Gatewa Rebuild $4,968,000 Jo Rebuild Jo Rebuild $1,201,500 Tear down andrebuildPillsbur $1,647,000 -Jo Tear Riverton down the $2,011,500 $3,591,000 $1,000,000 $1,200,000 $2,421,600 5161kV lineas Buildnew 6-mile Sub383-Monett $7,369,319 161kV 1590ACSR. to from ACSR 69kV 4/0 REC-Midland Midland andreconductor Rebuild $2,800,000 161kV from 1590ACSR 69kV convertin to ACSR of miles 4/0 4.0 andreconductor Rebuild $1,800,000 $6,000,000 $6,705,000 full of size 50MV to Paoli tie kV bus 138/69 Increase $1,631,250 $1,632,300 New Waldron sub cut-in sub New Waldron $1,632,300 $1,166,400 Install a new 28.8 MVAR ca MVAR anew 28.8 Install $1,166,400 $4,149,000 $2,250,000 $1,224,720 $125,000 $750,000 $750,000 $750,000 Re ratin Increase $500,000 $250,000 andre 795ACSR 69kV Lineto Reconductor $370,530 $749,250 Rebuild Jo Rebuild $749,250 $100,000 $324,000 $468,000
Cost Estimate Replace wavetrap Replace Add 2nd Enon 345/161 kV transformer Add 2ndEnon345/161 Dixon 161 Convert loadto for 161) built 161(already at Ridge Hooker-Gospel Operate 161kV line Wood Build Hooker-Fort Build Dixon-Hooker 161kV line 161kVBuild Maries-Dixon line Convert Hooker load to 161 loadto Hooker Convert Move Gospel Ridge load to 161 loadto Ridge Gospel Move Rebuild 33.4 miles 161kV miles from 33.4 161k Rebuild Ciltion-Holden Convert 3.7 mile Lindsay-Lindsay Switchyard 69 kV line to 138 kV. Lindsay substation conversion. substation Lindsay 138kV. 69kV lineto Switchyard mile Lindsay-Lindsay 3.7 Convert conversion. substation Criner 138kV. 69kV lineto mile Criner-Lindsay 10.3 Convert conversion. substation Cole 138kV. 69kV to mile Cole-Criner 10.2 Convert Reconductor the 14.37-mile 397 ACSR portion Southwest Station - Carnegie 138 kV line to 1272 ACSR. Replace Replace 1272ACSR. 138kV lineto -Carnegie Station Southwest portion 397ACSR 14.37-mile the Reconductor wav 3switches, Replace 1272ACSR. 138kV to linefrom Jct. -Hobart 397ACSR Carnegie 26.2-mile the Rebuild Build new 0.72-mile 69 kV line (one of double circuit) from new Monett S. substation to existing 69k to substation S. fromBuild new 69kV 0.72-mile new line(oneof Monett doublecircuit) line existing 69kV to trunk Build new substation 69kV 1.04-mile S. linefrom new Monett Expand Lindsay Switchyard to have andmove 138kV to buswork Expand kV OU Switchyard to transformer 138/69 Lindsay 138kV to Substation of 4miles andCole 69kV the OU between andconvert Switchyard Rebuild Gerorian115k South to from miles of miles County 6.1 4.1 Randal Reconductor ACSR 69kV -Nash 336.4 linefrom to 1/0 Upgrade 15-mile Wakita Build new 1.06-mile 69 kV line (second of double circuit for approx 0.72 mi, then single circuit for 0.3 for circuit approx single ofBuild new then mi, doublecircuit 69kV 1.06-mile 0.72 line(second 3-windin Install A A to the Missouri/Nebraska state border towards KCPL's Maryville substation. Upgrade the Nebraska Nebraska Upgrade the substation. KCPL's Maryville bordertowards state Missouri/Nebraska the to substation City from Nebraska the 3000Acapacity mileBuild anew least 345kV 11.2 at linewith Osage the at terminated T75 & V43 to only back Leave circuit Substation. Osage remove from Osage at and terminations around relays V05 Osage & Substation. reset together V67 from and circuits tie termination Remove equipment condition). V04 and ACSR. terminal 3-terminal 795 Remove Interchange. Upgrade (remove with Tap Co. V70 Manhattan Randall Substation. Interchange. Re-Conductor at line design.) Osage Georgia terminal new one-half kV Tie at and South 115 breaker termination ACSR. new to 795 line Add bus with Remove kV Co. Substation. 115 Randall Osage from Randall to) line (Re-build (not kV 115 around new V70 of into miles 2 approximately Construct from 69 kV to 161 kV. Add 4-161 kV breakers at Bonanza.from at Add4-161kV 161kV. 69kV breakers to beconverted to section OldMidland-Excelsior 161kV line. 1590ACSR Build Bonanza-Midland Upgrade CT 27th & Pine Lake Road 115/12kV #2 115/12kV &Pine Road 27th Lake Upgrade Grassland 230/ 115 kV XF #1 to 150.165 MVA 115kV XF 150.165 XF 230/ #1to Upgrade Grassland Convert Ft. Smith 161KV to 1-1/2 breaker design and install 3rd500-161KV bank. transformer andinstall design breaker 161KV Smith 1-1/2 to Ft. Convert Upgrde Line trap at both Jones Bus # 2and Lubbock South iInterchange South #2andLubbock Bus Jones both at Upgrde Linetrap Build new 8.6 miles 115 kV lineof 397.5 ACSR 115kV miles Build new ACSR lineof 8.6 397.5 dd 28.8 MVA 115kVdd 28.8 Ca Midland. at kV autotransformer dd 161/69 pg pg p p p rade terminal e rade terminal 24months SPP 06/01/17 100MVA unit. 1to ckt transformer rade Table Rock lace S lace Polace 800am lace p p p p p rin lin 391-Gatewa lin 422-Pillsbur lin 422-Jo lar Bluff lar with 2ndtransformer g g g of HSL East kV to HSL West 69 kV line to 143 MVA. Planned 143MVA. 69kV lineto b HSL kV of West to HSL East il rnfre 3wt 2 V rnfmr 60/7SP2 ots559 S 505492 24months SPP 06/01/17 field 125MVA #3with transformer transfomer. y transformer connectin transformer p -Jo CT andwave CT tra p p q Sullivan 161k at acitor 161k Kosh at acitor ui p p lin 389 69 kV as 161k lin 38969kV as p ment at both ends of line: breakers, wave tra breakers, of line: ends both at ment lin 59 69 kV as 161k lin 5969kV as p ctrbn o rsln 1 Vbs0/11 SPP 06/01/19 115kV bus onGrassland bank acitor p y p y 69 kV as 161k 69kV as Jo outside 161kV to from rebuildas lin 5969kV line, Stateline ctrbn tExnMbl18k usain 06/01/18 Exxon-Mobil at bank acitor 138kV substation. 69kV as 161k 69kV as y - Reinmiller 69 kV as 161k -Reinmiller69kV as Project Description/Comments Project p at Classen substation. Classen at g V Monett 376 161 kV bus to Monett 470 69 kV bus as as 47069kV bus Monett to 376161kV bus Monett V V V g p V V rtasomr 07 V nt 60/7SPP 06/01/17 MVA unit. 70/70 er transformer, lace 600A switch with 1200Aswitch. with 600Aswitch lace p rin g s-Farmin p A V art of lineu multi art V g o E 6 Vln ih25 CR 06/01/20 161kV 2156ACSR. linewith REC ton p lace switch, wave tra p s andswitches s pg ae06/01/17 rade y eeigCs 0/11 P 2mnh 048Jnsoo11k 310JnsooES11k 6 432/432 161 1 EES161kV Jonesboro 338170 161kV Jonesboro 505418 12months SPP 06/01/17 CTs. e metering OEi 08 06/01/16 OGEin2008. V mn.Bid 60/7MGO7 ots655 ersaCt 4 V519 ayil 4 V1356 2496/2496 65 345 1 345kV Maryville 541197 345kV City Nebraska 645458 72months GMO M 06/01/17 Build pment. yil 0/11 M 2mnh 421Sbe 4 V519 ayil 4 V135152496/2496 105 345 1 345kV Maryville 541197 345kV Sibley 541201 72months GMO M 06/01/17 ryville p rs, and upgrade CT ratios ratios andupgradeCT rs, n0/11 P 6mnh 276Csr o15k 268Cril15k 1 42 164/180 24.25 115 1 115kV Cargill 524648 115kV Co Castro 524746 36months SPP 06/01/19 on , and , idsbtto o15k 60/8SP1 ots544 aefed15k 226Bsln 1 V1158.14 115 1 115kV Bushland 524266 115kV Waterfield 524242 18months SPP 06/01/18 115kV to fild substation g p p North i 9 60/80/11 SPP 06/01/18 06/01/18 lin 59 r f 06/01/17 of art V 4 60/9MW 381Es ahta 385N ahta 3 359/359 230 1 Manhattan NW 532865 Manhattan East 532861 WR M 06/01/19 60/9OGE 06/01/19 60/80/11 EI3 ots309 nn343 nn23511560/560 345/161 2 286/286 286/286 286/286 286/286 6.07 6.86 3.89 5.44 Enon 344535 161 161 161 161 1 1 1 1 Enon 300597 30months AECI Ridge Gospel Wood Ft 06/01/17 Hooker 300883 300080 06/01/18 Dixon 300918 300919 Dixon Hooker 300919 Hooker 300918 Dixon 300918 Maries 300919 300096 AECI AECI AECI AECI M AECI M M 06/01/17 M 06/01/17 M 06/01/17 06/01/17 06/01/17 60/7MAC 098Hooker 300918 AECI M 06/01/17 06/01/17 M AECI 300883 Gospel Ridge Gospel 300883 AECI M 06/01/17 60/70/11 SPP 06/01/17 06/01/17 60/80/11 SPP SPP SPP 06/01/18 SPP 06/01/18 SPP 06/01/18 06/01/18 06/01/18 06/01/18 06/01/18 06/01/18 06/01/18 06/01/18 SPP SPP 06/01/17 06/01/17 06/01/17 06/01/17 60/7MOP 448Nbak iy35k ayil 4 V13511.2 345 1 345kV Maryville 345kV City Nebraska 645458 OPPD M 06/01/17 06/01/16 M KCPL 18 months 543030 Waldron 161k Waldron 543030 18months KCPL M 06/01/16 60/7MOE9months OGE M 06/01/17 05/31/16 60/7MOE32months OGE M 06/01/17 06/01/18 06/01/17 60/606/01/16 06/01/16
In Service a e 60/7WFEC WFEC WFEC 06/01/17 06/01/17 06/01/17 06/01/21 60/7WFEC 06/01/17 WFEC 06/01/17 60/6SPP 06/01/16 06/01/21 06/01/21 SPP 06/01/17 60/9AP1 ots585 ede18k 039Exnoi 3 V118246/287 138 1 ExxonMobil 138kV 508369 Perdue 138kV 508351 12months AEP 06/01/19 06/01/11 06/01/19 06/01/19 06/01/16 06/01/16 06/01/17 06/01/21 06/01/21 06/01/19 60/7SP4 ots571 oet36571 oet401116 100/100 161/69 1 470 Monett 547511 376 Monett 547510 48months SPP 06/01/17 06/01/20 60/0AP3 ots588 ua il18k 009SgrHl 9k 3/9200/220 455/478 261/303 21.85 138 138/69 1 138 1 1 SugarHill 69kV 138kV Diana 508079 138kV Street Trichel 508831 507763 SugarHill 138kV Humbug 138kV Fort 508080 Perdue 138kV 507731 508351 30months 12months 30months AEP AEP AEP 06/01/20 06/01/20 06/01/20 60/9AEP 06/01/19 60/1SP2 ots567 rsln 3 V567 rsln 1 V12015150/165 230/115 1 115kV Grassland 526676 230kV Grassland 526677 24months SPP 06/01/21 60/1SP6mnh 238JnsBs# 229LbokSItrhne220478/502 230 2 SInterchange Lubbock 526269 #2 Bus Jones 526338 6 months SPP 06/01/21 60/1SP2 ots540 hry15k 216Nrhet15k 1 . 157/173 8.6 115 2 115kV Northwest 524106 115kV Cherry 524009 24months SPP 06/01/21 M M M 650429 27th & Pine Lake Road 12kV &Pine Road 27th Lake 650429 M 2010 STEP DATE GRD A A A OGE 12 months 514927 HSLEast 69k HSLEast 514927 12months OGE EDE 48 months 547480 SUB 383 - Monett 161k SUB 383-Monett 547480 48months EDE A A A A A A A SPP SPP SPP 16 months 514922 Classen 138k Classen 514922 16months SPP SPP A P 0mnh 211Crie20k 210Crie15k 2 115kV Carlise 526160 230 kV Carlise 526161 30months SPP SPP E 369JWL 150 363SIHC 150 1 79.7/87.6 115 1 115.00 SMITH-C3 539693 3115.00 JEWELL 539669 KEC ECI ECI ECI P30months EP EP EP 506944 24months EP EP EP EP P1 ots586 ExxonMobil 138k 508369 18months EP P1 ots587 X ema u 1 243Sne wthn tto 1 V11505 157/173 0.55 115 1 115kV Station SangerSwitching 528463 OXY Permian Sub115 528575 18months PP Estimated Cost Source A 12 months 36 months 36 months 36 months 12 months 512626 Maid 69k Maid 512626 12 months 24 months 36 months 12 months 24 months 48 months 547511 Monett 4702 69k Monett 547511 48 months 18 months 12 months 12 months 12 months 12 months 12 months 12 months 24 months 48 months 48 months 48 months 48 months 48 months 48 months Purd 416J2 69k Monett 547404 547402 48 months 48 months 18 months 524364 Randall County Interchange 115k Interchange County Randall 524364 18 months 36 months 36 months 36 months 300071 Clinton 161k Clinton 300071 36 months 12 months 12 months 6 months nh 115Pie al 9V551 al re 3k 3/996/96 138/69 1 138kV Creek Falls 515814 269kV Falls Prices 515195 onths
