· MISO Transmission Expansion Plan 2011 Table of contents 2 1. Executive Summary

MISO Transmission Expansion Plan 2011 Table of contents

1

MISO Transmission Expansion Plan

2011

MISO Transmission Expansion Plan 2011 Table of contents

2

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

2. MTEP11 overview .................................................................................................................. 13 2.1 Investment summary ....................................................................................................... 13 2.2 Appendix overview ........................................................................................................... 17 2.3 Cost sharing summary ..................................................................................................... 19 2.4 MTEP Project types and Appendix overview ................................................................... 22 2.5 Economic assessment of recommended and proposed expansion ................................ 25 2.6 MTEP 11 futures retail rate impact .................................................................................. 33

3. Historical MTEP plan status ................................................................................................. 42 3.1 MTEP10 status report ...................................................................................................... 42 3.2 MTEP implementation history .......................................................................................... 43

4. Regional energy policy studies ........................................................................................... 45 4.1 Proposed Multi Value Project portfolio ............................................................................. 45 4.2 EPA Regulation Impact Analysis ..................................................................................... 79 4.3 Generation portfolio analysis ........................................................................................... 88

5. MISO resource assessment ................................................................................................. 97 5.1 Reserve margin requirements ......................................................................................... 97 5.2 Long term resource assessment ..................................................................................... 98

6. Near and long-term reliability analyses ............................................................................ 104 6.1 Reliability analysis results .............................................................................................. 111 6.2 Steady state analysis results ......................................................................................... 117 6.3 Voltage stability analysis results .................................................................................... 117 6.4 Dynamic stability analysis results .................................................................................. 117 6.5 Generator deliverability analysis results ........................................................................ 117 6.6 Long Term Transmission Rights (LTTR) ....................................................................... 120

Appendices

Appendix A: Projects recommended for approval Section A.1, A.2, A.3: Cost allocations Section A.4: MTEP11 Appendix A new projects

Appendix B: Projects with documented need & effectiveness Appendix C: Projects in review and conceptual projects Appendix D: Reliability studies analytical details with mitigation plan

Section D.1: Project justification Section D.2: Modeling documentation Section D.3: Steady state Section D.4: Voltage stability Section D.5: Transient stability Section D.6: Generator deliverability Section D.7: Contingency coverage Section D.8: Nuclear plant assessment

Appendix E: Additional MTEP11 Study support Section E.1: Reliability planning methodology Section E.2: Generations futures development Section E.3: MTEP11 futures retail rate impact methodology

Section E.4: Proposed MVP portfolio steady state and stability results Section E.5: Proposed MVP portfolio business case presentation Section E.6: Resource assessment results

Appendix F: Stakeholder substantive comments

MISO Transmission Expansion Plan 2011 Section 1 - Executive summary

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1. Executive Summary The annual MISO Transmission Expansion Plan (MTEP) identifies solutions to meet transmission needs and create value opportunities over the next decade and beyond. These solutions are defined via the implementation of a comprehensive planning approach which identifies essential transmission projects for approval and subsequent construction. MISO staff recommends the projects listed and described in MTEP11 Appendix A1 to the MISO Board of Directors for their review and approval.

MTEP11, the eighth edition of this publication, is the culmination of more than 18 months of collaboration between MISO planning staff and stakeholders. The primary purpose of this and other MTEP iterations is to identify transmission projects that:

Ensure the reliability of the transmission system over the planning horizon. Provide economic benefits, such as increased market efficiency. Facilitate public policy objectives, such as meeting Renewable Portfolio Standards. Address other issues or goals identified through the stakeholder process.

MTEP11 recommends $6.52 billion in new transmission expansion through the year 2021 for inclusion in Appendix A and construction. This is part of a continuing effort to ensure a reliable and efficient electric grid that keeps pace with energy and policy demands. Key findings and activities from the MTEP11 cycle include:

Recommendation of the first Multi Value Project portfolio for approval by the MISO Board of Directors: The portfolio is comprised of 17 projects, costing $5.6 billion.3 The proposed Multi Value Project (MVP) portfolio will create a regional network that provides reliability, public policy and economic benefits spread across MISO, such as

o Reliability benefits: The proposed MVP portfolio mitigates approximately 650 reliability violations for more than 6,700 system conditions, increasing the transmission system’s robustness under normal operation and extreme events.

o Public policy benefits: The proposed MVP portfolio enables the delivery of 41 million MWh of renewable energy.

o Economic benefits: The proposed MVP portfolio provides benefits in excess of the portfolio cost under all scenarios studied. These benefits are spread throughout the system, and each zone4 receives benefits of at least 1.6 and up to 2.8 times the costs it incurs.

o Qualitative benefits: The proposed MVP portfolio provides a number of additional qualitative benefits. For example, the transmission will support a variety of generation policies through utilizing a set of energy zones which support wind, natural gas and other fuel sources

Recommendation of 198 new Baseline Reliability, Generation Interconnection, or Other projects totaling $1.4 billion for approval by the MISO Board of Directors5: These projects, together with proposed projects listed in Appendix B, ensure compliance with all reliability standards and requirements and allow for the interconnection of approximately 2,700 MW of wind, nuclear, and other generation.

1 Projects in Appendix A reflect planned projects approved by or recommended for approval by the Board of Directors. Projects in Appendix B represent proposed projects for which a need has been identified, but are not timely or require additional analysis. Appendix C contains projects for which the need has not been verified. 2 $6.5 billion figure includes the $849 million in projects that were either approved or conditionally approved at the June 2011 MISO Board of Directors meeting.

3 Portfolio cost is as submitted and reflects nominal in-service date costs in whole or in part; the portfolio cost is equivalent to $5.2 billion in 2011 dollars. Total portfolio cost includes the Brookings County project, conditionally approved in June 2011 and the Michigan Thumb project, approved in December 2010. 4 Benefits were calculated based on the MISO proposed Local Resource Zones for Resource Adequacy 5 Total includes $118.5 million of projects that were approved during the June approval cycle.

MISO Transmission Expansion Plan 2011 Section 1 – Executive summary

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Economic assessment of transmission expansion: In addition to the proposed Multi Value Project portfolio, Appendices A and B contain a variety of planned and proposed transmission projects. Although premised largely on reliability, a subset of these projects will deliver market congestion reduction benefits of 0.9 to 1.0 times their cost beginning in 2016.

Confirmation of Long-Term Generation Resource Adequacy: The system has adequate capacity to meet its reserve requirements or Loss of Load Expectation (LOLE) criteria through 2021 based on currently announced generation retirements. However, these conclusions do not take into account capacity retirements that might be required by regulations imposed by the U.S. Environmental Protection Agency (EPA), which could significantly, and rapidly, erode reserve margins.

Determination of the potential impacts of EPA regulations on generation retirements: At the direction of stakeholders and Board of Directors, MISO evaluated the potential impacts of four new EPA regulations, including the impact of carbon reduction requirements. This study found the following potential impacts:

o Units at risk for retirement: Depending on economic conditions, including the cost of environmental regulation compliance, approximately 13 GW of existing coal generation is at-risk for retirement.

o Potential cost of compliance: The total 20-year net present value capital cost of compliance is expected to exceed $30 billion. This value includes the cost of retrofits on the system, the cost of replacement capacity, the cost of fixed operations and maintenance and the cost of transmission upgrades. This cost of compliance could increase the cost of energy by $5/MWh.

o Generation Resource adequacy impacts: If no replacement capacity is identified for Resource Adequacy purposes, then the system reserve margin could decrease to 6.9 percent in 2021. The 2021 reserve requirement is 18.2 percent.

Full implementation of a regional transmission planning approach: The proposed MVP portfolio is the realization of more than eight years of process, policy and engineering analysis. These solutions are premised on the integration of local and regional needs into a transmission solution that, when combined with the existing transmission system, provides the least cost delivered energy to customers.

In MTEP11, MISO completed analyses showing the near and long term affects of proposed transmission lines. In the coming years, MISO, through the continued integration of reliability, economic and public policy projects, will continue to drive grid efficiencies by ensuring that near-term projects support long-term goals.


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The MISO planning approach MISO is guided in its planning efforts by a set of principles established by its Board of Directors. These principles were created to improve and guide transmission investment in the region and to furnish an element of strategic direction to the MISO transmission planning process. These principles, confirmed in August 2011, are as follows:

Guiding Principle 1: Make the benefits of an economically efficient energy market available to customers by providing access to the lowest electric energy costs.

Guiding Principle 2: Provide a transmission infrastructure that safeguards local and regional reliability and supports interconnection-wide reliability.

Guiding Principle 3: Support state and federal energy policy objectives by planning for access to a changing resource mix.

Guiding Principle 4: Provide an appropriate cost mechanism that ensures the realization of benefits over time is commensurate with the allocation of costs.

Guiding Principle 5: Develop transmission system scenario models and make them available to state and federal energy policy makers to provide context and inform the choices they face.

To support these principles, a transmission planning process has been implemented reflecting a view of project value inclusive of reliability, market efficiency, public policy and other value drivers across all planning horizons studied. A number of conditions must be met through this process to build long-term transmission that can support future generation growth and accommodate new energy policy imperatives. These conditions are intertwined with the planning principles put forth by the MISO Board of Directors and include:

A robust business case for the plan. Increased consensus around regional energy policies. A regional tariff matching who benefits with who pays over time. Cost recovery mechanisms to reduce financial risk.

The following activities were undertaken to fulfill these conditions and—through them—the planning principles enunciated by the Board of Directors:

Safeguarding local and regional reliability: System reliability must be maintained throughout all MISO planning efforts, both on a local and interconnection-wide basis. This requirement can be difficult, in the face of changing generation and energy policy standards. Throughout 2011, MISO continued the transformation of the planning process to create an integrated transmission network that supports current and future reliability needs, while minimizing the cost of delivered energy. This value-based planning approach demonstrates a robust view of project benefits, through the analyses of many potential reliability, economic and policy-driven variables.

Distributing benefits commensurate with costs: The MISO planning approach is premised on the allocation of transmission costs in a manner that is commensurate with their benefits. To ensure this goal was met, MISO created a complete business case for the proposed Multi Value Project portfolio which demonstrated the regional spread of the economic benefits of the portfolio. In the future, MISO will continue to refine the business case for transmission projects and portfolios, as staff seek to optimize the transmission system to deliver the least-cost energy to consumers.

Responding to evolving energy policy: MISO examines multiple future scenarios in order to capture the impact of a wide array of potential policy outcomes. These future scenarios include varied demand and energy growth levels, and they also include the implementation of new policies which may have large impacts on the transmission system. For example, MISO conducted a thorough analysis of the U.S. Environmental Protection Agency (EPA) regulations to determine the impacts and action which will need to be taken as the regulations go into effect.


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Investments in system reliability and efficiency To respond to existing energy mandates and safeguard the system reliability, MTEP11 recommends 214 new projects for inclusion in Appendix A. These projects represent an incremental $6.5 billion in transmission infrastructure investment within the MISO footprint and fall into the following four categories:

Multi Value Projects (16 projects, $5.16 billion): Projects providing regional public policy, reliability and/or economic benefits.

Baseline Reliability Projects (39 projects, $424 million): Projects required to meet North American Electric Reliability Corporation (NERC) reliability standards. These standards impact facilities of a voltage greater than 100kV and represent the minimum standard applied across the MISO footprint.

Generator Interconnection Projects (26 projects, $273 million7): Projects required to reliably connect new generation to the transmission grid. The projects recommended for approval will allow for the connection of approximately 2,700 MW of wind, nuclear, and other generation

Other Projects (133 projects, $681 million): A wide range of projects, such as those designed to provide local economic benefit but not meeting the threshold requirements for qualification as Market Efficiency Project (MEP), and projects required to support the lower voltage transmission system.

The addition of new transmission projects in MTEP11 brings the total number of projects in Appendix A to 553, representing an expected investment of $10.0 billion through 2021. When completed, the projects will result in approximately 6,600 miles of new or upgraded transmission lines. Since the first MTEP cycle closed in 2003, transmission projects recommended for approval total $14.3 billion, of which $4.3 billion is associated with projects already in service.

MTEP11 contains 24 new Appendix A projects meeting cost-sharing eligibility criteria under the Baseline Reliability Project or Generator Interconnection provisions of the MISO Tariff. This report also features 16 projects meeting Multi Value Project cost sharing methodology criteria.

Economic assessment of planned and proposed projects As previously described, projects currently contained in Appendices A and B are primarily intended to address a reliability issue or need on the transmission system. However, those projects also have potential to create additional value, including the following:

Adjusted Production Cost Savings Reduced Energy And Capacity Losses Reduced Reserve Margins

For example, Table 1-1 shows an estimated Adjusted Production Cost benefit of $867 million in 2016 against a first year modeled transmission portfolio cost of approximately $1.1 billion. This benefit will lead to 20 to 40 year present value benefits of $9.1 to $20.6 billion, and economic benefit-to-cost ratios of 0.9 to 1.0. These economic benefits are in addition to the benefits derived from increased system reliability considerations initially driving the need for the majority of these projects.

6 Portfolio cost shown is as submitted and reflects nominal in-service date costs in whole or in part; equivalent to $4.7 billion in 2011 dollars. The Michigan Thumb Loop Expansion project with a cost of $510 million (2011 dollars) was approved in MTEP 10 and is part of the proposed Multi Value Project Portfolio. Its costs are not included in the above figure. 7

Project cost shown is the total cost, not just the cost shared or Transmission Owner contribution.


7

2016 Adjusted Production Cost

savings

20 Year Present Value, 3 percent Discount Rate

20 Year Present Value, 8.2 percent

Discount Rate



Discount Rate

MISO East $367 $5,627 $3,844 $8,742 $4,638

MISO Central $145 $2,210 $1,509 $3,433 $1,821

MISO West $355 $5,436 $3,714 $8,447 $4,482

MISO $867 $13,273 $9,066 $20,622 $10,941

Table 1-1: Economic benefits, in millions of 2016 dollars

The value-based planning process Uncertainties surrounding future policy decisions create challenges for those involved in the planning function and cause hesitancy for those with the resources to undertake transmission expansion projects. To minimize the risk in building a system under such conditions, the planning process must allow consideration of transmission projects in the context of potential outcomes. The goal is to identify plans resulting in the optimum amount of future value and the least amount of future regrets in areas such as cost incurred, right of way used, and benefits achieved.

MTEP11 identified and examined a wide array of future scenarios, which include the following:

The Business As Usual (BAU) with Mid-Low Demand and Energy Growth Rates Future Scenario is considered a status quo future scenario and continues the economic downturn-affected growth in demand, energy and inflation rates.

The Business as Usual (BAU) with Historic Demand and Energy Growth Rates Future Scenario is considered a status quo scenario, with a quick recovery from the economic downturn in demand and energy projections.

The Carbon Constraint Future Scenario models a declining cap on future CO2 emissions. The carbon cap is modeled after the Waxman-Markey Bill, which has an 83 percent reduction of CO2 emissions from a 2005 baseline by the year 2050.

The Combined Energy Policy Future Scenario includes a 20 percent federal RPS, a carbon cap modeled after the Waxman-Markey Bill, a “smart” transmission grid, and electric vehicles.


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Potential retail rate impacts for future policy scenarios To measure the potential impact to rate payers under each of the future scenarios, MISO projected potential impacts to the 2026 retail rate by calculating the impact of wholesale costs related to generation capital investment, production costs, transmission capital investment and distribution costs across the forecasted energy usage levels. In general, these rate impacts reflect differences between the type of generation and the associated transmission needed to integrate the generation in the various scenarios. Refer to Figure 1-1 for additional detail on theoretical impacts under various futures.

Figure 1-1: Comparison of estimated retail rate for each future scenario (cents per KWh in 2011 dollars)

Assuming that wholesale costs flow through to retail rates, rates for retail customers are projected to increase faster than inflation in all but one scenario, but the magnitude of the rate increases will vary greatly depending on actual economic and policy conditions. Assuming that all of the increase or decrease in wholesale costs flows through to the retail customer, this impact could range from a decrease of 1 percent for the Business as Usual with Mid-low Demand and Energy Growth Rate Future to an increase of 18.7 percent for the Combined Energy Policy Future.

2.61 2.61 2.61 2.61 2.61

3.63 3.30 3.584.20

4.70

1.66 2.202.07

2.38

2.300.73 0.62 0.66

0.820.75

8.63 8.72 8.92

10.02 10.36

0

2

4

6

8

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Business as Usual with Mid‐low Demand and Energy Growth Rates

MISO Current Retail Rate Business as Usual with Historic Demand and Energy Growth Rates

Carbon Constraint Combined Energy Policy

cents/kwh (2011$)

Distribution Generation Capital Generation Production Transmission


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Proposed MVP portfolio The proposed MVP portfolio is the culmination of more than eight years of transmission planning solutions, as transmission projects identified in MTEP03 through MTEP10 were brought together to form a cohesive, regional plan. Approximately 11 months of intensive studies were performed on the candidate portfolio, with heavy stakeholder involvement and review. At the end of the study, MISO recommends a proposed MVP portfolio for review and approval by the Board of Directors.

Figure 1-2: Proposed MVP portfolio

The proposed MVP portfolio combines reliability, economic and public policy drivers to provide a transmission solution that provides benefits in excess of its costs throughout the MISO footprint. This portfolio, when integrated into the existing and planned transmission network, resolves about 650 reliability violations for more than 6,700 system conditions, enabling the delivery of 41 million MWh of renewable energy annually to load. The portfolio also provides strong economic benefits; all zones8 within the MISO footprint see benefits of at least 1.6 to 2.8 times their cost.

8 Benefits were calculated based on the MISO proposed Local Resource Zones for Resource Adequacy


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Figure 1-3: Proposed MVP portfolio Zonal benefit-cost ratios

The portfolio also creates a transmission network that is able to respond to the ever-evolving reliability, generation and policy-based needs of the MISO footprint. For example, although the study was premised on a set of energy zones created to distribute wind capacity throughout the footprint in a least-cost pattern, these energy zones were also located with respect to existing infrastructure, such as transmission lines and natural gas pipelines. As a result the transmission will support a variety of different generation fuel sources, and with the fuel sources, a variety of generation policies.

Resource adequacy and risk assessment MTEP11 includes a forecast of resource adequacy based on projections of future generation and load to supplement and inform the assessment of the transmission system. The results of a study of the period 2012–2021 indicate that MISO will have sufficient generating capacity to meet demand through 2021, excluding the impacts of the EPA regulations. Net internal demand is expected to be 89 GW in 2012 and 97 GW in 20219. A total of 113 GW of resources are expected to be available to meet this demand in 2012 for the MISO region, increasing to 115 GW in 2021.

9 Net internal demand is equal to the median forecasted load. There is a 50 percent chance that peak load levels will exceed this prediction, while there is a 50 percent likelihood that peak load levels will be less than this prediction.


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Reserve margin 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021

Reserve margin (MW)

23,930 22,438 22,064 21,368 20,760 20,065 19,287 19,950 19,031 18,032

Reserve margin (percent)

27.0 24.8 24.2 23.3 22.5 21.5 20.5 21.0 19.9 18.6

Planning reserve margin requirement

(percent) 17.4 17.3 17.3 17.2 17.4 17.8 17.8 18 18.2 18.2

Table 1.2: 2012-2021 forecasted reserves

The MISO Planning Reserve Margin requirement varied throughout the 10-year period studied, from 17.4 percent in 2012 to 18.2 percent in 2021. The reserve margins projected through the assessment time frame varies from 27.0 percent to 18.6 percent for 2012-2021. The expected ability of forecasted resources to meet demand projections is anticipated to exceed the reliability levels represented by the accepted industry standard of one day in 10 years through 2019. However, these conclusions do not take into account capacity retirements that might be required by regulations imposed by the U.S. Environmental Protection Agency (EPA) which could significantly, and rapidly, erode reserve margins.

EPA impact analysis The U.S. Environmental Protection Agency (EPA) is finalizing four proposed regulations that will affect the MISO system. They require utilities to choose between retrofitting their generators with environmental controls or retiring them. At the direction of stakeholders and the Board of Directors, MISO evaluated the potential impacts of the new regulations, including the impact of carbon reduction requirements. This study evaluated the effects on capacity cost, resource adequacy, cost of energy and transmission reliability.10 A survey of the current fleet within MISO revealed 298 generation units will be affected by the four proposed regulations. The capacity of the units at risk for retirement is 12.7 GW, based on the assumptions surrounding the cost of environmental regulation compliance. The compliance cost of retrofitted units and replacement generation due to the EPA regulations are estimated to exceed $30 billion. Identifying all the costs to maintain regulation compliance and system reliability, a 7.0 to 7.6 percent increase in retail rates could be realized, excluding the impacts of carbon on energy prices. If carbon costs are included in the generation production costs, the rate affect increases to a range of 37.2 to 37.7 percent.

10 The EPA Regulation Impact Analysis was based on assumptions for proposed EPA regulations. The finalization of these regulations has the potential to introduce change and uncertainty.


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Figure 1-4: MISO rate impact excluding the cost of carbon in the production costs

The proposed EPA regulations could also have an impact on the system’s ability to meet demand. If no replacement capacity is identified for Resource Adequacy purposes, then the system reserve margin could decrease to 6.9 percent in 2021. The 2021 reserve requirement is 18.2 percent. However, if capacity is replaced with new and more reliable resources, there is a potential that Planning Reserve Margin (PRM) requirements could decrease by 0.2 to 1.0 percent.

Reserve margin

Forecasted reserves, without EPA regulations

Forecasted reserves, with EPA regulations

2016 2021 2016 2021

Adjusted resources (percent) 22.5 18.6 10.1 6.9

Reserve requirement (percent) 17.4 18.2 17.4 18.2

Table 1-3: Potential EPA impacts on resource adequacy

Conclusion MISO is proud to have an independent, transparent and inclusive planning process that is well positioned to study and address future transmission and policy-based needs in the region. We are also grateful for the input and support from our stakeholder community, which allows us to create well-vetted, cost-effective and innovative solutions to energize the heartland. We welcome feedback and comments from stakeholders, regulators and interested parties on the evolving electric transmission power system. For detailed information about MISO, MTEP11, renewable energy integration, cost allocation and other planning efforts, please visit www.misoenergy.org.

MISO Transmission Expansion Plan 2011 Section 2 – MTEP11 overview

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2. MTEP11 overview

2.1 Investment summary This section provides investment summaries of transmission system upgrades identified in MTEP11 and past MTEP studies that are still in the construction planning or execution processes.11 Chapter 2.4 describes the definitions of Appendix A, B, and C.

Approximately $6.5 billion is being added to Appendix A in this planning cycle, of which about $5.112 billion is the proposed Multi Value Project portfolio.

The estimated investment of the projects in MTEP11 Appendix A and Appendix B for 2011–2016 is $7.5 billion.

Appendix A contains $6.99 billion in investment through 2016 and an additional $3.2 billion from 2017-2021.

Appendix B contains $0.48 billion of investment through 2016. Appendix B also contains $29 billion in investment for 2017–2026, primarily comprised of two alternate Regional Generation Outlet Study (RGOS) plans.

Appendix C contains $6.5 billion in investment through 2016 and $37 billion in investment for 2017–2021.

Included in Appendix C is the MTEP08 reference future extra high voltage conceptual transmission overlay in 2018. Portions of the MTEP08 extra high voltage plan have been moved to the RGOS planning effort. There are also a number of large transmission proposals to address the renewable energy requirements in the region, with a $12 billion proposal in 2020. Therefore, there are many alternative and competing plans for renewable energy integration working their way through the planning process. Not all these proposals will reach Appendix A.

The expected project spending by year for Appendices A and B from 2011-2021 is in Figure 2.1-1. Projects may be comprised of multiple facilities. Investment totals by year assume that 100 percent of a project’s investment occurs when the facility goes into service. Since a large facility may require capital investment over multiple years, this assumption causes these numbers to appear ‘lumpier’ than the actual expenditures.

11 A summary of MTEP transmission investment including projects which have gone into service is included in section 3. 12 Cost shown is as submitted and reflects nominal in-service date costs in whole or in part; equivalent to $4.7 billion in 2011 dollars. The Michigan Thumb Loop Expansion project with a cost of $510 million (2011 dollars) was approved in MTEP 10 and is part of the proposed Multi Value Project Portfolio. Its costs are not included in the above figure.

Approximately $6.5 billion is being added to Appendix A in this planning cycle, of which about $5.1 billion is the proposed Multi Value Project portfolio.


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Figure 2.1-1: MTEP11 cumulative projected investment by year and Appendix

Transmission investment by Planning Region through 2021 is shown in Table 2.1-1. This table includes projects in Appendix A approved in prior MTEP planning cycles. Note that the projects are associated with a single planning region, though some projects may be in more than one planning region. These statistics are representative of investment in the planning regions.

Region Appendix A Appendix B Appendix C

Central $2,265,830,000 $219,152,000 $8,996,773,000

East $1,537,876,000 $148,701,000 $6,872,277,000

West $6,415,878,000 $233,899,000 $27,929,197,000

Total $10,219,584,000 $601,752,000 $43,798,247,000

Table 2.1-1: Projected transmission investment by Planning Region through 2021

$0

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2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021

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Table 2.1-2 shows new investment in 2011 Appendix A projects by preliminary cost allocation category and eligibility for cost sharing. Those categories are Baseline Reliability Project, Generation Interconnection Project, Transmission Service Delivery Project, Multi Value Projects, Market Efficiency Project and other. There were no Market Efficiency Projects and transmission delivery service projects in MTEP11. The numbers in Table 2.1-2 are a subset of Appendix A values shown in Table 2.1-1. These have a target Appendix of ‘A in MTEP11’ and are new to Appendix A in this planning cycle. Approximately $6.5 billion of investment is being added to Appendix A in this planning cycle. Actual cost allocations for shared projects are based on annual carrying charges and not total project investment; shared means that these projects are eligible for cost sharing. Not all costs of shared projects are eligible for sharing. For example, some Baseline Reliability Project costs and Generation Interconnection Projects are not shared, though only 10 percent of some Generation Interconnection Project costs may be shared to pricing zones. Projects are associated with single planning region, though they may have investment in multiple planning regions.

Region Share status

BRP GIP MVP13 Other

Central Not shared $8,351,000 $22,620,000 $62,111,000

Shared $40,826,000 $1,749,703,000

Central total $49,177,000 $22,620,000 $1,749,703,000 $62,111,000

East Not shared $11,700,000 $122,661,000

Shared $113,900,000 $22,180,000 $271,000,000

East total $125,600,000 $22,180,000 $271,000,000 $122,661,000

West Not shared $52,094,000 $37,494,000 $491,850,000

Shared $197,357,000 $191,094,000 $3,105,021,000

Excluded $4,900,000

West total $249,451,000 $228,588,000 $3,105,021,000 $496,750,000

Grand total $424,228,000 $273,388,000 $5,125,724,000 $681,522,000

Table 2.1-2: MTEP11 new Appendix A investment by allocation category & Planning Region

2 The Michigan Thumb Loop Expansion project with a cost of $510 million (2011 dollars) was approved in MTEP 10 and is part of the proposed Multi Value Project Portfolio. Its costs are not included in the above table. Costs shown is as submitted and reflects nominal in-service date costs in whole or in part; equivalent to $4.7 billion in 2011 dollars.


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A breakdown of new Appendix A project data reveals the new transmission build is spread over many states, with Illinois, Wisconsin, Iowa and Minnesota getting around $1 billion in new investment. The majority of that investment comes from the proposed Multi Value Project portfolio. South Dakota, Indiana, and Missouri also have significant projects. These geographic trends change over time as existing capacity in other parts of the system is consumed and new build becomes necessary there.

Figure 2.1-2: New Appendix A investment with allocation categorized by state

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IL WI IA MN SD IN MI IA/MO MO ND OH

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2.2 Appendix overview

Appendix A and B line summary There are approximately 6,600 miles of new or upgraded transmission lines projected from 2011-–2021 in MTEP11 Appendices A and B.

Of approximately 53,200 miles of line under MISO functional control, about 2,965 miles of transmission line upgrades are projected through 2021.

About 3,695 miles of transmission involving lines on new transmission corridors is projected through 2021.

Figure 2.2-1 depicts miles of new or upgraded lines by voltage class identified in Appendices A and B.

Figure 2.2-1: New or upgraded line miles by voltage class in Appendix A & B through 2021

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2011 2012 2013 2014 2015 2016 2017 2018 2019 2020

Mile

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765

345

230

161

138

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69


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Refer to Figure 2.2-2, which delineates new transmission line mileage by state for Appendices A and B through expected in service date of 2021.

Figure 2.2-2: New or upgraded line miles by state for Appendices A and B through expected in service date of 2021 by voltage class (kV)

Appendix C summary MTEP11 Appendix C lists and describes $48.6 billion of conceptual and proposed transmission investment. The MTEP08 reference future Extra High Voltage (EHV) conceptual overlay is $14 billion in 2018, comprised of approximately 65 projects. A number of those projects have been integrated into the Regional Generation Outlet Study effort and are now in Appendix B. Eleven of the MTEP08 reference future projects are now part of six proposed projects in the proposed Multi Value Projects portfolio. There are multiple proposals to enable integration and delivery of large amounts of renewable energy. One 765 kV proposal is for $12 billion in 2020. There are two direct current proposals for renewable energy, —$1.9 billion and $1.6 billion, respectively — in 2014. There is a proposal for 765 kV backbone transmission in lower Michigan for $2.5 billion in 2016. Some of these are competing proposals, so not all of the investment is expected. Many of the project proposals in Appendix C were added in order to address traditional reliability needs in the future. Some of these projects have just entered the planning process or are being revisited due to changes, such as load forecast adjustments caused by the economic downturn.