ts551 wse 3 V551 wse 1 V12015252/252 230/115 1 115kV Swisher 525212 230kV Swisher 525213 nths Project Lead Time h 416Fletn15V603 eta iyNrh15V1151 174/174 10 115 1 115kV North City Central 640434 115kV Fullerton 640176 ths s 523579 Canadian 69kV Canadian 523579 s s 524750 Dimmit Sub115kV Dimmit 524750 s 189Br 514839 300056 521008 Nash 69k Nash 521008 297Lindsa Crine 520977 520868 046Po 505436 525192 Kress Interchan Kress 525192 547498 SUB 439 - Stateline 161k SUB 439-Stateline 547498 451Gatewa Jo 547551 Jo 547593 Jo 547607 Pillsbur 547607 547685 110Paoli 4138k 515100 507202 Midland 161k Midland 161k REC Midland 507202 Huntin North 507196 507189 121BnnaTp11k 570 iln 6 V111489429/597 8.9 4 161 1 161kV Midland 507202 Bonanza Tap 161kV 515261 136VBI 161 k 515336 515305 Fort Smith 500k Smith Fort 515305 281Cole 520861 521104 505472 Table Rock 161k Table Rock 505472 526676 Grassland 115k Grassland 526676 508355 Welsh Reserve 138k Reserve Welsh 138k South Carnegie 508355 138k Junction Hobart 511445 511463 019Sullivan 301119 Kosh 301107 234RnalC 1 V542 ot eri 1 Georgia South 524322 115kV Co Randall 524364 296Cab onyItrhne15k 295Cob onyItrhne6 V3156 84/96 84/96 115/69 115/69 3 1 69kV Interchange County Crosby 69kV Interchange County Crosby 525925 525925 115kV Interchange County Crasby 115 kV Interchange County Crasby 525926 525926 From Bus Number used in SPP 7 7h&Filw 1 V536 ninHls15k 1 240/240 3 115 1 115kV Hills Indian 533166 115kV &Fairlawn 17th 175 MDWG bus Lindsa UniversitOklahoma Chamber S Chamber A sherville 161k sherville p y p p p bc atItrhne6 V568 lnesSb6 V16 . 88/97 1.5 69 1 Sub69kV Planters 526284 69kV Interchange East bbock p rin ant 138k ant lin 391161k lin 422161k lin 422161k lar Bluff 69k y g r South 390269k South il 6 044S 505494 field 161 y y y y Switch 161k 161k V V V p V g rin V V ton 161k ton V V V V V V y g V V V V g ard 138k s V V V 0k 245Aail ot necag 3 V120436/502 230 1 230kV Interchange Amarillo South 524415 30 kV e 115k V V V V g y V e 115k 138k SW V V V V V V From Bus Name V V V V V V 288Crine 520868 090Farmin 506970 524567 Northeast Hereford Interchan Northeast 524567 514835 Jo Gatewa 547483 Pillsbur 547551 Jo 547685 161k Reinmiller 547900 Jo 547500 547900 Lindsa 520979 Lindsa 520977 Po 505438 VBI 161k North 161k Smith Fort 504032 515300 161k Monett South 547510 69k Midland 161k Midland 507187 161k REC Midland 507202 507196 69k Wakita 161k Idalia 521085 505434 PALIOGE 269k 5Ta SW 515099 69k HSLWest 514921 514937 69k Redden 512696 525212 Swisher Count Swisher 525212 305Sdwc oN.1 owc 3 V118160/160 138 1 138kV 12Colwich No. Co Sedgwick 533065 281Cole 69k Table Rock 520861 505474 115k GeorgiaInterchange South 524322 470269k Monett 470269k Monett 547511 PT2 269k SW Monett 547511 547514 508840 Wilkes 138k Wilkes 138k Station Southwestern 508840 138k South Carnegie 511477 Holden 161k 511445 300124 To Bus Number used in SPP 0 ot iha 56 V16 . 153/159 3.8 69 1 Highway 6569kV South 908 MDWG bus Memorial 138k Memorial Lindsa p p p p p rin lin 389161k lin 595161k lin 59161k lar Bluff 161k g r Hgwy6 9k 919153/159 1.9 69 1 Highway 6569kV il 93116 125/125 161/69 3 field 69 y y y g y y Switch Switch o E 6 11520/729 11.1 161 1 REC ton 161k 161k p V V V V V V V V V V y y y V V V Interchan V V V ard 69k ard 138k V V V V V V V V V V To Bus Name V V g e 115k V g e 115k V V V 161 1 161 1 3 72/89 4 138 1 1 115 35 246/270 246/270 478/478 35 218/268 115 218/268 218/268 218/268 7.36 218/268 1 1.11 218/268 1.78 2.44 138 2.98 5.32 1 161 161 100/100 161 161 70/70 1 161 1 161 1 1 1 1 218/268 4.1 161/69 161/69 90/102 1 115 429/597 429/597 2 6 1.25 1 4 1 5 161 53/65 1 299/335 161/69 161 161 1 1 1 14.9 62/67 21.98 268/287 134/143 69 161 293/335 97/112 1 1 138/69 138 1.3 69 1 161 1 69 1 1 1 1 251/251 430/473 220/235 287/287 286/286 23.74 14.37 26.15 115 33.4 138 138 138 1 161 1 1 1 1 161 1 1/239/39 115/12 1 3/970/70 72/89 72/89 72/89 3.7 10.3 10.2 27/32 138/69 138 75/92 138 75/92 138 1 1 1 1 1.06 0.72 1.04 69 69 69 1 1 1 Circuit 500/161 230/115 161 6 15Mva 161 15Mva 161 1 2 115 115 115 Mva 28.8 138 69 7.2 Mvar 7.2 69 551248/1426 5 45 Voltages (kV)
Number of Reconductor
Number of New
Number of Voltage Conversion 7 2496/2496 28.8 Mva 28.8 168/168 160/160 72/72 Summer Rating Normal/Emergency r r r r NTC -Withdraw NTC -Withdraw NTC -Withdraw NTC -Withdraw T ihrw204326529SS$8,0 ntl w ak f72Ma aaiosa rs 9k 23/1RSP1 ots552 Kress 525224 12months SPP 52489 R 24months 12/31/11 SPS D 12/31/14 of 25 banks two Plant as configured 115kV bus East at bank capacitor 50Mvar Install 69kV Kress at capacitors Mvar of 7.2 banks two Install $2,025,000 $583,200 1 kV transformer 345/230 with substation -Draw Buildnew Frio $19,349,122 Roosevelt at Buildnew 130-mile 345kV line from substation -Draw new Frio to Potter $82,607,351 SPS SPS 50217 50259 SPS SPS 30213 30246 11051 20084 11050 20084 795 NTC -Withdraw 795 NTC -Withdraw NTC -Withdraw 20084 20084 NTC -Withdraw NTC -Withdraw NTC -Withdraw T ihrw20473107SS$,2,0 eodco .-ieGie onyItrhne-Lgc 1 Vln 63/1RSP18month SPP R 06/30/11 115kV line -Legacy Interchange County Gaines 5.5-mile Reconductor $2,320,300 SPS 11047 793 20084 NTC -Withdraw NTC -Withdraw NTC -Withdraw NTC - Withdraw 20084 776 11026 SPS $2,253,579 Build new 1-mile Deaf Smith to Panda 115 kV line 06/01/12 R SPS 6 months 524622 Deaf Smith Co Smith Deaf 524622 6months Midla SPS 527916 a CTs mile 115kV -Huntsville HEC 28.8 of lineandreset the portion Westar the Rebuild 5 $5,700,000 24months R 24months SPP 06/01/12 SPS 1 D D 24 SPP 12/31/13 06/01/12 SPP D WR D 12/31/13 12/31/13 10857 Buildnew Panda 1-mile to Smith Deaf 115kV line MID Plant -Pierce 795ACSR 115kV East 1.06-mile lineto Reconductor $2,253,579 652 moving by oldfrom when reti Midland BordenCounty kV at transformer 230/138 Addsecond $1,451,925 Midland MVA New at 400/440 kV rated transformer 345/138 $2,530,676 345kV at operate 230kV existing lineto -Midland Hobbs 89.22-mile Convert D $6,794,849 $655,534 Interchange Hobbs MVA at 515/560 kV new rated transformer 345/230 Install 20086 $8,324,480 NTC -Withdraw NTC -Withdraw NTC -Withdraw NTC -Withdraw NTC -Withdraw linej andreplace settings tap CT Change 2-mile -Sub928line. Sub906North Rebuild $4,638,000 wavetrap andrelays CT, 115kV -Huntsville HEC 21.1-mile lineandreplace Rebuild SPS $6,250,000 SPS SPS SPS SPS 11026 SPS 11196 11056 11091 11089 776 11090 857 797 824 824 20084 824 20084 OPPD 20084 20084 NTC -Withdraw MIDW 20084 NTC -Withdraw 20084 NTC -Withdraw 11139 NTC -Withdraw NTC -Withdraw 10914 NTC -Withdraw NTC -Withdraw 862 697 20082 20094 NTC -Withdraw NTC -Withdraw NTC -Withdraw NTC -Withdraw NTC -Withdraw NTC -Withdraw NTC -Withdraw NTC -Withdraw NTC -Withdraw T ihrw20477107SS$,3,1 eodco .4ml atPat-Mnatn15k ie0/01 P 2mnh 212East 524162 12months SPS R 04/30/14 04 115kV line Plant -Manhattan East 2.24-mile Reconductor 115kV 795ACSR linewith Interchange County -Randall Manhattan 1.6-mile Reconductor $6,434,410 $6,534,410 SPS SPS 11027 NTC -Withdraw 11097 777 830 20084 20084 NTC -Withdraw NTC -Withdraw NTC -Withdraw NTC - Withdraw 20084 773 11018 SPS $5,670,000 Add second 230/115 kV transformer at Roosevelt 06/01/13 D SPP 24 months 524908 Roosevelt Coun Roosevelt 524908 Canyon 24months 524516 SPP 36months SPP D 06/01/13 D 06/01/13 Roosevelt kV at transformer 230/115 Addsecond 115kV - Spring Draw line West Buildnew 9-mile Canyon $5,670,000 $4,975,165 SPS SPS 11018 11176 773 887 20084 20084 NTC -Withdraw NTC -Withdraw NTC -Withdraw NTC -Withdraw
2010 Requested Board Action Appendix A - Complete List ofAppendix Upgrades Network List A-Complete 00 1 10543 417 10506 20009 388 20000 00 6 10482 369 20006 00 4 10186 11032 146 782 20004 20084 03 5 10195 151 20031 00 7 10483 10636 10427 370 491 330 20006 20086 20006 10325 156 20004 11022 10633 774 10258 489 10571 20084 10686 10259 202 20094 440 537 203 20036 20075 20075 20075 00 3 10426 330 20006 08 2 11084 821 20084 03 5 10197 153 20031 00 00 50111 30105 20006 08 9 11049 794 20084 00 09 50102 30096 20006 50194 30187 20087 08 8 11172 883 20084 NTC_ID
PID
UID MIDW $5,250,000 Rebuild 26.55-mile Huntsville - St. John 115kV lineandre -St. Huntsville 26.55-mile Rebuild $5,250,000 MIDW CL$300U $13,000 KCPL GMO D 22400Rcnutr75-ieDaodJt acxeSuhet6 Vln rm10C o36AS 06/01/17 for 65MVA Rate 336ACSR with 1-mile ACSR of 4/0 Reconductor $400,000 336ACSR 69kV -Sarcoxie to linefrom Cu Southwest Jct. Diamond 7.55-mile 1/0 Reconductor 3-windin Install $2,274,000 -Cartha Jct. Atlas 3.5-mile Reconductor $8,000,000 $1,277,935 EDE EDE EDE EDE A P $2,907,749 SPS SPS P $1,260,000 SPS P 1,2,4 Buildnew Prin $11,922,643 $2,200,000 SPS SPS SPS P $24,147,866 $2,110,980 SPS SPS P $600,000 SPS WR WR $2,300,000 Rebuild SW Lawrence - Wakarusa 115 kV line 06/01/11 R WR 18 months 533271 SW Lawrence 115k Lawrence SW 533271 18months WR R 06/01/11 115kV line -Wakarusa Lawrence SW Rebuild $2,300,000 WR R$889,000 WR WR WR WR WR P$0,0 Re $100,000 EP Facility Owner
2010 Project Type $8,920,699 $8,920,699 $1,000,000 Install 30 Mvar ca 30Mvar Install $1,000,000 $3,070,000 $2,784,000 $5,850,000 $900,000 Add a second Grave 115/69 kV Grave transformer 115/69 Addasecond $900,000 $580,000 $810,000