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2.3 Cost sharing summary

Multi Value Projects Multi Value Projects represent a new project type eligible for cost sharing effective since July 16, 2010, and conditionally accepted by the Federal Energy Regulatory Commission on December 16, 2010. Multi Value Projects provide numerous benefits, including, improved reliability, reduced congestion costs, and meeting public policy objectives. As discussed in more detail in Section 4.1, MISO staff is recommending

a portfolio of Multi Value Projects to the MISO Board of Directors for inclusion into Appendix A of MTEP 11. The proposed Multi Value Project portfolio includes the Michigan Thumb Loop project, approved in August 2010; the Brookings to Minneapolis-St. Paul project, conditionally approved in June 2011; and 15 additional projects being proposed to the MISO Board of Directors for the first time. The cost of the proposed MVP portfolio in 2011 dollars is $5.2 billion, including the $1.2 billion in projects that have previously been approved or conditionally approved by the MISO Board of Directors. See Table 4.1-1 for individual project costs.

The costs of Multi Value Projects will have a uniform 100 percent regional allocation based on withdrawals and will be recovered from customers through a monthly energy usage

charge. This charge will apply to all MISO load, excluding load under Grandfathered Agreements, and also to export and wheel-through transactions not sinking in PJM.

Figure 2.3-1 shows a 40-year projection of indicative annual MVP Usage Rates based on the proposed MVP portfolio using current year cost estimates and estimated in-service dates. Additional detail on the indicative MVP Usage Rate, including indicative annual MVP charges by Local Balancing Authority, is included in Appendix A-3.

The costs of Multi Value Projects will have a 100 percent regional allocation and will be recovered from customers through a monthly energy usage charge calculated using the applicable MVP Usage Rate.


20

Figure 2.3-1: Indicative MVP usage rate for proposed MVP portfolio from 2012 to 2051

Baseline Reliability, Market Efficiency, and Generation Interconnection

Projects A total project cost of $446.6 million, associated with new Baseline Reliability Projects and Generation Interconnection Projects for inclusion in MTEP 11 Appendix A, are eligible for cost sharing. The cost includes 12 Baseline Reliability Projects at $247.2 million and 10 Generation Interconnection Projects at $199.3 million. A total of $99.7 million of that goes directly to the generator. Of the $346.9 million in project costs, excluding the portion allocated to generators and eligible for cost sharing, 88.7 percent or $307.8 million remains in the pricing zone where the project is located. The remaining 11.3 percent, or $39.1 million, is allocated to neighboring pricing zones or system-wide to all pricing zones. Additional details on the new Baseline Reliability Projects and Generation Interconnection Projects eligible for cost sharing in MTEP 11 are in Appendix A-1.

Since the cost sharing methodologies for Baseline Reliability Projects, Generation Interconnection Projects, and Market Efficiency Projects were implemented in 2006, there have been 136 projects eligible for cost sharing. That’s $3.4 billion in transmission investment, with each project type representing the following number of projects and total project cost:

Baseline Reliability Projects – 79 projects, $2.9 billion. Generation Interconnection Projects – 56 projects, $550.4 million with $279.1 million allocated

directly to the generator. Market Efficiency Project – 1 project, $5.6 million.

$1.44

$1.03

$0.90

$0.00

$0.20

$0.40

$0.60

$0.80

$1.00

$1.20

$1.40

$1.60Indicative MVP Usage Rate ($/M

Wh in

2011$)

Indicative MVP Usage Rate 20‐year Average MVP Usage Rate 40‐year Average MVP Usage Rate


21

Figure 2.3-2 provides the breakdown, by pricing zone, of all project costs assigned to the zone based on the cost allocation at the time of approval for Baseline Reliability Projects, Generation Interconnection Projects, and Market Efficiency Projects from MTEP06 to the current MTEP11 report. The costs of approximately $2.8 billion, allocated to each pricing zone from prior MTEP report cycles, have been updated to reflect the current estimates on in-service project cost and in-service date. They do not include projects that have been withdrawn.

The red bar represents the Transmission Owner’s share of project costs not allocated to other pricing zones, equal to $1.8 billion across all pricing zones. The blue bar represents the portion of project costs allocated to a pricing zone for projects located in other pricing zones, equal to $927 million across all pricing zones. Note that the values shown in Figure 2.3-2 exclude the portion of Generation Interconnection Projects assigned directly to the generator.

Additional detail by pricing zone on the information shown in Figure 2.3-2 is located in Appendix A-2.2. The cost values for the new MTEP11 cost shared projects have been converted to reflect indicative annual charges for those projects for 2012 to 2021. See Appendix A-2.1.

() = Transmission Owner transmission investment

Figure 2.3-2: Allocated project cost from MTEP06 to MTEP11 for approved Baseline Reliability, Generation Interconnection, and Market Efficiency Projects.14

14 Costs allocated for projects located in the now non-existent First Energy pricing zone are included in the values shown. The MI13AG and MI13ANG zones have been combined into the MICH13A zone.

0.0 0.3 0.8 1.4 1.4 1.5 5.2 9.1 10.4 17.6 19.4 21.033.8 37.0

55.3

94.3111.9118.3

138.7142.1156.4

167.0

437.3

569.8

621.3

‐

100

200

300

400

500

600

700

Allocated Project Cost (Nominal Dollars)

Millions

Costs allocated for projects located in the Pricing Zone

Costs allocated from projects located outside Pricing Zone


22

2.4 MTEP Project types and Appendix overview MTEP Appendices A, B and C indicate the status of a given project in the MTEP planning process. Projects start in Appendix C when submitted into the MTEP process, transfer to Appendix B when MISO has documented the project need and effectiveness, then move to Appendix A after approval by the MISO Board of Directors. While moving from Appendix C to Appendix B to Appendix A is the most common progression through the appendices, projects may also remain in Appendix C or Appendix B for a number of planning cycles or may go from C to B to A in a single cycle.

MTEP11 Appendix A lists projects approved by the MISO Board of Directors in prior MTEPs but have not been built, and also lists projects and associated facilities recommended to the MISO Board of Directors for approval in this cycle. The new projects are indicated as “A in MTEP11” in the target Appendix field in the Appendix listing. The Appendix ABC field is indicated as B>A, or C>B>A, for new projects and A for previously approved projects. Projects in Appendix A are classified on the basis of their respective designation in Attachment FF to the Tariff.

Baseline Reliability Projects are required to meet North American Electric Reliability Corp. (NERC) standards. Costs for a Baseline Reliability Projects may be shared if the voltage level and project cost meet the thresholds designated in the Tariff.

Generation Interconnection Projects are upgrades that ensure the reliability of the system when new generators interconnect. The customer may share the costs of network upgrades if a contract for the purchase of capacity or energy is in place, or if the generator is designated as a network resource. Not all GIPs are eligible for cost sharing.

Transmission Service Delivery Projects are required to satisfy a Transmission Service request. The costs are assigned to the requestor.

Market Efficiency Projects, formerly referred to as regionally beneficial projects, meet Attachment FF requirements for reduction in market congestion. Market Efficiency Projects are shared based on benefit to cost ratio of the project, cost and voltage thresholds.

Multi Value Projects meet Attachment FF requirements to provide regional public policy economic and/or reliability benefits. Costs are shared with loads and export transactions in proportion to metered MWh consumption or export schedules.

A project not meeting any of these classifications is designated as ‘Other.’ The ‘Other’ category incorporates a wide range of projects, including those intended to provide local reliability or economic or similar benefits; but not meeting requirements as Market Efficiency Projects or Multi Value Projects (MVPs). Many other projects are required on the transmission system, less than 100 KV, which is not part of the bulk electric system under MISO functional control.

Projects start in Appendix C when submitted into the MTEP process, transfer to Appendix B when MISO has documented the project need and effectiveness, then move to Appendix A after approval by the MISO Board of Directors.


23

MTEP Appendix A MTEP Appendix A contains transmission expansion plan projects recommended by MISO staff and approved by the MISO Board of Directors for implementation by Transmission Owners.

Projects in Appendix A have a variety of drivers. Many are required for maintaining system reliability in accordance with the North American Electric Reliability Corporation (NERC) Planning Standards. Others may be required for Generation Interconnection or Transmission Service. Some projects may be required for regional reliability organization standards. Other projects may be required to provide distribution interconnections for load serving entities. Appendix A projects may be required for economic reasons, to reduce market congestion or losses in a particular area. They may also be needed to reduce resource adequacy requirements through reduced losses during system peak or reduced planning reserve. Projects may be required to enable public policy requirements, such as current state renewable portfolio standards. All projects in Appendix A address one or more MISO documented transmission issues.

Projects in Appendix A may be eligible for regional cost-sharing per provisions in Attachment FF of the Tariff. Such a project must go through the following process to be moved into Appendix A:

MISO staff must validate that the project addresses one or more transmission issue.

MISO staff must consider and review alternatives with the Transmission Owner.

MISO staff must consider and review costs with the Transmission Owner.

MISO staff must endorse the project.

MISO staff must verify that the project is qualified for cost-sharing as a Baseline Reliability Project, Generation Interconnection Project, Market Efficiency Project or Multi Value Project per provisions of Attachment FF.

MISO staff must hold a stakeholder meeting to review any such project or group of projects in which costs can be shared, or other major projects for zones where 100 percent of costs are recovered under Tariff.

MISO staff must take the new project to the Board of Directors for approval. Projects are moved to Appendix A following a presentation at any regularly scheduled Board meeting.

Appendix A is periodically updated and posted as projects go through the process and are approved. Projects are generally moved to Appendix A in conjunction with the annual review of the MTEP report. A June mid-cycle approval option is available for projects which have been under study in an open process for an appropriate period of time and need to be approved prior to the normal December cycle. However, should circumstances dictate, recommended projects need not wait for completion of the next MTEP for Board of Directors approval and inclusion in Appendix A.

MTEP Appendix B Projects in Appendix B have been analyzed to ensure they effectively address one or more documented transmission issues. In general, MTEP Appendix B contains projects still in the Transmission Owners planning process or still in the MISO review and recommendation process. It may contain multiple solutions to a common set of transmission issues. Projects in Appendix B are not yet recommended or approved by MISO, so they are not evaluated for cost sharing. There may be some potential Baseline Reliability Projects, Market Efficiency Projects or Multi Value Projects for which MISO staff has not been able to prove the need. Thus, while some projects may eventually become eligible for cost-sharing, the target date does not require a final recommendation for the current MTEP cycle. The project will likely be held in Appendix B until the review process is complete and the project is moved to Appendix A.


24

MTEP Appendix C Appendix C may contain projects still in the early stages of the Transmission Owner planning process or have just entered the MTEP study process and have not been reviewed. Like those projects in Appendix B, they are not evaluated for cost sharing. There are also some long-term conceptual projects in Appendix C which will require significant planning before they are ready to go through the MTEP process and move into Appendix B or Appendix A. Appendix C may also contain project alternatives to the best alternative in Appendix B. Therefore, a project could revert from B to C if a better alternative is determined and the Transmission Owner is not ready to withdraw the previous best alternative. Appendix C projects are not included in the MTEP initial power flow models used to perform baseline reliability studies.


25

2.5 Economic assessment of recommended and proposed expansion

Expansion plan MISO MTEP Appendix A/B contains planned/proposed projects that primarily address reliability needs.

These projects may also provide economic benefits, including:15

● Adjusted Production Cost (APC) savings

● CO2 emission reductions

● Energy loss benefits

Study results This analysis models a subset of Appendix A and B projects scheduled to be in-service by 2016. Not all Appendix A and B projects are modeled. The analysis models projects that have expected in-service dates after July 15, 2011, and December 31, 2016. Except the Michigan Thumb Loop Expansion, the proposed MVP portfolio is excluded. Projects not driving economic benefits are excluded as well, such as capacitor banks, circuit breaker upgrades and control room upgrades.

The PROMOD® simulations and economic analysis show that the Appendix A/B projects will bring not only reliability, but substantial economic benefit to MISO. In 2016, these projects will create $867 million in Adjusted Production Cost savings, when a total of $5.2 billion of new transmission projects are modeled. Over the following 20 to 40 years, these projects will create $9.1 to $20.6 billion dollars in Adjusted Production Cost savings, creating benefits that range from 0.9 to 1.0 times the cost of the projects modeled. Additionally, these projects will provide even greater economic benefits under higher load growth or higher gas prices.

The simulations and analysis also show that the Appendix A/B projects create benefits through a reduction in losses. In 2016, the annual energy loss decrease is about 45.8 GWH, which equates to about $41 million in savings.

Finally, the Appendix A/B projects provide CO2 relief for the MISO system. The increased transmission capacity will allow for less expensive power to be imported and less wind to be curtailed. This leads to a forecasted decrease in coal unit generation and therefore a CO2 reduction of 8 million tons.

More detailed methodology and benefit calculation assumptions are described later in this chapter.

15 MISO benefits include all MISO members as of 12/6/2011. First Energy is excluded.

The PROMOD® simulations and economic analysis show that the Appendix A/B projects will bring not only reliability, but substantial economic benefit to MISO. Over the 20 to 40 years following 2016, Appendix A and B projects will create approximately $8.3 to $18.9 billion in present value benefits.


26

Economic benefits Table 2.5-1 shows the Adjusted Production Cost savings for the MTEP11 Appendix A/B projects. The MTEP11 Appendix A/B projects will provide MISO $867 million in Adjusted Production Cost savings.

2016 Adjusted Production Cost

savings



Discount Rate



Discount Rate

MISO East $367 $5,627 $3,844 $8,742 $4,638

MISO Central $145 $2,210 $1,509 $3,433 $1,821

MISO West $355 $5,436 $3,714 $8,447 $4,482

MISO $867 $13,273 $9,066 $20,622 $10,941

Table 2.5-1: Economic benefits, in millions of 2011 dollars

As discussed, the full portfolio of Appendix A and B projects is not modeled. Thus, the total cost of the MTEP11 Appendix A/B projects in the MTEP11 2016 power flow case is $5.2 billion. Table 2.5-2 shows the Benefit- to-Cost ratio of the Appendix A/B projects, based on the economic benefits in 2.5-1 and $5.2 billion project cost, under different timeframes and discount rates.

Discount Rate Present Value Timeframe

B/C Ratio

3 percent 20 Years 0.88

8.2 percent 20 Years 0.86

3 percent 40 Years 1.00

8.2 percent 40 Years 0.91

Table 2.5-2: B/C ratio of MTEP11 Appendix A/B projects

Benefits will change with variation in the underlying assumptions. To see how the benefits are affected by other factors, MISO conducted sensitivity runs. The sensitivities tested are as follows:

1) Higher load growth: Load is 5 percent higher than the load in reference future;

2) Lower load growth: Load is 5 percent lower than the load in reference future;

3) Higher gas price: Gas prices are 40 percent higher than those in the reference future;

4) Lower gas price: Gas prices are 40 percent lower than those in the reference future;


27

Table 2.5-3: The Adjusted Production Cost savings, Load Cost savings and market congestion benefits of the MTEP11 Appendix A/B project for MISO in different sensitivities

Discount Rate

Present Value

Timeframe

Annualizedproject

cost (million $)

Base case

5 percenthigher load

5 percentlower load

40 percent higher

gas price

40 percentlower

gas price

3 percent 20 Years $901 0.88 1.06 0.76 1.08 0.73

8.2 percent 20 Years $924 0.86 1.04 0.74 1.05 0.71

3 percent 40 Years $792 1.00 1.21 0.87 1.23 0.83

8.2 percent 40 Years $872 0.91 1.10 0.79 1.11 0.75

Table 2.5-4: Benefit-to-cost ratio sensitivity

The base case benefits-to-cost ratio of MTEP11 Appendix A/B projects range from 0.71 to 1.23. The benefits-to-cost ratio tend to be higher in the high load case and high gas price case, and lower in the low load case and low gas price case.

The benefits captured in this section only include the economic benefits in generation production cost savings. Benefits not captured include operating reserve benefits, planning reserve margin benefits and reliability benefits. Benefits to cost ratios will be larger and may be greater than 1.0 if all those benefits are captured. Furthermore, the projects in current MTEP11 Appendix A/B are mainly reliability projects. They need to be built to relieve the reliability violations in the system. Economic benefits are side benefits from those projects. A benefit to cost ratio of less than 1 does not imply the projects are not needed.

The proposed Multi Value Project portfolio provides a wide range of benefits, as described in MTEP11 Chapter 4.1.

Base case 5 percent higher load

5 percent lower load

40 percent higher gas

price

40 percent lower gas

price

Annual Adjusted Production Cost savings (million $) $867 $1,047 $748 $1,062 $716


(million $) $13,273 $16,012 $11,457 $16,244 $10,959

20 Year Present Value, 8.2 percent Discount Rate

(million $) $9,066 $10,937 $7,826 $11,096 $7,485


(million $) $20,622 $24,877 $17,800 $25,239 $17,026

20 Year Present Value, 8.2 percent Discount Rate

(million $) $10,941 $13,198 $9,444 $13,390 $9,033


28

Loss benefits Loss benefits refer to the benefit of reduced line losses that occur when new high voltage transmission lines (Appendix A/B) are added to the system.

Loss benefits attributed to Appendix A/B projects are summarized in Table 2.5-5. The decrease in losses in 2016 is 45,781 MWH. Using the company’s hourly load-weighted LMP to price this energy loss yields a savings of approximately $41 million.

The loss at peak hour in MISO increases approximately 346.8MW from without Appendix A/B case to with Appendix A/B case, so the capacity loss benefits are actually negative. This is because Appendix A/B projects will allow more long-distance import from non-MISO entities at peak hour to displace MISO generation. Consequently, the long distance power transportation increases losses. Since the capacity loss benefit is negative, the value of capacity loss benefit will be $0.

Energy loss

benefit

Value of energy loss

benefit

Capacity of loss (peak) benefit

Value of capacity loss

benefit

Maximum hourly loss decrease

MISO 45,781 MWH $41 million -346.8 MW $0 391.4 MW

Table 2.5-5: MISO loss benefits with Appendix A/B project in 2016

Other benefits Table 2.5-6 shows the annual generation and capacity factor changes for different types of MISO units. After adding the Appendix A/B projects, capacity factors on fossil fuel generators stay the same or decline somewhat. MISO generation (excluding wind) decreases by about 10,457 GWH. Adding the Appendix A/B projects leads to less wind energy being curtailed (10,143 GWH).

Table 2.5-6 also indicates that coal units and combined cycle units generate less in the case, including Appendix A/B projects. This drives annual CO2 emission to decrease by approximately 8 million tons. That reduction is relative to the case without Appendix A/B projects, not the case without added wind generation. From Table 2.5-6, we can see the reduction in ST Coal, CT Gas and combined cycle units. The combined effect in CO2 emission is about 2 percent.

Loss benefits refer to the benefit of reduced line losses that occur when new high voltage transmission lines (Appendix A/B) are added to the system.

This drives annual CO2 emission to decrease by approximately 8 million tons.


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Generation (MWH) Capacity Factor

Combined Cycle

No Appendix projects. 25,267,913 21.22 percent

With Appendix projects. 20,804,817 17.47 percent

Change -4,463,096 -3.75 percent

CT Gas



Change -900,309 -0.45 percent

CT Oil

No Appendix projects. 68,820 0.16 percent

With Appendix projects. 15,908 0.04 percent


Hydro



Change -338 0.00 percent

IGCC




Nuclear



Change 0 0.00 percent

ST Coal



Change -4,788,897 -0.85 percent

ST Gas




ST Oil



Change 189 0.00 percent

Wind

No Appendix Projects 42,108,491 27.99 percent

With Appendix Projects 52,251,508 34.73 percent

Change 10,143,018 6.74 percent

Table 2.5-6: 2016 generation and capacity factor change for different type units

CO2 emission (ton)

No Appendix projects. 423,370,598 With Appendix projects. 415,237,057

Emission decrease 8,133,541

Table 2.5-7: 2016 annual CO2 emission change for different type units


30

Study methodology and assumptions The data for the economic benefit assessment comes from two PROMOD® case runs: one case without the Appendix A and B projects, and one case with these projects.

Only those projects that will not drive economic benefits are excluded to provide a more accurate analysis. Examples of projects not adding economic benefit include capacitor banks, circuit breaker upgrades, rebuilds of existing lines or substations and control room upgrades. These projects will not cause impedance or rating changes to existing lines, and will not affect system topology from steady-state economic study perspective.

PROMOD® cases The MTEP11 2016 summer peak power flow case, which has been reviewed by MISO stakeholders and incorporates the latest PJM system update, was used as the starting point for this study. Two 2016 PROMOD® cases were developed:

● 2016 PROMOD® case with Appendix A/B projects.

● 2016 PROMOD® case without Appendix A/B projects.

Both cases use the same MTEP11 BAU (Business As Usual with low demand and energy growth rate) Future database (containing all the generator, load, fuel and environmental information). The detailed information associated with the BAU Future can be found in Appendix E2. The only difference between these two PROMOD cases is the power flow cases (i.e., the transmission topologies) that are used.

Power flow case To develop these two PROMOD® cases, two power flow cases are required:

● One power flow case with Appendix A/B projects.

● One power flow case without Appendix A/B projects.

For both power flow cases, the Transmission Systems outside of the MISO footprint are the same; from the Eastern Interconnection Regional Reliability Organization (ERAG) 2010 series 2016 summer peak power flow case. The MISO portion, in the power flow case with Appendix A/B projects, is from the MTEP11 2016 summer peak power flow case, including all Appendix A/B projects except proposed Multi Value Projects. The MISO portion, in the power flow case without Appendix A/B projects, is from the ERAG 2010 series 2011 summer peak power flow case, representing the current transmission topology in MISO. Table 2.5-8 summarizes the differences between these two power flow cases.

Power flow case with Appendix A/B

Power flow case without Appendix A/B

MISO transmission MTEP11 2016 summer peak (ERAG 2011 summer peak + Appendix A/B)

ERAG 2011 summer peak

Non-MISO transmission ERAG 2016 summer peak ERAG 2016 summer peak

Generation/load/interchange Not used in PROMOD(R) Not used in PROMOD(R)

Table 2.5-8: Power flow cases difference

In the power flow case with the Appendix A/B projects, the Michigan Thumb Loop project is in the case. None of the other proposed Multi Value Projects were included in the case because the proposed MVP portfolio is not finalized. Among them, only 3 out of 16 projects have an expected in-service date on or before 2016. The benefits of proposed MVP projects are evaluated together as a portfolio in the proposed


31

MVP Portfolio Study. They are not included in the power flow case with Appendix A/B projects used in this study.

New generators The new generators identified in MTEP11 Steps 1 and 2, under the BAU Future, are included in this study. More details on these generators can be found in Appendix E2.

Event file The event file contains the list of flow gates which will be treated as transmission constraints. The quality of the event file has a big impact on the quality of the study results. As PROMOD® has a limit on the number of events, all N-1 or N-2 contingencies cannot be included in the event file. The event file for this 2016 PROMOD® case includes the flowgates from:

● MISO master flowgates file.

● NERC book of flowgates.

● Appendix A/B projects that have rating upgrades were also included in the event file with different ratings in each of the two PROMOD® cases.

The PROMOD® Analysis Tool (PAT) was also used to identify events with potential reliability problems. Those events were also included in the event file.

Economic benefits From each PROMOD® case, The Adjusted Production Cost (APC) was calculated. The APC is equal to the production cost adjusted by sales revenue and purchases cost.

The comparison of the economic indices from two PROMOD® cases (with Appendix A/B case, and without Appendix A/B case) yields the Adjusted Production Cost savings. These savings are the annual Adjusted Production Cost decrease from the case without Appendix A/B projects to the case with Appendix A/B projects, so there is a cost savings.

Loss benefits Energy loss benefit (MWH) is the annual loss decrease (MWH) from without Appendix A/B case

to with Appendix A/B case.

Capacity loss benefit (MW) for MISO is the loss decrease (MW) from without Appendix A/B case to with Appendix A/B case in MISO’s peak load hour.

Dollar value of energy loss benefit is the annual MISO loss cost decrease from without Appendix A/B case to with Appendix A/B case. Company loss cost is calculated by multiplying a company’s hourly losses by its load- weighted LMP. The annual sum of these values for all MISO companies is the annual MISO loss cost.

Dollar value of capacity loss benefit represents the value of deferring additional generation construction. It is calculated using $650/kW-$1200/kW, the price range for the construction of different units. If the capacity loss benefit is positive, the corresponding dollar value is the capacity loss benefit multiplied by these prices. If the capacity loss benefit is negative, this value will be 0.


32

Maximum hourly loss decrease is the maximum hourly loss decrease (MW) from without Appendix A/B case to with Appendix A/B case.

Other impacts Generation, capacity factor and CO2 emission change compares two things: 1) the change of

generation and the capacity factor of different types of units and 2) change of CO2 emission between with and without Appendix A/B projects cases.


33

2.6 MTEP 11 futures retail rate impact The electricity industry is facing significant policy changes from the state and federal level. These changes are generating uncertainty for the industry and its customers, including potential rate increases to retail electricity customers. As shown in Figure 4.1-2, all but 1 of the 12 states in the MISO footprint has enacted a Renewable Portfolio Standard (RPS) mandate or goal. There is a great deal of uncertainty about how these goals will be achieved, including the location of future generation and the required transmission to enable renewable integration. In addition to state policies, there is on-going discussion at the federal level on implementation of policies, including federal RPS, carbon reduction, smart grid and others. To address these potential futures, MISO examines multiple scenarios through its long-term planning process to capture the wide range of potential policy outcomes.

Current retail electricity rates The current cost of electricity to the retail customer must be considered before examining the potential impact of the future scenarios. In MISO the current average retail rate, weighted by load in each state, for residential, commercial and industrial sector, is 8.7 cents/kWh, about 10 percent lower than the national average of 9.7 cents/kWh.16 Refer below to Figure 2.6-1, which provides the average retail rate in cents per kWh for each state in the MISO footprint. It shows the rate paid by consumers varies greatly across the MISO footprint. Based on information provided by the Energy Information Administration (EIA) in Annual Energy Outlook 2011; the generation, transmission and distribution cost components of the retail electricity rate in 2011 are estimated to average 63.0 percent, 7.1 percent and 29.9 percent, respectively.17 This equates to approximately 5.5 cents/kWh for generation, 0.6 cents/kWh for transmission and 2.6 cents/kWh for distribution.18 For this rate impact analysis, it is assumed the average MISO residential customer uses approximately 1,000 kWh of electricity each month, equivalent to annual electricity charges of $1,044; based on an 8.7 cents/kWh retail rate.

16 Data courtesy of the Energy Information Administration (EIA) Electric Power Monthly from March 2011. MISO average rate was calculated by taking the load weighted average of the 12 states in the MISO footprint. 17 MISO average generation, transmission and distribution components were calculated based on rate component data provided in the EIA Annual Energy Outlook in 2011 for the following modeling regions: MRO-East, MRO-West, RFC-MI, RFC-West, SERC-Central, and SERC-Gateway. The modeling regions were weighted based on MISO load in each of the regions. 18 Each category assumes some allocation of general and administrative expenses.

The electricity industry is facing significant policy changes from the state and federal level. These changes are generating uncertainty for the industry and its customers, including potential rate increases to retail electricity customers.


34

Figure 2.6-1: MISO retail rate for all sectors in cents/kWh (2011 dollars)

Future policy scenarios MISO examined a number of policy-driven future generation expansion scenarios to develop an array of “best plans” for a range of possible outcomes. These scenarios derive from policy discussions, and they will evolve depending on the direction of legislation. The scenarios represent a range of potential policies and have been used to estimate potential impacts to retail rate payers in the MISO footprint.19

Business as Usual with Mid-low Demand and Energy Growth Rates assumes a slow recovery from the economic downturn and its impact on demand and energy projections. This scenario assumes existing standards for resource adequacy, renewable mandates and little or no change in environmental legislation.

Business as Usual with Historic Demand and Energy Growth Rates assumes a quicker recovery from the economic downturn and a return to historic demand and energy growth rates. This scenario assumes existing standards for resource adequacy, renewable mandates and little or no change in environmental legislation.

Carbon Constraint models a declining cap on CO2 emissions. The carbon cap is modeled after the Waxman-Markey bill, with a modified timeline to reach a 42 percent reduction by 2033 from 2005 levels. For the 2026 rate impacts calculated in this analysis, a 25 percent carbon reduction is targeted.

Combined Energy Policy combines the impact of multiple policy scenarios into one future. Smart grid is modeled within the demand growth rate. It is assumed an increased penetration of smart grid applications will lower overall demand growth. Growth in electric vehicle usage is captured with a higher energy growth rate and is assumed to increase off-peak energy usage.

19 For additional description of the MTEP 11 scenarios refer to section 4.3 and Appendix E.2

10.210.0

8.8 8.7

8.3 8.1 8.0

7.67.4 7.3

7.0 6.9

MI WI IL OH MN MT IN SD MO IA KY ND

MISO Load Weighted Average = 8.7 cents/kwh


35

To meet the various policy objectives, all scenarios included in this rate impact analysis require significant investment in generation and transmission expansion across the 15-year study horizon. This is expected to affect retail electricity rates, especially since a large share of generation and transmission assets have or soon will reach the end of their recoverable book-life. For example, approximately 55 percent of the generating capacity in the MISO footprint is at least 30 years old. As shown in this analysis, all but one of the scenarios shows retail rates increasing at a rate greater than inflation.

Overview of rate impact methodology and results To measure the potential impact to rate payers under each of the scenarios; MISO projected a 2026 retail rate by estimating annual revenue requirements for the generation, transmission and distribution rate components.20 This projection was based on the following assumptions:

Transmission component o Includes proposed MVP portfolio (constant across all scenarios). o Additional required reliability transmission investment through 2026 (constant across all

scenarios).21 o Non-depreciated current transmission that would still be recoverable in 2026 (constant

across all scenarios). Generation component

o Production costs for MISO generation resources associated with each scenario in 2026; including fuel, emissions, and variable operations and maintenance expenses.

o Capital costs, including fixed operations and management, associated with the capacity expansion for each scenario through 2026.22

o Non-depreciated current generation that would still be recoverable in 2026 (constant across all scenarios).