Cost Estimate A A A Install 20 Mvar capacitor bank at Eudora115k at bank capacitor 20Mvar Install Add 230kV linefrom Seminole to Hobbs 11315. UID 1001, PID by Replaced 115kV 795ACSR. with GeorgiaInterchange -South Station Switching 4-mile Osage Rebuild Build new 5-mile Hastings - Bush 115kV line -Bush Build new 5-mile Hastings Rebuild 1.53-mile Co-op - Wakarusa 115kV line -Wakarusa Co-op 1.53-mile Rebuild Co-O Consumer -Farmer's mile Bismarck 2.9 Rebuild Scott New Ft kV at transformer 161/69 Ta eodco -ieOaeSicigSain-RnalCut necag 1 Vln ih795 2 with 230kV Ckt Build new -Grassland Jones line kV 115 Interchange County Randall - Station Switching ACSR Osage 2-mile Reconductor dd third Potash Junction Interchange 115/69 kV transforme 115/69 Interchange Junction Potash dd third MVA ratin 84/84 with kV autotransformer 115/69 Tuco dd third Adrian161k at bank capacitor dd 20Mvar pg p p Litchfield - Marmaton 161 kV with new SWBourb5 bus and 22 miles of 161 kV line to Ft Scott of and22miles Ft 161kV bus lineto 161kV new with -Marmaton SWBourb5 Litchfield rade wavetra lace two sets of switches at New Boston on terminal to North New North to onterminal New Boston at Boston of switches sets two lace g g e-Hthad20k ie0/11 P 48months SPS D 03/01/12 230kV line le -Hitchland transformer connectin transformer p p at Gladstone from 1200 800Ato Gladstone at acitor bank at S at bank acitor Project Description/Comments Project p rin g g new 161 kV bus to Monett Cit Monett new to 161kV bus hill 115k g otws 9k iefo / CRt 3 CR06/01/17 336ACSR to 69kV linefrome Northwest ACSR 4/0 V V V A p 115k p lace CT, wavetra r V g y Suh6 V 06/01/15 69kV. South p , breakers, andrela breakers, , Mvar 12/31/11 D SPP 12 months 524162 East Plant 115kV East 524162 12months SPP D 12/31/11 Mvar mesfr 60/3DOP 4mnh 406SB96Nrh6 V672 U 2 9k 92110/110 2 69 1 SUB 92869kV 647928 SUB 69kV 906North 647006 24months OPPD D 06/01/13 forumpers E 60/5DW 6mnh 349Hthno nryCne 1 V501 utvle15k 1 . 164/194 7.7 115 1 115kV Huntsville 530618 115KV Center Energy Hutchinson 533419 36months WR D 06/01/15 HEC t e 23/3DSP3mnh 286CpokRC-Vamo 3 V563 odnCut necag 3 V22018168/168 230/138 2 230kV Interchange BordenCounty 526830 -Vealmoor REC 138kV Caprock 522896 3months SPP D 12/31/13 red y s D MIDW 30 months 530618 Huntsville 115k Huntsville 530618 30months MIDW D s 60/2DKP ots543015 6months KCPL D 06/01/12 06/01/15 06/01/13 60/1RWR R 06/01/11 06/01/13 06/01/11 12/01/11 43/4R 04/30/14 33/3R 03/31/13 06/01/13 60/4D 06/01/14 R 04/30/14 /11 P 8mnh 286Pesn il35k 291Pte onyItrhne35k 4 3 1643/1793 130 345 1 345kV Interchange County Potter 523961 Hill Pleasant 345kV 524896 48months SPS D 2/31/14 3/4RSP1 ots545 ahte a 1 V546 adl onyItrhne15k 1 . 246/271 1.6 115 1 115kV Interchange County Randall 524364 Tap 115kV Manhatten 524354 12months SPP R /30/14 In Service R1 ots532929 18months WR R R RWR R WR 18 months 532930 Fort Scott 161k Scott Fort 532930 18months WR R D D R D R DWRDWR D SPS 48 months 527894 Hobbs 230kV Hobbs 527894 48months SPS D D D D 2010 STEP DATE EDE 18 months 547533 SUB 109 - Atlas Junction 69k Junction SUB 109-Atlas 547533 18months EDE EDE 36 months 547510 South Monett 161k Monett South 547510 36months EDE EDE 12 months 547527 SUB 436 - Webb Cit SUB 436-Webb 547527 12months EDE A SPP 24 months 527961 Potash Junc 69k Junc Potash 527961 24months SPP SPP SPS P 36months SPS P 18months SPP P 2mnh 541240 12months SPP SPP SPP P 12months SPP P15months EP
0mnh 349Hthno nryCne 1 V501 utvle15k 1 11164/194 21.1 115 1 115kV Huntsville 530618 115KV Center Energy Hutchinson 533419 30 months W Estimated Cost Source 24 months 18 months 24 months 525826 Tuco 69k Tuco 525826 24 months 18 months 18 months 18 months 18 months 18 months ots579 ob 4 V571 iln 4 V1358.21475/1623 89.22 345 1 345kV Midland 527916 345kV Hobbs 527896 2 months mnh 284HbsItrhne20k 579 ob necag 4 V13520515/560 345/230 1 345kV Interchange Hobbs 527896 230kV Interchange Hobbs 527894 months Project Lead Time 232Gie onyItrhne15k 236Lgc 1 V11555120/154 5.5 115 1 115 kV Legacy 527346 115kV Interchange County Gaines 527322 s 533234 Bismark 115k Bismark 533234 533236 523267 Pringle Interchange 230k Pringle Interchange 523267 327S Eudora115k 533267 533240 508068 North New Boston 69K New North Boston 508068 232SuhGogaItrhne15k 235OaeSicigSain15k 1 115kV Station Switching Osage 524345 115kV GeorgiaInterchange South 524322 277GAE315k 276Gae26k 2 1 Grave 269kv 523796 Sub115kV Bush 524124 GRAVE 3115kv 523797 Sub115 Hastings 524136 526337 Jones 230kV Jones 526337 524345 547538 46 atPat15k 215Pec 1 V11510 246/271 1.06 115 1 Pierce 115kV 524185 Plant 115kV East 24162 From Bus Number used in SPP MDWG bus Pesn il35V549 laatHl 3k 4/3 560/560 345/230 1 Hill Pleasant 230kV 524897 Hill Pleasant 345kV 6 Southwest Bourbon161k Southwest A A Farmer's Consumer CO-OP 115k Consumer Farmer's Osage Switching Station 115kV Station Switching Osage SUB 131 - Diamond Junction 69k SUB Junction 131-Diamond vondale 161k drian 161k p rin PatItrhne15k 224MnatnSb15k 1 .4226/249 2.24 115 1 Sub115kV Manhattan 524224 115kV Plant Interchange g d 4 V529 iln 3 V13518400/440 345/138 1 138kV Midland 522992 nd 345kV Rural 69kV Rural hill 115k Ws 1 V544 pigDa 1 V1159157/173 9 115 1 115kV SpringDraw 524544 115kV West V V V V nyItrhne15k 257PnaEeg usain eeod15k 1 120/154 1 115 1 Hereford 115kV Panda Substation, Energy 524597 115kV Interchange unty V V V yItrhne15k 299RoeetCut necag 3 V22015252/289.8 230/115 2 230kV Interchange County Roosevelt 524909 115kV Interchange ty V V V V y Cardinal 69k Cardinal From Bus Name V V V V V V V 527276 365Fr ct 6/9100/110 161/69 1 115k Wakarusa Co-o Consumer Farmer's 533277 115k Wakarusa 533236 Scott Fort 533277 161k Scott Fort 533635 532930 115k Junc Potash 527962 John 115k St. 530624 161k Gladstone 543016 SUB 110-Orono 547534 SUB 108-Cartha 547532 523095 Hitchland 230k Hitchland 523095 115k Tuco 525828 69k South City SUB 376-Monett 547582 547401 69k New Boston 508067 267Gasad20k 2 230kV Grassland 526677 115kV Interchange County Randall 524364 To Bus Number used in SPP MDWG bus eioe20k 1204 492/541 45 230 1 Seminole 230kV SUB 69k 362-Sarcoxie Southwest V V V V V V V V g g o Junction 69k o Junction V e Northwest 69k e Northwest To Bus Name p 115k V V V V V 1 .3223/240 181/181 223/240 312/342 22 1.53 2.9 4.09 115 115 115 1 161 1 1 1 40/40 164/199 293/335 54/65 54/65 71/96 54/65 115/69 1 26.55 1 115 7.55 161 3.5 69 1 69 1 100/100 161/69 69 69 1 1 1 1 1 1 1 1 Circuit 115/69 115/69 1 4 115 3 26.72 230 1 5 115 1 139/160 2 115 1 50Mvar 115 115 115 20Mva 161 230 69 14.4 Mvar 14.4 69 Voltages (kV)
Number of Reconductor 34 Number of New
Number of Voltage Conversion 8 227/249 492/541 157/173 492/541 30 Mva 20 Mva 40/40 84/84 Summer Rating Normal/Emergency r r r NTC - Modif - NTC NTC - Modify - Timing NTC NTC - Modif - NTC NTC - Modif - NTC 2020 2019 2018 2017 2016 2015 2014 2013 2012 2011 NTC 1034 11359 SPS regional reliab regional SPS 11359 1034 NTC NTC NTC 30286 50320 NPPD regional reliab regional NPPD 50320 30286 NTC NTC NTC NTC NTC NTC NTC 1002 11316 SPS regional reliab regional SPS 11316 1002 NTC NTC reliab regional AEP 11171 NTC 882 NTC NTC NTC 1004 11318 SPS regional reliab regional NTC SPS 11318 NTC 50336 1004 30298 NTC NTC NTC NTC reliab regional EDE 10608 472 NTC NTC NTC NTC 156 11389 SPS regional reliab regional SPS 11389 156 NTC NTC NTC 673 10879 WFEC regional reliab regional reliab regional WFEC WFEC 10879 11116 673 846 NTC NTC reliab regional WR reliab regional WR 11346 11344 1022 1022 NTC NTC NTC 30305 50347 OGE regional reliab regional reliab regional OGE OGE 50347 50345 30305 30303 NTC NTC NTC NTC 764 11009 SPS regional reliab regional SPS 11009 764 NTC NTC 1073 11444 WR regional reliab regional reliab regional reliab regional WR WR SPS 11444 11413 11046 1073 1073 792 NTC NTC NTC NTC NTC NTC T 09 50334 30296 NTC NTC NTC NTC NTC NTC NTC reliab regional SPS 11353 1029 reliab regional WFEC 11429 NTC NTC OGE 1085 NTC NTC 11439 1095 NTC NTC NTC NTC NTC NTC NTC NTC NTC NTC 764 11007 SPS regional reliab regional SPS 11007 764 NTC NTC NTC 2010 Requested Board Action y y y Timin Soe20831850156 30148 20048 Scope Sco Appendix Reliab B - p e g 03 2 10548 422 20036 00 9 10509 391 20000 07 3 10685 537 20075 20085 NTC_ID ility Network Upgr 0011354 1030 0411424 1084 0811388 1048 0611372 1036 11421 1081 0111315 1001 0211345 1022 0311412 11411 1073 1073 0211383 1042 11319 1005 0311384 1043 5 11129 858 4 11117 847 5 11134 858 11263 949 7 10891 677 10616 479 9 11311 997 5 11133 11132 11131 858 11130 858 858 858 10865 659 7 50325 50324 50323 50322 677 10894 677 677 677 677 3 11100 833 2 50352 422 2 50348 422 3 50326 537 846 11115 WFEC regional reliab regional WFEC 11115 846 7 11378 774 3 50316 537 3 50353 50350 537 537 PID ades Recommended for NTC for Recommended ades UID WFEC WFEC WFEC MIDW GMO OGE OGE OGE regional reliab regional OGE OGE OGE OGE EDE regional reliab regional reliab regional EDE EDE EDE regional reliab regional EDE EDE EDE EDE EDE EDE EDE EDE SPS regional reliab regional SPS SPS regional reliab regional SPS D re EDE reliab regional SPS A A A A SPS regional reliab regional SPS SPS regional reliab regional SPS SPS regional reliab regional SPS reliab regional SPS D re EDE reliab regional SPS D re re EDE EDE A A SPS regional reliab regional SPS WR regional reliab regional WR WR regional reliab regional reliab regional WR WR EP EP EP EP EP EP Facility Owner re re re re re re re re re re re re re re re re re re re re re re re reliab regional g g g g g g g g g g g g g g g g g g g g g g g g g g g ional reliab ional ional reliab ional reliab ional reliab ional reliab ional reliab ional reliab ional reliab ional reliab ional reliab ional reliab ional reliab ional reliab ional reliab ional reliab ional reliab ional reliab ional reliab ional reliab ional reliab ional reliab ional reliab ional reliab ional reliab ional reliab ional reliab ional reliab ional