Distribution component o Assumes that the distribution component of the current MISO retail rate at 2.6 cents/kWh

will grow at the assumed rate of inflation through 2026. To calculate MISO’s 2026 retail rate, revenue requirements for the generation, transmission and distribution components described above were distributed uniformly across the forecasted 2026 energy usage levels. The 2026 rate was then discounted, using the assumed inflation rate to 2011 for comparison to the current MISO retail rate. The results of this calculation for each scenario are shown in

Figure 2.6-2, which depicts the impact the scenarios could have on customer’s retail rates. Note that the rates calculated for the future scenarios include costs for generation, transmission and distribution; but do not include general and administrative costs. All but one of the scenarios shows that retail rates can be expected to grow at a rate faster than would be experienced if rates simply increased by inflation. However, the magnitude of this impact varies greatly across the four scenarios, from a 1 percent decrease for the Business as

Usual with Mid-low Demand and Energy Growth Rate scenario to a 19 percent increase for the Combined Energy Policy Future. Major rate drivers for each scenario are discussed in more detail in the next section.

20 Additional detail on the rate calculation methodology is provided in Appendix E.3. 21 Based on the proposed MVP portfolio listed in Table 4.1-1 in Section 4.1 with a total project cost of more than $5.2 billion. 22 Refer to Section 4.3 for details on the capacity expansion, by fuel type, for each MTEP 11 Future. Generation siting maps for each MTEP 11 Future are also provided in Section 4.3.

All but one of the scenarios shows that retail rates can be expected to grow at a rate faster than would be experienced if rates simply increased by inflation.


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Figure 2.6-2: Comparison of estimated retail rate for each future scenario (Cents per KWh in 2011 Dollars)

Scenario Rate (cents/kWh)

Percent (Change from current retail

rate)

BAU with Mid-low Demand and Energy Growth Rates 8.62 -1.2 percent

MISO Current Retail Rate 8.72 0.0 percent

BAU with Historic Demand and Energy Growth Rates 8.91 +2.1 percent

Carbon Constraint 10.0 +14.6 percent

Combined Energy Policy 10.34 +18.6 percent

Table 2.6-1: 2026 retail rate impacts in 2011 dollars of for each future scenario

2.61 2.61 2.61 2.61 2.61

3.63 3.30 3.584.20

4.70

1.66 2.202.07

2.38

2.300.73 0.62 0.66

0.820.75

8.63 8.72 8.92

10.02 10.36

0

2

4

6

8

10

12

Business as Usual with Mid‐low Demand and Energy Growth Rates

MISO Current Retail Rate Business as Usual with Historic Demand and Energy Growth Rates

Carbon Constraint Combined Energy Policy

cents/kwh (2011$)

Distribution Generation Capital Generation Production Transmission


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Rate impact drivers under future policy scenarios Table 2.6-2 compares the Business as Usual with Mid-low Demand and Energy Growth Rates (BAUMLDE) scenario’s estimated retail rate to the current retail rate. This is done by using the rate components to illustrate what is driving the overall estimated decrease of $11 to the average residential ratepayer’s annual electricity costs.23 The BAUMLDE is the only scenario where we find an estimated retail rate marginally lower than the current MISO retail rate. Two factors contribute to this lower rate:

1) The lower demand growth rate will require fewer new capacity resources, though there are 23,900 MW of wind and solar resources added to meet the state renewable mandates.

2) The increased output of renewable resources, which typically have no fuel costs, and therefore very low production costs, from 8 percent of output in 2011 to 16 percent in 2026, reduces generation production cost.

Rate component

Generation capital24

Generation production

Transmission Distribution Total

MISO current retail rate (cents per kWh2011 dollars)

3.30 2.20 0.62 2.61 8.72

BAUMLDE future retail rate (cents per kWh2011 dollars)

3.63 1.66 0.71 2.61 8.62

Percentage change in projected retail rate

10.1 percent

-24.4 percent

16.1 percent - -1.2

percent

Projected change in avg. residential rate payer’s annual electricity bill

$39.96 $(64.26) $11.89 - $ (12.40)

Table 2.6-2: Comparison of BAUMLDE future retail rate to current

23 Residential annual electricity costs calculated assuming average monthly usage of 1,000 kWh. 24 Generation Capital includes both annual capital charges and fixed O&M expenses.


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Table 2.6-3 below compares the Business as Usual with Historic Demand and Energy Growth Rates (BAUHDE) scenario estimated retail rate to the MISO current retail rate to illustrate which component is influencing the overall estimated annual increase of $23 to the average residential ratepayer’s electricity costs. The increase in generation capital and transmission in the BAUHDE scenario is in part driven by the need to meet the state renewable mandates included in the study. To meet the current state RPS mandates in the MISO footprint, an additional 26,800 MW of wind and solar resources are added through 2026. Offsetting the increase in generation and transmission investment is a reduction in generation production costs as low cost renewable resources deliver an increasing share of total energy, accounting for 8 percent of output in 2011 and increasing to 16 percent in 2026.

Rate component

Generation capital



MISO current retail rate (cents per kWh 2011 dollars)

3.30 2.20 0.62 2.61 8.72

BAUHDE future retail rate (cents per kWh 2011 dollars )

3.58 2.07 0.65 2.61 8.91


8.4 percent -6.0 percent 5.8 percent - 2.1

percent

Projected change in avg. residential rate payer’s annual

electricity bill $33.33 $ (15.76) $ 4.29 - $21.86

Table 2.6-3: Comparison of BAUHDE future retail rate to current


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Table 2.6-4 below compares the estimated rate under the Carbon Constraint scenario, which targets a 25 percent reduction in CO2 emissions by 2026 from 2005 levels, leading to an estimated 15 percent increase over the current MISO retail rate, equating to a $155 increase over the current residential ratepayer’s annual electricity costs.

In the Carbon Constraint scenario, there is approximately 21,600 MW of resources retired to achieve required carbon reduction levels. However, due to the very low effective demand growth rate after considering demand response, only 10,000 MW of non-renewable generation is added. Approximately 21,000 MW of renewable resources are added to meet the state RPS mandates. This additional 31,000 MW of resources is driving the 28 percent increase in the generation capital component of the carbon constraint scenario compared to the current retail rate.

One of the drivers for the 9 percent increase in the generation production component is the increase in energy served by natural gas fueled resources -- from 2 percent in 2011 to 18 percent in 2026. For the transmission component, note that while the percentage increase is much higher than for the BAUMLDE and BAUHDE scenarios, this does not represent an increase in transmission investment, since the same level of transmission investment is assumed for all scenarios. The energy growth rate is lower, so the cost per kWh is higher, and the transmission costs are spread over less energy.

Rate component

Generation capital



MISO current retail rate (cents per kWh2011

dollars) 3.30 2.20 0.62 2.61 8.72

Carbon Cap Constraint future retail rate (cents per kWh2011 dollars)

4.20 2.38 0.82 2.61 10.02


27.5 percent 8.5 percent 30.1 percent - 14.6

percent

Projected change in average residential rate

payer’s annual electricity bill

$108.63 $ 22.37 $22.22 - $153.23

Table 2.6-4: Comparison of Carbon Constraint future retail rate to current


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Table 2.6-5 below compares the Combined Energy Policy estimated retail rate - including a 20 percent Federal RPS, carbon constraint, smart grid investment and increased electric vehicle usage - to the MISO current retail rate by rate component. This illustrates the drivers of the overall estimated increase of 19

percent, equating to a $196 increase for the average residential ratepayer’s annual electricity cost.

Similar to the Carbon Constraint future, the Combined Energy Policy future assumes the retirement of 24,500 MW of generation resources to achieve the 25 percent reduction in carbon emissions from 2005 levels by 2026. The estimated 43 percent increase in the generation capital component is driven by the 43,200 MW of new resources, including 28,800 MW of new wind generation to meet the 20 percent Federal RPS.

For the generation production component, the increased usage of natural gas resources for the Combined Energy Policy scenario (from 2 percent of energy served in 2011 to

18 percent in 2026) is slightly less than for the Carbon Constraint Future. That’s likely due to the increased percentage of energy served by low-production cost wind generation -- from 8 percent in 2011 to 21 percent in 2026.

Rate Component

Generation capital



MISO current retail rate (cents per kWh 2011 dollars)

3.30 2.20 0.62 2.61 8.72

Combined energy policy future retail rate (cents

per kWh 2011 dollars)

4.70 2.30 0.75 2.61 10.34


42.5 percent 4.6 percent 18.6 percent - 18.6 percent

Projected change in average

residential rate payer’s

annual electricity bill

$168.35 $ 12.25 $13.76 - $194.35

Table 2.6-5: Comparison of combined energy policy future retail rate to current

The range of outcomes illustrates the importance of performing long-term scenario analyses to provide decision-makers with the information needed to minimize rate increases to customers.


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Potential rate impacts from the four future scenarios demonstrate that higher electricity rates are likely. The magnitude of the increase will vary, depending on actual economic and policy situations. The range of outcomes illustrates the importance of performing long-term scenario analyses to provide decision-makers with the information needed to minimize rate increases to customers.

MISO Transmission Expansion Plan 2011 Section 3 – Historical MTEP plan status

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3. Historical MTEP plan status This section provides an update on the implementation of projects approved in the MISO Transmission Expansion Plan (MTEP) - and furnishes a historical perspective of all past MTEP approved plans. These projects were approved by the MISO Board of Directors in previous MTEP cycles or are recommended for approval in MTEP11. Any given MTEP Appendix A contains newly approved projects, along with previously approved projects not in service when the MTEP Appendices were prepared.

3.1 MTEP10 status report MISO transmission planning responsibilities include monitoring progress and implementation of essential expansions identified in the MTEP. The MISO Board of Directors approved the last MTEP (MTEP10) in December 2010. This section provides a review of the status of previously approved projects listed in MTEP 10 Appendix A.

The MISO Board of Directors has been receiving quarterly updates on the status of active plans since December 2006. The information in this report reflects the 2nd Quarter of 2011 status report to the Board of Directors, which included status on MTEP10 Appendix A projects through June 30, 2011.

Tracking the progress of projects ensures a good faith effort to move projects forward, as prescribed in the Transmission Owner’s agreement. Most approved projects do move forward, despite possible complications, such as equipment procurement delays, construction difficulties and regulatory processes taking longer than anticipated. A project is only considered ‘off-track’ if MISO cannot determine a reasonable cause for delays, as described above. These approved MTEP projects have completed the planning process and are the solution to Transmission System issues. They may be driven by reliability issues, Transmission Service requests, Generation Interconnection requests or market flow constraints. More than half of the MTEP Appendix A projects is comprised of multiple facilities.

MTEP10 Appendix A has 586 projects comprised of 1,025 facilities. These figures have been updated to reflect the progress of members’ projects. MTEP10 Appendix A includes expansion facilities through 2020. A total of 99 percent of the approved facilities included in MTEP10 are in service, on track or have encountered reasonable delays. That translates to $4.680 billion of the $4.727 billion included in MTEP10 Appendix A.

There were 101 in-service date adjustments to projects. Little or no impact on reliability is expected because in-service date adjustments were primarily driven by the economic slowdown. Transmission Owners may adjust project in-service dates to match system needs.

Withdrawn projects should be examined to ensure the planning process of MISO and its members address required system additions, and there was a good reason for withdrawing the project, or a different project covers the need. MTEP10 Appendix A contains projects approved in past MTEPs not yet in service, so withdrawn facilities may have been approved in prior MTEPs but withdrawn after MTEP10 was approved. There were 33 facilities (3 percent of 1025) withdrawn for the following reasons:

The customer’s plans changed or the service request was withdrawn.

The plan was replaced with another plan.

The plan was redefined to better meet the needs.

The load forecast dictated that the project was no longer needed.

All withdrawn facilities were withdrawn for valid reasons. The majority were cancelled because service requests were withdrawn or load forecast was reduced.


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3.2 MTEP implementation history This section encompasses the implementation and status of all approved MTEP plans, including the current MTEP plan. A historical perspective shows extensive variability in transmission plan development. This is normal, caused by the long development time of transmission plans and the regular and periodic updating of the transmission plans.

Refer to Figure 3.2-1, which depicts cumulative investment dollars for projects, categorized by plan status, for MTEP03 through the current MTEP11 cycle. MTEP11 data depicted in Figure 3.2-1, subject to Board approval, is from the current MTEP study and will be added to the data tracked by the MISO Board of Directors. The steady increase in planned facilities testifies to the coordinated planning efforts of MISO and its Transmission Owners. These statistics include only MISO members who participated in this planning cycle.

Since MTEP03 $4.4 billion of approved projects have been constructed and are in service. $199 million of MTEP projects are currently flagged as being under construction. However, there

are over $900 million of projects with expected in service dates in 2011. $9.3 billion of MTEP projects are currently planned. Since MTEP03 $480 million of MTEP projects have been withdrawn.

Figure 3.2-1: Cumulative approved investment by facility status


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Figure 3.2-2 depicts MTEP project investment by facility status for each MTEP iteration. The historical perspective shows extensive variability in development. This is caused by the long development time of transmission plans and the regular and periodic updating of the transmission plans. The irregular shape of the graph represents the maturation of the MTEP process, and demonstrates the good faith effort of MISO Transmission Owners to implement the approved plan.

MTEP06 and MTEP07 were approved in the same calendar year, which accounts for the comparatively small number of projects in MTEP07.

In MTEP08, the number of developing needs increased the number of planned projects, including several large upgrades.

MTEP09 was a year for analysis and determination of the best plans to serve those needs. The in-service category can be seen increasing in past MTEPs as projects are built.

MTEP10 contains significant adjustments for reduced load forecasts and presents a transmission planning approach driven by proposed Multi Value Projects (MVPs), an adaptable rather than fixed methodology, which takes into account market and policy uncertainties and defines an array of multiple facility scenarios capable of performing well no matter what the future holds, integrating mandated renewable energy sources and providing market benefits.

MTEP11 contains most of the proposed Multi Value Project (MVP) portfolio which is comprised of approximately $5.1 billion in transmission investment.

Figure 3.2-2: Approved MTEP investment by facility status.

MISO Transmission Expansion Plan 2011 Section 4 – Regional energy policy studies

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4. Regional energy policy studies

4.1 Proposed Multi Value Project portfolio MISO staff recommends that the proposed Multi Value Project (MVP) portfolio be approved by the MISO Board of Directors for inclusion into Appendix A of MTEP11. This recommendation is based on the strong reliability, public policy and economic benefits of the portfolio that are distributed across the MISO footprint in a manner that is commensurate with the portfolio’s costs. In short, the proposed portfolio will:

Provide benefits in excess of its costs under all scenarios studied, with its benefit to cost ratio ranging from 1.8 to 3.0.

Maintain system reliability by resolving reliability violations on approximately 650 elements for more than 6,700 system conditions and mitigating 31 system instability conditions.

Enable 41 million MWh of wind energy per year to meet renewable energy mandates and goals. Provide an average annual value of $1,279 million over the first 40 years of service, at an

average annual revenue requirement of $624 million. Support a variety of generation policies by using a set of energy zones which support wind,

natural gas and other fuel sources. This report summarizes the key reliability, public policy and economic benefits of the proposed MVP portfolio, as well as the scope of the analyses used to determine these benefits. Additional information on the portfolio and study analyses will be available in the full MVP portfolio report, which is scheduled to be published in October 2011.

Figure 4.1-1: Proposed MVP portfolio


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The proposed MVP portfolio includes the Brookings Project, conditionally approved in June 2011, and the Michigan Thumb Loop project, approved in August 2010. It also includes 15 additional projects which, when integrated into the transmission system, provide multiple kinds of benefits under all studied future scenarios25.

Project State Voltage (kV)

In Service Year

Cost (M,

2011$)26

1 Big Stone–Brookings SD 345 2017 $191

2 Brookings, SD–SE Twin Cities MN/SD 345 2015 $695

3 Lakefield Jct. Winnebago–Winco–Burt area &

Sheldon–Burt area–Webster MN/IA 345 2016 $506

4 Winco–Lime Creek–Emery–Blackhawk–Hazleton IA 345 2015 $480

5 N. LaCrosse–N. Madison–Cardinal & Dubuque Co.–Spring Green–Cardinal

WI 345 2018/2020 $714

6 Ellendale–Big Stone ND/SD 345 2019 $261

7 Adair–Ottumwa IA/MO 345 2020 $152

8 West Adair–Palmyra Tap MO/IL 345 2020 $98

9 Palmyra–Quincy–Merdosia–Ipava &

Meredosia–Pawnee IL 345 2017 $392

10 New Pawnee–Pana IL 345 2018 $88

11 Pana–Mt. Zion–Kansas–Sugar Creek IL/IN 345 2019 $284

12 Reynolds–Burr Oak–Hiple IN 345 2019 $271

13 Michigan Thumb Loop expansion MI 345 2015 $510

14 New Reynolds–Greentown IN 765 2018 $245

15 Pleasant Prairie–Zion Energy Center WI/IL 345 2014 $26

16 Fargo–Oak Grove IL 345 2019 $193

17 Sidney–Rising IL 345 2016 $90

Total $5,197

Table 4.1-1: Proposed MVP portfolio

25 More information on these scenarios may be found in the business case description. 26 Costs shown are inclusive of transmission underbuild upgrades and upgrades driven by short circuit requirements.


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Public policy decisions over the last decade have driven changes in how the transmission system is planned. The recent adoption of Renewable Portfolio Standards (RPS) and clean energy goals across the MISO footprint have driven the need for a more regional and robust transmission system to deliver renewable resources from often remote renewable energy generators to load centers.

Figure 4.1-2: Renewable energy mandates and clean energy goals within the MISO footprint27

Beginning with the MTEP03 Exploratory Studies, MISO and stakeholders began to explore how to best provide a value added regional planning process to complement the local planning of MISO members. These explorations continued in later MTEP cycles and in specific targeted studies. In 2008, MISO, with the assistance of state regulators and industry stakeholders such as the Midwest Governor’s Association (MGA), the Upper Midwest Transmission Development Initiative (UMTDI) and the Organization of MISO States (OMS), began the Regional Generation Outlet Study (RGOS) to identify a set of value based transmission portfolios necessary to enable Load Serving Entities (LSEs) to meet their RPS mandates. The goal of the RGOS analysis was to design transmission portfolios that would enable RPS mandates to be met at the lowest delivered wholesale energy cost. The cost calculation combined the expenses of the new transmission portfolios with the capital costs of the new renewable generation, balancing the trade offs of a lower transmission investment to

27 Existing and planned wind as included in the Candidate MVP Portfolio. State RPS mandates and goals include all policies signed into law by June 1, 2011.

The recent adoption of Renewable Portfolio Standards (RPS) across the MISO footprint have driven the need for a more regional and robust transmission system to deliver renewable resources from often remote renewable energy generators to load centers.


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deliver wind from low wind availability areas, typically closer to large load centers; against a larger transmission investment to deliver wind from higher wind availability areas, typically located further from load centers. While much consideration was given to wind capacity factors when developing the energy zones utilized in the RGOS and Candidate MVP Portfolio Analyses, the zones were chosen with consideration of more factors than wind capacity. Existing infrastructure, such as transmission and natural gas pipelines, also influenced the selection of the zones. As such, although the energy zones were created to serve the renewable generation mandates, they could be used for a variety of different generation types, to serve various future generation policies. Figure 4.1-3 depicts the correlation between the natural gas pipelines in the MISO footprint and the energy zones.

Figure 4.1-3: RGOS and Candidate MVP Incremental Energy Zones and natural gas pipelines

The zones were chosen with consideration of more factors than wind capacity. Existing infrastructure, such as transmission and natural gas pipelines, also influenced the selection of zones.


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The RGOS analysis produced three reliable transmission portfolios. Elements common between these three portfolios, and common with previous reliability, economic and generation interconnection analyses, were identified to create the 2011 Candidate MVP portfolio. This portfolio represented a set of “no regrets” projects which were believed to provide multiple kinds of reliability and economic benefits under all alternate futures studied.

The 2011 Candidate MVP Portfolio Analysis hypothesized that this set of candidate projects creates a high value transmission portfolio, enabling MISO states to meet their near term RPS mandates. This study evaluated the Candidate MVP portfolio against the MVP cost allocation criteria to prove or disprove this hypothesis, as well as to confirm that the benefits of the portfolio would be widely distributed across the footprint. The output from the study,

a proposed MVP portfolio, will reduce the wholesale cost of energy delivery for the consumer by enabling the delivery of low cost generation to load, reducing congestion costs and increasing system reliability, regardless of the future generation mix.

Over the course of the Candidate MVP Portfolio Analysis, the MVP portfolio was refined into the proposed portfolio that is now recommended to the MISO Board of Directors for approval. The portfolio was refined to ensure that the portfolio as a group and each project contained within it was justified under the MVP criteria, discussed below, and to ensure that the portfolio benefit to cost ratio was optimized.

Figure 4.1-4: Candidate versus proposed MVP portfolio

The output from the study, a proposed MVP portfolio, will reduce the wholesale cost of energy delivery for the consumer by enabling the delivery of low cost generation to load, reducing congestion costs and increasing system reliability, regardless of the future generation mix.


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The proposed MVP portfolio will enable the delivery of the renewable energy required by public policy mandates, in a manner more reliable and economic than it would be without the associated transmission upgrades. Specifically, the portfolio mitigates approximately 650 reliability constraints under 6,700 different transmission outage conditions, for steady state and transient conditions under both peak and shoulder load scenarios. Some of these conditions could be severe enough to cause cascading outages on the system. By mitigating these constraints, approximately 41 million GWh per year of renewable generation can be delivered to serve the MISO state renewable portfolio mandates.

Under all future policy scenarios studied, the proposed MVP portfolio delivers widespread regional benefits to the transmission system. For example, based on scenarios that did not consider new energy policies, the benefits of the proposed portfolio were shown to range from 1.8 to 3.0 times its total cost.

Figure 4.1-5: Proposed MVP portfolio benefits spread

Additionally, these benefits are spread across the system, in a manner commensurate with their costs. Taking into account the significant economic value created by the portfolio, the distribution of these value,

and the ability of the portfolio to meet MVP criterion 1 through its reliability and public policy benefits, MISO staff recommends the 2011 proposed MVP portfolio to the MISO Board of Directors for their review and approval.

Additional information on the proposed MVP portfolio, and the analyses used to design the portfolio, will be summarized in the full MVP portfolio report. This report will be published later in 2011.

The benefits created by the proposed MVP portfolio are spread across the system, in a manner commensurate with its costs.


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MISO planning approach The goal of the MISO planning process is to develop a comprehensive expansion plan that reflects a fully integrated view of project value inclusive of reliability, market efficiency, public policy and other value drivers across all planning horizons. This process is guided by a set of principles established by the MISO Board of Directors, adopted on August 18, 2005. The principles were created in an effort to improve and guide transmission investment in the region and to furnish an element of strategic direction to the MISO transmission planning process. These principles, modified and approved by the MISO Board of Directors System Planning Committee on May 16, 2011, are:

Guiding Principle 1: Make the benefits of an economically efficient energy market available to customers by providing access to the lowest electric energy costs.

Guiding Principle 2: Provide a transmission infrastructure that safeguards local and regional reliability and supports interconnection-wide reliability.

Guiding Principle 3: Support state and federal energy policy objectives by planning for access to a changing resource mix.

Guiding Principle 4: Provide an appropriate cost mechanism that ensures the realization of benefits over time is commensurate with the allocation of costs.

Guiding Principle 5: Develop transmission system scenario models and make them available to state and federal energy policy makers to provide context and inform the choices they face.

A number of conditions must be met to build longer term transmission able to support future generation growth and accommodate new energy policies. These conditions are intertwined with the planning principles put forth by the MISO Board of Directors and supported by an integrated, inclusive transmission planning approach. The conditions that must be met to build transmission include:

A robust business case that demonstrates value sufficient to support the construction of the transmission project.

Increased consensus on current and future energy policies. A regional tariff that matches who benefits with who pays over time. Cost recovery mechanisms that reduce financial risk.

Multi Value Project portfolio drivers The 2011 Candidate MVP Portfolio Analysis was based on the need to economically and reliably help states meet their public policy needs. The study identified a regional transmission portfolio that will enable the MISO Load Serving Entities (LSEs) to meet their Renewable Portfolio Standards (RPS). The analyses and their results describe a robust business case for the portfolio. This business case demonstrates that not only will the proposed MVP portfolio reliably enable Renewable Portfolio Standards to be met, but it will do so in a manner where its economic benefits exceed its costs.

While the study focused upon the RPS requirements, the transmission portfolio will ultimately have widespread benefits beyond the delivery of wind and other renewable energy. It will enhance system reliability and efficiency under a variety of different generation build outs. It will also open markets to competition, reducing congestion and spreading the benefits of low cost generation across the MISO footprint. The Candidate MVP Portfolio Analysis focused on identifying and increasing the benefits of the transmission portfolio, including the reliability, economic and public policy drivers.


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Tariff requirements The Candidate MVP Portfolio Analysis and the recommendation of the proposed MVP portfolio were premised on the MVP criteria described in Attachment FF of the MISO Tariff and shown below.

Criterion 1

A Multi Value Project must be developed through the transmission expansion planning process to enable the transmission system to deliver energy reliably and economically in support of documented energy policy mandates or laws enacted or adopted through state or federal legislation or regulatory requirement. These laws must directly or indirectly govern the minimum or maximum amount of energy that can be generated. The MVP must be shown to enable the transmission system to deliver such energy in a manner that is more reliable and/or more economic than it otherwise would be without the transmission upgrade.

Criterion 2

A Multi Value Project must provide multiple types of economic value across multiple pricing zones with a Total MVP benefit to cost ratio of 1.0 or higher, where the total MVP benefit to cost ratio is described in Section II.C.7 of Attachment FF to the MISO Tariff. The reduction of production costs and the associated reduction of LMPs from a transmission congestion relief project are not additive and are considered a single type of economic value.

Criterion 3

A Multi Value Project must address at least one transmission issue associated with a projected violation of a NERC or Regional Entity standard and at least one economic based transmission issue that provides economic value across multiple pricing zones. The project must generate total financially quantifiable benefits, including quantifiable reliability benefits, in excess of the total project costs based on the definition of financial benefits and Project Costs provided in Section II.C.6 of Attachment FF.

The MVP cost allocation criteria requires evaluation of the portfolio on a reliability, economic and energy delivery basis. The scope of the analysis was designed to demonstrate this value, both on a project and portfolio basis. The projects in the MVP portfolio were evaluated against MVP criteria 1 and their ability to reliably enable the renewable energy mandates of the MISO states was quantified.

In addition, the Tariff identifies specific types of economic value which can be provided by Multi Value Projects. These values are:

Production cost savings where production costs include generator startup, hourly generator no-load, generator energy and generator Operating Reserve costs. Production cost savings can be realized through reductions in both transmission congestion and transmission energy losses. Productions cost savings can also be realized through reductions in Operating Reserve requirements within Reserve Zones and, in some cases, reductions in overall Operating Reserve requirements for the Transmission Provider.

Capacity losses savings where capacity losses represent the amount of capacity required to serve transmission losses during the system peak hour including associated planning reserve.

Capacity savings due to reductions in the overall Planning Reserve Margins resulting from transmission expansion.

Long-term cost savings realized by Transmission Customers by accelerating a long-term project start date in lieu of implementing a short-term project in the interim and/or long-term cost savings realized by Transmission Customers by deferring or eliminating the need to perform one or more projects in the future.


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Any other financially quantifiable benefit to Transmission Customers resulting from an enhancement to the transmission system and related to the provisions of Transmission Service.

The full proposed portfolio was evaluated against the benefits defined in the Tariff for MVP projects. In addition to the benefits described above, the operating reserve and wind siting benefits for the portfolio were quantified, as allowed under the last Tariff defined economic value. These benefits are described more fully in the economic benefit section later in the report.

Public policy needs Twelve of 13 states in the MISO footprint have enacted either RPS requirements or renewable energy goals which require or recommend varying amounts of load be served with energy from renewable energy resources. The Candidate MVP Portfolio Analysis focused on the transmission necessary to economically and reliably meet the state RPS mandates. Figure 4.1-6 below provides additional details on these renewable energy requirements and goals.

Figure 4.1-6: RPS mandates and goals within the MISO footprint

RPS mandates vary from state to state in their specific requirement details and implementation timing, but they generally start in about 2010 and are indexed to increase with load growth. While state laws support a number of different types of renewable resources, and multiple types of renewable resources will play a role in meeting state RPS mandates, the majority of renewable energy resources installed in the foreseeable future will likely focus on harnessing the abundant wind resources throughout the MISO footprint.


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Enhanced reliability and economic drivers The ultimate goal of the MISO planning process is to reliably deliver energy to load at the lowest possible cost. This requires a strategy premised upon a low cost approach to transmission and generation investment. This premise supports the overall constructability of the transmission portfolio, while reducing financial risk associated with overbuilding the system.

Transmission strategy A transmission strategy addressing both local needs and regional drivers allows the MISO system to realize significant economic and reliability benefits. Regional transmission, such as the transmission in the proposed MVP portfolio, increases reliability in the MISO footprint, opens the market to increased competition and provides access to low cost generation, regardless of fuel type. Development of a strong regional transmission backbone is analogous to the development of the U.S. Interstate Highway System. While developed for specific wartime reasons, the system has realized significant additional benefits in subsequent years. Similarly, the proposed MVP portfolio will create reliability, economic and public policy benefits that reach beyond the immediate needs exhibited in this analysis.

The overall goal for the Candidate MVP Portfolio Analysis was to design a transmission portfolio which takes advantage of the linkages between local and regional reliability and economic benefits to bring value to the entire MISO system. The portfolio was designed using reliability and economic analyses, applying several futures scenarios to determine the robustness of the designed portfolio under a number of future potential energy policies.

Development of the Candidate MVP portfolio In order to provide widespread benefits commensurate with costs, MISO developed an initial portfolio of candidate MVP projects that were hypothesized to provide widespread benefits across the footprint. The projects selected as candidates for possible inclusion in the broader portfolio were then intensively evaluated in the Candidate MVP Portfolio Analysis to ensure they were justified and contributed to the portfolio business case.

The goal of the Candidate MVP Portfolio Analysis was to design a transmission portfolio which takes advantage of the linkages between local and regional reliability and economic benefits to bring value to the entire MISO system.


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Figure 4.1-7: Initial 2011 Candidate MVP portfolio

The Candidate MVP portfolio was the first portfolio developed for review under the recent Tariff revisions establishing the MVP cost allocation classification. It was developed by considering regional system enhancements that could potentially provide multiple types of value, including enhanced reliability, reduced congestion, increased market efficiency, reduced real power losses and the deferral of otherwise needed capital investments in transmission. The portfolio was designed to enhance and complement the existing system performance, working cohesively with the individual elements of the portfolio and with the existing transmission grid, to produce a more robust and efficient system. Ultimately, the first portfolio represents a set of “no regrets” projects, providing benefits to the system in all futures scenarios studied.

Historical studies MISO began to investigate the transmission required to integrate wind and provide the best value to consumers in 2002. The analyses continued through subsequent MTEP cycles, with exploratory and energy market analyses. As the demand for renewable energy grew, driven largely by an increasing level of renewable energy mandates or goals, additional regional studies were conducted to determine the transmission necessary to support these policy objectives. These studies included the Joint and Coordinated System Plan (JCSP), the Regional Generation Outlet Studies (RGOS), and analyses by the Organization of MISO States (OMS) Cost Allocation and Regional Planning (CARP) group.


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Figure 4.1-8: Prior study input into Candidate MVP portfolio

As analyses continued, the policy and economic drivers behind a regional transmission plan continued to grow. This growth was partly fueled by the development of the MISO energy and operating reserve market, which allows for regional transmission to provide regional benefits through increasing market efficiency, enabling low cost generation to be delivered to load. Simultaneously, an increase in state energy policy mandates drove the need for a robust regional transmission network, capable of responding to legislated changes in generation requirements.


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Wind siting strategy As an increasing number of states in the MISO footprint began to enact renewable energy mandates or goals, a strategy for siting wind generation was required to minimize the cost of delivered energy to consumers. To determine the low cost solution, encompassing generation and transmission capital cost, MISO developed a set of potential energy zones or locations where wind generation could feasibly be located, on a state by state basis28. In conjunction with state regulators and other stakeholders, MISO used these zones to explore a number of long term transmission and generation strategies to meet the state RPS requirements. These analyses focused on the tradeoffs between local wind generation, which typically requires less transmission expansion but a larger amount of wind turbines to deliver a given amount of wind energy; versus regional wind generation, which requires fewer wind turbines at the cost of higher levels of transmission expansion.

Figure 4.1-9: Capital costs of transmission and generation

28 More information on the zone development may be found in the RGOS report at http://www.midwestiso.org/Library/Repository/Study/RGOS/Regional percent20Generation percent20Outlet percent20Study.pdf.


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The study results demonstrated that the low cost approach to wind generation siting, when both generation and transmission capital costs are considered, is a combination of local and regional wind generation locations, as shown by the white area in Figure 4.1-9. This approach was affirmed by the Midwest Governors’ Association as the best method for wind zone selection and used as the basis for the final phase of the RGOS analysis in 2010. It was also used as the basis for the wind siting approach for the Candidate MVP Portfolio Analysis. The set of energy zones chosen for the Candidate MVP Portfolio Analysis are shown below in Figure 4.1-10 as blue ovals.

Figure 4.1-10: Candidate MVP Incremental Energy Zones29

29 Zones shown represent the rough geographic area of each energy zone.


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Candidate MVP Portfolio Analysis study scope The Candidate MVP Portfolio Analysis combined the MISO Board of Director Planning Principles and the conditions precedent to transmission construction to develop a transmission portfolio that meets public policy, economic and reliability requirements. The analysis built a robust business case for the recommended transmission, using the newly created Multi Value Project (MVP) cost allocation methodology approved by FERC. The candidate transmission was tested against a variety of potential policy futures. This maximized the value of the transmission portfolio and reduced potential negative risks associated with its construction due to changes in future demand and energy growth. The output of the study was a justified portfolio of proposed MVPs for inclusion in MTEP11 Appendix A and, if approved by the MISO Board of Directors, subsequent construction.

The MVP cost allocation criteria requires the evaluation of the portfolio on a reliability, economic and energy delivery basis. The analyses were designed to demonstrate this value, both on a project and portfolio basis. To this end, the Candidate MVP Portfolio Analysis included the studies and output shown in table 4.1-2.

These analyses focused on three main areas. The project valuation analyses focused on justifying each individual MVP project against the MVP criteria. The portfolio valuation analyses determined the benefits of the portfolio in aggregate, quantifying additional reliability and economic benefits. Finally, a series of system performance analyses were performed to ensure that the system reliability will be maintained with the proposed MVP portfolio in service.

The MVP cost allocation criterion requires the evaluation of the portfolio on a reliability, economic and energy delivery basis.


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Analysis Type Analysis Output Purpose

Steady state List of thermal overloads mitigated by the proposed MVP portfolio transmission projects

Project valuation

Alternatives Relative value of the candidate MVP projects against a stakeholder or MISO identified alternative Can include steady state and production cost analyses

Project valuation

Underbuild requirements

Document any incremental transmission required to mitigate constraints created by the addition of the proposed MVP portfolio

System performance

Short circuit Document any incremental upgrades required to mitigate any short circuit / breaker duty violations

System performance

Stability List of violations mitigated by the proposed MVP portfolio transmission projects Includes both transient and voltage stability analysis

System performance / Portfolio valuation

Generation enabled

Document wind curtailed, and additional wind that is enabled by the proposed MVP portfolio

Portfolio valuation

Production cost Adjusted Production Cost (APC) benefits of the entire proposed MVP portfolio

Portfolio valuation

Robustness testing

Quantification of portfolio benefits under various policy futures or transmission conditions

Portfolio valuation

Operating reserves Impact

Impact of the proposed MVP portfolio on existing operating reserve zones and quantification of this benefit

Portfolio valuation

Planning Reserve Margin (PRM) benefits

Capacity savings due to reductions in the system wide Planning Reserve Margin caused by the addition of the proposed MVP portfolio to the transmission system

Portfolio valuation

Transmission loss reductions

Capacity losses savings, where capacity losses represent the amount of capacity required to serve transmission losses during the system peak hour

Portfolio valuation

Wind generation capital investment

Quantification of the incremental wind generator capital cost savings enabled by the wind siting methodology supported by the proposed MVP portfolio

Portfolio valuation

Avoided capital investment (transmission)

Document the future baseline transmission investment that may be avoided due to the installation of the proposed MVP portfolio

Portfolio valuation

Table 4.1-2: Candidate MVP Portfolio Analyses and Output


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Proposed MVP portfolio overview

Figure 4.1-11: 2011 proposed MVP portfolio


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The proposed MVP portfolio consists of 17 projects spread across the MISO footprint. These projects work together with the existing transmission network to enhance the reliability of the system, support public policy goals and enable the more efficient dispatch of market resources. Table 4.1-3 below describes the projects that make up the proposed MVP portfolio.

Project State Voltage (kV)

In Service Year

Cost (M,

2011$)

1 Big Stone–Brookings SD 345 2017 $191

2 Brookings, SD–SE Twin Cities MN/SD 345 2015 $695

3 Lakefield Jct. –Winnebago–Winco–Burt area &

Sheldon–Burt area–Webster MN/IA 345 2016 $506

4 Winco–Lime Creek–Emery–Blackhawk–Hazleton IA 345 2015 $480

5 N. LaCrosse–N. Madison–Cardinal & Dubuque Co. –Spring Green–Cardinal

WI 345 2018/2020 $714

6 Ellendale–Big Stone ND/SD 345 2019 $261

7 Adair–Ottumwa IA/MO 345 2020 $152

8 West Adair–Palmyra Tap MO/IL 345 2020 $98

9 Palmyra–Quincy–Merdosia–Ipava &

Meredosia–Pawnee IL 345 2017 $392

10 New Pawnee–Pana IL 345 2018 $88

11 Pana–Mt. Zion–Kansas–Sugar Creek IL/IN 345 2019 $284

12 Reynolds–Burr Oak–Hiple IN 345 2019 $271

13 Michigan Thumb Loop Expansion MI 345 2015 $510

14 New Reynolds–Greentown IN 765 2018 $245

15 Pleasant Prairie–Zion Energy Center WI/IL 345 2014 $26

16 Fargo–Oak Grove IL 345 2019 $193

17 Sidney–Rising IL 345 2016 $90

Total $5,197

Table 4.1-3: Proposed MVP portfolio


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Reliability benefits and analyses The proposed MVP portfolio maintains system reliability by resolving violations on approximately 650 transmission elements for more than 6,700 system conditions. It also mitigates 31 system instability conditions. More information on these constraints can be found in Appendix E4, and a full write up of the analyses will be included in the full MVP portfolio report. A description of the reliability analysis results follows in the next section.

Steady state A series of steady state analyses were conducted to determine the transmission line overloads and system voltage constraints mitigated by the proposed MVP portfolio. The primary steady state analysis was performed on a set of 2021 shoulder peak models, with both 2021 and 2026 mandated wind levels considered. Shoulder peak models were chosen for the primary analysis, as the high wind levels required by the renewable portfolio mandates are more likely to create system constraints under these conditions. A 2021 peak analysis was also conducted to ensure the full reliability benefits of the proposed portfolio were captured. Each set of analyses were performed on: 1) a model with the RPS mandated wind, without any incremental transmission; 2) a model with the RPS mandated wind and the MVP portfolio. The results from the two analyses were compared to determine what constraints were mitigated by the proposed MVP portfolio.

A total of 384 thermal overloads were mitigated by the proposed MVP portfolio under shoulder peak conditions, for approximately 4,600 system conditions. In addition, approximately 100 additional thermal overloads and 150 voltage violations were mitigated by the proposed MVP portfolio in the summer peak analysis.

Stability Transient Stability

MISO performed a set of transient stability analyses to ensure the ability of existing and proposed generation to remain synchronous with other system generation under severe fault conditions, as required by NERC and regional reliability standards. Two scenarios were studied to evaluate the impact of major fault conditions without any voltage or damping criteria violations. The first scenario included all the incremental wind zones with none of the proposed MVPs portfolio modeled, and the second scenario included incremental wind zones and the proposed MVP portfolio.

Based on the comparative analysis involving simulation of approximately 650 fault conditions under both scenarios, there were 31 fault conditions that without the proposed MVP portfolio would cause the system to experience undamped oscillations, causing generators to trip offline or incur damage due to high speed rotation, creating safety risks for plant personnel and potentially causing a large scale loss of load. These conditions were resolved by the addition of the proposed MVP portfolio to the system, and no additional stability violations were determined with the MVP portfolio in service.

The proposed MVP portfolio maintains system reliability by resolving violations on approximately 650 transmission elements for more than 6,700 system conditions.


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Voltage Stability Analysis

MISO performed voltage stability analyses to identify voltage collapse conditions under high energy transfer conditions from major generation resources to major load sinks. Such transfers may occur during critical dispatch scenarios, such as when local area generation near large load centers are offline and remote generation resources are supplying energy to the load centers. Two scenarios were studied to evaluate the incremental energy transfer capability. The first scenario included all the incremental wind zones with none of the proposed MVP portfolio modeled, and the second scenario included all the incremental wind zones and the proposed MVP portfolio.

MISO did not observe any voltage stability issues with the proposed MVP portfolio in place, and with the high energy transfers corresponding to the highest wind resource output levels. Additionally, the comparative transfer analysis simulated high transfer conditions from the wind rich West Region of the MISO footprint to major load centers such as Minneapolis-St. Paul, Madison, St Louis and Des Moines. The results, shown in Appendix E4, illustrate that the addition of the proposed MVP portfolio causes an increase in transfer capability from wind rich regions to major load centers that ranges from 960 to 1,841 MW. This additional transfer capacity will increase system reliability and robustness, allowing additional energy sources to be dispatched to serve load centers as needed.

Short circuit The addition of significant amounts of new high voltage transmission to the grid can increase the system connectivity, resulting in lowered impedance for short circuit currents. This can cause available fault currents throughout the system to exceed circuit breaker interrupting capabilities. MISO staff and Transmission Owners performed a series of high level short circuit analyses to identify any breaker or substation equipment needing to be upgraded after the addition of the proposed MVP portfolio to the transmission system. These analyses were performed directly by the affected Transmission Owners, with MISO staff providing modeling information for the proposed MVP projects. Any identified circuit breaker upgrades were verified through independent analysis by MISO staff, and their costs were included in the portfolio. Overall, nine circuit breakers were identified for replacement, at a total cost of $2.2 million.


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Underbuild requirements To ensure that the proposed MVP portfolio works well with the existing system to maintain reliability, MISO conducted analyses to determine any constraints that are present with the proposed MVP Portfolio and not present without the proposed portfolio. Any new constraints were identified for mitigations, and the appropriate mitigation was determined in coordination with the impacted Transmission Owners.

Below is a full list of the underbuild upgrades. Overall, approximately $70 million of transmission investment is associated with such underbuild.

Underbuild requirements

Burr Oak to East Winamac 138 kV line uprate

Lake Marian 115/69 kV transformer replacement

Arlington to Green Isle 69 kV line uprate

Columbus 69 kV transformer replacement

Casey to Kansas 345 kV line uprate

Lake Marian to NW Market Tap 69 kV line uprate

Franklin 115/69 kV transformer replacements

Castle Rock to ACEC Quincy 69 kV line uprate

Kokomo Delco to Maple 138 kV line uprate

Wabash to Wabash Container 69 kV line uprate

Spring Green 138/69 kV transformer replacement

Davenport to Sub 85 161 kV line uprate

West Middleton West Towne 69 kV line uprate

Ottumwa Montezuma 345 kV line uprate

Table 4.1-4: Proposed MVP portfolio underbuild requirements

Alternatives assessment To ensure the proposed MVP portfolio provides cost-effective benefits to the MISO system, MISO considered alternatives to the Candidate MVP portfolio. In addition, similar alternatives were also considered in the prior studies which led to the selection of the initial Candidate MVP portfolio.

A “do-nothing” alternative was first considered. This alternative was used as a baseline to determine the system performance in delivering future generation requirements to load. It was demonstrated that, without major additions to the regional transmission system, significant generation curtailment would be required to maintain system reliability. Such a system would lead to heavy system loading conditions, potential instabilities, reduced reliability margins and would limit the ability of the states in the MISO footprint to meet their renewable energy mandates. As such, it was determined that significant system enhancements would be needed to meet renewable energy mandates and maintain system reliability.

An alternative build-out based on a piecemeal resolution of each facility experiencing an overload was considered. Such a plan would build incremental local upgrades to mitigate the reliability issues directly caused by the injection of the mandated wind into the transmission system. This would result in a minimum of 650 transmission projects, as compared to the 17 larger projects that comprise the proposed


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MVP portfolio. MISO does not believe that 650 projects on the existing system could be completed in the same reliable or timely manner as the construction of the proposed MVP portfolio.

Also, this alternative would cost approximately $4.7 billion, based only upon the constraints found in the steady state reliability analysis. Additional investment would most likely be required to mitigate the constraints found in the stability analyses. This alternative would provide much lower benefits to the MISO system, as it does not provide long term solutions that increase the regional transmission capability. This solution would enable less wind to be delivered, endangering the ability of the states in the MISO footprint to meet their renewable energy mandates. It would provide significantly less economic benefits, as the regional values quantified below would be reduced or eliminated.

Figure 4.1-12: Candidate versus proposed MVP portfolio

The final alternative considered was the optimization of a regional transmission solution. Analysis surrounding this alternative began with the creation of the Candidate MVP portfolio, a derivative of the highest value transmission solutions from studies beginning in 2003 and continuing to the present. This candidate portfolio was optimized by evaluating each transmission line separately and in the context of other lines in the portfolio. This optimization included analyses of a different transmission configuration in Iowa, the removal of the Adair to Thomas Hill line, an option to reconfigure the transmission lines across southern Illinois and the removal of the New Reynolds to Sullivan 765 kV line segment from the candidate portfolio. Although not all these changes were found to be justified, the investigations into the proper portfolio configuration increased the reliability, economic and public policy benefits of the final, proposed MVP portfolio.


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Public policy benefits The proposed MVP portfolio was built upon a set of energy zones that, although they can be used for alternative forms of generation, were premised upon a low cost approach to wind generation siting. Through resolving reliability constraints that would otherwise result in the curtailment of wind generation, the proposed MVP portfolio enables the delivery of 41 million MWh of renewable energy annually to support the renewable energy mandates of the MISO states through at least 2026.

Economic benefits Multi Value Projects represent the next step in the evolution of the MISO transmission system: a regional network that, when combined with the existing system, provides value in excess of its costs under a variety of future policy and economic conditions. These benefits are quantified below. More information on the method used to quantify the values can be found in Appendix E5, and a more detailed analysis will be included in the full MVP portfolio report, which will be published later in 2011.

Figure 4.1-13: Proposed MVP portfolio economic benefits

Through resolving reliability constraints that would otherwise result in the curtailment of wind generation, the proposed MVP portfolio enables the delivery of 41 million MWh of renewable energy annually.


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Congestion and fuel savings The proposed MVP portfolio allows for a more efficient dispatch of generation resources, opening markets to competition and spreading the benefits of low cost generation throughout the footprint. These benefits were quantified through a series of production cost analyses, which captured the economic benefits of the proposed MVP transmission and the wind it enables. These benefits reflect the savings achieved through the reduction of transmission congestion costs and through more efficient generation resource utilization.

In order to show the economic benefits of the portfolio under a variety of different potential policy based futures, MISO calculated four sets of Adjusted Production Cost (APC) benefits. The futures analyzed were designed to ‘bookend’ the range of potential future policy outcomes, ensuring that all of the most likely future policy scenarios and their impacts were within the range bounded by the results. The futures analyzed are described below.

Business As Usual with Continue Low Demand and Energy Growth assumes that current energy policies will be continued, with continuing recession level low demand and energy growth projections.

Business As Usual with High Demand and Energy Growth assumes that current energy policies will be continued, with demand and energy returning to pre-recession growth rates

Carbon Constrained assumes that current energy policies will be continued, with the addition of a carbon cap modeled on the Waxman-Markey Bill.

Combined Energy Policy assumes multiple energy policies are enacted, including a 20 percent federal RPS, a carbon cap modeled on the Waxman Markey Bill, implementation of a smart grid and widespread adoption of electric vehicles.

More information on these futures may be found in Appendix E2.

Figure 4.1-14: Proposed MVP portfolio Adjusted Production Cost Benefits

The future scenarios without any new energy policy mandates provide a baseline of the proposed MVP portfolio’s benefits under current policy conditions. Additionally, the evaluation of the Carbon Constrained

$-

$5,000

$10,000

$15,000

$20,000

$25,000

$30,000

$35,000

$40,000

$45,000

Low Demand and Energy Growth Historic Demand and Energy Growth

20 Year Present Value, 8.2% Discount Rate





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and Combined Policy future scenarios provide ‘bookends’ which help show the full range of benefits that may be provided by the portfolio. When the ‘Business as Usual’ future scenarios with no new energy policies were analyzed, the proposed MVP portfolio will produce an estimated $12.4 to $40.9 billion in 20 to 40 year Present Value (PV) Adjusted Production Cost (APC) benefits, depending on the timeframe, discount rate, energy growth rates and demand growth rates considered. This benefit would increase to a maximum present value of $91.7 billion under the Combined Policy future scenario.

Operating reserves In addition to the energy benefits quantified in production cost analyses, the proposed MVP portfolio will also reduce operating reserve costs. The MVPs decrease congestion on the system, increasing the transfer capability into several key areas that would otherwise have to hold additional operating reserves under certain system conditions.

Figure 4.1-15: Operating reserve zones

MISO determined that the addition of the proposed MVP portfolio will eliminate the need for the Indiana operating reserve zone, and the need for additional system reserves to be held in other zones across the footprint would be reduced by half. This creates the opportunity to locate an average of 690,000 MWh of operating reserves annually where it would be most economical to do so, as opposed to holding these reserves in prescribed zones, creating benefits of $28 to $87 million in 20 to 40 year present value terms.


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System planning reserve margin The system planning reserve is calculated by determining the amount of generation required to meet a one day in 10 year Loss of Load Expectation (LOLE). It has two components: the unconstrained system Planning Reserve Margin (PRM), and the congestion contribution. The proposed MVP portfolio reduces transmission congestion across MISO, thereby reducing the system PRM and decreasing the amount of generation needed to maintain the PRM.

Figure 4.1-16: Expected planning reserve margin, with and without congestion

Through reducing the PRM, the proposed MVP portfolio allows the deferral of new generation, creating $1.0 to $5.1 billion in present value benefits, depending on whether a 20 or 40 year present value is considered, as well as the future growth and discount rates.

Transmission line losses The addition of the proposed MVP portfolio to the transmission network reduces overall system losses, reducing the generation needed to serve the combined load and transmission line losses. The energy value of these loss reductions is considered in the congestion and fuel savings benefits, but the loss reduction also helps to reduce future generation capacity needs. Specifically, when installed generation capacity is only just sufficient to meet peak system load plus the planning reserve margin, a reduction in transmission losses creates benefits through reducing the amount of generation that must be built. This creates $111 million to $396 million in present value savings, depending on the timeline of the present value calculations, the discount rate and energy/demand growth rates.


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Wind turbine investment As discussed previously, MISO determined a wind siting approach that results in a low cost solution, when transmission and generation capital costs are considered. This approach sources generation in a combination of local and regional locations, placing wind local to load, where less transmission is required; and regionally, where the wind is the strongest. However, this strategy depends on a strong regional transmission system to deliver the wind energy. Without this regional transmission backbone, the wind generation would have to be sited close to load, requiring the construction of significantly larger amounts of wind capacity to produce the renewable energy mandated by public policy.

Figure 4.1-17: Local versus combination wind siting

In the RGOS study, it was determined that 11 percent less wind would need to be built to meet renewable energy mandates in a combination local/regional methodology relative to a local only approach. Approximately 2.9 GW less generation capacity is required for the combination siting approach, creating present value benefits of $1.4 billion to $2.5 billion.

Transmission investment In addition to relieving constraints under shoulder peak conditions, the proposed MVP portfolio will eliminate some future baseline reliability upgrades. A modeling simulating 2031 summer peak load conditions was created to determine what future baseline reliability upgrades would not be needed, and this model was run both with and without the proposed MVP portfolio. The proposed MVP portfolio eliminates the need for baseline reliability upgrades on 23 lines between 2026 and 2031. This creates benefits which have 20 and 40 year present values of $268 and $1,058 million, respectively.


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Business case variables and impacts The projected benefits created by the proposed MVP portfolio are dependent on projections of future policy and economic variables.

The most critical variables considered were:

Future energy policies o Includes a range of policy, demand and energy growth assumptions o Sensitivities were conducted to determine the impact of a legislated cost of carbon or

national renewable energy mandate Length of Present Value Calculations: 20 or 40 years from the portfolio’s in service date Discount Rate: 3 percent to 8.2 percent Natural gas prices: $5-$8 (Business as Usual Scenarios)

$8-$10 (Combination Policy and Carbon Constrained Futures) Wind turbine capital cost: 2.0 to 2.9 $M/MW

Figure 4.1-18: Benefit – cost variations due to business case assumptions

Depending on which variables are assumed, the present value of the benefits created by the entire portfolio can vary between $18.5 and $126.0 billion in 20 to 40 year present value terms. This savings yield benefits ranging from 1.8 to 5.7 times the portfolio cost.

It should be noted that the benefits of the portfolio do not depend upon the implementation of any particular future energy policy to exceed the portfolio costs. Under existing energy policies, a conservative discount rate of 8.2 percent and 20 year present value terms, the portfolio produces benefits that are 1.8 times its cost. However, if other energy policies or enacted, or a lower discount rate is used, this benefit has the potential to greatly increase.

1.9

1.9

1.9

1.9

1.8

1.8

2.0

2.1

2.2

2.4

3.6

5.8

- 1.00 2.00 3.00 4.00 5.00 6.00

Wind Turbine Capital Cost

Discount Rate

Present Value Timespan

Natural Gas Prices

Future Policy Scenario

All variables

Conservative Assumptions Broader Assumptions

Under existing energy policies, the proposed MVP portfolio creates benefits that are at least 1.8 times its cost.


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Portfolio benefits and cost spread A key principle of the MISO planning process is that the benefits from a given transmission project must be spread commensurate with its costs. The MVP cost allocation methodology distributes the costs of the portfolio on a load ratio share across the MISO footprint, so the proposed MVP portfolio must be shown to deliver a similar spread of benefits.

Figure 4.1-19: Proposed MVP portfolio production cost benefits spread

The proposed MVP portfolio provides benefits across the MISO footprint in a manner that is roughly equivalent to its costs allocation. For each of the local resource zones, as shown in Figure 4.1-19 above, the portfolio’s benefits are at least 1.6 to 2.9 times the cost allocated to the zone.

Qualitative and social benefits The previous sections demonstrated that the proposed MVP portfolio provides widespread economic benefits across the MISO system. However, these metrics do not fully quantify the benefits of the portfolio. Other benefits, based on qualitative or social values, are discussed in the next sections. These sections suggest that the quantified values from the economic analysis may be conservative because they do not account for the full potential benefits of the portfolio.


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Enhanced generation policy flexibility Although the proposed Multi Value Project portfolio was primarily evaluated on its ability to reliably deliver energy required by the renewable energy mandates, the portfolio will provide value under a variety of different generation policies. The energy zones, which were a key input into the Candidate MVP portfolio Analysis, were created to support multiple generation fuel types. For example, the correlation of the energy zones to the existing transmission lines and natural gas pipelines were a major factor considered in the design of the zones. This can be seen in Figure 4.1-20, which shows the correlation between the energy zones and natural gas pipelines.

Figure 4.1-20: Energy zone correlation with natural gas pipelines

Increased system robustness A transmission system blackout, or similar event, can have wide spread repercussions, resulting in billions of dollars of damage. The blackout of the Eastern and Midwestern U.S. during August 2003 affected more than 50 million people and had an estimated economic impact of between $4 and $10 billion.30

The proposed MVP portfolio creates a more robust regional transmission system which decreases the likelihood of future blackouts by:

Strengthening the overall transmission system by decreasing the impacts of transmission outages.

Increasing access to additional generation under contingent events. Enabling additional transfers of energy across the system during severe conditions.

30 Data sourced from: The Economic Impacts of the August 2003 Blackout, The Electricity Consumers Resource Council (ELCON)


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Figure 4.1-21: June 2011 LMP map with proposed MVP portfolio overlay

For example, the proposed MVP portfolio will allow the system to respond more efficiently during high load periods. During the week of July 17, 2011, high load conditions existed in the eastern portion of the MISO footprint, while the western portion of the footprint experienced lower temperatures and loads. Thermal limitations on west to east transfers across the system limited the ability of low cost generation from the west to serve the high load needs in the east, as shown in Figure 4.1-21. The proposed MVP portfolio will increase the transfer capability across the system, allowing access to additional generation resources to offset the impact and cost of severe or emergency conditions.

The proposed MVP portfolio will increase the transfer capability across the system, allowing access to additional generation resources to offset the impact and cost of severe or emergency conditions.


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Decreased natural gas risk Natural gas prices have historically varied widely, causing corresponding fluctuations in the cost of energy from natural gas fueled generation. Also, recent Environmental Protection Agency (EPA) regulations and proposed regulations limiting the emissions permissible from power plants will likely lead to more natural gas fired generation. This may put additional upward pressure on natural gas costs as demand increases. However, the proposed MVP portfolio can help partially offset the associated natural gas price risk by providing additional access to generation that uses fuels other than natural gas (e.g. nuclear, wind, solar and coal) during periods with high natural gas prices.

Figure 4.1-22: Historic U.S. natural gas electric power prices

Assuming a natural gas price increase of 25 percent to 60 percent, the proposed MVP portfolio provides 5 percent to 40 percent higher production cost benefits.

0123456789

10

U.S. Natural Gas Electric Power Price (Dollars per Thousand Cubic

Feet)


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Decreased wind generation volatility As the geographical distance between wind generation increases, the correlation in the wind output decreases. This leads to a higher average output from wind for a geographically diverse set of wind plants, relative to a closely clustered group of wind plants. The proposed MVP portfolio will increase the geographic diversity of wind resources that can be delivered, increasing the average wind output available at any given time.

Figure 4.1-23: Wind Output correlation to distance between wind sites


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Local investment and job creation In addition to the direct benefits of the proposed MVP portfolio, studies have shown the indirect economic benefits of transmission investment. They estimated that, for each million dollars of transmission investment:

Between $0.2 and $2.9 million of local investment is created. Between 2 and 18 employment years are created.31

The wide variations in these numbers are primarily due to the extent to which materials, equipment and workers can be sourced from a ‘local’ region. For example, each million dollars of local investment supports 11 to 14 employment years of local employment, as compared to 2 to 18 employment years which are created for non-location specific transmission investment.

The proposed MVP portfolio supports the creation of between 17,000 and 39,800 local jobs, as well as $1.1 to $9.2 billion in local investment. This calculation is based upon a creation of $0.3 to $1.9 million local investment and 3 to 7 employment years per million of transmission investment.

Carbon reductions The proposed MVP portfolio enables the more economical dispatch of generation, as low cost wind resources displace higher cost generation. This redispatch creates a reduction in the total carbon output produced by MISO generation of between 8.3 to 17.8 million tons annually.

Some of the future policy scenarios included a cost of carbon. This carbon cost is additive to the overall system production cost, and it was based upon a carbon cost of $50 per ton.