2010 Project Type ilit lt $2, ility $1, ility lt $8, ility lt $2, ility lt $2, ility ility lt $1, ility ility ility lt $1, ility $5, ility $1, ility ilit ilit ilit ilit ilit ilit ilit ilit ilit ilit ilit ilit ilit ilit ilit ilit ilit ilit ilit ilit ilit ilit ilit ilit ilit ilit lt $1, ility lt $3, $1, ility ility Build new substation with Tap the Str ility ility ility ility ility ility lt $1, ility lt New Tap Litchfield - Marmaton ility $3, ility ility $1, ility ility ility ility ility ility ility ility ility lt $1, ility ility ility ility y y y y y y y y y y y y y y y y y y y y y y y y y y y 1,3,0 eul 52ml ndro-Bacad6 Vln s18k.0/11 60/2SP3 ots501 ndro 3 V520828 Anadarko 138kV 520814 36months SPP 06/01/12 06/01/15 138kV. as 69kV line Blanchard Anadarko - 25.2-mile Rebuild $14,737,500 $13,500,000 Rebuild or reconductor 11.4-mile Rock H Rock 11.4-mile reconductor or Rebuild $13,500,000 $14 $16,000,000 $26,825,000 $6 $1 $2 $6 $2 $4 $1 $1 $2 $3 $7 $6 $4,149,000 $2,250,000 28.8MVAR Install ca 28.8MVAR anew Install ca $1,166,400 $1,166,400 $7,347,754 $8,750,767 $112,500 Replace relay in OGE's Alva substation OGE's relay in Replace $112,500 $749 $300 $150 $500,000 $476,500 Reconductor 1.55 miles of69kV Sub between 1/0Cu 1.55 miles Reconductor $476,500 $295,313 Reconductor Sanger Switch - OXY Permian 115 kV line with 397.5 ACSR 06/01/16 06/01/16 SPP 18 months 528575 OXY Permian Sub 11 Permian OXY 528575 18months SPP 06/01/16 06/01/16 397.5ACSR with 115kV line Permian OXY - Switch Sanger Reconductor $295,313 $324,000 $468,000 $352,350 Install 6 Mvar capacitor bank at Wells 69 kV 06/01/11 SPP 22 months 515202 Wells 69kV Wells 515202 River Lake 69kV Little 22months 514991 22months SPP 06/01/11 SPP 12/01/11 River Lake 69kV bank atLittle 6Mvar Install capacitor 69kV bank atWells 6Mvar Install capacitor $352,350 $352,350 $150,000 $150,000 Lynn County 115kV Interchange 526656 12months SPP 06/01/12 06/01/13 Convert Lynn County to115kV service Substation $100,000 $945,000 $50,000 5,0 prd eaiga USicyr n ida wthad ls h omlyoe rnr-Lnsy6 Vln 60/1WFE 06/01/11 Lindsay 69kV - line openCriner thenormally close andLindsay Switchyard; Switchyard atOU relaying Upgrade $50,000 , , , , , , , , , , , , 125,000 Rebuild 2-mile Blanchard - OU Switchyard 69 kV line as 138 kV. 06/01/12 SPP 12 months 520828 Blanchard 138 kV 521104 OU Switchy OU 521104 138kV Blanchard 520828 12months SPP 06/01/12 138kV. as 69kV Switchyard line OU - Blanchard 2-mile Rebuild 125,000 9,0 prd ap ony156 VTasomr# o8/6MA0/11 60/2SP2 ots555 ap necag 1 V5251 Happy 115kV Interchange 525154 28months SPP 06/01/12 06/01/14 #2to84/96MVA Happy Upgrade County 115/69kV Transformer 890,000 9,0 prd ap ony156 VTasomr# o8/6MA0/11 60/2SP2 ots555 ap necag 1 V5251 Happy 115kV Interchange 525154 28months SPP 06/01/12 06/01/14 #1to84/96MVA Happy Upgrade County 115/69kV Transformer 890,000 6,0 ovr eeodItrhne-N-eeodItrhne6 Vln 7 o15k evc 60/40/11 P 8mnh 52460 18months SPP 06/01/11 06/01/14 to115kV Z72 service 69kV Interchange line NE-Hereford - Interchange Convert Hereford 362,500 126,250 973,000 Reconductor 9.85 miles of 69 kV 1/0 Cu between Sub #170 and Sub #345 with 556 ACSR 06/01/15 EDE 24 months 547542 SUB 170 - NI SUB 170- 547542 24 months EDE 06/01/15 556ACSR of69kV Sub between #170andSub 1/0Cu #345with 9.85miles Reconductor 973,000 5,0 eodco .5mlso / Uwt 5 CR0/11 06/ 06/01/14 556ACSR with CU 1/0 of miles 2.85 Reconductor 550,000 968 201 647 011 591 369 705 , 600 971 100 243 000 890,000 0,0 d eodprle -idn rnfre tSeal0/11 PD3 ots690 tgl 3k 515Seal35V235204 345/230 2 345kV Stegall 659135 230kV Stegall 659206 36months NPPD 06/01/15 atStegall transformer 3-winding parallel Add second 000,000 100,500 Reconductor 3.58 miles of69kV Sub between 1/0Cu 3.58miles Reconductor 100,500 953,500 Upgrade existing Swisher 230/115 kV transformer to 252 MVA 06/01/16 06/01/16 SPP 24 months 525213 Swisher 230 kV 525212 Swisher Swisher 525212 230kV Swisher 525213 24months SPP 06/01/16 06/01/16 680,000 to252MVA 230/115kV transformer Swisher existing Upgrade 953,500 8,0 ntl .9mls15k ieadisaltria qimn tOhlreadPryo usain 60/1MSP535 Och 523154 SPP M 06/01/11 andPerryton substations atOchiltree equipment terminal andinstall 115kV line 0.19miles Install 181,400 1,0 eodco 1mlso / ih364AS 60/5SP2 ots502 rde 299LnsyS 91 53/65 11 69 1 Lindsay SW 520979 Bradley 520829 24months SPP 06/01/15 336.4ACSR of1/0with 11miles Reconductor 712,500 0,0 eodco .-ieCniga tto uky a 1 Vln ih75AS 60/30/11 P 8mnh 284Cunning 527864 18months SPP 06/01/13 06/01/13 795ACSR with 115kV Buckeye - line Station Tap Cunningham 8.5-mile Reconductor 607,000 771,875 500 , , ,
250 Rebuild Jo Rebuild 250 Re 000 Re 000 Cost Estimate , , , , , , , , , , , , 000 000 Ta Ordinance LoneStar - Hooks 1.68-mile Rebuild 000 750 Re 000 000 Rebuild Gatewa Rebuild 000 Jo Rebuild Jo Rebuild 500 P andrebuild down Tear 000 Jo theRiverton - down Tear 500 000 Monett Sub as 383- 5161kV line 6-mile new Build 319 000 , 000 osrc 1 Vbsa EHrfr necag oacp w rnfre emnl,to15kV 115 two terminals, transformer two accept to Interchange NE-Hereford Add 2nd115/69kV 84/96MVA transformer. terminal. at 115kV andonefuture line terminals, line bus kV 115 Construct osrc prxmtl ie f15k iefo uoItrhnet PAentySubstation. SP-Abernathy to Interchange Tuco from line kV 115 of Convert SP-Abernathy to115kV service. Substation miles 6 approximately Construct n i oehraon sg usain ev nyV3&T5triae tteOsage the at terminated T75 & V43 to only back Leave circuit Substation. remove Osage at from Osage and relays terminations around V05 Osage reset & Substation. together V67 from and circuits tie equipment Remove termination ACSR. condition). and terminal V04 795 Interchange. 3-terminal with Upgrade Co. Remove (remove V70 Tap Randall Manhattan Re-Conductor Substation. at Interchange. line design.) new Osage terminal Georgia one-half kV Tie at and South 115 breaker ACSR. termination new 795 to Add line with bus Remove Co. kV Substation. Randall 115 Osage from Randall to) line (Re-build kV (not 115 around new V70 of into miles 2 approximately Construct Build new 1.06-mile 69 kV line 69kV line 1.06-mile new Build 3-windin Install Ta S Convert 8.7-mile S Convert 3-mile Convert 6-mile Stillwater - S Mehan Cushin - Convert 14-mile Build new 0.72-mile 69 kV line 69kV line 0.72-mile new Build toexistin Monett new S. substation from 69kV line 1.04-mile new Build Rebuild Bann - Lone Star Ordinance 69 kV with 1272ACSR 69kV with Ordinance LoneStar Bann - Rebuild Reedin Convert 7-mile 3/0to556.5 from 69kV line Alva Freedom - 18.5-mile Rebuild Up Rebuild 12.63 miles oftheGeor 12.63miles Rebuild ntl 9k wthnrho ot live usainadsuho HPWFY pnnew Open LH-PLW&FNY. of south and Substation Plainview North of north switch switch kV 69 Install a h 5h&Wvry-Mniel 1 Vln nonw8t tetsbtto.Ta onand down Tear substation. Street 87th new into line KV 115 Monticello - Waverly circuit. double new as line existing rebuild & 95th the Tap 1/32k itiuintasomr ev 9k negon al oLwec akt efdby fed be to new kV Park Install 69 Lawrence load. the to to distribution off cable Substation Soncy underground line Sunset the kV Z33 serve from 69 converted to Leave line the Interchange. Y72 outofCoulter transformer kV transformer. split kV 115 distribution Sub 115/13.2 the kV Soncy new 115/13.2 a At tapping to by Street. terminate Soncy service and & kV bus I-40 115 at to Interchange Z33 Coulter of miles 1.04 Convert osrc prxmtl . ie f15k iefo hrySre usaint Hastings to substation Street Cherry from line kV 115 of miles 3.5 substation approximately Construct a xsigCsig-Bitw18k ieit e rewo usain ul e Greenwood new Build substation. Greenwood new into line kV 138 Bristow 138/69kV transformer. with substation - Cushing existing Tap a h rs live iy15k iewt rs ua.CnetKesRrlsbtto o115 to substation Rural Kress Convert Rural. Kress with Planview line North kV 115 Convert City substation. Plainview kV. Plainview - North Kress with the line Tap kV 115 City Plainview to115kV. substation - Kress the Tap ul ie fdul ici 9k iefo e rnlnsbtto oMler hfil 9kV 69 Sheffield - Mulberry to substation Franklin kV new 69 from Sheffield line - kV Mulberry 69 to circuit substation toSheffield. double andconnecting line tapping Franklin line, of new miles from 6 line Build kV 69 circuit toMulberry. double andconnecting line tapping line, of miles 6 Build elc aerp,Csadjmesa ohWlfr n uasbttossc htterminal that such substations Yuma and Wolfford both at jumpers T72 the192MVA ofthe115kV line and rating notconstrain does equipment CTs wavetraps, Replace p g p p p existin rade 15-mile Wakita -Nash 69 kV line from 1/0to336.4ACSR from 69kV line -Nash Wakita 15-mile rade 138kV wavetralace lace the Colb 800am lace 6/9k rnfre tFaki 60/3MW 386Faki 6 V523 rnln6 V1116 100/110 161/69 1 69kV Franklin 532938 161kV Franklin 533876 WR M 06/01/13 atFranklin 161/69 kV transformer , and close switch 3811 at Plainview Cit 3811atPlainview switch andclose p p p g ne ri 4 Vln noanwsbtto t8t tet0/11 4mnh 372Srne re 497Cag1351099/1195 345 1 Craig 542977 Creek Stranger 532772 24months 06/01/11 at87thStreet substation anew into 345kV line Craig - anger lin 391 - Gatewa 391- lin P 422- lin Jo 422- lin Oak Grove -Hw g y transformer connectin transformer p p -Jo y wavetra rin 69/34.5 kV transformer with alar with 69/34.5kV transformer p rin g p p Valle illsbur acitor bank atLo acitor g g lin 38969kV 161k as lin p Valle Switch Lakes Twin - p lin 5969kV 161k as lin illsbur s at both ends. Reset CTs at Lone Star South. Reset rela South. atLoneStar Reset CTs Reset atbothends. s 560MVA 345/115/14.4 kV three-winding transformer at transformer 560MVA 345/115/14.4kV three-winding p 161 kV line at new Franklin substation 06/01/13 M WR 533876 Franklin 161kV Franklin 533876 WR M 06/01/13 substation Franklin atnew 161 kV line at Nashua with lar with atNashua p y p p y y - Mehan to138k - 69kV line ctrbn tWnsoo18k usain 06/01/16 138kV substation. bank atWinnsboro acitor y lin 5969kV line lin 69kV 161k as rin y 69kV 161k as 99Ta -Kni y ( ( - Reinmiller 69 kV as thensin approx for 0.72mi, circuit ofdouble second circuit one ofdouble g g g ia Pacific - Keatchie 138 kV line from 795ACSR to1272ACSR from 138kV line Keatchie - Pacific ia Valle Project Description/Comments Project 69 kV line to138k 69kV line p p e 69 kV line to138k e 69kV line 69 kV circuit into new Greenwood substation Greenwood new into 69kV circuit g y g 69 kV line to138k 69kV line ans Monett 376 161kV toMonett bus 47069 kV as bus ill - Cart p V y V V r 3 Vsbtto. 