If such a carbon cost was to occur, benefits would increase by between $3.8 and $15.4 billion in 20 and 40 year present value terms, respectively.

Conclusions and recommendations MISO staff recommends the proposed MVP portfolio to the MISO Board of Directors for their review and approval. This recommendation is premised on the ability of the portfolio to meet MVP criterion 1, as each project in the portfolio was shown to more reliably enable the delivery of wind generation in support of the renewable energy mandates of the MISO states in a cost effective manner.

The recommendation is also supported by the strong economic benefits of the portfolio, which delivers a large amount of value in excess of costs under all conditions and policy scenarios studied. Furthermore, these benefits are spread across the MISO footprint, in a manner commensurate with the allocation of the portfolio’s costs.

31 Source: Employment and Economic Benefits of Transmission Infrastructure Investment in the U.S. and Canada, The Brattle Group

The proposed MVP portfolio reliably enables the delivery of wind generation in support of public policy needs, while delivering value in excess of its cost in all scenarios studied.


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4.2 EPA Regulation Impact Analysis

Study disclaimer The objective of the MISO EPA Regulation Impact Analysis is to inform stakeholders. MISO has no intention or authority to direct generation unit strategies. That authority belongs exclusively to the individual asset owners. The MISO analysis provides an overview of the impacts from the MISO regional perspective. Any sub regional evaluation of the data would be an incorrect interpretation and application of the results.

The detailed results of the analysis were derived from a limited set of economic assumptions that included low demand and energy growth, low gas prices and variation of carbon prices with sensitivities performed on gas and carbon prices. Retirement impacts can change with different assumptions for these variables. The study also assumes that the natural gas Transmission System is sufficient to accommodate the increased dependence on the natural gas fleet. This addresses some of those issues, but can’t capture all future outcomes. To better understand the affects of changing inputs and risks of the uncertainty of carbon, additional analysis needs to be performed.

An additional caveat - since completion of this analysis - the EPA finalized the Cross State Air Pollution Rule (CSAPR). In general, the final regulation mandated more restrictive emission limits for some states than was modeled in this analysis. The final CSAPR has stronger state limitations in most cases but allows for a national trading program, which may allow for more flexibility in meeting the limits. The overall impact of this change is unknown at this time.

The EPA Regulation Impact Analysis was based on assumptions for proposed EPA regulations. Finalization of the remaining three regulations has the potential to introduce the risk of additional change and uncertainty, similar to what occurred with the CSAPR regulation. Any of the final regulations could differ from what was modeled in this analysis.

EPA impact results summary The United States Environmental Protection Agency (EPA) is finalizing four proposed regulations that will affect the MISO system. They require utilities to choose between retrofitting their generators with environmental controls or retiring them. At the direction of its members, stakeholders and Board of Directors, MISO evaluated the potential impacts of the new regulations, including the impact of carbon reduction requirements. This study evaluated the effects on capacity cost, resource adequacy, cost of energy and transmission reliability. The 4 proposed EPA regulations are:

Cooling Water Intake Structures (CWIS) – section 316(b) of the Clean Water Act (CWA)

Coal Combustion Residuals (CCR) Cross State Air Pollution Rule (CSAPR) formerly known as Clean Air Transport Rule (CATR) Mercury and Air Toxics Standards (MATS), formerly known as EGU Maximum Achievable

Control Technology (MACT)

A survey of the current fleet within MISO revealed a number of generation units will be affected. Impacts ranged from the installation of control equipment and expected redispatch to meet emission budgets, to potential retirement of units where the costs to comply outweigh the benefits of continued operation.


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A survey of the current fleet within MISO revealed a number of generation units will be affected. Impacts ranged from the installation of control equipment and expected redispatch to meet emission budgets, to potential retirement of units where the costs to comply outweigh the benefits of continued operation. Figure 4.2-1 shows that there are 298 units affected by these four proposed regulations and that the majority of the units (55 percent) are affected by three or all four regulations.

Figure 4.2-1: Number of coal units affected by EPA regulations.

The studies were conducted with the Electric Generation Expansion Analysis System (EGEAS) software package developed by the Electric Power Research Institute (EPRI), commonly used by utility generation planners. MISO performed more than 400 sensitivity screens with the EGEAS optimal generation capacity expansion model to identify the units most at-risk for potential retirement. The sensitivities consisted of variation in gas costs, carbon costs and retrofit compliance costs. From those sensitivities, MISO identified nearly 13,000 MW of units at risk for retirement. Those units were offered to the EGEAS

model as an economic choice to retrofit for compliance or retirement. The model makes this decision by comparing alternatives and selecting an expansion forecast that minimizes costs, including capital investment, production (including emissions) and annual fixed operations and maintenance.

MISO ran two economic alternatives. The first assumed a $4.50 cost for natural gas and $0 for carbon. Compliance with all the identified regulations and the expected cost for that compliance, based on stakeholder feedback through the study process, was also assumed. The second analysis used most of the same assumptions but increased costs of up to $50 per ton for carbon production. The analysis on carbon costs was done because the uncertainty of future carbon reduction requirements may cause asset owners to change their approach.

35 Units; 20,200 MW

67 Units; 16,000 MW

189 Units; 32,000 MW

7 Units; 844 MW

Coal Units Impacted by EPA Regulations

Impacted by 1 Regulation




Nearly 13GW of generation is at risk of retiring.


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The results of the EGEAS analysis produced:

2,919 MW at-risk for retirement at $4.50/MMBtu natural gas price and $0/ton carbon cost. 12,652 MW at-risk for retirement with a $4.50 per MMBtu natural gas cost and $50 per ton carbon

cost.

Using a suite of planning products, MISO’s evaluation on the range of potential impacts indicates the following:

The total 20-year net present value capital cost of compliance may range from $31.6 billion for 2,919 MW of retirement to $33.0 billion for 12,652 MW of retirement. Both values are in 2011 dollars and include the cost of retrofits on the system, the cost of replacement capacity, the cost of fixed operations and maintenance and the cost of transmission upgrades.

o Capital costs for retrofits are $28.2

billion and $22.5 billion, respectively.

o Maintenance of the Planning Reserve Margin (PRM) is obligated under the MISO Tariff. So it is expected that any capacity retirements would eventually be matched with replacement capacity to support PRM requirements. To maintain this requirement, it is estimated that the replacement costs would be $1.7 billion and $9.6 billion, respectively.

o The annual fixed operations and maintenance impacts the total cost impact by $1.1 billion and $0.0, respectively.

o Retirement of units will have an impact on localized Transmission System reliability. To ensure voltage and transmission thermal support on the system, an estimated $580 million and $880 million, respectively, of additional transmission upgrades could be necessary to maintain system reliability due to the identified potential unit retirements. The transmission numbers depend on location and any change from the study assumptions could change the cost. Also, this assumes that any replacement capacity is not located at the retired unit locations. If replacement capacity is located at retired unit sites, it is likely the transmission upgrade costs will decrease.

By replacing traditionally less reliable capacity with new resources, there is a potential that

Planning Reserve Margin (PRM) requirements could decrease by having a more reliable fleet. Loss of Load Expectation (LOLE) analysis showed reductions of 0.2 to 1.0 percent. If no replacement capacity is identified for resource adequacy purposes, then Loss of Load Expectation (LOLE) analysis shows that the LOLE on the system could be on the order of 0.21 to 1.028 days/year. The current target is 0.1 days/year. Refer to Chapter 5.2 for more information on EPA impacts on resource adequacy.

There will also be an increase in the MISO load-weighted LMP of between $1.2/MWh-$4.8/MWh

(2011 dollars). This is driven by two key factors: (1) newly retrofitted units are less efficient because of the emission controls, and (2) retired coal facilities are replaced with natural gas fired

3 GW of MISO generation is likely to retire because the cost of retrofit is higher than the cost of replacement.

It will cost MISO approximately $30 billion to comply with the new regulations, regardless of compliance strategy, increasing rates by more than 7 percent.


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capacity resulting in a greater dependence on the higher cost energy. These numbers exclude effects of carbon costs on energy prices.

Identifying all the costs to maintain regulation compliance and system reliability, a 7.0 to 7.6 percent increase in retail rates could be realized, excluding the impacts of carbon on energy prices. If carbon costs are included in the generation production costs, the rate affect increases to a range of 37.2 to 37.7 percent.

There are compliance risks associated with meeting the proposed regulations. As identified previously, additional investment in the generation fleet and the Transmission System will be needed maintain bulk power system reliability – at a cost. However, another risk that is not addressed directly within this analysis but should be mentioned is the time in which units comply. Figure 4.2-2 shows a high level timetable of rule implementation and compliance deadlines. If it is determined that capacity should be retired, it would take at least two to three years to build a combustion turbine to replace that capacity. Also, if Transmission System reliability requires bulk transmission upgrades, a minimum of five years could be required for a transmission line to become operational. The deadline from final regulation to compliance may be difficult to meet for some parts throughout the bulk power system.

Figure 4.2-2: Estimated timeline for regulation development and implementation

2010 2011 2012 2013 2014 2015 2016 20172018 & beyond

MATS

CCR

CSAPR

CWA

Develop Regulation

Compliance with MATS

Develop Regulation

Compliance with CSAPR

Develop Regulation Compliance with CCR

Develop Regulation Compliance with CWA


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Sensitivities impact Just as in the MISO Transmission Expansion Plan (MTEP), MISO uses a scenario planning process in the analysis and evaluation of these EPA regulations. Evaluating the impact over the EPA regulations requires that many conditions be considered separately and in combination with each other. MISO evaluated six scenarios with 77 sensitivities for each of the scenarios. The scenarios are:

Base conditions, no new regulations Cooling Water Intake Structures section – 316(b) of the Clean Water Act (CWA) Coal Combustion Residuals (CCR) Cross State Air Pollution Rule (CSAPR) formerly known as Clean Air Transport Rule (CATR) Mercury and Air Toxics Standards (MATS) formerly known as EGU Maximum Achievable Control

Technology (MACT) Combination of all 4 regulations

Figure 4.2-3 demonstrates the sensitivities evaluated for each regulation analysis. There are six regulation scenarios and six branches to this decision tree. Only the first branch is shown in Figure 4.2-3.

Figure 4.2-3: Decision tree of EPA cases

Regulation

High Cost

Expected Cost

$6.00

$10.00

$8.00

$4.50

$10.00

$6.00

$8.00

$0.00

$100.00

$10.00

$0.00

$100.00

$10.00

$0.00

$100.00

$10.00

$0.00

$100.00

$10.00

$0.00

$100.00

$10.00

$0.00

$100.00

$10.00

$0.00

$100.00

$10.00

6 Regulation Scenarios

Compliance Cost

Natural Gas Price $/MMBtu

Carbon Price $/ton


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For each of the scenarios, 77 sensitivity cases consisting of two variations in compliance costs, natural gas costs and carbon price levels were modeled to produce a combined total of more than 400 sensitivity cases. The results indicated that up to 23,000 MW of coal capacity could be at-risk because of regulation compliance.

From these sensitivity cases, a few general conclusions can be made.

EPA regulation impacts: Compliance associated with the Mercury and Air Toxics Standards (MATS) produces the most at-risk units as its compliance costs and emission reductions have the greatest impact of the proposed regulations.

Compliance costs: Higher compliance costs result in more at risk units. Evaluating all natural gas and carbon sensitivities for the high compliance cost cases resulted in up to 23,000 MW of at-risk capacity. However, running the same sensitivities at the more expected compliance costs as recommended and reviewed through the MISO stakeholder process, up to 13,000 MW of capacity was considered to be at risk.

Natural gas prices: Lower natural gas prices produced more at-risk capacity than higher gas

prices. The lower natural gas prices provide more incentive to retire capacity as the alternative resources provide competitive energy costs for the system. Conversely, when gas prices are high, the coal units find enough revenue on the system to cover compliance costs and keep general energy prices lower.

Carbon prices: Adding cost to carbon, beyond the EPA regulations, puts economic pressure on units with higher carbon production rates. Because of this, higher carbon prices put more economic pressure on the coal units within the system, and the economics favor natural gas and carbon neutral capacity. So more coal units are at-risk for retirement with the higher carbon prices applied.

The units at-risk for retirement range from 0 MW to 23,000 MW based on the economic assumptions within the sensitivities. Cases where no units were at-risk for retirement include low compliance costs, higher gas prices and no carbon costs applied. This occurs because it minimizes the cost for compliance while increasing the potential revenue for generators within the energy market through higher natural gas prices. Cases that produce at-risk generation up to 23,000 MW include high compliance costs, low gas prices and varying levels of carbon costs.

Figure 4.2-4 depicts an example of the affects of the cost of compliance, gas and carbon from the identified potential retirements of 2,919 MW.


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Figure 4.2-4: Tornado chart demonstrating the impacts of sensitivities on potential capacity retirements

Potential carbon regulation At the end of 2010, the EPA issued a proposed schedule for establishing greenhouse gas (GHG) standards under the Clean Air Act for fossil fuel fired power plants and petroleum refineries. This is the first step the EPA is taking to address carbon. How that will unfold is not known. One of the ways for MISO to evaluate the impacts of carbon compliance is to add a cost to carbon that can represent either a carbon production tax or the effective costs to comply through reduction in carbon output by technology applications. This increases the dispatch cost in $/MWh for all units that produce carbon. Higher carbon emitting units receive a greater cost penalty that will change the order that all units in MISO are dispatched.

Figure 4.2-5 illustrates how the capacity of at-risk for retirement units increases as the cost of carbon increases. At $50/ton, 12,652 MW’s of units are at risk for retirement. This should be compared to the 2,919 MW identified without the carbon costs applied. This illustrates the importance of assessing the affect of future carbon regulations in the analysis. If money is spent to retrofit the unit for the EPA regulations, based on the assumption of no new carbon requirements, and carbon regulations materialize in the $35-$50/ton range, the investment becomes at risk at that later date.


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Figure 4.2-5: Carbon impacts on retrofit/retirement decision

Rate impact In general, the retail rates on the system are driven by the costs of generation production, generation capital costs, transmission capital costs and distribution capital costs. The MISO EPA regulation analysis identifies costs that impact three of the four components of the rates.

When the impact of carbon cost is excluded from the rate increase calculation, the greatest impact on the rates comes from the capital cost component. The capital cost increase comes in two forms, the EPA capital compliance cost and the capital cost for replacement capacity. Figure 4.2-6 demonstrates the comparison of the rate impact of the two retirement scenarios with the current average system rate. The overall increase in the rates because of compliance with the EPA regulations is approximately 7.0 to 7.6 percent.

The relatively small rate increase difference between the two scenarios is due to the balance of capital cost configurations. The total EPA regulation related capital cost comes in three forms - 1) control equipment, 2) capital cost for replacement capacity and 3) transmission capital cost needed for retired capacity. The relationship between the three costs is a balance between retired capacity to forgo costs for control equipment while adding replacement capacity and transmission costs for the forgone capacity, versus more control costs to retrofit generation. In other words, as retirements increase, the total control equipment cost decrease, while replacement capacity and transmission costs increase – and vice versa. A balance of all three costs occurs to end up with the least cost strategy.

The overall increase in the rates because of compliance with the EPA regulations is approximately 7.0 to 7.6 percent.


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Figure 4.2-6: MISO rate impact excluding the cost of carbon in the production costs

Figure 4.2-7 demonstrates the rate impacts when a cost for carbon compliance is included in the generation production costs. In this comparison, the production costs are the primary driver for the rate increases that are 37.2 to 37.7 percent. The cost of carbon drives the retirements of 12,652 MW in this analysis. Applying the carbon cost to both scenarios demonstrates the total impact that carbon has on both capital investment and production costs.

Figure 4.2-7: MISO rate impact including the cost of carbon in the production costs


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4.3 Generation portfolio analysis MISO performed regional assessments using the Electric Generation Expansion Analysis System (EGEAS) on the MISO footprint as of June 1, 2011. Using assumed projected demand, energy for each company and common assumptions for resource forecasting, MISO developed models to identify least cost generation portfolios needed to meet resource adequacy requirements of the system for each future scenario.

Future scenario definitions Scenario-based analysis provides the opportunity to develop plans for different future scenarios. A future scenario is a postulate of what could be, which guides the assumptions made about a given model. The outcome of each modeled future scenario is a generation expansion plan, or generation portfolio. Generation portfolios identify the ‘least cost’ generation required to meet reliability criteria based on the assumptions for each scenario. MTEP11 has examined multiple future scenarios:

1. Business As Usual with Low Demand and Energy Growth Rates

2. Business As Usual with Historical Demand and Energy Growth Rates

3. Combined Energy Policy 4. Carbon Constraint

A more detailed discussion of the assumptions and methodology around these scenarios is presented later in Section 4.3 and in Appendix E.2.

Figure 4.3-1 on the following page represents capacity expansions for each defined future scenario through the 2026 PROMOD® study year. The capacity added is required to maintain stated reliability targets for each region. Stated targets for MISO are defined by means of the Module E Resource Adequacy Assessment.

MISO developed models to identify least cost generation portfolios needed to meet resource adequacy requirements of the system for each future scenario.


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Figure 4.3-1: MISO modeled system aggregate nameplate installed MW from 2026 PROMOD Model.

Recognizing that redundancies across the existing MTEP10 future scenarios and assumptions did not provide any additional information, MISO staff, along with the planning advisory committee, narrowed down to four the scenarios for analysis in MTEP11. A diverse set of generation scenarios emerges when examining the MTEP11 future. While making comparisons across futures with different growth rates for demand and energy can be difficult, some observations can be made when studying future scenarios as a group or when comparing one to another.

Traditionally, most base load capacity needs have been met with coal and nuclear generation. Gas-fired combined cycle units have taken over some of the base load generation role thanks to the discovery of large quantities of shale gas and subsequent lower prices. Rising construction costs, pending EPA regulations and many uncertainties surrounding the future of nuclear generation are also factors. In the combined energy policy and Carbon Constraint scenarios coal units are retired in order to achieve the 42 percent carbon reduction cap. To achieve these targets within the specified time, 55 percent (~44,000 MW) of the oldest and least efficient coal units were retired in the analyses for the combined energy policy scenario and 50 percent (~40,000 MW) were retired in the Carbon Constraint scenario. Much of this base load generation capacity was replaced with natural gas-fired combined cycles and energy efficiency programs.

In all future scenarios, the addition of state-mandated renewable energy capacity overshadows thermal capacity, because most states within the MISO footprint have renewable energy standards and an abundance of existing capacity. The presence of lower demand and energy starting points and growth rates during the study are also factors. A large portion of capacity needs are being met through demand response and energy efficiency programs, which are allowed to compete against traditional supply-side resources in the EGEAS program for the first time in MTEP11. The Global Energy Partners study conducted for MISO in 2010 provided the demand response and energy efficiency estimates.

‐

‐

(24,735)(21,546)

44,005

60,123

70,642

50,322

(40,000)

(20,000)

‐

20,000

40,000

60,000

80,000

S1: BAU with Low D&E S2: BAU with Historical D&E S3: Combined Policy S4: Carbon ConstraintNam

eplate Expansion (MW)

MISO Capacity Additions (2011‐2026)

Queue/Planned Wind Photovoltaic Combined Cycle

Combustion Turbine Energy Efficiency Demand Response Retired Capacity


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Figure 4.3-2 demonstrates the value of costs for the study period through 2026. Production and capital costs are provided. Production costs include fuel, variable and fixed operations and maintenance and emissions costs (where applicable). Capital costs represent the annual revenue needed for new capacity. Each future scenario has a unique set of input assumptions, such as demand and energy growth rates, fuel prices, carbon costs and RPS requirements, which drive the future capacity expansion capital investments and total production costs.

Figure 4.3-2: MISO present value of cumulative costs in 2011 U.S. dollars


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Each of the future scenarios has a different impact on carbon dioxide output. Refer to Figure 4.3-3, which demonstrates the varying impact for each of the defined future scenarios. Figure 4.3-3 compares 2005 carbon production provided by the dispatch of a 2005 EGEAS model and year-end 2030 carbon production associated with the capacity expansion for each future scenario.

Continued demand and energy growth at levels close to historic trends will result in the need for additional generating capacity. If this capacity is dominated by coal or natural gas, carbon output will increase on an annual basis. The increased penetration of renewable resources and energy efficiency will result in a system reduction in carbon dioxide.

Figure 4.3-3: MISO carbon production

The increased penetration of renewable resources and energy efficiency will result in a system reduction in carbon dioxide.


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Siting of capacity Generation resources forecasted from the expansion model for each of the scenarios are specified by fuel type and timing, but these resources are not site-specific. Completing the process requires a siting methodology tying each resource to a specific bus in the power flow model. A guiding philosophy and rule-based methodology, in conjunction with industry expertise, was used to site forecasted generation. Refer to Figure 4.3-4, which depicts capacity siting associated with the Business As Usual with Historical Demand and Energy Growth Rates scenario. Likewise, Figure 4.3-5 shows the associated demand response siting for the BAU with Historical Demand and Energy Growth Rates scenario. The siting methodology used for this and the other future scenarios is explained further in Appendix E2.

Figure 4.3-4: Future capacity sites for MISO BAU with historical demand and energy growth rates scenario


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Figure 4.3-5 Future DR sites for MISO BAU with historical demand and energy scenario

Generation futures development A planning horizon of at least 15 years is needed to accomplish long range economic transmission development, since large projects normally take 10 years to complete. Performing a credible economic assessment over this time is challenging. Long-range resource forecasting, power flow and security constrained economic dispatch models are required to extend to at least 15 years. Since no single model can perform all of the functions for integrated transmission development, a value-based planning process is developed by integrating the best models available. This allows the evaluation of the long-term transmission requirements to proceed.

The following broad steps outline the value-based planning process that MISO has been implementing. It starts with the analysis of value drivers and ends with a reliability assessment to meet both economic and reliability needs.

● Step 1: Create a regional generation resource forecast.

● Step 2: Site the new generation resources into the power flow and economic models for each future scenario.

● Step 3: Design preliminary transmission plans for each future scenario, if needed.

● Step 4: Test for robustness.

● Step 5: Perform reliability assessment, consolidation and sequencing.

● Step 6: Final design of integrated plan.

● Step 7: Cost allocation.


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MISO’s planning approach continues to evolve to integrate its planning. One focus of the MTEP 11 planning effort is to refresh a set of available future scenarios to capture potential energy policy outcomes.

In recognition of the uncertainty of energy policies and availability of associated resources in the 15-20 year time frame, a multi-dimensional regional resource forecasting is required, to identify what’s necessary to supplement generation interconnection queue capacity. The regional resource forecast model determines, on a consistent least-cost basis, the type and timing of new generation and energy efficiency needs driven by energy policies and other long-term integrated resource plans generation not reflected in the current queue.

This section summarizes Steps 1 and 2 of the integrated transmission planning process, where regional resource forecasting is performed using scenario-based analysis to identify and site generation for several potential future scenarios. With the increasingly interconnected nature of organizations and federal interests, forecasting greatly enhances the planning process for electricity infrastructure. The futures analysis provides information on the cost and effects of environmental legislation, wind development, demand-side management programs, legislative actions or inactions and many other potential scenarios which can be postulated and performed.

Future scenarios and assumptions for the models for Steps 1 and 2 were developed with stakeholder involvement. The MISO Planning Advisory Committee (PAC) provided the opportunity for stakeholder input necessary to comply with FERC Order 890 planning protocols. Scenarios have been developed and subsequently refreshed to reflect shifts in energy policies in the last few years, in coordination with the committee, through efforts in MTEP09, MTEP10, the Joint Coordinated System Planning and the Eastern Wind Integration and Transmission Study.

In MTEP11, four primary future scenarios were used for robustness (best-fit) testing of proposed transmission plans associated with major studies, such as the 2011 Candidate MVP Portfolio study and transmission project evaluation under various market efficiency studies. New to MTEP 11 future scenario development is the inclusion of Global energy study estimated DSM projections, which are offered as demand side resources to compete against conventional supply-side resources based on economics. A notable portion of capacity needs are being met through demand side programs which are economically chosen for each of the MTEP11 futures.

MISO consulted with Global Energy Partners LLC (Global) in 2010 to perform an evaluation of Demand Response (DR) and Energy Efficiency (EE) potential in the MISO footprint. This effort developed a 20-year forecast for the MISO region and the rest of the Eastern Interconnection. This study demonstrated the enhanced modeling capabilities of DSM programs in the Electric Power Research Institute’s (EPRI) Electric Generation Expansion Analysis System (EGEAS), the regional resource forecasting software tool used to assist in long term resource planning as part of Step 1 of the MTEP seven-step process. The study found DR and EE programs could significantly affect the load growth and future generation needs of the system. In MTEP11, Global provided DR and EE estimates for EGEAS to perform regional resource forecasting. An associated siting methodology for chosen demand response programs was also developed to facilitate business case development of proposed transmission plans. See the links below for more complete study results:

Volume 1: https://www.misoenergy.org/_layouts/MISO/ECM/Redirect.aspx?ID=78818

Volume 2: https://www.misoenergy.org/_layouts/MISO/ECM/Redirect.aspx?ID=78819

The assumptions for the models and the results presented in this document reflect the prices and policies leading to publication. MISO recognizes changes have occurred in many of these assumptions and will continue to update.

A full discussion of the assumptions and results of Steps 1 and 2 of the economic analysis process can be found in Appendix E2 of this document.


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The following describes the various future scenarios in greater detail:

The Business As Usual with Low Demand and Energy Growth Rates future scenario is considered the status quo scenario and continues the impact of the economic downturn on demand, energy and inflation rates. This scenario models the power system as it exists today with reference values and trends, with the exception of demand, energy and inflation growth rates. The demand, energy and inflation growth rates are based on recent historical data and assume existing standards for resource adequacy, renewable mandates and that environmental legislation remains unchanged. Renewable Portfolio Standard (RPS) requirements vary by state, and have many potential resources that can apply.

The Business As Usual with Historical Demand and Energy Growth Rates future scenario is considered a status quo scenario, with a quick recovery from the economic downturn in demand and energy projections. This scenario models the power system as it exists today with reference values and trends—with the exception of demand and energy growth rates—and is based on recent historical data prior to the economic downturn. This scenario assumes existing standards for resource adequacy renewable mandates and that environmental legislation will remain unchanged. Renewable Portfolio Standard (RPS) requirements vary by state and have many potential renewable resources that can apply.

The Combined Energy Policy future scenario was developed to capture the effects of multiple future policy scenarios into one future. This scenario includes a federal Renewable Portfolio Standard, a carbon cap and trade, smart grid and electric vehicles. The RPS is modeled assuming all states are required to meet a 20 percent federal RPS mandate by 2025. The carbon cap is modeled after the Waxman-Markey bill, which requires an 83 percent reduction of CO2 emissions from a 2005 baseline by the year 2050. That is achieved through a linear reduction from 2011 to 2050 with mid point goals of 3 percent in 2015, 17 percent in 2023 and 42 percent in 2033. This future employs coal retirements, with the oldest and least efficient coal units retired first. Smart grid is modeled by reducing the demand growth rate, assuming that a higher penetration of smart grid will lower the overall growth of demand. Electric vehicles are modeled by increasing the energy growth rate. They are assumed to increase off-peak energy usage and—increase the overall energy growth rate.

The Carbon Constraint future scenario models a declining cap on future CO2 emissions. It is modeled in the same way as in the Combined Energy Policy future scenario. Renewable Portfolio Standard (RPS) requirements vary by state, and have many potential renewable resources that can apply.


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Refer to Table 4.3-1, which illustrates the key input variables for each future scenario. Each future has a unique set of input assumptions driven by a range of policy decisions. With extensive stakeholder involvement under the Planning Advisory Committee, the consensus has been reached with respect to the methodology for determining baseline demand and energy growth rates for each of MTEP11 futures. The resulted baseline demand and energy growth rates for the four MTEP 11 futures are tabulated as follows:

Future scenarios MISO wind penetration

(GW)

MISO demand growth

rate

MISO energy growth

Rate

Gas price

Carbon Cost / reduction target

Business As Usual with Low Demand & Energy

29 1.26

percent 1.26

percent $5.00 None

Business As Usual With Historical Demand & Energy

32 1.86

percent 1.86

percent $5.00 None

Combined Energy Policy 40 1.26

percent 1.26

percent $8.00

$50/ton

(42 percent by 2033)

Carbon Constraint 27 0.66

percent 0.66

percent $8.00

$50/ton

(42 percent by 2033)

Table 4.3-1: Future scenario input assumptions

MISO Transmission Expansion Plan 2011 Section 5 - MISO resource assessment

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5. MISO resource assessment

5.1 Reserve margin requirements As directed under Module E of the MISO Tariff, the system planning reserve is calculated by determining the amount of generation required to meet a 1 day in 10 years (0.1 day per year) Loss of Load Expectation (LOLE). The MISO Planning Reserve Margin (PRM), based on the system-wide MISO concident load peak and resources based on their installed capacity rating (that is, PRMSYSIGEN), for the 2011/2012 Planning Year (PY) is 17.40 percent, increasing 2 percentage points from the 2010/2011’s 15.40 percent. The Planning Reserve Margin based on Unforced Capacity (PRM_UCAP) declined from 4.50 percent to 3.81 percent, and applies to the non-coincident peak of each Load Serving Entity (LSE).

The majority of the 2 percent PRMSYSIGEN increase can be attributed to three factors. In approximate values: The increased uncertainty of forecasting the load contributed to 0.8 percent of the increase; the forced outage rates of resources were up and contributed to 0.7 percent of the increase; and the external system support was found less effective and contributed to 0.6 percent of the increase. While these three factors contributed a total increase of 2.1 percent, other factors contributed an offsetting decrease of about 0.1 percent.

Unlike previous years, the 2011 PRM reflects no component due to transmission congestion. For example, had there been no congestion in the two previous years, the PY 2009 value would have been 0.6 percent marginally lower than its 15.4 percent, and the PY 2010 value would have been lower by 0.4 percent. All previous congestion was due to effects of bottled-up resources that could not likely be counted as available to serve system wide load. Like previous studies, the 2011 MISO LOLE found no evidence of load pockets

where the lack of resources would require importing more than the Transmission System’s ability to deliver.