06/01/16 138kVort substation. , V ard 69 kV line to138kV. 69kVard line rebuild as 161 kV from Stateline to outside Jo tooutside Stateline 161kV as from rebuild y g to allow North Plainview Substation tobefedb Substation Plainview North toallow er am er hage line from 336 ACSR to 1272 ACSR and 06/01/14 AEP 24 months 509082 Rock H Rock 509082 24months AEP 06/01/14 336 ACSR to1272ACSR and from hage line p g p ) 69 kV line. Re 69kV line. V from new Monett S. substation toexistin newMonett S. substation from rui 0/11 P Colb SPP 06/01/11 unit er art of multi line u line ofmulti art p 161 k 41adSb#5 ih56AS 60/50/11 D 4mnh 443SUB 547443 24months EDE 06/01/15 06/01/15 556ACSR #451 andSub #359with 35adSb#5 ih56AS 60/50/11 D 4mnh 456SUB 547576 24months EDE 06/01/15 06/01/15 556ACSR #345 andSub #451with acit V V y V wavetra V ( 5.4 miles p p aesic 06a oeSa 06/01/13 6006atLoneStar switch lace pg ) g . Replace . Replace 69kV line trunk ae06/01/17 rade 7hSre 60/13 ots527 7h538 7h13515560/616 345/115 1 87th 533283 87th 532775 30months 06/01/11 87th Street j umpers, up umpers, y g s atPittsbur s le circuit for 0.3 for circuit le p p i 9 60/80/11 SPP 06/01/18 06/01/18 59 lin g r f 06/01/17 of art g y 69k Cox rade rade g 06/01/12 . V 4 06/01/14 06/01/14 60/70/11 SPP 06/01/17 06/01/17 60/306/01/13 06/01/13 06/01/11 60/80/11 SPP SPP SPP 06/01/18 SPP 06/01/18 SPP 06/01/18 06/01/18 06/01/18 06/01/18 06/01/18 06/01/18 SPP 06/01/18 SPP 06/01/18 06/01/17 06/01/17 06/01/17 06/01/17 06/01/15 06/01/13 06/01/15 60/606/01/16 06/01/16 60/5M 06/01/15 60/3MW 398Faki 9k 374Sefed16 72/72 72/72 6 6 69 69 1 1 Sheffield 533774 Mulberry 533767 69kV Franklin 532938 69kV Franklin 532938 WR WR M M 06/01/13 06/01/13 60/20/11 P ots562 ofodItrhne15k 245Ym necag15k 1 192/192 115 1 115kV Interchang Yuma 526475 115kV Interchange Wolfford 526524 6months SPP 06/01/12 06/01/12
In Service 60/1SPP 06/01/11 60/1SP24months SPP 06/01/11 06/01/16 60/2WE 12months WFEC 06/01/12 60/1SP6mnh 229Lgtoe6 V555 ot live 9k 69 1 69kV Plainview North 525256 69kV Lighthose 525249 6months SPP 06/01/11 60/1GO6mnh 541203 6 months GMO 06/01/11 60/12 ots537 5h&Wvry538 otclo1215223/245 115 1&2 Monticello 533281 95th& Waverly 533278 24months 06/01/11 60/1SP6mnh 514792 6months SPP 06/01/11 06/01/11 06/01/11 06/01/15 06/01/17 60/7SP4 ots571 oet36571 oet401116 100/100 161/69 1 Monett 470 547511 Monett 376 547510 48months SPP 06/01/17 06/01/15 06/01/15 06/01/15 06/01/15 60/5SPP 06/01/15 60/5OE553 uhn 3 V553 rso 3 V118120/120 138 1 138kV Bristow 515035 138kV Cushing 515033 OGE 06/01/15 01/14 EDE 12 months 547438 SUB EXPLORER SPRING CITY TAP 547592 SUB 38 SUB 547592 TAP CITY SPRING EXPLORER SUB 547438 12months EDE 01/14 M P 2mnh 209Cer 1 V543 atns15k 1 . 174/192 3.5 115 1 115kV Hastings 524136 Cherry 115kV 524009 12months SPP M M SPP 525225 Kress Rural 115lV Rural Kress 525225 SPP M 2010 STEP DATE G 101OakGrove 69k 515021 OGE G 152S S 515512 St 515512 Mehan 138k 515011 515513 OGE OGE OGE OGE EDE 48 months 547480 SUB 383 - Monett SUB 383 - 161k 547480 48months EDE SPP A A A A SPP SPP A A SPP WR EP 21 months 508057 Hooks 508063 Lone Star Ordinance Ta Ordinance LoneStar 508063 Hooks South 138k LoneStar EP 508057 508297 21months 15months EP EP P24months EP P1 ots597 Lo 138k Winnsboro 509071 508317 18months 18months EP EP Estimated Cost Source ots506 rnr6 V507 ida 9k 972/89 69 1 Lindsay 69kV 520977 69kV Criner 520868 6 months C 24 months 36 months 24 months 30 months 524567 NE Hereford 115 kV 524573 NE Hereford 69kV NE Hereford 524573 115kV NE Hereford 524567 30 months 18 months 8mnh 451Monett 470269k 547511 48 months 48 months 48 months 48 months 48 months Purd 48 months Monett 69k 416J2 48 months 547404 547402 48 months 48 months 1mnh 003Bann 69k 508053 21 months 18 months
Project Lead Time 288Tc 1 V553 P brah 1 V1156157/173 6 115 1 Abernathy SP- 115kV 525732 115kV Tuco 525828 521008 Nash 69k Nash 521008 547498 SUB 439 - Stateline 161k Stateline SUB 439- 547498 451Gatewa Jo 547551 Jo 547593 Jo 547607 P 547607 547685 215SnyTp15k 221NwSny15k 1 .4157/173 1.04 115 1 Soncy New 115kV 524201 115kV Soncy Tap 524195 234RnalC 1 V542 ot eri 1 South Georgia 524322 115kV Co Randall 524364 520806 521037 004Geor 509064 525257 North Plainview 115kV Plainview North 525257 From Bus Number used in SPP
eeodItrhne15k 524567 115kV Interchange Hereford 6 MDWG bus Reedin AHA5 6.0510 SMTHVL 5161.00 541204 NASHUA 5 161.00 A Alva 69kV (OGE) illsbur lva 69k p p illwater p p p g rin rin lin 391161k lin 422161k lin 422161k lin ans lre535 ertnItrhne11501 157/173 0.19 115 1 Perryton Interchange 523158 iltree 41-Rpbi 450SB39-RPBI AT16 .572/72 1.55 69 1 REPUBLIC EAST 359- SUB 547580 Republic 451- y y g 4 EULCNRHAT574 U 5 eulc16 .872/72 3.58 69 1 Republic 451- SUB 547443 REPUBLIC NORTHEAST 345 - g g 69k South 390269k ia-Pacific 138k ia-Pacific Valle Valle g ill 69 kV p y y 138k a tto 1 V584 uky a 1 V11585 226/249 8.55 115 1 115kV Buckeye Tap 528348 115kV Station ham 161k ort 138k ort 161k V 138 k V V V y y V CHOLS ST. 547576 SUB 345 SUB 547576 ST. CHOLS 138k 138k V V V V V V V V V V V V V V 243Sne wthn tto 1 V11505 157/173 0.55 115 1 115kV Station Switching Sanger 528463 5 V V V V From Bus Name V 109Hw 515019 Kni Mehan 138k 515514 S 515513 Cushin 515512 515033 69k Tap Ordinance LoneStar 508063 Pittsbur 508313 Colb 530646 443Jo Gatewa 547483 P 547551 Jo 547685 Reinm 547900 Jo 547500 547900 South Monett 161k 547510 69k Wakita 521085 006Crhg 9k 91. 123/143 11.4 69 1 69kV Carthage 509056 509050 Keatchie REC 138k REC Keatchie 509050 520847 520915 451Monett 470269k Monett 470269k 547511 269k PT2 Monett SW 547511 547514 286Av 9k WE)16 48/48 69 1 Alva 69kV (WFEC) 520806 To Bus Number used in SPP 3HpyItrhne6 V2156 84/96 115/69 2 Happy 69kV Interchange 53 3HpyItrhne6 V1156 84/96 115/69 1 Happy 69kV Interchange 53 MDWG bus Cashion 138k Cashion 69k Freedom Northeast Hereford Interchange 115kV lnhr 3 V1182. 212/264 25.2 138 1 138 kV Blanchard illsbur p p p p rin y p lin 389161k lin 595161k lin 59161k lin 99Ta e 138k y g 34.5k Valle iller g y OLNSUHET16 .554/65 2.85 69 1 SOUTHWEST JOPLIN - 9 g y 138k 161k 1 V12015252/252 230/115 1 115 kV 161k 138k EULCNRHAT16 .572/72 9.85 69 1 NORTHEAST REPUBLIC - p 161 k r 3 V1182212/264 2 138 1 138kV ard V V 69k y V V 138k V V V V V V V V V V V V V V V V
V To Bus Name p 69k V V 6 224/265 161 1 3 26 287/287 12.63 52/66 138 72/72 268/286 1 194/222 194/222 8.69 3 5.98 14 69 138 138 1 138 138 1 1 1 1 144/179 7 280/331 143/143 72/89 138 1.68 1 25/28 69 1 138 1 18.5 1 69 1 69/34.5 3 6 .6218/268 218/268 218/268 218/268 7.36 218/268 1.11 218/268 1.78 2.44 2.98 5.32 218/268 53/65 161 161 6 161 161 1 161 1 161 1 1 1 1 14.9 161 69 1 1 2 1 246/270 4 115 1 910 27/32 75/92 75/92 1.06 0.72 1.04 69 69 69 1 1 1 Circuit 1/984/96 115/69 1 2 115 6 211/211 161 115 115 115 3 28.8Mva 28.8Mva 138 138 69 96Mvar 6Mvar 69 69 Voltages (kV) 5.4 Number of Reconductor
Number of New
Number of Voltage Conversion 1 160/160 90/121 00/400 Summer Rating Normal/Emergency r r NTC - Withdraw - NTC Withdraw - NTC Withdraw - NTC Withdraw - NTC T ihrw20475100SS$26731Bidnw10ml 4 Vln rmPte onwFi rwsbtto tRoeet1 atRoosevelt substation Draw - Frio tonew Potter from 345kV line 130-mile new Build $82,607,351 SPS 11050 795 20084 Withdraw - NTC T ihrw20475101SS$93912BidnwFi rwsbtto ih3520k rnfre 23/4DSS2 ots52489 24months SPS D 12/31/14 345/230kV transformer with substation Draw - Frio new Build $19,349,122 SPS 11051 795 20084 Withdraw - NTC NTC - Withdraw - NTC T ihrw20477107SS$,3,1 eodco .4ml atPat-Mnatn15k ie0/01 P 2mnh 212East 524162 12months SPS R 04/30/14 04 Manhattan - Plant 115kV East line 2.24-mile Reconductor 795ACSR County with Manhattan 115 kV Interchange Randall line - 1.6-mile Reconductor $6,434,410 $6,534,410 SPS SPS 11027 11097 777 830 20084 20084 Withdraw - NTC Withdraw - NTC Withdraw - NTC NTC - Withdraw - NTC NTC - Withdraw - NTC NTC - Withdraw 20084 773 11018 SPS $5,670,000 Add second 230/115 kV transformer at Roosevelt 06/01/13 D SPP 24 months 524908 Roosevelt Coun Roosevelt 524908 Canyon 24months 524516 SPP 36months SPP D 06/01/13 D 06/01/13 atRoosevelt 230/115kV transformer Add second 115kV line Draw Spring - Canyon West 9-mile new Build $5,670,000 $4,975,165 SPS SPS 11018 11176 773 887 20084 20084 Withdraw - NTC Withdraw - NTC Withdraw - NTC Withdraw - NTC T ihrw204326529SS$8,0 ntl w ak f72Ma aaiosa rs 9k 23/1RSP1 ots552 Kress 525224 12months SPP R 12/31/11 69kV atKress of7.2Mvar banks two Install capacitors $583,200 SPS 50259 30246 20084 Withdraw - NTC NTC - Withdraw 20084 30213 50217 SPS $2,025,000 Install 50 Mvar capacitor bank at East Plant 115 kV bus configured as two banks of25 banks two as 115kV configured Plant bank bus atEast 50Mvar Install capacitor $2,025,000 SPS 50217 30213 20084 Withdraw - NTC Withdraw - NTC NTC - Withdraw 20084 776 11026 SPS $2,253,579 Build new 1-mile Deaf Smith to Panda 115 kV line 06/01/12 R SPS 6 months 524622 Deaf Smith Co Smith Deaf 524622 6months SPS 5 R 24months 06/01/12 SPS D 06/01/12 toPanda 115kV line Smith Deaf 1-mile new Build to795ACSR 115kV line Pierce - Plant East 1.06-mile Reconductor $2,253,579 reti when County atBorden Midland by from old 230/138kV moving transformer Add second $1,451,925 $2,530,676 SPS SPS SPS 11026 11196 11056 776 857 797 20084 20084 Withdraw - NTC 20084 Withdraw - NTC Withdraw - NTC Withdraw - NTC NTC - Withdraw 20086 652 10857 WR $5,700,000 Rebuild the Westar portion of the 28.8 mile HEC - Huntsv - HEC ofthe28.8mile portion theWestar Rebuild $5,700,000 1 24 SPP WR SPP D 10857 D 12/31/13 652 12/31/13 20086 Withdraw - NTC Withdraw - NTC Withdraw - NTC Withdraw - NTC 345/138kV New transformer at345kV tooperate 230kV Midland line - Hobbs Convert 89.22-mile existing Withdraw - NTC $6,794,849 $655,534 515/560MVA rated Interchange atHobbs 345/230kV new transformer Install $8,324,480 SPS j line andreplace tapsettings CT Change Sub 928line. - Sub 906North 2-mile Rebuild SPS $4,638,000 SPS Huntsv - HEC 21.1-mile Rebuild $6,250,000 11091 11089 11090 824 824 824 20084 20084 OPPD 20084 Withdraw - NTC MIDW Withdraw - NTC Withdraw - NTC 11139 10914 862 697 20082 Withdraw - NTC 20094 Withdraw - NTC Withdraw - NTC Withdraw - NTC Withdraw - NTC Withdraw - NTC Withdraw - NTC Withdraw - NTC Withdraw - NTC T ihrw20473107SS$,2,0 eodco .-ieGie onyItrhne-Lgc 1 Vln 63/1RSP18month SPP R 06/30/11 County Legacy - Interchange 115kV Gaines line 5.5-mile Reconductor $2,320,300 SPS 11047 793 20084 Withdraw - NTC Withdraw - NTC NTC - Withdraw - NTC NTC - Withdraw - NTC Withdraw 2021