Benefits associated with system-wide diversity must be considered since compliance with Module E Resource Adequacy Requirements is based on representing each Load Serving Entity’s (LSE) non-coincident monthly peak demand on the appropriate individual CPnodes. MISO has determined that a diversity factor of 4.55 percent will be used for the 2011/12 Planning Year. This is an increase from the 3.00 percent diversity factor used last year. MISO believes the 1.55 percent increase in diversity factor is appropriate in order to appropriately capture the diversity of all LSEs within the MISO BA without significantly increasing the loss of load risk to the MISO system. After consideration for load diversity, the PRM is based on the Load Serving Entity’s non-coincident peak and resources based on their installed capacity rating (that is, PRMLSEIGEN), and the value is 12.06 percent.

Projected planning reserve margin requirements for 2012 through 2020 are also calculated in the LOLE Study and are utilized in Section 5.2 as a comparison to the projected reserves. The complete 2011 report on MISO Loss of Load Expectation (LOLE) study can be found at the following link:

https://www.midwestiso.org/Library/Repository/Meeting percent20Material/Stakeholder/LOLEWG/2011/2011 percent20LOLE percent20Report.pdf

The system planning reserve is calculated by determining the amount of generation required to meet a 1 day in 10 years (0.1 day per year) Loss of Load Expectation (LOLE). The MISO Planning Reserve Margin (PRMSYSIGEN) for the 2011/2012 Planning Year (PY) is 17.40 percent.


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5.2 Long term resource assessment Although current load and resource forecasts do not predict insufficient capacity within the next 10 years, various uncertainties could change that forecast. Less capacity expansion than expected, increased level of generation unit retirements, uncertainty around load forecast, increased forced outage rates due to an aging generation infrastructure and possible lack of external support - are all uncertainties which may negatively affect future Resource Adequacy. The risk of these uncertainties on reliability is assessed through Loss of Load Expectation (LOLE) analysis and the results summarized in this section.

Of specific interest is the uncertainty around the pending EPA regulations, one of which has been finalized. The passage of these regulations could lead to increased unit retirements throughout the MISO region; quickly eroding reserve margins from their projected levels.

Recent proposals from the Environmental Protection Agency (EPA) and the uncertainty around carbon control may force retirements of generation within the MISO footprint, which would quickly erode reserve margins from their projected levels. With the anticipated decline of coal generation due to EPA regulations, environmental and economic trends; approximately 3,000 MW of coal generation could be retired in the MISO system by 2015, for a natural gas cost of $4.5/MMBtu and no carbon cost applied. These coal retirements could grow to 12.6 GW of generation, at a carbon cost of $50/ton. If no replacement capacity is identified for Resource Adequacy purposes, then the system reserve margin could decrease to 6.9 percent in 2021. Table 5.2-1 below shows the impact of these scenarios on 2016 and 2021 reserve margins. Refer to MTEP11 chapter 4.2 for more information about the EPA Regulation Impact Study.

Reserve margin

3 GW coal generation retirements

12.6 GW coal generation retirements

2016 2021 2016 2021

Projected reserve margin (percent) 19.9 16.2 10.1 6.9

Planning reserve margin requirements (percent)

17.4 18.2 17.4 18.2

Table 5.2-1: Potential EPA impacts on resource adequacy

Absent EPA regulations, MISO projects sufficient capacity relative to demand over the next 10 years. The following section summarizes this situation, and provides forecasts of future demand, capacity, and reserves through 2021. Risks, such as the proposed EPA regulations, are also examined to gauge the potential affect on resource adequacy.

The MISO 2011 Long Term Resource Assessment report will be posted at: https://www.misoenergy.org/Planning/SeasonalAssessments/Pages/SeasonalAssessments.aspx

Refer to Appendix E6 for a more detailed discussion and breakdown of the data presented below.

Absent EPA regulations, MISO projects sufficient capacity relative to demand over the next 10 years ……

With EPA regulations and no replacement capacity, the system reserve margin could decrease to 6.9 percent in 2021


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Forecasted demand MISO Load Serving Entities are required by current resource adequacy practices to report their non-coincident peak forecasted demand to MISO out 10 years. These demands were collected from the Module E Capacity Tracking (MECT) tool and aggregated to a MISO level. MISO’s total internal demand and net internal demand for the 10th-year peak are expected to be approximately 101 GW and 97 GW, respectively. The forecasted MISO annual growth rate from 2012-2021 is approximately 1.0 percent, a slight increase from the 2010 LTRA.

Demand (MW)

2012 2013 2014 2015 2016 2017 2018 2019 2020 2021

Unrestricted non-

coincident 97,206 99,149 99,560 100,313 101,034 101,761 102,574 103,515 104,475 105,520

Estimated diversity

4,230 4,315 4,333 4,366 4,397 4,429 4,464 4,505 4,547 4,592

Total internal 92,976 94,834 95,227 95,947 96,637 97,332 98,110 99,010 99,929 100,928

Direct control load

management 1,118 1,118 1,118 1,118 1,118 1,118 1,118 1,118 1,118 1,118

Interruptible load

3,093 3,093 3,093 3,093 3,093 3,093 3,093 3,093 3,093 3,093

Net internal demand

88,765 90,623 91,016 91,736 92,426 93,121 93,899 94,799 95,718 96,717

Table 5.2-2: 2012-2021 forecasted demand


100

Forecasted capacity

MISO’s total designated capacity for the 10th year peak is expected to be approximately 115 GW. A total of 2,549 MW of Generation Interconnection queue projects32 are expected to be available for the 10th year peak based on a thorough study of the queue. Behind-the-Meter Generation (BTMG) is treated as a capacity resource and not a load modifier to align with the current resource adequacy practices outlined within Module E and standard industry practice.

Capacity (MW) 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021

Internal designated capacity resources

103,698 103,698 103,698 103,698 103,698 103,698 103,698 103,698 103,698 103,698

External designated

capacity resources 4,894 4,894 4,894 4,894 4,894 4,894 4,894 4,894 4,894 4,894

Behind-the-meter generation

3,608 3,608 3,608 3,608 3,608 3,608 3,608 3,608 3,608 3,608

Future planned resources

495 862 881 904 986 986 986 2,549 2,549 2,549

Total designated capacity

112,695 113,062 113,081 113,104 113,186 113,186 113,186 114,749 114,749 114,749

Table 5.2-3: 2012-2021 forecasted capacity

Forecasted reserves The target reserve margin requirement varies throughout the 10-year period, from 17.4 percent in 2012 to 18.2 percent in 2021. The reserve margins projected through the assessment time vary from 27.0 percent to 18.6 percent for 2012-2021. This is in excess of the MISO target reserve margins through 2019.

Reserve margin 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021

Reserve margin (MW)

23,930 22,438 22,064 21,368 20,760 20,065 19,287 19,950 19,031 18,032

Reserve margin (percent)

27.0 24.8 24.2 23.3 22.5 21.5 20.5 21.0 19.9 18.6

Planning reserve margin requirement

(percent) 17.4 17.3 17.3 17.2 17.4 17.8 17.8 18 18.2 18.2

Table 5.2-4: 2012-2021 forecasted reserves

32 Generator Interconnection Queue data as of March 28th, 2011


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Forecasted risk To quantify effects each future uncertainty has on the 50/50 and 90/10 load level scenarios, 48 sensitivities were run. The various sensitivities simulate increased forced outage rates across the footprint, no load modifying resources, no external support and increased unit retirements due to the pending EPA regulations (3 GW of coal retirements and 12.6 GW) for both 2016 and 2021. In each case, variables were changed to observe the effects on Loss of Load Expectation (LOLE). Both 2016 and 2021 had 48 identical cases created to observe its effect on LOLE. An additional eight cases were run for 2021 based on the premise that Generation Interconnection gas-fired projects, approximately 5,000 MW, would have a 100 percent chance of being built, if MISO experiences 12.6 GW of early coal retirement due to EPA regulations. An LOLE of one day in 10 years is an industry standard benchmark for minimum system reliability. When studying the 2016 and 2021 systems, with no early coal facility retirements due to environmental regulations, the analysis shows only a few cases exceeding this benchmark for each year. It should be noted that this is only when unlikely significant impacts occur to the system, such as a 90/10 load forecast with either combination of no external support, no load modifying resources, or 50 percent higher forced outage rates. A summary of results for 2016 and 2021 is given in figures 5.2-1 and 5.2-2, respectively. The summary shows the LOLE and corresponding reserve margin for each case run in the analysis. Uncertainty exists given the potential effect of pending environmental legislation on MISO’s system. The results indicate risk exponentially exceeding one day in 10 years given increased early retirement of MISO base generation, combined with current future generation resources expected to be built in the Generation Interconnection Queue.


102

Figure 5.2-1: Year 2016 LOLE sensitivity to variable adjustment

17.40%3.81%

‐75%‐70%‐65%‐60%‐55%‐50%‐45%‐40%‐35%‐30%‐25%‐20%‐15%‐10%‐5%0%5%10%15%20%25%30%35%40%45%

0%

10%

20%

30%

40%

50%

60%

70%

80%

90%

100%

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Reserve Margin

Loss of Load

Expectation

LOLE 1 Day in 10 Years LOLE Criteria

1 Year in 10 Years LOLE Installed Capacity Reserve Margin

2016 Installed Capacity Reserve Margin Requirement Unforced Capacity Reserve Margin

2011 Unforced Capacity Reserve Margin Requirement

50/50 Load Forecast 90/10 Load Forecast

Case Case

1 Base2 3 GW EPA Retire (3 GW)3 No Load Modifying Resources (LMR)4 No External Resources (EXT)5 50% Increased Forced Outage Rates (FOR)6 (3 GW), (LMR)7 (3 GW), (EXT)8 (3 GW), (FOR)

9 (EXT), (LMR)10 (FOR), (LMR)11 (FOR), (EXT)12 12.6 GW EPA Retire (12.6 GW)13 (3 GW), (EXT), (LMR)14 (3 GW), (FOR), (LMR)15 (3 GW), (FOR), (EXT)16 (FOR), (LMR), (EXT)

17 (12.6 GW), (LMR)18 (12.6 GW), (FOR)19 (12.6 GW), (EXT)20 (3 GW), (FOR), (LMR), (EXT)21 (12.6 GW), (FOR), (LMR)22 (12.6 GW), (EXT), (LMR)23 (12.6 GW), (FOR), (EXT)24 (12.6 GW), (FOR), (LMR), (EXT)


103

Figure 5.2-2: Year 2021 LOLE sensitivity to variable adjustment

C D

18 (12.6 GW), (FOR)19 (12.6 GW), (EXT)20 (3 GW), (FOR), (LMR), (EXT)H (12.6 GW) (Gas), (FOR), (LMR), (EXT)21 (12.6 GW), (FOR), (LMR)22 (12.6 GW), (EXT), (LMR)23 (12.6 GW), (FOR), (EXT)24 (12.6 GW), (FOR), (LMR), (EXT)

18.20%3.81%

‐75%‐70%‐65%‐60%‐55%‐50%‐45%‐40%‐35%‐30%‐25%‐20%‐15%‐10%‐5%0%5%10%15%20%25%30%35%40%

0%

10%

20%

30%

40%

50%

60%

70%

80%

90%

100%

1 2 3 4 5 6 7 8 9 1011 1213141516 17 181920 21222324 1 2 3 4 5 6 7 8 9 1011 1213141516 17 181920 21222324

Reserve Margin

Loss of Load

Expectation

LOLE 1 Day in 10 Years LOLE Criteria

1 Year in 10 Years LOLE Installed Capacity Reserve Margin

2021 Installed Capacity Reserve Margin Requirement Unforced Capacity Reserve Margin

2011 Unforced Capacity Reserve Margin Requirement

50/50 Load Forecast 90/10 Load Forecast

Case Case

1 Base2 3 GW EPA Retire (3 GW)3 No Load Modifying Resources (LMR)4 No External Resources (EXT)5 50% Increased Forced Outage Rates (FOR)6 (3 GW), (LMR)A 12.6 GW EPA Retire (12.6 GW) w/Partial Gas Replacement (Gas)7 (3 GW), (EXT)8 (3 GW), (FOR)9 (EXT), (LMR)10 (FOR), (LMR)11 (FOR), (EXT)

B (12.6 GW) (Gas), (LMR)C (12.6 GW) (Gas), (FOR)D (12.6 GW) (Gas), (EXT)12 (12.6 GW)13 (3 GW), (EXT), (LMR)14 (3 GW), (FOR), (LMR)15 (3 GW), (FOR), (EXT)16 (FOR), (LMR), (EXT)E (12.6 GW) (Gas), (FOR), (LMR)F (12.6 GW) (Gas), (EXT), (LMR)17 (12.6 GW), (LMR)G (12.6 GW) (Gas), (FOR), (EXT)

A B D E F G H A B E G HC F

MISO Transmission Expansion Plan 2011 Section 6 – Near and long-term reliability analyses

104

6. Near and long-term reliability analyses MISO performs an annual Reliability Assessment through its MISO Transmission Expansion Plan (MTEP).

MISO also conducts Baseline Reliability studies in support of MTEP to ensure the Transmission System is in compliance with two entities: applicable national Electric Reliability Organization (ERO) reliability standards and reliability standards adopted by Regional Reliability Organizations applicable within the Transmission Provider region. MISO’s studies typically include simulations to assess transmission reliability in the near and long term, using power flow models representing conditions two, five and 10 years out.

MISO identified various transmission issues through the studies. Planned and proposed transmission upgrades needed to mitigate identified issues are included in the 2011 MISO Transmission Expansion Plan. Planned transmission upgrades are in MTEP Appendix A following MISO Board of Directors approval. Proposed transmission upgrades are in MTEP Appendix B.

In MTEP 2011, MISO conducted regional studies using the following base models:

2013 Summer Peak 2016 Summer Peak 2016 Shoulder Peak 2016 Light Load 2021 Summer Peak 2021 Shoulder Peak

MISO member companies and external RTO companies use firm drive-in and drive-out transactions to determine net interchanges for these models. These are documented in the 2011 series Multi-Area Modeling Working Group (MMWG) interchange. MISO determines total generation necessary to be dispatched for each of the models after aggregating total load with input received from Transmission Owners.

Generation dispatch within the model building process has become complex. Growing inputs from various planning processes and expected shifts in generation portfolio within the MISO footprint are big reasons.

Inputs in the dispatching process:

Generation retirements Generator market cost curves Generator deliverable capacity designation Wind generation output modeling under various system conditions Incremental generation needed to meet applicable renewable mandates


105

Load

(MW)

Generation

(MW)

Load

(MW)

Generation

(MW)

Load

(MW)

Generation

(MW)

2013 Summer Peak 41,515 40,065 42,004 39,356 24,906 25,896 108,425 105,317 ‐3,1082016 Summer Peak 43,271 41,183 42,736 40,931 25,559 27,809 111,567 109,923 ‐1,6442016 Shoulder Peak 31,529 32,945 33,467 32,659 21,294 20,847 86,289 86,451 1622016 Light Load 22,262 20,778 28,185 29,264 9,883 9,511 60,330 59,553 ‐7772021 Summer Peak 45,921 41,378 41,126 41,595 26,768 26,816 113,815 109,788 ‐4,0272021 Shoulder Peak 34,557 37,749 33,876 30,757 19,932 18,630 88,365 87,136 ‐1,229

West Sub Region Central Sub Region East Sub Region

Scenario

Total

MISO Interchange

(MW)

Total Load

(MW)

Total

Generation

(MW)

Table 6-1: MTEP11 models summary

Associated power flow models in MISO Planning Regions are modeled above. Loads are received directly from members. Generation dispatched by MISO in each region is derived from a number of factors, such as modeling of wind. The 5- and 10-year out models have wind zones dispatched in wind integration studies (Regional Generation Outlet Study and proposed Multi Value Project study). Wind zone modeling is based on wind generation required to meet state renewable portfolio standards. Wind projects required to meet state renewable portfolio standards are incrementally needed beyond existing and planned wind with signed interconnection agreements. These wind zones are spread throughout the MISO footprint. The size of these wind zones is determined in two ways: 1) consideration of existing and planned wind near the region and 2) aggregate MISO renewable portfolio standards requirements in 5- and 10-year scenarios. MISO models all planned and incremental wind-existing required to meet state mandates at 20 percent of capacity in summer peak and 90 percent of capacity in shoulder and light load scenarios.

Near term assessment Near term assessment involves study of the MTEP 2- and 5-year out models. A total of 38 Baseline Reliability Projects (6-MISO East, 6-MISO Central and 26-MISO West Region) and 27 Generation Interconnection Projects (3-MISO East, 8-MISO Central and 16-MISO West Region), adding up to $693 million, are recommended in the planning cycle. More than $685 million in sub-transmission investment is also planned. Detailed documentation of these plans is included in Appendix D1.

Straits power flow control – back to back HVDC voltage source converter A notable near term Baseline Reliability plan in MTEP11 is the Straits HVDC project. Through the years, power transfers through transmission in the Upper Peninsula (UP) of Michigan have increased so much that re-dispatching local generation around the area’s constraints is now a formidable task. The peninsula’s system has been split for extended periods in the past few years. The split was created by opening the electrical connections between Indian Lake and Hiawatha 138 kV stations. Consequently, the Transmission System east of Hiawatha is supplied by local generation and lower Michigan through two Straits 138 kV cables. While operating in this mode for extended periods has effectively trapped through flows, performing maintenance on METC lines in lower Michigan has become harder because of the eastern Upper Peninsula’s reliance on METC tie lines.

A total of 38 Baseline Reliability Projects (6-MISO East, 6-MISO Central and 26-MISO West Region) and 27 Generation Interconnection projects (3-MISO East, 8-MISO Central and 16-MISO West Region), adding up to $702 million, are being recommended in the current planning cycle. More than $676 million in sub-transmission investment is also planned.


106

The planned addition of 200 MW Straits back-to-back DC Voltage Source Converter (VSC) will eliminate the need to split the system to prevent overloads. This improves reliability by keeping the system intact. This will improve system reliability. Modern voltage source converter HVDC technology, unlike line commutated converter HVDC technology, provides dynamic reactive power to improve system voltages. It can also be tuned to improve system damping during system swings. This VSC is expected to be able to produce approximately 100 MVARs of reactive power.

All transmission plans in the final NERC Reliability Assessment include additional planned and proposed transmission projects or operating steps. They are necessary to meet system performance requirements of applicable standards. Noteworthy MISO near term issues within the RFC footprint have been documented below and grouped into the local regions:

Minnesota Most constraints in Minnesota are on the 115 kV transmission lines. In most cases, use of existing Special Protection Schemes (SPS) and Operating Guides (Op-Guide) alleviate thermal issues. Coal Creek runback, Taconite Harbor special protection schemes and Ramsey special protection schemes are notable SPS and Operating Guides used in the constraint mitigation.

Iowa Generation re-dispatch mitigates most identified Iowa constraints. In almost all cases, these constraints are driven by wind. While in the long term, proposed Multi Value Projects will provide needed outlet for these wind resources, in the near term they will need to be curtailed to alleviate thermal constraints.

Southeast Wisconsin Category C events (See Appendix E1 for descriptions of NERC TPL standards) drive a number of southeast Wisconsin generator outlet issues. Generation curtailment associated with outages local to the generators will be used to relieve these constraints.

Marquette County-Michigan Thermal loading issues in Marquette County in the Upper Peninsula of Michigan driven by Category C events were identified in both 2- and 5-year-out models. Local mining load curtailment will be used to mitigate these constraints.

Illinois A few 138 kV constraints in the Mount Vernon and St. Louis metropolitan areas are thermal constraints driven by Category C events. These conditions will be mitigated by reconductoring of a few sections and load curtailment at some stations. Constraints electrically tied closely to the Taum Sauk Pumping Station are identified in the shoulder scenario with Taum Sauk operating in a pumping mode. The situation will be mitigated by a curtailment of interruptible pumping load. Generation redispatch will mitigate a majority of the remaining constraints.


107

Tippecanoe County-Indiana A number of 138 kV loadings here are driven by wind. Proposed Multi Value projects, when approved, will alleviate loadings in the long term planning horizon. Use of wind curtailment through established Operating Guides will be employed to alleviate issues in the near term

Cincinnati-Ohio A couple of 138 kV circuits on the east side of the metropolitan area are overloaded for various category C events. Operating guides involving load switching and operating lines radially will alleviate the thermal constraints in the near term. A proposed project to reconductor circuits is being evaluated for the long term.


108

Long term assessment Long term assessment primarily focuses on reliability issues driven by renewable generation. In addition to existing and planned wind, an incremental 8.5 GW of nameplate capacity is needed in the 10-year planning horizon to meet renewable mandates. The mandates grow further to 10.7 GW in the 15-year out horizon. Growth in wind within five years is compelling wind curtailments. These curtailments will be significant in the long term. The proposed Multi Value Project Study (see Chapter 4.1) shows a possible curtailment of more than 34 TWHr wind energy, in lieu of no long term transmission plans to integrate wind. This equates to about 63 percent of the MISO renewable portfolio standards requirement. As part of the MVP Study, significant transmission (about $5 billion) is planned in the current planning cycle. Though primarily intended to alleviate wind driven constraints in MISO, these projects provide long term help by offloading the underlying 100 kV system, and providing increased outlet for conventional generation as well. These CMVP projects mitigate thermal constraints on about 500 branches for more than 6,400 category B and C contingent events, encompassing study of shoulder and summer peak scenarios.

Figure 6-1: 2011 Proposed MVP portfolio

A brief summary of these new plans is documented below:

Ellendale to Big Stone to Brookings A new line planned from North Dakota into Minnesota provides an outlet to North Dakota wind by directly transferring wind energy at 345 kV, thus offloading the existing 230 kV circuits.


109

Brookings to Twin Cities In addition to transferring wind from North Dakota, this new 345 kV line helps transfer additional southwestern Minnesota wind into Minneapolis-St. Paul. Through various transformations throughout the path, this circuit provides on and off ramps for power transfer.

North LaCrosse to North Madison to Cardinal This new transmission, a continuation of the northern 345 kV path, connects the North Lacrosse station at the Minnesota-Wisconsin border into the Madison load center.

Pleasant Prairie to Zion Energy Center Creating a new tie line between American Transmission Company (ATC) and Commonwealth Edison (ComEd), this new 345 kV circuit provides an outlet for southeast Wisconsin generation noted in the near term assessment, in addition to allowing wind energy transfer from the Dakotas and Minnesota.

Lakefield to Winnebago to Winco-Burt, Lime Creek to Emery to Blackhawk to Hazleton, Sheldon to Burt to Webster 345kV These lines facilitate transfer of wind from MISO’s West Region closer to large load centers in Illinois and Wisconsin by connecting existing wind heavy areas around Lakefield and Sheldon, and further accessing wind in central Iowa from the Lime Creek area to Hazleton. It provides on and off ramps for power transfer through intermediate transformations.

Dubuque County to Spring Green to Cardinal and Oak Grove to Fargo Both projects, one connecting to Madison, Wisconsin; and the other to the northern Illinois station at Fargo, provide an outlet for the Western Region wind and connections to load centers. The two projects also help offload transmission constraints out of the Quad Cities Station.

Ottumwa to Adair to Palmyra This new line provides an outlet for a wind zone in Missouri, and offloads transmission constraints driven through transfers between Iowa and Illinois.

Palmyra to Pawnee to Sugar Creek This 300 mile line connects Palmyra station at the Missouri-Illinois border to Sugar Creek at the Illinois-Indiana border. The project helps facilitate wind energy transfer between MISO’s West and East planning regions.


110

Sidney to Rising This new line helps offload underlying transmission and facilitates power transfer between Illinois and Indiana by closing a short electrical distance between two existing 345 stations, providing increased reliability between the states.

Reynolds to Hiple This new circuit offloads the existing 138 kV parallel circuits by connecting Reynolds station in Indiana’s wind heavy Tippecanoe County to Hiple in northeast Indiana.

Reynolds to Greentown This 765 kV circuit helps further offload existing transmission by creating a new 765 kV station at Reynolds and transferring wind to the closest existing 765 kV station at Greentown. The circuit significantly reduces loadings on 138 kV as well as 345 kV transmission network in Indiana.


111

6.1 Reliability analysis results The results of MTEP11 Reliability Analyses are included in Appendix D.2–D.8 and posted at the Midwest ISO File Transfer Protocol (FTP) site at ftp://mtep.midwestiso.org/mtep11/. MISO Planning Regions are separated into West, Central and East. Refer to Table 6.1-1-2 on the following pages, which shows generation, load, losses and interchange modeled in each of the five planning models used in MTEP11 Reliability Analysis.

Planning Region

BA Name 2013 Summer Peak

Generation Load Loss Interchange

East

NIPSCO 3,149 3,716 50 -617

METC 12,730 9,722 317 2,691

ITCT 10,017 10,883 218 -1,084

Central

HE 1,249 827 34 388

DEI 6,716 7,980 307 -1,577

Vectren 1,561 1,708 22 -169

DEO&K 4,656 5,561 133 -1,042

IP&L 3,371 3,312 72 -17

BREC 1,660 1,638 10 11

CWLD 28 266 1 -239

AmerenMO 9,350 9,251 148 -49

AmerenIL 9,948 9,867 186 -104

CWLP 562 330 3 230

SIPC 256 345 5 -94

West

WEC 7,208 7,067 142 -9

XEL 8,704 10,277 267 -1,846

MP 2,632 1,465 77 1,090

SMMPA 176 556 1 -381

GRE 2,960 2,787 87 83


112

Planning Region

BA Name 2013 Summer Peak

Generation Load Loss Interchange

OTP 1,250 1,702 74 -527

ALTW 4,056 3,895 73 88

MPW 242 161 1 80

MEC 6,294 4,716 93 1,485

MDU 161 548 9 -395

DPC 1,215 926 62 228

ALTE 2,710 2,540 92 75

WPS 2,164 2,782 71 -691

MGE 260 795 12 -547

UPPC 34 224 16 -206

Table 6.1–1: Near term model (2013) generation, load, losses and interchange results by balancing area


113

Planning Region

BA Name 2016 Summer Peak 2016 Shoulder Peak 2016 Light Load

Generation Load Loss Interchange Generation Load Loss Interchange Generation Load Loss Interchange

East

NIPSCO 3,150 3,837 52 -739 1,436 2,953 49 -1,565 2,003 2,092 36 -126

METC 12,806 9,971 299 2,537 7,827 8,351 231 -756 2,347 3,602 126 -1,381

ITCT 11,853 11,165 236 452 11,584 9,475 235 1,874 5,161 3,908 119 1,135

Central

HE 1,443 827 40 576 1,207 827 28 352 1,625 827 25 773

DEI 6,846 8,138 307 -1,606 4,863 5,972 185 -1,301 3,485 3,803 82 -408

Vectren 1,591 1,708 22 -139 899 1,708 26 -835 1,747 1,708 21 19

DEO&K 4,656 5,569 130 -1,047 3,946 4,040 76 -174 3,169 2,514 42 609

IP&L 3,415 3,456 73 -118 2,218 2,417 50 -253 1,179 1,174 16 -15

BREC 1,719 1,671 12 37 1,259 1,473 12 -225 1,449 1,451 13 -15

CWLD 30 351 3 -325 30 254 2 -225 24 173 1 -150

AmerenMO 9,513 9,351 172 -10 6,806 7,510 134 -838 7,258 7,456 113 -312

AmerenIL 10,905 9,988 221 696 10,623 7,986 168 2,468 8,847 8,170 131 546

CWLP 561 330 3 228 562 330 3 229 330 330 1 -2

SIPC 253 362 5 -114 247 262 5 -19 154 133 2 19

West WEC 7,752 7,300 145 298 6,128 5,300 108 712 2,525 3,281 69 -834

XEL 8,426 10,602 255 -2,437 6,977 7,471 233 -733 5,005 5,392 221 -614


114

Planning Region

BA Name 2016 Summer Peak 2016 Shoulder Peak 2016 Light Load

Generation Load Loss Interchange Generation Load Loss Interchange Generation Load Loss Interchange

MP 2,594 1,525 44 1,018 1,907 1,414 39 416 1,742 1,296 82 372

SMMPA 185 676 1 -492 43 484 1 -436 22 347 1 -325

GRE 3,001 2,960 39 -51 1,996 2,074 23 -155 997 1,252 26 -285

OTP 1,241 1,429 81 -270 1,032 1,016 80 -65 1,198 1,037 74 84

ALTW 4,307 4,048 81 178 4,697 2,950 97 1,649 2,998 2,926 130 -58

MPW 247 165 1 81 273 127 1 145 63 98 1 -36

MEC 6,319 5,427 101 791 4,523 3,848 77 591 2,380 2,036 82 262

MDU 188 575 9 -396 134 410 6 -283 152 292 7 -147

DPC 1,187 1,027 60 100 561 752 41 -232 319 478 32 -192

ALTE 2,892 2,654 87 148 2,033 1,940 64 27 1,524 1,233 37 251

WPS 2,522 2,829 68 -377 2,603 2,143 57 402 1,789 1,328 41 418

MGE 288 830 12 -555 10 583 11 -585 40 341 6 -308

UPPC 35 227 14 -207 29 174 8 -152 25 116 2 -94

Table 6.1–2: Generation, load, losses and interchange results by balancing authority


115

Long term models

Planning Region

BA Name 2021 Summer Peak 2021 Shoulder Peak

Generation Load Loss Interchange Generation Load Loss Interchange

East

NIPSCO 3,027 4,006 70 -1,049 1,851 4,006 81 -1,206

METC 12,419 10,368 332 1,720 6,885 10,368 251 -1,074

ITCT 11,370 11,744 248 -622 9,895 11,744 186 979

Central

HE 1,553 827 32 693 972 827 24 333

DEI 7,118 6,299 256 557 4,128 6,299 226 -2,257

Vectren 1,590 1,708 24 -142 1,235 1,708 15 -51

DEO&K 4,426 5,200 127 -905 3,429 5,200 99 -657

IP&L 3,247 3,684 70 -511 2,081 3,684 53 -715

BREC 1,668 1,789 10 -132 1,307 1,789 8 -31

CWLD 85 266 1 -182 70 266 1 -129

AmerenMO 9,495 9,042 184 270 6,925 9,042 157 -1,200

AmerenIL 11,469 10,635 257 577 9,939 10,635 216 1,436

CWLP 669 330 2 336 444 330 2 197

SIPC 277 380 6 -109 226 380 5 -62

West WEC 7,129 7,632 154 -666 5,559 7,632 130 -124

XEL 8,521 11,186 344 -3,015 7,542 11,186 478 -1,257


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Planning Region

BA Name 2021 Summer Peak 2021 Shoulder Peak

Generation Load Loss Interchange Generation Load Loss Interchange

MP 2,538 1,643 95 800 2,066 1,643 84 760

SMMPA 176 754 1 -580 99 754 1 -464

GRE 2,793 3,199 95 -504 1,951 3,199 82 -511

OTP 1,595 1,575 80 -61 2,256 1,575 113 966

ALTW 4,382 4,276 102 4 5,352 4,276 148 2,024

MPW 273 170 2 102 222 170 1 90

MEC 6,253 5,670 106 477 6,906 5,670 146 2,516

MDU 250 618 9 -378 427 618 9 -42

DPC 1,148 1,105 59 -16 830 1,105 70 -61

ALTE 3,420 2,833 92 492 1,876 2,833 87 -283

WPS 2,486 2,910 64 -490 2,538 2,910 77 258

MGE 385 899 12 -527 96 899 24 -560

UPPC 30 228 7 -205 29 228 3 -147

Table 6.1–3: Long term model generation, load, losses and interchange results by balancing authority


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6.2 Steady state analysis results MTEP11 Appendix E1.1.4 lists contingencies tested in steady state analysis. Contingencies were simulated in MTEP11 2013 summer peak, 2016 summer peak, shoulder peak and light load, 2021 summer peak and shoulder peak models. All steady state analysis-identified constraints and associated mitigations are tabulated in results tables in MTEP11 Appendix D.3.