2010 Requested Board Action Appendix Reliab B - 00 1 10543 417 10506 20009 10695 388 20000 546 20073 00 6 10482 369 20006 08 8 11032 782 20084 00 4 10186 146 20004 08 2 11084 821 20084 10197 153 20031 00 3 10426 330 20006 00 5 10325 156 20004 00 7 10483 10636 10427 370 491 20006 330 20086 20006 11022 774 20084 10258 10571 10686 10259 202 440 537 20036 203 20075 10696& 10697 20075 20075 546 20073 09 8 10633 489 20094 03 5 10195 151 20031 00 00 50111 30105 20006 08 8 11172 883 20084 00 09 50102 30096 20006 50194 30187 20087 08 9 11049 794 20084 NTC_ID ility Network Upgr
PID ades Recommended for NTC for Recommended ades UID IW$5 MIDW CL$13 KCPL GMO D $400 $2 $8 $1 EDE EDE EDE EDE A A A P $24,147,866 SPS P $2,907,749 SPS SPS P $2,110,980 SPS $600 SPS P $11 SPS P $2,200,000 SPS SPS P $1 SPS WR R$2 WR WR WR R$889 WR WR WR P$100 EP EP EP Facility Owner re re g g ional reliab ional reliab ional
2010 Project Type ilit ilit y y $16 $28 $8,920,699 $1,000,000 Install 30Mvar Install ca $1,000,000 $5,850,000 $3,070,000 $2,784,000 $900,000 Add a second Grave 115/69kV transformer Add asecond $900,000 $580,000 $810,000 , , , , , , 300 , 260 250 274 000 277 , , 922 000 500 , , , U 000 , ,
000 000 65MVA 336ACSR for of4/0ACSR with Rate 1-mile Reconductor 000 Re 000 Cost Estimate , , , , , , 000 Rebuild SW Lawrence - Wakarusa 115 kV line 06/01/11 R WR 18 months 533271 SW Lawrence 115k Lawrence SW 533271 18months WR R 06/01/11 115kV line Wakarusa - Lawrence SW Rebuild 000 , 000 Rebuild 26.55-mile Huntsville - St. J 000 06/01/17 to336ACSR 1/0Cu from 69kV Southwest Sarcoxie line - Jct. Diamond 7.55-mile Reconductor 3-windin Install 000 Cartha - Jct. Atlas 3.5-mile Reconductor 000 935 , , 643 Build new Prin new Build 643 000 000 Rebuild 1.53-mile Co-op - Wakarusa 115kV line Wakarusa - Co-op 1.53-mile Rebuild A A A Reconductor the 14.37-mile 397 ACSR portion Southwest Station - Carne - Station Southwest 397ACSR portion the14.37-mile Reconductor Carne the26.2-mile Rebuild Build new Jones - Grassland 230kV Ckt 2 Grassland - Jones new Build Replaced by PIDReplaced 1001,UID 11315 795ACSR. 115kV Interchange with South Georgia - Station Switching Osage 4-mile Rebuild Add 230 kV line from Hobbs toSeminole Hobbs from Add 230kV line eodco -ieOaeSicigSain-RnalCut necag 1 Vln ih795 with line kV 115 Interchange County Randall - Station Switching ACSR Osage 2-mile Reconductor Ta Rebuild 2.9 mile Bismarck - Farmer's Consumer Co-O Consumer Farmer's - Bismarck 2.9mile Rebuild Scott atFt 161/69kVNew transformer Install 20 Mvar capacitor bank 115k atEudora 20MvarInstall capacitor 115kV Bush line - Hastings 5-mile new Build dd third Potash Junction Interchan Junction Potash dd third 84/84MVA with ratin 115/69kV autotransformer Tuco dd third 161k bank atAdrian dd 20Mvar capacitor pg p p Litchfield - Marmaton 161 kV with new SWBourb5 bus and 22 miles of 161 kV line to Ft Scott toFt of161kV line and22miles bus SWBourb5 new 161kV Marmaton with - Litchfield rade wavetrarade Boston New toNorth onterminal Boston atNew ofswitches sets two lace g g e-Hthad20k ie0/11 P 48months SPS D 03/01/12 230kV line Hitchland - le transformer connectin transformer p p at Gladstone from 800A to1200 from atGladstone acitor bank atS acitor g ae 0/4 V tMdad1/11 P 4mnh 296Midla 527916 24months SPP D 12/31/13 400/440MVArated atMidland ie - Hobart Jct. 138 kV line from 397 ACSR to 1272 ACSR. Replace 3 switches, wave 3switches, 397ACSR to1272ACSR. Replace from 138kV line Jct. Hobart - ie ille Project Description/Comments Project p 1 Vln n elc T aerpadrly IW3 ots531 ucisnEeg etr15K 368Huntsv 530618 Energy 115KV Center Hutchinson 533419 30months MIDW D wavetrap andrelays CT, andreplace 115 kV line rin g ohn 115 kV line andre ohn 115kV line e 115/69kV transforme g g hill new 161kV toMonett new bus Cit g otws 9k iefo / CRt 3 CR06/01/17 4/0ACSR to336ACSR from 69kV line e Northwest 115 k V V V A p 115k ille p lace CT r 1 Vln n ee T tHC0/11 R3 ots531 ucisnEeg etr15K 368Huntsv 530618 Energy 115KV Center Hutchinson 533419 36months WR D 06/01/15 atHEC CTs andreset 115 kV line V g , wavetra y Suh6 V 06/01/15 South 69kV. g ie 138 kV line to 1272 ACSR. Replace to1272ACSR. Replace 138kV line ie p, breakers Mvar 12/31/11 D SPP 12 months 524162 East Plant 115kV Plant East 524162 12months SPP D 12/31/11 Mvar mesfr 60/3DOP 4mnh 406SB96Nrh6 V672 U 2 9k 92110/110 2 69 1 SUB 92869kV 647928 69kV SUB 906North 647006 24months OPPD D 06/01/13 for umpers , andrela e 23/3DSP3mnh 286CpokRC-Vamo 3 V563 odnCut necag 3 V22018168/168 230/138 2 County Borden 230kV Interchange 526830 138kV Vealmoor - REC Caprock 522896 3 months SPP D 12/31/13 red y IW3 ots501 Huntsv 530618 30months MIDW D s 60/1RWR R 06/01/11 60/2DKP ots543015 6 months KCPL D 06/01/12 06/01/15 06/01/13 06/01/13 06/01/11 12/01/11 60/4D 06/01/14 43/4R 04/30/14 43/4R 04/30/14 06/01/13 33/3R 03/31/13 2/31/14 D SPS 48 months 524896 Pleasant H Pleasant 524896 48months SPS D 2/31/14 3/4RSP1 ots545 ahte a 1 V546 adl onyItrhne15k 1 . 246/271 1.6 115 1 County 115kV Interchange Randall 524364 115kV Manhatten Tap 524354 12months SPP R /30/14 In Service w 06/01/21 06/01/21 R1 ots532929 18months WR R R RWR R WR 18 months 532930 Fort Scott 161k Scott Fort 532930 18months WR R D D D D R D R DWRDWR D SPS 48 months 527894 Hobbs 230kV Hobbs 527894 48months SPS D D 2010 STEP DATE EDE 12 months 547527 SUB 436 - Webb Cit Webb SUB 436- 547527 12months EDE EDE 18 months 547533 SUB 109 - Atlas Junction 69k Junction Atlas SUB 109- 547533 18months EDE D 6mnh 450South Monett 161k 547510 36months EDE P 18months SPP SPP 24 months 527961 Potash Junc 69k Junc Potash 527961 24months SPP SPP A A A P 2mnh 541240 12months SPP P 36months SPS SPS P 12months SPP SPP SPP P15months EP EP EP Estimated Cost Source 24 months 18 months 18 months 24 months 525826 Tuco 69k Tuco 525826 24 months 18 months 18 months 36 months 36 months 18 months 18 months ots579 ob 4 V571 iln 4 V1358.21475/1623 89.22 345 1 345kV Midland 527916 345kV Hobbs 527896 2 months mnh 284HbsItrhne20k 579 ob necag 4 V13520515/560 345/230 1 345kV Interchange Hobbs 527896 230kV Interchange Hobbs 527894 months Project Lead Time 232Gie onyItrhne15k 236Lgc 1 V11555120/154 5.5 115 1 Legacy 115kV 527346 County 115kV Interchange Gaines 527322 s 533236 533234 Bismark 115k Bismark 533234 547538 227Prin 523267 327S 115k Eudora 533267 533240 145Carne 138k Junction Hobart 511445 511463 508068 North New Boston 69K Boston New North 508068 526337 Jones 230kV Jones 526337 232SuhGogaItrhne15k 235OaeSicigSain15k 1 115kV Station Switching Osage 524345 115kV Interchange South Georgia 524322 524345 216Hsig u 1 214Bs u 1 V1 Sub 115kV Bush 524124 Sub 115 Hastings 524136 523797 GRAVE 3 GRAVE 523797 46 atPat15k 215Pec 1 V11510 246/271 1.06 115 1 115kV Pierce 524185 115kV Plant East 24162 From Bus Number used in SPP
Pleasant Hill 6 MDWG bus Southwest Bourbon 161k Bourbon Southwest SUB 131 - Diamond Junction 69k Junction Diamond SUB 131- Farmer's Consumer CO-OP 115k CO-OP Consumer Farmer's A A Osage Switching Station 115kV Station Switching Osage vondale 161k 161k drian p rin g PatItrhne15k 224MnatnSb15k 1 .4226/249 2.24 115 1 Manhattan Sub 115kV 524224 115kV Interchange Plant g Interchan le d 4 V529 iln 3 V13518400/440 345/138 1 138kV Midland 522992 nd 345kV Rural 69kV Rural g hill ille ie South 138k ie Ws 1 V544 pigDa 1 V1159157/173 9 115 1 115kV Draw Spring 524544 115kV West V 115 k 1 v539 rv 9v2 Grave 269kv 523796 115 kv 115 k ill V V 4 V536 otrCut necag 4 V135101643/1793 130 345 1 County Potter 345kV Interchange 523961 345 kV 345kV 524897 Pleasant H Pleasant 524897 345kV V nyItrhne15k 257PnaEeg usain eeod15k 1 120/154 1 115 1 115kV Panda Energy Hereford Substation, 524597 unty 115kV Interchange V V V V yItrhne15k 299RoeetCut necag 3 V22015252/289.8 230/115 2 County Roosevelt 230kV Interchange 524909 ty 115kV Interchange g V e 230k V V y Cardinal 69k Cardinal V V
V From Bus Name V V V V V V 365Fr ct 6/9100/110 161/69 1 115k Wakarusa Co-o Consumer Farmer's 115k 533277 Wakarusa 533236 Scott Fort 533277 161k Scott Fort 533635 532930 115k Junc Potash 527962 115k St. John 530624 161k Gladstone 543016 Orono SUB 110- 547534 Cartha SUB 108- 547532 527276 523095 Hitchland 230k Hitchland 523095 115k Tuco 525828 Monett SUB 376- Cit 547582 547401 69k Boston New 508067 138k Station Southwestern Carne 511477 511445 267Gasad20k 2 230kV Grassland 526677 524364 Randall County 115kV Interchange Randall 524364 To Bus Number used in SPP MDWG bus SUB 362 - Sarcoxie Southwest 69k Southwest Sarcoxie SUB 362- eioe20k 1204 492/541 45 230 1 230kV Seminole g ille ille ie South 138k ie 1 V11577164/194 7.7 115 1 115 kV 1 V1152. 164/194 21.1 115 1 115 kV V ill 3k 4/3 560/560 345/230 1 230kV V V V V V V V g g V 69k o Junction e Northwest 69k e Northwest y V South 69k To Bus Name p 115k V V V V V V 1 .3223/240 181/181 223/240 312/342 22 1.53 2.9 4.09 115 115 115 1 161 1 1 1 40/40 293/335 164/199 54/65 54/65 71/96 54/65 115/69 1 220/235 287/287 26.55 1 115 7.55 161 3.5 69 1 69 1 161/69100/100 69 14.37 69 26.15 1 1 1 138 1 138 1 1 1 1 1 1 Circuit 115/69 115/69 3 26.72 230 1 139/160 2 115 1 4 115 115 115 20Mva 161 230 1 50Mvar 115 1 5 115 914.4Mvar 69 Voltages (kV)
Number of Reconductor 34 Number of New
Number of Voltage Conversion 2 492/541 227/249 492/541 157/173 30 Mva 20 Mva 84/84 40/40 Summer Rating Normal/Emergency r r r