6.3 Voltage stability analysis results MTEP11 Appendix E1.1.1 lists types of transfers tested in voltage stability analysis. The study did not find low voltage areas or voltage collapse points for critical contingencies in transfer scenarios close to the base load levels modeled in the MTEP11 2016 summer peak and shoulder peak models. A summary report with associated p-v plots is documented in MTEP11 Appendix D.4.

6.4 Dynamic stability analysis results MTEP11 Appendix E1.1.4 lists types of disturbances tested in dynamic stability analysis. Disturbances were simulated in MTEP11 2016 light load and shoulder peak load models. The system was stable. Results tables listing all simulated disturbances along with damping ratios are tabulated in MTEP11 Appendix D.5.

6.5 Generator deliverability analysis results Generator deliverability analysis was performed in MTEP11 to ensure continued deliverability of aggregate deliverable network resources. A total of 370 MW of deliverability is restricted due to constraints identified in MTEP11. These constraints have not been planned for in the current MTEP cycle and will be investigated in the subsequent MTEP cycle (MTEP12). This compares to more than 900 MW in MTEP10 and more than 3,000 MW of restricted deliverability in MTEP09. This progressive reduction in restricted deliverability has been accomplished through planned upgrades in past MTEP cycles.

MTEP10 Deliverability Constraint Total

Generation Restricted

Percentage of MWs

Impacted

Rating (MVA)

Percent Overload

MTEP Project

ID

Target Appendix MTEP11

Boone Jct.--Ft. Dodge 161 kV line

226 23 percent 147 115.8 2941 C

East Calamus--Grand Mound 161 kV line

237 24 percent 176 112.8 1619 In Service in

MTEP11, A in MTEP08

Table 6.5-1: The list of mitigations for the outstanding constraints from MTEP10 that were proven effective


118

The description of table 6.5-2 column headings is below.

● An Overload Branch is caused by “bottling-up” of aggregate deliverable generation. Deliverability was tested only up to the granted NR (Network Resource) levels of the existing and future NR units modeled in the MTE11 2016 case.

● Use the Map ID to find an approximate location of the overloaded element on Fig. 6.5-1

● Contingency is the outage created in the overload. In some cases, the system may be system intact, so there is no outage. Detailed contingency definitions are included in the Appendix.

● Rating is the rating of the overloaded element used in the analysis. It’s normal if the system is intact, but an emergency for post contingent constrained branches.

● Delta Increase is the difference in loading after ramping up generation compared to before ramping up of generation in the “gen pocket.”

Overloaded Branch Area Map ID Contingency

Rating (MVA)

Delta Increase

Wilmarth to Swan Lake 115 kV line XEL 1 Wilmarth to Helena 345 kV line 110 19.19

percent

Wilmarth to Eastwood 115 kV line XEL 1 Wilmarth to Summit 115 kV line 190.8 4.59

percent

Medford Jct. to Waseca Junction 69 kV line

ALTW 1 Loon Lake to Loon Lake Tap 115 kV

line 30

8.23 percent

Turkey Hill 345/138 kV transformer33

AMIL 2 C-BLWN-4511

Caokia 345/138 kV transformer Cahokia to Baldwin 345 kV line

672 1.81

percent

Table 6.5-2: The MTEP11 constraints that limit deliverability of about 370 MW of Network Resources. See Appendix D6 for the detailed results with a list of impacted Network Resources.

33 The Turkey Hill 345/138 kV transformer has a MTEP Appendix C project 3001 that will mitigate the deliverability constraint. Projects targeted as mitigation for deliverability constraints will be moved to Appendix B.


119

Figure 6.5-1: General location of MTEP11 2016 SUPK baseline generator deliverability constraints

MISO will create a Technical Review Group of stakeholders to address generator deliverability issues in the MTEP12 planning cycle.


120

6.6 Long Term Transmission Rights (LTTR)

This section documents planned upgrades to address constraints driving infeasibility of Long Term Transmission Rights. Refer to Table 6.6-1, which shows the uplift costs associated with the infeasible LTTRs in the 2011 Annual Allocation.

Year Total Stage1A

(GW) Total LTTR

Payment ($M) Total Infeasible

Uplift ($M) Uplift Ratio

2011 Allocation 354.3 211.2 7.6 3.60 percent

Table 6.6-1: Uplift costs associated with infeasible LTTR in the 2010 annual allocation

Refer to Table 6.6-2, which further details the infeasible uplift to binding constraints from the annual auction. Binding constraints are filtered for those with values greater than $75,000. Planned mitigations have been documented against constraints where future proposed or planned upgrades have already been identified through other planning studies. MISO constraints with no identified plans in the current planning cycle result in uplift of less than $600 thousand or less than 10 percent. MISO will coordinate with its Transmission Owners on investigation of these constraints in MTEP12 planning cycle. Additionally, MISO will coordinate with adjacent RTOs on seams constraints.

Table 6.6-2: Infeasible uplift to binding constraints from the annual auction

Constraint Summer

2011 Fall 2011

Winter 2011

Spring 2012

Grand Total

Planned Mitigation

'3442' (Rising 345/138 TR1 (flo) Dresden - Pontiac 345kV )

$0 $1,160,037 $245,685 $0 $1,405,721 P2239 Rising to Sidney 345kV CMVP Line ISD:

6/1/2017

'3191' (IP Rising 345/138 XFMR 1 (flo) Clinton - Brokaw 345 (IP4535))

$661,750 $0 $0 $0 $661,750 P2239 Rising to Sidney 345kV CMVP Line ISD:

6/1/2017

FOX_LK 500 161 kV to RUTLAND 500 161 kV

$93,517 $362,743 $0 $12,870 $469,130

3205 Lakefield-Burt & Sheldon-Webster 345

kV line 3213 Candidate MVP Portfolio 1 - Winco to

Hazleton 345 kV

'3570' (Pleasant Prairie-Zion Energy Center 345 flo Cherry Valley-Silver Lake 345 R)

$8,163 $217,895 $317 $5,725 $232,100

P2844 Pleasant Prairie - Zion Energy Center

CMVP ISD: 3/6/2014 and P3022 Oak Grove -

Fargo CMVP ISD: 12/31/2016

'3451' (Edwards-Kewanee (CE) 138kV (flo) Powerton-Goodings Gr (R)+Powerton

$230,959 $0 $0 $0 $230,959 Palmyra – Meredosia – Pawnee + Meredosia – Ipava CMVP Line ISD:


121

Constraint Summer

2011 Fall 2011

Winter 2011

Spring 2012

Grand Total

Planned Mitigation

(R)-Powerton (B) 345kV) 6/1/2018

CEDAR_RG 3 138 kV to OHMSTEAD 1 138 kV

($153) $211,978 $2,702 ($495) $214,033 no planned upgrade

LUCAS 358 161 kV to LUCAS 369 69.0 kV

$79,263 $47,607 $0 $79,263 $206,134

P3170 CMVP line from Ottumwa – Adair –

Palmyra – Thomas Hill ISD: 6/1/2018

'3443' (Coffeen North-Ramsey 345kV (flo) Praire State-W Mt Vernon 345kV + W Mt Vernon 345/138kV TR4)

$0 $197,097 $0 $0 $197,097

P2237, P2238 and P2240 CMVP line from Pana to Mount Zion to Kansas to Sugar Creek 345 kV ISD: 6/1/2020

'3180' (W. Mt. Vernon-E. W. Frankfort 345 (flo) St. Francois-Lutesville 345)

$7,438 $174,845 $0 $0 $182,282

P2295 Upgrade terminal equipment on W. Mt.

Vernon-E. W. Frankfort 345 kV ISD: 6/1/2012

'6214' (Bunge-Hastings 161 kV flo Cooper-St. Joe 345 kV)

$58,400 $79,302 $37,151 ($264) $174,589 No MISO planned

upgrade

'3771' (Pleasant Prairie - Zion 345kV)

($188) $172,630 $0 ($2,460) $169,982

P2844 Pleasant Prairie - Zion Energy Center

CMVP ISD: 3/6/2014 and P3022 Oak Grove -

Fargo CMVP ISD: 12/31/2016

RICH2 4 230 kV to ROSEAUMP 400 230 kV

$22,475 $100,784 $0 $23,259 $146,518 Manitoba Constraint

'3646' (Nucor-Whitestown 345kV (flo) Rockport-Jefferson 765kV)

$0 $107,761 $17,251 $0 $125,012 P3203 Reynolds to Greentown 345kV

CMVP ISD: 12/31/2013

'3737' (Alliat Hills 345/161 Xfmr flo Tiffin-Duane Arnold 345 + Tiffin-Hills 345)

$0 $99,826 $22,465 $0 $122,291

P1344 Build a new 345 kV Morgan Valley

(Beverly) substation which taps the Arnold -Tiffin 345 kV line ISD:

12/31/2014

'6061' (Richer -- Roseau 230kV line (R50M))

$0 $113,054 $0 $0 $113,054 Manitoba Constraint


122

Constraint Summer

2011 Fall 2011

Winter 2011

Spring 2012

Grand Total

Planned Mitigation

'2571' (Marktown - Inland Steel 5 138kV (flo) Burnham - Munster 345kV)

$0 $104,875 $6,743 $0 $111,618 P2792 Northwest Circuit

reconfiguration ISD: 12/1/2013

WINBALTW 572 69.0 kV to DELEAST 794 69.0 kV

$8,288 $0 $0 $102,475 $110,762 no planned upgrade

ROSEAUMP 400 230 kV to MORNVLL 400 230 kV

$48,038 $30,945 $9,035 $21,987 $110,005 Manitoba Constraint

KANSAS00 HAB 138 kV to HARBOR01 4 138 kV

$0 $96,544 $5,946 $0 $102,489 Manitoba Constraint

'1613' (Volunteer - Phipps Bend 500)

$14,828 $101,497 ($20,853) $5,282 $100,754 TVA Constraint

'549' (Dresden-Elwood 1222 345 kV l/o Dresden-Electric 1223 345 kV)

$100,293 $0 $434 $0 $100,727 PJM Constraint

'3312' (Lanesville 345/138kV Xfmr (flo) Lanesville - Brokaw - Pontiac 345kV)

$28,717 $31,182 $33,304 $0 $93,203

P2236, P2237, P2238 345kV loop around area

including additional 345/138kV transformers.

'2497' (State Line-Wolf Lake 138)

$0 $90,273 $0 $0 $90,273 P2792 Northwest Circuit

reconfiguration ISD: 12/1/2013

'6124' (Sub K/Tiffin-Arnold 345kV)

$84,536 $0 $0 $4,922 $89,459

P3022 Oak Grove - Fargo 345kV CMVP line

ISD: 6/1/2016 and P3127 Dubuque -

Cardinal 345kV CMVP line ISD: 12/31/2020

'3353' (Lanesville 345/138 (flo) Kincaid - Pawnee 345 + 2106 SPS)

$81,727 ($14,531) $16,830 $0 $84,026

P2236, P2237, P2238 345kV loop around area

including additional 345/138kV transformers.

6007' (GENTLMN3 345 REDWILO3 345 1)

($270) $96,112 ($14,467) ($639) $80,737 MRO Contraint

'2336' (BentnHrbr-Palisades345/Cook-Palisades345)

$0 $76,971 $0 $0 $76,971 no planned upgrade

DRAFT – MISO Transmission Expansion Plan 2011 Appendices

123

Appendices

Most MTEP11 appendices are available and accessible on the MISO public webpage. Confidential appendices, such as D.2 - D.8, are available on the MISO MTEP11 FTP site. Access to the FTP site requires an id and password.

A link to the MTEP11 appendices, on the MISO public website, is below:

https://www.midwestiso.org/Library/Pages/ManagedFileSet.aspx?SetId=694

The confidential appendices are located at:

ftp://mtep.midwestiso.org/mtep11/

Appendix A: Projects recommended for approval

Section A.1, A.2, A.3: Cost allocations Section A.4: MTEP11 Appendix A new projects

Appendix B: Projects with documented need & effectiveness Appendix C: Projects in review and conceptual projects Appendix D: Reliability studies analytical details with mitigation plan (ftp site)

Section D.1: Project justification Section D.2: Modeling documentation Section D.3: Steady state Section D.4: Voltage stability Section D.5: Transient stability Section D.6: Generator deliverability Section D.7: Contingency coverage Section D.8: Nuclear plant assessment

Appendix E: Additional MTEP11 Study support Section E.1: Reliability planning methodology Section E.2: Generations futures development Section E.3: MTEP11 futures retail rate impact methodology

Section E.4: Proposed MVP portfolio steady state and stability results Section E.5: Proposed MVP portfolio business case presentation Section E.6: Resource assessment results

Appendix F: Stakeholder substantive comments

MTEP11 Midwest ISO Transmission Expansion Plan 2011

Project Table Field Legend

Appendix A contains projects which are being or have been approved by Midwest ISO Board of Directors.Transmission Owners are obligated to make a good faith effort to construct projects in Appendix A.

Appendix B projects have been reviewed by Midwest ISO staff for need and effectivenes.

Appendix C projects are new to planning process or conceptual

Project table has blue highlighted header. A project may have multiple facilties. Facility table has yellow highlighted header. A project's facilities may have different in service dates.


Field DescriptionTarget Appendix Target appendix for the MTEP11 planning cycle. "A in MTEP11" projects were reviewed and approved in

MTEP11. This column also indicates what projects were approved in prior MTEPs that are not yet in service.

Region Midwest ISO Planning Region: Central, East or WestGeographic Location by TO Member System

Project geographic location by Transmission Owner member systems

PrjID Project ID: Midwest ISO project identifierProject Name Project name (short name)Project Description A description of the project's componentsState 1 State project is located or first state if in multiple statesState 2 If applicable, the second state the project is locatedAllocation Type per FF Project Type per Attachment FF of Tariff. BaseRel is Baseline Reliability, GIP is Generator Interconnection

Project, TDSP is Transmission Delivery Service Project, RegBen is Regionally Beneficial Project, Other is non of the above. Preliminary project types may be designated for Appendix B and C projects

Share Status Projects moving to Appendix A in current planning cycle are eligible for cost allocation per terms in Attachment FF. Projects are Shared, Not Shared or Excluded. Preliminary sharing designations may be input for Appendix B or C projects.

Other Type Indicates the project driver behind Other type projects. Estimated Cost Total estimated project cost from Facility tableExpected ISD (Min/Max) Dates when project is expected to be in service. Min and Max dates. Expected ISD are in Facility table.Plan Status Indicates where project is in planning or implementation. Proposed, Planned, Under Construction, In

Service. Minimum of information in Facility tableMax kV Maximum facility voltage in project. Summary information from Facility tableMin kV Minimum facility voltage in project. Summary information form Facility tableApp ABC Appendix the project is in. B>A or C>B for projects moving during this planning cycle.MISO Facility Y for facilities under Midwest ISO functional control. NT for non-transferred facilities under Agency

Agreements

MTEP11 MISO Transmission Expansion Plan 2011 Appendix AAppendix A: Project Table 9/7/2011 Project Summary Information from Facility table

Target Appendix

Planning Region

Geographic Location by TO Member System PrjID Project Name Project Description State 1 State2

Allocation Type per FF Share Status Other Type Estimated Cost

Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP11 Central AmerenIL 2065 Stallings 345/138 kV Sub - Replace 560 MVA 345/138 kV transformer

Stallings 345/138 kV Substation-Replace 560 MVA, 345/138 kV Transformer with 700 MVA unit. Install a 345kV ring bus

IL BaseRel Shared $10,075,000 6/1/2012 6/1/2012 Planned 345 138 B>A Y

A in MTEP11 Central AmerenIL 2239 Candidate MVP Portfolio 1 - Sidney to Rising 345 kV line

Sidney to Rising 345 kV line, plus 345 kV ring bus at Rising and breaker-and-a-half arrangement at Sidney.

IL MVP Shared $83,230,000 6/1/2016 11/15/2016 Planned 345 B>A Y

A in MTEP11 Central AmerenIL 2980 Tazewell-San Jose Rail - Reconductoring Tazewell-San Jose Rail Substation section of East Springfield-Tazewell-1384 138 kV Line - Reconductor 3.67 miles of 927 kcmil ACAR conductor at the Tazewell end of the line with conductor capable of carrying at least 1278 A under summer emergency conditions

IL BaseRel Not Shared $3,251,000 6/1/2013 6/1/2013 Planned 138 B>A Y

A in MTEP11 Central AmerenIL 2981 McLean-Oglesby 138 kV Reconductor Replace 9.72 miles of 138 kV line on L1382, from McLean County Substation to El Paso Tap to a minimum 1200A SE capability

IL BaseRel Not Shared $5,100,000 9/1/2013 9/1/2013 Planned 138 B>A Y

A in MTEP11 Central AmerenIL 3017 Candidate MVP Portfolio 1 - Palmyra -Quincy-Meredosia - Ipava & Meredosia-Pawnee 345 kV Line

Palmyra Tap to Quincy to Meredosia to Ipava 345 line and Meredosia to Pawnee 345 kV line. Install additional transformers at Quincy, Meredosia and Pawnee. 345 kV ring bus at Quincy, Meredosia, and Ipava, with breaker-and-a-half arrangement at Pawnee and Palmyra Tap Substations.

IL MVP Shared $432,160,000 6/1/2016 11/15/2017 Planned 345 138 B>A Y

A in MTEP11 Central AmerenIL 3169 Candidate MVP Portfolio 1 - New Pawnee to Pana - 345 kV Line

Pawnee to Pana 345 kV, 31 mile line including additional transformer at Pana


A in MTEP11 Central AmerenIL 3337 G931 Paxton-Gilman Reconductoring Reconductor to 1200 A summer emergency capability IL GIP Not Shared $7,390,000 12/1/2013 12/1/2013 Planned 138 C>B>A YA in MTEP11 Central AmerenIL 3357 Hennepin-E. Kewanee L1552 - Increase

Ground ClearanceG545 and G569 Increase ground clearance on 477 kcmil ACSR conductor to permit operation at 120 degrees C. Upgrade E. Kewanee breaker and terminal equipment to 1200 A capability

IL GIP Not Shared $3,180,000 12/31/2012 12/31/2012 Planned 138 C>B>A Y

A in MTEP11 Central AmerenIL 3358 G545 Generator connection and bus rearrangement - E. Kewanee

Rearrange 138 kV bus at E. Kewanee and install terminal equipment (including 1200 A breaker) to connect wind farm (G545)


A in MTEP11 Central AmerenIL 3359 G569 Generator connection and bus upgrade - E. Galesburg

Upgrade 138 kV bus at E. Galesburg and install terminal equipment, including 1200 A breaker, to facilitate connection of wind farm (G569).

IL GIP Not Shared $834,000 10/1/2012 10/1/2012 Planned 138 C>B>A Y

A in MTEP11 Central AmerenIL 3360 G931 Generator connection and Establishment of Sheldon Soth Switching Station

Construct a new 138 kV switching station to connect a new wind farm (G931) to the Watseka-Morrison Ditch-1 138 kV line. Upgrade relaying at Watseka terminal.

IL GIP Not Shared $4,425,000 5/6/2011 5/6/2011 In Service 138 C>B>A Y

A in MTEP11 Central AmerenIL 3361 G996 Generator connection and bus upgrade - Paxton, South

Install terminal equipment, including 2000 A breaker, to facilitate connection of wind farm (G996). Install 2000 A bus-tie breaker


A in MTEP11 Central AmerenIL 3370 Oreana Substation - Add 138-69 kV Transformer

To accommodate the installation of a new 138-69 kV transformer at Oreana, install 1-2000 A breaker and 2-2000 A disconnect switches to expand ring bus. Install 138 kV, 600 A motor operated disconnect switch at high-side of new 138-69 kV transformer.

IL Other Not Shared Condition $750,000 6/1/2012 6/1/2012 Planned 138 C>B>A Y

A in MTEP11 Central AmerenIL, DEM 2237 Candidate MVP Portfolio 1 - Pana - Mt. Zion - Kansas - Sugar Creek 345 kV line

Pana to Mt. Zion to Kansas to Sugar Creek 345 kV line. Install transformers at Mt. Zion and Kansas, with 345 kV ring bus at Mt. Zion and breaker-and-a-half arrangement at Kansas and Pana.


A in MTEP11 Central AmerenIL, MEC 3022 Candidate MVP Portfolio 1 - Fargo-Oak Grove 345 kV Line

Fargo-Galesburg-Oak Grove (MEC) 345 kV Line - New 70 mile, 3000 A summer emergency capability line. 345 kV ring bus at Fargo.

IA IL MVP Shared $272,249,969 12/1/2014 11/15/2019 Planned 345 138 B>A Y

A in MTEP11 Central AmerenMO 2306 Nortwest Cape Area 345/161 kV Substation Install 560 MVA, 345/161 kV Transformer. Provide 345 kV supply from 11 mile 345 kV line extension from Lutesville Substation

MO BaseRel Shared $30,751,000 6/1/2016 6/1/2016 Planned 345 161 B>A Y

A in MTEP11 Central AmerenMO 3170 Candidate MVP Portfolio 1 - West Adair-Palmyra Tap 345 kV Line

West Adair - Palmyra 345 kV, 58 miles of line; Establish Palmyra Tap Substation

MO MVP Shared $112,790,000 11/15/2016 11/15/2020 Planned 345 B>A Y

A in MTEP11 Central AmerenMO 3355 Labadie Breaker Replacements Replace Breakers on Bland and Montgomery line positions with 3000 A, 50 kA breakers

MO Other Not Shared Reliability $2,610,000 12/31/2011 12/31/2011 Planned 345 C>B>A Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP11 Central AmerenMO 3368 Bailey Substation Install 2-2000 A bus-tie breakers and 2-138 kV circuit switchers

MO Other Not Shared Reliability $4,000,000 6/1/2012 6/1/2012 Planned 138 C>B>A Y

A in MTEP11 Central AmerenMO, ITCM

2248 Candidate MVP Portfolio 1 - Adair - Ottumwa 345

West Adair Substation - New 560 MVA, 345/161 kV Transformer. New 71 mile 345 kV line from Adair to Ottumwa with 3000 A summer emergency capability. 345 kV ring bus at West Adair

IA MO MVP Shared $244,627,764 6/1/2017 11/15/2020 Planned 345 161 B>A Y

A in MTEP11 Central DEM 3377 Scottsburg 69kV - 28.8MVAR Capacitor Replace Scottsburg 69kV - 7.2Mvar capacitor with a 28.8 Mvar capacitor and upgrade 69kV capacitor switching equipment

IN Other Not Shared Reliability $500,000 12/31/2015 12/31/2015 Planned 69 C>B>A Y

A in MTEP11 Central DEM 3378 Canal 69kV Dist Sub Canal Sub - Purchase land and build 22.4MVA, 69/12kV sub near Canal Road and Allison Street in the 5762 ckt.

OH Other Not Shared Reliability $756,196 6/1/2012 6/1/2012 Planned 69 12 C>B>A Y

A in MTEP11 Central DEM 3379 Shelbyville McKay Rd. 69kV Dist Sub Shelbyville McKay Rd. - add new 69/12kV distribution sub in the 6976 ckt. Loop through with 954acsr and a set of 1200A line switches.

IN Other Not Shared Reliability $303,710 6/1/2014 6/1/2014 Planned 69 12 C>B>A Y

A in MTEP11 Central DEM 3380 Noblesville Sta. 138kV Brkrs and 345kV Ckt Sws

Noblesville Gen. Sta. - Replace 138KV OB OCB: 138TR, 13869-9, 138230-7, 13886 and Circuit Switchers: 345230-11, 34519.

IN Other Not Shared Condition $2,909,606 12/31/2011 12/31/2011 Planned 345 138 C>B>A Y

A in MTEP11 Central DEM 3383 H.E. Rocklane Alternate 69kV Feed Ckt. 6999 new Sherman Rd. Jct. to H.E. Rocklane line section. Replace DEM 69kV poles to accommodate new H.E. tap line. This will be an alternate feed to Rocklane - operated N.O. - built and owned by HE, inside DEM area.

IN Other Not Shared Reliability $64,568 2/6/2011 2/6/2011 In Service 69 C>B>A Y

A in MTEP11 Central DEM 3384 Hortonville to Marathon Jct. 69kV Reconductor

Hortonville to Marathon Jct. section of ckt. 6917 - Replace 336ACSR and 477ACSR with 954ACSS@200C. Upgrade Marathon Jct 600A switches to 1200A.

IN Other Not Shared Reliability $1,409,099 12/1/2012 12/1/2012 Planned 69 C>B>A Y

A in MTEP11 Central DEM 3385 Carmel Homeplace to Springmill Jct 69kV Reconductor

Carmel Homeplace to Springmill Jct. section of ckt. 69155 - Reconductor with 954ACSS@200C


A in MTEP11 Central DEM 3386 Carmel Springmill Rd. to Hortonville 69kV Line and Brkrs

Carmel Springmill Rd. Sub - Add 3-69kV breakers in straight bus config and build new .23 mile 69kV 954ACSS@200C line from Springmill Sub to old Springmill Jct. to complete circuit to Hortonville. Change operating mode at Homeplace to close loop from 146th to Springmill.


A in MTEP11 Central DEM 3387 Tri-County Wind Energy 230kV Station - DPP J028

J028 - 230kV - Gen. interconnect sub - install three brkr ring bus for 200MW wind farm between Attica and Lafayette in the 23027 ckt.

IN GIP Not Shared $3,778,246 6/1/2013 6/1/2013 Planned 230 C>B>A Y

A in MTEP11 Central DEM 3388 Walton to Logansport S. 69kV Reconductor Walton to Logansport S. - Reconductor 69kV - 69110 line with 477acsr at 100C


A in MTEP11 Central DEM 3389 WVPA Center Valley 138kV Dist Sub DEM to install new line switching in the 138kV - 13867 ckt. at intersection with SR39 for tap line to radially feed new WVPA Center Valley dist sub

IN Other Not Shared Reliability $236,677 12/1/2011 12/1/2011 Planned 138 12 C>B>A Y

A in MTEP11 Central DEM 3390 Inland Container to Hillsdale 69kV Line Rebuild

Rebuild 69kV - 6906 line from Inland Container to WROW Jct. to Hillsdale - 477acsr26x7 at 100C

IN Other Not Shared Condition $3,663,434 12/31/2011 12/31/2011 Planned 69 C>B>A Y

A in MTEP11 Central DEM 3391 Elnora to Newberry 69kV Line Rebuild Rebuild 69kV - 6959 line section from Elnora to Newberry - 477acsr26x7 at 100C

IN Other Not Shared Condition $1,716,818 12/31/2011 12/31/2011 Planned 69 C>B>A Y

A in MTEP11 Central DEM 3392 DEM Speed to LGEE Paddys West 345kV tie

New DEM Speed to LGEE Paddys West 345kV tie line IN Other Not Shared Reliability $15,000,000 12/31/2012 12/31/2012 Planned 345 C>B>A Y

A in MTEP11 Central DEM, NIPS 2202 Candidate MVP Portfolio 1 - Reynolds to Greentown 765 kV line

Reynolds to Greentown 765 kV line IN MVP Shared $186,875,000 6/1/2018 8/1/2018 Planned 765 345 B>A Y

A in MTEP11 Central IPL 3273 Southwest - Stout CT Line Rating Upgrade Increase line rating above 322 MVA to mitigate the potential overload


A in MTEP11 Central IPL 3274 South - Stout S Line Rating Upgrade Increase line rating above 272 MVA to mitigate the potential overload


A in MTEP11 Central Vectren (SIGE) 2460 Leonard Rd 69kV Substation Add new 69kV switching substation near Leonard Rd IN Other Not Shared Reliability $2,150,000 6/1/2013 6/1/2013 Planned 69 C>B>A NTA in MTEP11 Central Vectren (SIGE) 2462 Y53 Stringtown to Folz Reconductor Reconductor existing 69kV line for more capacity IN Other Not Shared Condition $2,500,000 6/1/2013 6/1/2013 Planned 69 C>B>A NTA in MTEP11 Central Vectren (SIGE) 2463 Y31 Mt Vernon to Givens 69kV recond. Reconductor existing 69kV line for more capacity IN Other Not Shared Condition $5,700,000 6/1/2013 6/1/2013 Planned 69 C>B>A NT


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP11 Central Vectren (SIGE) 2464 Y33 Mt Vernon to New Harmony 69kV recond.