Appendix D-AECIJCSP NetworkUpgrades 01 30355 30311 01 30356 30312 104 104 1056 1077 1076 1064 1063 1062 1061 1060 1059 1058 1057 5 1126 951 8 10781 283 10916 283 10369 283 10368 283 9 11 EIrgoa eiblt o AT$2,500,000 regionalreliability-nonOATT AECI 11310 1130 1130 996 995 1126 994 1126 1126 954 953 952 10367 283 5 1126 955 1 08 EIrgoa eiblt o AT$,0,0 6/9k rnfre tLmr0/11 EI1 ots305 0745AA 69/ 1 5LAMAR 300794 300651 18months AECI M 06/01/11 161/69kVtransformeratLamar Build21milesof161kVlinefromtheCampClarksubtoKAMO'sLamar $3,800,000 $9,833,000 regionalreliability-nonOATT regionalreliability-nonOATT AECI AECI 10783 10782 611 610 PID 7 6 19 EIrgoa eiblt o AT$,0,0 prd rnfre o8 V nt0/11 60/1AC 8mnh 019Sullivan 300119 18months AECI 06/01/11 06/01/11 UpgradeTransformerto84MVAunit $2,800,000 regionalreliability-nonOATT AECI 11396 19 EIrgoa eiblt o ATMv odfo tge 9k o11k 60/10/11 ots558 tge 6 V50558 301 Stigler161kV Gobbler 505588 300168 Gobbler 6months 18months 300168 Maries161kV Kingdom 300096 18months 300090 AECI Kingdom 18months 18months 300090 AECI 06/01/11 18months AECI AECI 06/01/11 06/01/11 AECI 06/01/11 06/01/11 06/01/11 Muskoge 06/01/11 06/01/11 300909 Sullivan 06/01/11 06/01/11 06/01/11 300119 18months 06/01/11 18months AECI AECI 06/01/11 06/01/11 06/01/11 06/01/11 Upgrade Transformerto84MVAunit Upgrade Transformerto84MVAunit $2,000,000 Move loadfromStigler69kVto161 UpgradeTransformerto56MVAunit $2,000,000 regionalreliability-nonOATT UpgradeTransformerto56MVAunit $2,500,000 regionalreliability-nonOATT 11417 AECI Addnew84MVATransformer $2,500,000 regionalreliability-nonOATT 11416 AECI $2,700,000 regionalreliability-nonOATT Rebuildlinewith795ACSRrated100C 11404 AECI regionalreliability-nonOATT 11403 AECI $200,000 UpgradeTransformerto84MVAunit regionalreliability-nonOATT 11402 AECI $2,800,000 regionalreliability-nonOATT 11401 AECI regionalreliability-nonOATT 11400 AECI 11399 AECI 11398 11397 1138 1138 UID 9 8 9 8 7 6 5 7 6 AECI AECI AECI AECI AECI EIrgoa eiblt o AT$,0,0 eul eg rso 9k iet 15 V 60/10/11 EI2 ots300887 24months AECI 3 06/01/11 18months 06/01/11 AECI 06/01/11 06/01/11 $48,600 Rebuild Beggs -Bristow69kvlineto51/51MVA Rebuild Cassville -Seligman69kVlineto70/70MVA regionalreliability-nonOATT $2,506,500 $1,380,000 regionalreliability-nonOATT AECI regionalreliability-nonOATT AECI AECI A A A A A A A A A EIrgoa eiblt o AT$64,800 regionalreliability-nonOATT AECI ECI ECI ECI ECI ECI ECI ECI ECI ECI Facility Owner re re re re re re re re re g g g g g g g g g ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit ional reliabilit inter-regional inter-regional inter-regional inter-regional inter-regional
2010 Project Type y y y y y y y y y -nonOAT -nonOAT -nonOAT -nonOAT -nonOAT -nonOAT -nonOAT -nonOAT -nonOAT T T T T T T T T T $100,000,000 $11,124,00 $3,000,00 $9,693,00 $2,400,00 $2,400,00 $872,00 $872,00 $560,00 $560,00
Cost Estimate 0 0 0 0 0 0 0 0 0 The proposedlineconnectstotheMorgan-Neosho345kVnearKansasbord The proposedlineconnectstotheMorgan-Neosho345kVnearKansasbord The proposedlineconnectstotheMorgan-Neosho345kVnearKansasbord The proposedlineconnectstotheMorgan-Neosho345kVnearKansasbord The proposedlineconnectstotheMorgan-Neosho345kVnearKansasbord 15Mvar Add A Rebuild Ke rebuild theexistin rebuild theexistin Build MansfieldCentral-MansfieldNorth-Norwood-Mt.Grove161over6 Build Scru Build A Install FisherTransformerNo.2138/69kV56MV Install ChecotahtransformerNo.2138/69kV56MV GRDA 1bus(GRDA2gen).AttheSportsmanAcres345kVa345/161 connects toSportsmanAcres345kVbuswhichviaa5mile345kVcircuit - ThisistheproposedBlackberrysub.From108mile345kVline GRDA 1bus(GRDA2gen).AttheSportsmanAcres345kVa345/161 connects toSportsmanAcres345kVbuswhichviaa5mile345kVcircuit - ThisistheproposedBlackberrysub.From108mile345kVline GRDA 1bus(GRDA2gen).AttheSportsmanAcres345kVa345/161 connects toSportsmanAcres345kVbuswhichviaa5mile345kVcircuit - ThisistheproposedBlackberrysub.From108mile345kVline GRDA 1bus(GRDA2gen).AttheSportsmanAcres345kVa345/161 connects toSportsmanAcres345kVbuswhichviaa5mile345kVcircuit - ThisistheproposedBlackberrysub.From108mile345kVline bus (GRDA2gen).AttheChouteau345kVa345/161transformerconnectsto connects toChouteau345kVbuswhichviaa5mile345kVcircuitGRDA1 - ThisistheproposedBlackberrysub.From108mile345kVline Add newHolden161/69kVXfmr#2 Install 7.2MvarcapacitorbankatTexanna69kV dd newThomasHill345/161kVXfmr
5 . 4Mvar p ache Flats-Scru gg y stone-Fisher Ta
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capacitor g g Fredericktown161kVta Fredericktown161kVta p 161kVline gg
at s 161kVline Project Description/Comments
p Milan with954ACSR,100
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total g (hs 60/1MAC 000309 LMR1112.3286/286 21.23 161 1 5LAMAR 300794 300070 AECI M 06/01/11 (this th 1.
o R R 9 e e e e e 11/01/11 11/01/11 06/01/11 06/01/11 02/01/11 02/01/11 02/01/11 02/01/11 06/01/12 06/01/11 60/10/11 AECI 06/01/11 06/01/11 06/01/11 06/01/11 06/01/11 06/01/11 06/01/11 60/10/11 AECI 06/01/11 06/01/11 60/10/11 AECI 06/01/11 06/01/11
In Service 06/01/11 06/01/11 M M M M M 2010 STEP DATE A A A A A A A A A AECI ECI C 30month 18month ECI ECI ECI ECI ECI ECI ECI ECI Estimated Cost Source 24 months 24 month 24 month 6 months 6 months
Project Lead Time s s s s 070SotmnArs35k 071SotmnArs11k 4/6 505/505 977/977 505/505 161 5 345/161 Chouteau161kV 300069 2 SportsmanAcres161kV 345 300741 345/161 SportsmanAcres161kV 300741 1 1 SportsmanAcres345kV 300740 SportsmanAcres161kV 300741 SportsmanAcres345kV 300740 GRDA 1345kV 512650 SportsmanAcres345 300740 50559 30004 50561 30014 014Hle 6 V303 odn6 V2116 56/56 161/69 2 Holden69kV 300336 Holden161kV 300124 30007 30007 30009 30061 34402 020Mln6 V6 15Mvar 69 Milan69kV 300280 020Txna6 V6 7.2Mvar 69 Texanna69kV 300280 67 lcbry35k 070SotmnArs35k 4 108 345 1 SportsmanAcres345kV 300740 Blackberry345 kV 96272 01 asil 9k 084Slga 9k 99270/70 9.2 69 1 Seligman69kV 300824 Cassville69kV 00819 From Bus Number used in SPP MDWG bus 4 9 0 9 9 5 7 8 5 eg 9k 089Bitw16 67 51/51 16.71 69 1 Bristow 300889 Beggs 69kV Checotah 138k Thomas Hil Ke Fredericktow Fredericktow Mansfiel Scru A Fisher 138k pache Flat y stone Da gg 34481 s 11k 012Slia 9k 6/984/84 161/69 1 Sullivan69kV 301152 161kV 11k 012Slia 9k 6/984/84 161/69 2 Sullivan69kV 301152 161kV d nb11k 013GblrKo 9k 6/984/84 84/84 161/69 161/69 2 1 GobblerKnob69kV 300173 GobblerKnob69kV 300173 Knob 161kV Knob 161kV wth6 V300 al rw 9k 913 122/122 1.32 69 1 SallyBrown69kV 300905 e Switch69kV iy11k 057KndmCt 9k 6/956/56 56/56 161/69 161/69 3 2 KingdomCity69kV 300517 KingdomCity69kV 300517 City 161kV City 161kV s V n n m From Bus Name V 30012 30112 Fisher69k 300931 30089 011FisherTa 300131 34458 34597 30061 To Bus Number used in SPP 8 ais6 V3116 84/84 161/69 3 Maries69kV 184 tge 6 V161 Stigler161kV 8 0 8 5 MDWG bus 6 6 5 7 hmsHl23511625/62 345/161 2 Thomas Hil Fredericktown U Wedeken Ta Mt. Grov JC ZionTa Scru Checotah 69k gg 6 1.4 161 1 s e p p V p
V To Bus Name E 6 02286/28 20.2 161 1 138/6 138/6 2 2 3 .6274/27 1.4 4.26 138 161 161 1 161 1 1 1 Circuit
6 84/84 161 Voltages (kV) 9 9
Number of Reconductor 2.2 2.2 Number of New
Number of Voltage Conversion 1369/136 1067/106 286/28 286/28 194/19 191/191 56/56 56/56 9 7 Summer Rating Normal/Emergency 6 5 4 5 4 4 1 1045 11446 AECI regional reliability - non OATT $2,500,000 Upgrade Ashervill transformer to No. 1 to 56 MVA 06/01/12 06/01/12 AECI 24 months 300056 Asherville 161 kV 301194 Asherville 69 kV 1 161/69 56/56 956 11270 AECI regional reliability - non OATT $939,000 Reconductor Dardenne-LakeSt. Louis-Enon 161 kV line from 477 ACSR to 1192 ACSR 06/01/12 M AECI 300596 Dardenne 300602 Lake St Louis 1 161 1.1 372/372 957 11271 AECI regional reliability - non OATT $3,821,545 Convert Mt. Grove-Cabool 69 k V line to 161kV 06/01/12 M AECI 301128 Mt. Grove 300917 Cabool 1 161 9.51 286/286 958 11272 AECI regional reliability - non OATT $5,762,455 Convert Cabool-Willow Springs 69 k V line to 161kV 06/01/12 M AECI 300917 Cabool 300122 Willow Springs 1 161 14.34 286/286 959 11273 AECI regional reliability - non OATT $1,900,000 Convert Cabool load to 161 06/01/12 M AECI 300917 Cabool 1 161 960 11274 AECI regional reliability - non OATT $11,124,000 Build Blackberry 345/161 kV sub (this will likely change to build Jasper 345/161 sub be 06/01/12 M AECI 300739 Blackberry 300127 Blackberry 1 345/161 392/392 961 11275 AECI regional reliability - non OATT $5,000,000 kV line) 06/01/12 M AECI 300127 Blackberry 300794 Lamar 1 161 20 286/286 962 11276 AECI regional reliability - non OATT $3,600,000 Build Holman-Cross Way 161 9.0 miles 06/01/12 M AECI 301159 Holman 300062 Crossway 1 161 9 286/286 963 11277 AECI regional reliability - non OATT $2,880,000 Build Holman-Rogersville 161 kV line - 7.2 mi 06/01/12 M AECI 301160 Holman 300832 Rogersville 1 161 7.2 286/286 1065 11405 AECI regional reliability - non OATT $5,349,000 Add new 161/69 kV substation at Steele tied to Entergy Hayti and Blytheville North 06/01/12 06/01/12 AECI 18 months 300756 Steele 161 kV 300769 Steele 69 kV 1 161/69 1078 11418 AECI regional reliability - non OATT $11,360,000 Build new 161 kV line from Lamar to Carthage 06/01/12 06/01/12 AECI 36 months 505488 Carthage 161 kV 300794 Lamar 161 kV 1 161 28.4 286/286 1079 11419 AECI regional reliability - non OATT $750,000 Build Georgetown-Dresden 161 kV line; Move Dresden load to 161 06/01/12 06/01/12 AECI 24 months 300082 Georgetown 161 kV 300526 Dresden 161 kV 1 161 2.5 286/286 981 11295 AECI regional reliability - non OATT $1,900,000 Convert Dresden load to 161 kV. 06/01/12 M AECI 300526 Dresden 1 161 30277 50311 AECI regional reliability - non OATT $440,000 Install 40 Mvar capacitor at Cabool 161 kV 06/01/13 AECI 12 months 300917 Caboo 161 40 Mvar 964 11278 AECI regional reliability - non OATT $29,508,769 Build Miami-Cassville 161 over 69 06/01/13 06/01/11 AECI 48 months 512631 Miami 161 kV 300682 Cassville 161 kV 1 161 64.81 286/286 965 11279 AECI regional reliability - non OATT $16,391,231 Build Cassville-Reeds Spring 161 over 69 06/01/13 06/01/11 AECI 48 months 300682 Cassville 161 kV 547492 Reeds Spring 161 kV 1 161 36 286/286 966 11280 AECI regional reliability - non OATT $2,402,000 Build Notch-Simmons Mt 161, 06/01/13 06/01/11 AECI 24 months 300490 Notch 300903 Simmons Mt 1 161 6.005 286/286 967 11281 AECI regional reliability - non OATT $1,005,750 Build Simmons Mt-Bear Creek 161, 06/01/13 06/01/11 AECI 24 months 300903 Simmons Mt 300933 Bear Creek 1 161 2.23 286/286 968 11282 AECI regional reliability - non OATT $1,900,000 move Simmons load to 161 06/01/13 06/01/11 AECI 300903 Simmons Mt 1 161 969 11283 AECI regional reliability - non OATT $1,900,000 move Bear Creek load to 161 06/01/13 06/01/11 AECI 300933 Bear Creek 1 161 970 11284 AECI regional reliability - non OATT $3,692,910 Build Bristow-Gypsy 138 kV line; 06/01/13 06/01/12 AECI 36 months 300137 Bristow 300916 Gypsy 1 138 11.085 245/245 971 11285 AECI regional reliability - non OATT $7,107,090 Build Gypsy-Stroud City 138 kV line; 06/01/13 06/01/12 AECI 36 months 300916 Gypsy 512706 Stroud City 1 138 16 245/245 972 11286 AECI regional reliability - non OATT $1,900,000 Convert Gypsy load to 138 kV 06/01/13 06/01/12 AECI 300916 Gypsy 1 138 973 11287 AECI regional reliability - non OATT $1,900,000 Convert Stroud load to 138 kV 06/01/13 06/01/12 AECI 300914 Stroud 1 138 974 11288 AECI regional reliability - non OATT $4,800,000 Build Stroud-Warwick 138 kV line 06/01/13 06/01/12 AECI 36 months 300914 Stroud 300915 Warwick 1 138 12 245/245 975 11289 AECI regional reliability - non OATT $2,240,000 Build Warwick-Luther 138 Kv line (Warwick Tap-Warwick already built for 138) 06/01/13 06/01/12 AECI 24 months 300915 Warwick 300135 Luther 1 138 5.61 228/228 976 11290 AECI regional reliability - non OATT $3,900,000 Convert Warwick load to 138 06/01/13 06/01/12 AECI 300915 Warwick 1 138 1086 11430 AECI regional reliability - non OATT Rebuild line as 69 kV under 161 kV and reuse 336 ACSR 06/01/13 M AECI 300821 Jenkins 69 kV 300671 Flat Creek 69 kV 1 69 10.9 51/51 1087 11431 AECI regional reliability - non OATT Rebuild line as 69 kV under 161 kV and reuse 336 ACSR 06/01/13 M AECI 300671 Flat Creek 69 kV 300662 Cape Fair 69 kV 1 69 3.6 51/51 1088 11432 AECI regional reliability - non OATT Rebuild line as 69 kV under 161 kV and reconductor with 336 ACSR 06/01/13 M AECI 300748 Neosho (EDE) 69 kV 300750 Neosho (AECI) 69 kV 1 69 3.75 70/70 1089 11433 AECI regional reliability - non OATT Rebuild line as 69 kV under 161 kV and reconductor with 336 ACSR 06/01/13 M AECI 300748 Neosho (EDE) 69 kV 300758 Sweetwater 69 kV 1 69 11.55 70/70 1090 11434 AECI regional reliability - non OATT Rebuild line as 69 kV under 161 kV and reconductor with 336 ACSR 06/01/13 M AECI 300758 Sweetwater 69 kV 300759 Wanda 69 kV 1 69 4.5 70/70 1091 11435 AECI regional reliability - non OATT Rebuild line as 69 kV under 161 kV and reconductor with 336 ACSR 06/01/13 M AECI 300819 Cassville 69 kV 300826 Wheaton (Barry) 69 kV 1 69 12 70/70 1092 11436 AECI regional reliability - non OATT Rebuild Bear Creek - Simmons Mountain 69 kV line to 122/122 MVA 06/01/13 M AECI 300713 Bear Creek 69 kV 300792 Simmons Mountain 69 kV 1 69 2.235 122/122 977 11291 AECI regional reliability - non OATT $6,500,000 Add 2nd Huben 345/161 kV transformer 06/01/14 M AECI 300042 Huben 300088 Huben 2 345/161 392/392 978 11292 AECI regional reliability - non OATT $8,040,890 Build St Francis-Dudley 161 kV line 06/01/14 M AECI 300115 St Francis 300820 Dudley 1 161 14 286/286 979 11293 AECI regional reliability - non OATT $8,730,110 Build Dudley-Essex 161 kV line 06/01/14 M AECI 300820 Dudley 300075 Essex 1 161 15.2 286/286 1066 11406 AECI regional reliability - non OATT $2,000,000 Upgrade Transformer to 84 MVA unit 06/01/14 AECI 18 months 301283 Fredricktown 69 kV 300079 Fredricktown 161 kV 1 161/69 84/84 1067 11407 AECI regional reliability - non OATT $2,000,000 Upgrade Transformer to 84 MVA unit 06/01/14 AECI 18 months 301283 Fredricktown 69 kV 300079 Fredricktown 161 kV 2 161/69 84/84 1080 11420 AECI regional reliability - non OATT $772,500 Rebuild Greenview - J&7 69 kV line 06/01/14 06/01/14 AECI 18 months 300777 Greenview 69 kV 300779 J&7 69 kV 1 69 5.15 70/70 982 11296 AECI regional reliability - non OATT $1,900,000 Install new 345/161 kV transformer at Cassville 06/01/15 06/01/11 AECI 24 months 300682 Cassville 161 kV 300819 Cassville 69 kV 1 161/69 56/56 30278 50312 AECI regional reliability - non OATT $165,000 Install 15 Mvar capacitor at Cassville 161 kV 06/01/15 AECI 12 months 300682 Cassville 161 15 Mvar 30279 50313 AECI regional reliability - non OATT $264,000 Install 24 Mvar capacitor at Pea Ridge 161 kV 06/01/15 AECI 12 months 301144 Pea Ridge 138 24 Mvar 1068 11408 AECI regional reliability - non OATT $1,998,000 Rebuild line to 70/70MVA rating 06/01/16 AECI 24 months 300862 Enterprise 69 kV 300877 Stigler 69 kV 1 69 13.32 70/70 30280 50314 AECI regional reliability - non OATT $297,000 Install 27 Mvar capacitor at Dresden 161 kV 06/01/16 AECI 12 months 300526 Dresden 161 27 Mvar 30281 50315 AECI regional reliability - non OATT $165,000 Install 15 Mvar capacitor at Shawnee Bend 161 kV 06/01/16 AECI 12 months 300566 Shawnee Bend 161 15 Mvar 983 11297 AECI regional reliability - non OATT $1,632,000 Build Maries-Dixon 161kV line 06/01/17 M AECI 300096 Maries 300919 Dixon 1 161 5.44 286/286 984 11298 AECI regional reliability - non OATT $2,864,965 Build Dixon-Hooker 161kV line 06/01/17 M AECI 300919 Dixon 300918 Hooker 1 161 6.86 286/286 985 11299 AECI regional reliability - non OATT $2,535,035 Build Hooker-Fort Wood 161kV line 06/01/17 M AECI 300918 Hooker 300080 Ft Wood 1 161 6.07 286/286 986 11300 AECI regional reliability - non OATT $200,000 Operate Hooker-Gospel Ridge at 161 (already built for 161) 06/01/17 M AECI 300918 Hooker 300883 Gospel Ridge 1 161 3.89 286/286 987 11301 AECI regional reliability - non OATT $1,900,000 Convert Dixon load to 161 06/01/17 M AECI 300919 Dixon 1 161 988 11302 AECI regional reliability - non OATT $1,900,000 Convert Hooker load to 161 06/01/17 M AECI 300918 Hooker 1 161 989 11303 AECI regional reliability - non OATT $1,900,000 Move Gospel Ridge load to 161 06/01/17 M AECI 300883 Gospel Ridge 1 161 30282 50361 AECI regional reliability - non OATT $165,000 Install 15 Mvar capacitor at Kosh 161 kV 06/01/17 AECI 12 months 301107 Kosh 161 15 Mvar 990 11304 AECI regional reliability - non OATT $7,000,000 Add 2nd Enon 345/161 kV transformer 06/01/18 06/01/17 AECI 30 months 300597 Enon 344535 Enon 2 345/161 560/560 30283 50317 AECI regional reliability - non OATT $165,000 Install 15 Mvar capacitor at Sullivan 161 kV 06/01/18 AECI 12 months 301119 Sullivan 161 15 Mvar 1044 11385 AECI regional reliability - non OATT $15,030,000 Rebuild 33.4 miles 161 kV from Ciltion-Holden 161 kV 06/01/21 AECI 36 months 300071 Clinton 161 kV 300124 Holden 161 kV 1 161 33.4 286/286
Appendix D - AECI JCSP Network Upgrades 2 BEFORE THE NEW MEXICO PUBLIC REGULATION COMMISSION
IN THE MATTER OF AN INVESTIGATION ) INTO THE PRUDENCE OF SOUTHWESTERN ) PUBLIC SERVICE COMPANY’S ) PARTICIPATION IN THE SOUTHWEST ) POWER POOL REGIONAL TRANSMISSION ) Case No. 07-00390-UT ORGANIZATION ) ) SOUTHWESTERN PUBLIC SERVICE COMPANY, ) ) Respondent. )
CERTIFICATE OF SERVICE
I HEREBY CERTIFY that a true and correct copy of Southwest Power Pool’s Filing
of the 2010 SPP Transmission Expansion Plan Report in Accordance with Section 15 of the
Uncontested Stipulation was served on the following parties by electronic mail on this 13th day
of January, 2011.
Gary L. Hurse, General Manager Jeffrey Fornaciari, Esq. Lea County Electric Cooperative, Inc. Hinkle, Cox. Eaton, Coffield & Hensley 1300 W. Avenue D 218 Montezuma Lovington, NM 88261 Santa Fe, NM 87501
[email protected] [email protected]
Joan E. Drake, Esq. Robert M. Pomeroy, Esq. William C. Scott, Esq. Thorvald A. Nelson, Esq. Modrall, Sperling, Roehl, Harris & Sisk, Holland & Hart, LLP P.A. 8390 E. Crescent Parkway, Suite 400 PO Box 2168 Greenwood Village, CO 80111 Albuquerque, NM 87103-2168 [email protected] [email protected]
Bradford C. Berge, Esq. Amy M. Shelhamer, Esq. Holland & Hart, LLC Courtney, Countiss, Brian & Bailey, LLP 110 North Guadalupe, Suite 1 PO Box 9238 Santa Fe, NM 87501 Amarillo, TX 79105-9238 [email protected] [email protected]
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Jerry F. Shackelford, Esq. Thomas B. Hudson, Jr., Esq. Xcel Energy Services, Inc. Ron H. Moss, Esq. 816 Congress Avenue – Suite 1650 Graves, Dougherty, Hearon & Moody, P.C. Austin, TX 78701 401 Congress Avenue – Suite 2200 [email protected] Austin, TX 78701 [email protected]
Randall W. Childress, Esq. Thomas Wander, Director Stacey J. Goodwin, Esq. Regulatory Projects Law Office of Randall W. Childress, PC Public Service Company of New Mexico 300 Gallisteo Street – Suite 205 Alvarado Square – MS 0920 Santa Fe, NM 87501 Albuquerque, NM 87158 [email protected] [email protected]
Daniel A. Najjar, Esq. Evan D. Evans 2200 Brothers Road David Stevens PO Box 22249 El Paso Electric Company Santa Fe, NM 87502-2249 123 W. Mills [email protected] El Paso, TX 79901 [email protected] [email protected]
Stephen Fogel Richard P. Noland, Esq. 5806 Sierra Madre James M. Bushee, Esq. Austin, TX 78759-3924 James E. Guy, Esq. [email protected] Sutherland, Asbill & Brennan, LLP 701 Brazos Street – Suite 970 Austin, TX 78701-2559 [email protected] [email protected]
Anthony J. Trujillo, Esq. Jeffrey Taylor, Esq. Gallagher & Kennedy, PA Assistant Attorney General 1233 Paseo de Peralta PO Drawer 1508 Santa Fe, NM 87501 Santa Fe, NM 87504-1508 [email protected] [email protected]
Peter Gould, Esq. Charles T. Pinson, General Manager NMIEC Central Valley Electric Cooperative PO Box 31326 1505 N 13th St Santa Fe, NM 87594-1326 PO Box 230 [email protected] Artesia, NM 88211 [email protected]
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Andrea Crane Jerry W. Partin, Manager The Columbia Group Roosevelt County Electric Coop., Inc. PO Box 810 121 North Main Street Georgetown, CT 06829 Portales, NM 88130
[email protected] [email protected]
Lance Adkins, General Manager Ashley Schannauer, Esq. Farmers’ Electric Cooperative, Inc. NMPRC – Legal Division 3701 North Thornton St 1120 Paseo de Peralta Clovis, NM 88101 Santa Fe, NM 87501
[email protected] [email protected]
Dahl Harris, Esq. Robert Hirasuna, Esq. NMPRC – Legal Division NMPRC – General Counsel 1120 Paseo de Peralta 1120 Paseo de Peralta Santa Fe, NM 87501 Santa Fe, NM 87501
[email protected] [email protected]
James Martin, Esq. Jeff Primm NMPRC – Hearing Examiner NMPRC – Utilities Division 1120 Paseo de Peralta 1120 Paseo de Peralta Santa Fe, NM 87501 Santa Fe, NM 87501 [email protected] [email protected]
Dated this 13th day of January, 2011.
ATTORNEY FOR SOUTHWEST POWER POOL, INC.
KANTER & GRUBESIC, P.A.
John T.L. Grubesic Post Office Box 25483 Albuquerque, New Mexico 87125-0483 (505) 247-1541
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