Reconductor existing 69kV line for more capacity IN Other Not Shared Condition $10,600,000 6/1/2014 6/1/2014 Planned 69 C>B>A NT

A in MTEP11 East ITC 1868 Cato GIS replacement Replace GIS Equipment MI Other Not Shared Condition $5,400,000 12/1/2012 12/1/2012 Planned 120 C>B>A YA in MTEP11 East ITC 2931 Adams-Spokane/Burns1-Jewel 120 kV

RebuildRebuild 2.4 miles of DC 3/0 Cu 120 kV lin to 1431 ACSR 230 kV construction.

MI BaseRel Not Shared $3,200,000 6/30/2012 6/30/2012 Proposed 120 C>B>A Y

A in MTEP11 East ITC 3276 ITCT Annual Breaker Replacement Program for 2013

Annual Breaker Replacement Program Mi Other Not Shared Condition $9,000,000 12/31/2013 12/31/2013 Planned C>B>A Y

A in MTEP11 East ITC 3277 ITCT Annual NERC Relay Loadability Compliance Program for 2013

Annual NERC Relay Loadability Program Mi Other Not Shared Reliability $2,400,000 12/31/2013 12/31/2013 Planned C>B>A Y

A in MTEP11 East ITC 3278 ITCT Annual Potential Device Replacement Program for 2013

Annual Potential Device Replacement Program Mi Other Not Shared Condition $300,000 12/31/2013 12/31/2013 Planned C>B>A Y

A in MTEP11 East ITC 3279 ITCT Annual Relay Betterment Program for 2013

Annual Relay Betterment Program Mi Other Not Shared Condition $1,800,000 12/31/2013 12/31/2013 Planned C>B>A Y

A in MTEP11 East ITC 3280 ITCT Annual Wood Pole Replacement Program for 2013

Annual Wood Pole Replacement Program Mi Other Not Shared Condition $3,000,000 12/31/2013 12/31/2013 Planned C>B>A Y

A in MTEP11 East ITC 3281 Lima Substation Distribution Interconnection Request Mi Other Not Shared Distribution $8,400,000 12/31/2012 12/31/2012 Planned 120 C>B>A YA in MTEP11 East ITC 3283 Dexter Township Substation Distribution Interconnection Request Mi Other Not Shared Distribution $2,676,000 11/1/2012 11/1/2012 Planned 120 C>B>A YA in MTEP11 East ITC 3284 ITCT Customer Interconnections - Year

2015Distribution Interconnection Request Mi Other Not Shared Distribution $2,000,000 12/31/2015 12/31/2015 Planned C>B>A Y

A in MTEP11 East ITC 3285 Fermi & Shoal 120kV Capacitors 33.3 Mvar Capacitors at Fermi and Shoal 120kV Mi BaseRel Not Shared $3,800,000 6/1/2013 6/1/2014 Planned 120 C>B>A YA in MTEP11 East ITC 3286 Fermi 345kV Disconnect Replacement

Project - 3rd RowReplace 345kV Disconnects, add 3rd 345kV Row Mi Other Not Shared Condition $5,050,000 4/30/2012 12/31/2013 Planned 345 C>B>A Y

A in MTEP11 East ITC 3495 NERC Alert Facility Ratings for 2011 Verify and remediate facilities as required due to the industry-wide NERC alert

MI Other Not Shared Reliability $1,700,000 12/31/2011 12/31/2011 Planned C>B>A Y

A in MTEP11 East ITC 3503 Air Flow Spoilers Installation Install air flow spoilers on approximately 15 miles of the targeted areas of the Belle River-Greenwood-Pontiac and Belle River-Blackfoot 345 kV double circuit tower lines.

MI Other Not Shared Reliability $1,620,000 12/31/2012 12/31/2012 Planned 345 C>B>A Y

A in MTEP11 East ITC 3516 J025-Macomb County LF Gas Gen. Facility 12.8 MW LF Gas Gen. tapping the Carbon Tap on the 120kV Jewell - St. Clair 120kV line.

MI GIP Shared $485,000 9/1/2011 9/1/2011 Planned 120 C>B>A Y

A in MTEP11 East METC 1809 Keystone-Hodenpyl 138 kV Rebuild Rebuild the 27 mile Keystone to Hodenpyl 138 kV line to 954 ACSR (Pre-build to 230 kV construction).

Mi BaseRel Shared $32,600,000 12/31/2013 12/31/2013 Planned 138 C>B>A Y

A in MTEP11 East METC 2812 Twining - Alcona 138kV Rebuild Rebuild the Twining-Mio 138kV 38 mile line to 954 ACSR future-double-circuit (pre-built to 230kV)

MI BaseRel Shared $43,300,000 5/31/2012 5/31/2012 Planned 138 C>B>A Y

A in MTEP11 East METC 3139 Tippy-Wexford 138 kV Circuit Uprgrade Terminal Equipment upgrade at Tippy MI Other Not Shared Reliability $20,000 6/1/2012 6/1/2012 Planned 138 C>B>A YA in MTEP11 East METC 3287 Riggsville Rebuild Rebuild 138 kV bus and switches Mi Other Not Shared Condition $4,600,000 9/30/2011 9/30/2011 Planned 138 C>B>A YA in MTEP11 East METC 3288 METC Annual Breaker Replacement

Program for 2013Annual Breaker Replacement Program Mi Other Not Shared Condition $6,000,000 12/31/2013 12/31/2013 Planned C>B>A Y

A in MTEP11 East METC 3289 METC Annual NERC Relay Loadability Compliance Program for 2013

Annual NERC Relay Loadability Program Mi Other Not Shared Reliability $2,400,000 12/31/2013 12/31/2013 Planned C>B>A Y

A in MTEP11 East METC 3290 METC Annual Potential Device Replacement Program for 2013

Annual Potential Device Replacement Program Mi Other Not Shared Condition $300,000 12/31/2013 12/31/2013 Planned C>B>A Y

A in MTEP11 East METC 3291 METC Annual Relay Betterment Program for 2013

Annual Relay Betterment Program Mi Other Not Shared Condition $1,200,000 12/31/2013 12/31/2013 Planned C>B>A Y

A in MTEP11 East METC 3292 METC Annual Wood Pole Replacement Program for 2013

Annual Wood Pole Replacement Program Mi Other Not Shared Condition $4,800,000 12/31/2013 12/31/2013 Planned C>B>A Y

A in MTEP11 East METC 3293 METC Annual Battery Replacement Program for 2013

Annual Battery Replacement Program Mi Other Not Shared Condition $100,000 12/31/2013 12/31/2013 Planned C>B>A Y

A in MTEP11 East METC 3294 METC Annual Power Plant Control Relocation Program for 2013

Annual Power Plant Control Relocation Program Mi Other Not Shared Operations $3,120,000 12/31/2013 12/31/2013 Planned C>B>A Y

A in MTEP11 East METC 3295 METC Sag Clearance Program for 2013 Sag Clearance Program Mi Other Not Shared Clearance $3,600,000 12/31/2013 12/31/2013 Planned C>B>A YA in MTEP11 East METC 3296 METC Spill Prevention Control and

Countermeasure Program for 2011Annual SPCC Program Mi Other Not Shared Condition $3,100,000 12/31/2011 12/31/2011 Planned C>B>A Y

A in MTEP11 East METC 3297 METC Spill Prevention Control and Countermeasure Program for 2012

Annual SPCC Program Mi Other Not Shared Condition $3,100,000 12/31/2012 12/31/2012 Planned C>B>A Y

A in MTEP11 East METC 3298 METC Spill Prevention Control and Countermeasure Program for 2013

Annual SPCC Program Mi Other Not Shared Condition $3,100,000 12/31/2013 12/31/2013 Planned C>B>A Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP11 East METC 3299 METC Customer Interconnections - Year 2015

Distribution Interconnection Request Mi Other Not Shared Distribution $2,500,000 12/31/2015 12/31/2015 Planned C>B>A Y

A in MTEP11 East METC 3303 Cottage Grove-East Tawas 138 kV Rebuild Rebuild 12.3 miles of 138 kV line MI BaseRel Shared $11,400,000 6/1/2015 6/1/2015 Planned 138 C>B>A Y

A in MTEP11 East METC 3304 Croton-Nineteen Mile 138 kV Rebuild Rebuild 21.5 miles of 138 kV 110 CU to 954 ACSR (Pre-build to 230 kV construction).

Mi BaseRel Shared $26,600,000 12/31/2013 12/31/2013 Planned 138 C>B>A Y

A in MTEP11 East METC 3306 Karn-Cottage Grove 138 (Karn Position 488) Relay Replacement Project

Mi Other Not Shared Reliability $200,000 6/1/2012 6/1/2012 Planned 138 C>B>A Y

A in MTEP11 East METC 3308 Livingston to Gaylord 138 kV Dual Pilot Relay Protection Scheme Installation

Install new dual pilot relay scheme on 138kV circuit Mi Other Not Shared Reliability $315,000 12/31/2012 12/31/2012 Planned 138 C>B>A Y

A in MTEP11 East METC 3491 NERC Alert Facility Ratings for 2011 Verify and remediate facilities as required due to the industry-wide NERC alert

MI Other Not Shared Reliability $2,100,000 12/31/2011 12/31/2011 Planned C>B>A Y

A in MTEP11 East METC 3505 Eaton Rapids Load Interconnection Serve new load in Eaton Rapids with 2 new 138kV circuits from Clinton Jct. and the Delhi-Tompkins circuit

MI Other Not Shared Distribution $28,500,000 1/1/2013 1/1/2013 Planned 138 A Y

A in MTEP11 East METC 3517 G905-Gratiot County Wind Generation 200 MW wind farm connecting at the new METC owned Redstone substation

MI GIP Shared $21,630,500 10/31/2011 12/31/2012 Planned 138 C>B>A Y

A in MTEP11 East METC 3518 G809-MCV 190 MW increase of the existing MCV Co-generation plant

MI GIP Shared $64,000 6/1/2012 6/1/2012 Planned 345 C>B>A Y

A in MTEP11 East METC 3520 NERC Alert Facility Ratings for 2011: Eureka - Vestaburg 138 kV line upgrade

Eureka - Vestaburg 138 kV line upgrade: Remediate sag limits to conductor rating of circuit

Mi BaseRel Not Shared $1,100,000 6/1/2012 6/1/2012 Planned 138 C>B>A Y

A in MTEP11 East METC 3521 NERC Alert Facility Ratings for 2011: Bullock - Summerton 138 kV line upgrade

Bullock - Summerton 138 kV line upgrade: Remediate sag limits to conductor rating of circuit

Mi BaseRel Not Shared $3,600,000 6/1/2012 6/1/2012 Planned 138 C>B>A Y

A in MTEP11 East NIPS 3203 Candidate MVP Portfolio 1 - Reynolds to E. Winnamac to Burr Oak to Hiple 345 kV

Reynolds to E. Winnamac to Burr Oak to Hiple 345 kV line and tie in second AEP 345 kV circuits at Reynolds and Hiple

IN MVP Shared $271,000,000 12/31/2019 12/31/2019 Planned 345 B>A Y

A in MTEP11 East WPSC 3328 Barryton New Distribution Interconnection from the Hersey to Weidman circuit

MI Other Not Shared Distribution $100,000 12/31/2011 12/31/2011 Planned 69 C>B>A Y

A in MTEP11 East WPSC 3329 Burnips to Wayland Rebuild the Burnips to Wayland line section with a larger conductor

MI Other Not Shared Reliability $7,250,000 12/31/2011 12/31/2013 Planned 69 C>B>A Y

A in MTEP11 East WPSC 3330 Cansovia Capacitor Bank Install a Capacitor Bank tap at the Casnovia substation MI Other Not Shared Reliability $260,000 12/31/2011 12/31/2011 Planned 69 C>B>A YA in MTEP11 East WPSC 3331 Redwood to Hart Rebuild the Redwood to Hart line section with a larger

conductorMI Other Not Shared Reliability $750,000 12/31/2015 12/31/2015 Planned 69 C>B>A Y

A in MTEP11 East WPSC 3332 Bass Lake Transmission Upgrade Install Relaying MI Other Not Shared Reliability $250,000 2/28/2011 2/28/2011 In Service 69 C>B>A YA in MTEP11 East WPSC 3333 Lemon Junction Transmission Station Construct a single breaker station MI Other Not Shared Reliability $350,000 12/31/2011 12/31/2011 Planned 69 C>B>A YA in MTEP11 East WPSC 3334 Casnovia to Sternberg Rebuild a portion of the line for Distibution Underbuild MI Other Not Shared Reliability $400,000 6/30/2011 6/30/2011 In Service 69 C>B>A YA in MTEP11 East WPSC 3335 Burnip Transmission Station Upgrade Upgrade to replace outdated equipment. Bus, breakers,

relays, and other equipment as necessary.MI Other Not Shared Condition $900,000 12/31/2013 12/31/2013 Planned 69 C>B>A Y

A in MTEP11 West ATC LLC 174 Canal-Dunn Road 138 kV Construct a 7.7 mile Canal - Dunn Road 138 ckt , Sum rate 400; install a new 138/69 kV transformer at Dunn Road substation.

WI Other Not Shared Reliability $24,763,300 3/1/2012 3/1/2012 Planned 138 69 B>A Y

A in MTEP11 West ATC LLC 333 Hiawatha-Indian Lake conversion to 138 kV Hiawatha-Indian Lake conversion to 138 kV MI Other Excluded Condition $4,900,000 6/1/2013 6/1/2013 Planned 138 B>A Y

A in MTEP11 West ATC LLC 1143 G282, 37628-02 Net: rating of HILLMAN 138/69 kV TRANSFORMER 1 is upgraded to 100 MVA. Int: The Generator is required to provide a 138/34.5kV transformer, a circuit breaker and a disconnect switch on the high side of the 138/34.5kV transformer and 34.5kV facilities to c

WI GIP Not Shared $4,200,000 12/31/2012 12/31/2012 Planned 0.6 B>A Y

A in MTEP11 West ATC LLC 1699 Mckenna & Chaffee Ck Capacitor Banks Upgrades

Upgrade Mckenna 6.3 MVAR capacitor bank to 15.3 MVAR and upgrade Chaffee Ck 10.8 MVAR to 14.4 MVAR capacitor bank

WI Other Not Shared Reliability $686,750 7/31/2011 7/31/2011 Planned 69 C>B>A Y

A in MTEP11 West ATC LLC 1705 Bass Creek area upgrades Install a 138/69 kV transformer at Bass Creek substation, Uprate Townline Road-Bass Creek 138 kV line

WI Other Not Shared Reliability $6,975,946 4/1/2011 4/1/2011 In Service 138 69 B>A Y

A in MTEP11 West ATC LLC 1729 Uprate Straits-McGulpin 138 kV Uprate overhead portions of Straits-McGulpin 138-kV circuits #1 & #3 to 200 F degree summer emergency ratings

MI BaseRel Not Shared $300,000 4/20/2011 4/20/2011 In Service 138 C>B>A Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP11 West ATC LLC 1950 2nd Kewaunee 345-138 kV Transformer Reconfigure Kewaunee 345/138 kV switchyard and install a 2nd Kewaunee 345-138 kV transformer of 500 MVA.

WI BaseRel Shared $17,697,000 3/17/2011 3/17/2011 In Service 345 138 B>A Y

A in MTEP11 West ATC LLC 2036 Uprate Y-40 Gran Grae-Boscobel 69 kV Increase line clearance to 200/300 deg F SN/SE WI Other Not Shared Condition $5,291,028 12/15/2011 12/15/2011 Planned 69 B>A YA in MTEP11 West ATC LLC 2037 Rebuild Dane-Okee 69 kV Rebuild Dane-Okee 69 kV WI Other Not Shared Reliability $6,798,033 6/19/2012 6/19/2012 Planned 69 C>B>A YA in MTEP11 West ATC LLC 2055 Clear Lake-Woodmin 115 kV Construct a 7.5 mile 115 kv line from Clear Lake to a

new Woodmin distribution substationWI Other Not Shared Reliability $21,331,000 6/1/2012 6/1/2012 Planned 115 B>A Y

A in MTEP11 West ATC LLC 2800 Uprate Arpin-Hume 115-kV Marshfield Electric & Water Department project to increase ground clearance to operate the line at 200 Deg F

WI BaseRel Not Shared $191,000 9/10/2010 9/10/2010 In Service 115 B>A Y

A in MTEP11 West ATC LLC 2820 Replace Bluemound 230/138kV transformerT1

Replace Bluemound 230/138kV transformer T1 with a 400 MVA unit

WI Other Not Shared Condition $8,200,000 5/31/2012 5/31/2012 Planned 230 138 B>A Y

A in MTEP11 West ATC LLC 2842 Uprate Spring Green-Stage Coach 69-kV Uprate Spring Green-Stage Coach 69-kV WI Other Not Shared Reliability $6,957,394 4/8/2011 4/8/2011 In Service 69 B>A YA in MTEP11 West ATC LLC 2844 Candidate MVP Portfolio 1 - Pleasant

Prairie-Zion Energy Center 345 kV lineConstruct a new Pleasant Prairie-Zion Energy Center 345-kV line

WI IL MVP Shared $28,856,000 3/16/2014 3/16/2014 Planned 345 C>B>A Y

A in MTEP11 West ATC LLC 2846 Straits power flow control Install AC-DC-AC Back to Back Voltage Source Converterpower (VSC) flow controller at the Straits 138-kV substation

MI BaseRel Shared $90,000,000 5/1/2014 5/1/2014 Planned 138 138 A Y

A in MTEP11 West ATC LLC 3095 Uprate 9Mile-Roberts 69 kV line 6952 Increase ground clearance for the 9Mile-Roberts 69 kV line 6952 to 176 deg f clearance for all seasons & Install Arresters, Replace Select Components

MI Other Not Shared Reliability $19,743,032 4/1/2012 4/1/2012 Planned 69 B>A Y

A in MTEP11 West ATC LLC 3108 Rebuild Pine River-Straits 69kV dbl ckt line Rebuild Pine River-Straits 69kV dbl ckt line with t2-477 ACSR

MI Other Not Shared Reliability $40,804,513 6/1/2014 6/1/2014 Planned 69 B>A Y

A in MTEP11 West ATC LLC 3126 Install a 2nd Chandler Transformer Install a 2nd Chandler Transformer & reconfigure bus to 138 kV Ring bus

MI Other Not Shared Reliability $9,700,000 12/9/2012 12/9/2012 Planned 138 69 C>B>A Y

A in MTEP11 West ATC LLC 3157 Line Y-95 Fount Valley-Fountain Valley Tap-Red Granite Tap-ACEC Spring Lake Tap-Silver Lake-Wautoma Uprate

Line Y-95 Fount Valley-Fountain Valley Tap-Red Granite Tap-ACEC Spring Lake Tap-Silver Lake-Wautoma Uprate

WI Other Not Shared Reliability $362,468 6/17/2011 6/17/2011 In Service 69 C>B>A Y

A in MTEP11 West ATC LLC 3160 G706-H012 Line X-6 Portage-Hamilton-Staff-Friesland-North Randolph 138 kV Uprate

G706-H012 Line X-6 Portage-Hamilton-Staff-Friesland-North Randolph 138 kV Uprate

WI GIP Not Shared $1,447,679 12/31/2011 12/31/2011 Planned 138 C>B>A Y

A in MTEP11 West ATC LLC 3161 G749 EcoMont Wind Farm New EcoMont substation tapped into Belmont Tap-Rewey Tap 69 kV Line for G749

WI GIP Not Shared $4,569,183 11/30/2012 11/30/2012 Planned 69 C>B>A Y

A in MTEP11 West ATC LLC 3188 Pleasant Prairie-Zion 345-kV uprate Replace 345kV Wave traps at the ComEd Zion SS and Jumpers

IL Other Not Shared Economic $1,544,571 3/25/2011 3/25/2011 In Service 345 B>A Y

A in MTEP11 West ATC LLC 3206 G833-4_J022-3 Long Term Solution 1) Construct a new Barnhart 345 & 138 kV substation2) InWI GIP Shared $173,309,000 6/1/2018 6/1/2018 Planned 345 B>A YA in MTEP11 West ATC LLC 3395 Milwaukee Co T-D Install a new Milwaukee Co T-D substation by looping in

line 5042 (Bluemound-Everett 138kV)WI Other Not Shared Distribution $33,500,000 4/1/2015 4/1/2015 Planned 138 13.2 C>B>A Y

A in MTEP11 West ATC LLC 3396 Uprate Blue River Tap-Muscoda 69 kV Uprate Blue River Tap-Muscoda 69 kV line by increasing clearance at a distribution crossing to 564 Amps

WI Other Not Shared Condition $580,000 11/15/2010 11/15/2010 In Service 69 C>B>A Y

A in MTEP11 West ATC LLC 3427 Nordic-Perch Lk Uprate (AM) Increase ground clearance for the Nordic-Perch Lk 138 kV line

MI BaseRel Not Shared $1,543,040 3/7/2011 3/7/2011 In Service 138 C>B>A Y

A in MTEP11 West ATC LLC 3428 Stage Coach-Timberlane 69kV uprate Increase ground clearance for the Stage Coach-Timberlane 69kV line

WI Other Not Shared Reliability $35,000 4/8/2011 4/8/2011 In Service 69 C>B>A Y

A in MTEP11 West ATC LLC 3432 Uprate Stoughton-Oregon 69kV line Uprate Stoughton-Oregon 69kV line WI Other Not Shared Reliability $570,000 4/21/2011 4/21/2011 In Service 69 C>B>A YA in MTEP11 West ATC LLC 3433 Uprate Stagecoach-Mt Horeb NE-Mt Horeb

69 kV line Y-128Uprate Stagecoach-Mt Horeb NE-Mt Horeb 69 kV line Y-128


A in MTEP11 West ATC LLC 3447 Ontonagon 138/69kV Tr uprate Retap CT related to Ontonagon 138/69 kV Tr to obtain a higher rating

MI Other Not Shared Reliability $12,410 12/7/2010 12/7/2010 In Service 138 69 C>B>A Y

A in MTEP11 West ATC LLC 3448 Ontonagon 138/69kV Tr Replacement Replace the Ontonagon 138/69 kv Tr with a larger unit MI Other Not Shared Reliability $935,786 12/1/2011 12/1/2011 Planned 138 69 C>B>A YA in MTEP11 West ATC LLC 3449 Rebuild the Atlantic-M38 69kV line Rebuild the Atlantic-M38 69kV line with a larger

conductorMI Other Not Shared Reliability $18,878,963 12/31/2013 12/31/2013 Planned 69 C>B>A Y

A in MTEP11 West ATC LLC 3451 Y-136 Mt Horeb-Verona 69kV Rerate Increase ground clearance on the Mt Horeb-Verona 69kV line


A in MTEP11 West ATC LLC 3452 Y-158 Bass Ck-Sheepskin 69kV Rerate Increase ground clearance on the Bass Ck-Sheepskin 69kV line



Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP11 West ATC LLC 3453 Y-25 Waupun-S Fond du Lac 69kV Rerate Increase ground clearance on the Waupun-S Fond du Lac 69kV line

WI Other Not Shared Reliability $2,186,630 2/28/2012 2/28/2012 Planned 69 C>B>A Y

A in MTEP11 West ATC LLC 3457 GIC J060 Garden City Wind Phase I Interconnect GIC J060 Garden City Wind MI GIP Not Shared $4,779,758 12/30/2011 12/30/2011 Planned 138 0.69 C>B>A YA in MTEP11 West ATC LLC 3458 Aurora 115-69kV T3 Replacement Aurora 115-69kV T3 Replacement WI Other Not Shared Condition $2,958,914 6/3/2011 6/3/2011 In Service 115 69 C>B>A YA in MTEP11 West ATC LLC 3459 A-157 Hume-Wildwood 115kV Uprate Increase ground clearance on the Hume-Wildwood

115kV lineWI BaseRel Not Shared $50,000 4/12/2011 4/12/2011 In Service 115 C>B>A Y

A in MTEP11 West ATC LLC 3460 Y-93 Berlin-Ripon 69kV Uprate Increase ground clearance on the Berlin-Ripon 69kV line WI Other Not Shared Reliability $1,389,745 2/28/2011 2/28/2011 In Service 69 C>B>A Y

A in MTEP11 West ATC LLC 3461 N-144 McMillan-Wildwood 115kV Uprate Increase ground clearance on the McMillan-Wildwood 115kV line

WI BaseRel Not Shared $50,000 2/28/2011 2/28/2011 In Service 115 C>B>A Y

A in MTEP11 West ATC LLC 3472 Pleasant Prairie Bus Reconfiguration Construct a new 6-rung breaker-and-a-half 345 kV bus at the P4 site adjacent to the existing P4 yard.


A in MTEP11 West ATC LLC 3479 Progress-Aviation 138 kV Uprate Increase ground clearance for the Progress-Aviation line to 187 degrees F

WI Other Not Shared Condition $492,563 3/1/2012 3/1/2012 Planned 138 C>B>A Y

A in MTEP11 West ATC LLC 3480 Engadine Load Move Construct a new radial 69-kV tap from the existing Indian Lake-Hiawatha 69-kV line 6913 to the Engadine Substation


A in MTEP11 West ATC LLC 3488 Uprate Brick Church to Walworth 69 kV line Asset management project to uprate Y-159 from Brick Church to Walworth 69 kv Line


A in MTEP11 West ATC LLC 3489 UprateY-34 Jennings Road to Darlington 69 kV line

Asset management project to uprate Y-34 from Jennings Road to Darlington 69 kv Line


A in MTEP11 West ATC LLC 3504 Y-80 Omro to Winneconne Rerate Rerate Line Y-80 conductor from Omro sub to Winneconne sub to a rating of 580 amps


A in MTEP11 West ATC LLC, XEL, ITCM

3127 Candidate MVP Portfolio 1 - N LaCrosse-N Madison-Cardinal -Spring Green - Dubuque area 345-kV

N LaCrosse- N Madison - Cardinal 345-kV & Dubuque County - Spring Green - Cardinal 345 kV line. Spring Green and Briggs Road transformers

IA WI/IA MVP Shared $679,260,000 12/31/2018 12/31/2020 Planned 345 138 B>A Y

A in MTEP11 West DPC 3397 Genoa to La Crosse Tap 161 Rebuild Rebuild of the 161 kV line from Genoa to the La Crosse tap.

WI BaseRel Shared $18,000,000 6/1/2014 6/1/2014 Planned 161 C>B>A Y

A in MTEP11 West DPC 3434 Lufkin 161 kV substation Build a new 161 kV substation on the Alma to Elk Mound 161 line in the Eau Claire area.


A in MTEP11 West GRE 2571 MN Pipeline-Menahga 8.0 mile line MN Pipeline-Menahga 8.0 mile line. Built 115 kV but will be operated at 34.5.

MN Other Not Shared Distribution $4,199,990 11/15/2014 11/15/2014 Planned 115 C>B>A Y

A in MTEP11 West GRE 2599 Shell Lake (IM) 5.0 mile, 115 kV line Shell Lake (IM) 5.0 mile, 115 kV line MN Other Not Shared Distribution $4,201,000 10/31/2014 10/31/2014 Planned 115 C>B>A YA in MTEP11 West GRE 2643 Parkers Prairie 115 kV conversion Parkers Prairie 115 kV conversion, New Distribution tap MN Other Not Shared Distribution $1,220,998 5/1/2013 5/1/2013 Planned 115 C>B>A Y

A in MTEP11 West GRE 2679 Ramsey-Grand Forks (81.02 mi.) 230 kV Rebuild

Ramsey-Grand Forks (81.02 mi.) 230 kV Rebuild MN Other Not Shared Condition $40,500,000 11/1/2019 11/1/2019 Planned 230 C>B>A Y

A in MTEP11 West GRE 3467 MISO G604 Connect Oak Glen Wind Farm to 69 kV system MN GIP Not Shared $1,722,464 7/1/2011 7/1/2011 Under Constru 69 B>A YA in MTEP11 West GRE 3468 MISO H062 Connect H062 Wind Generation MN GIP Not Shared $1,312,741 9/1/2011 9/1/2011 Under Constru 69 B>A YA in MTEP11 West GRE 3469 MISO H061 Connect H061 Wind generation MN GIP Not Shared $192,530 10/1/2011 10/1/2011 Planned 69 B>A YA in MTEP11 West GRE/MP 2634 Savanna-Cromwell Savanna-Cromwell MN BaseRel Shared $30,000,225 11/2/2012 12/1/2014 Planned 115 B>A YA in MTEP11 West ITCM 3191 G164-Lakefield Jct 345 kV Breaker & Half Convert the Lakefield 345kV ring bus to breaker and a

half.MN GIP Shared $8,148,000 4/29/2011 4/29/2011 In Service 345 B>A Y

A in MTEP11 West ITCM 3192 G604-Ellendale 69 kV Switch Station Construct a new Ellendale 69kV four terminal breaker station. The Hayward-West Owatanna 69kV line will be rerouted into the Ellendale breaker station. Then change the N.O. point on the line to closed.

MN GIP Shared $1,913,706 8/15/2010 12/31/2011 In Service 69 B>A Y

A in MTEP11 West ITCM 3193 G741-Martin Co Waste Heat Construct a new 69kV tap to the G741 customer. Tap the Trimont (IPL)-Sherburn(SCREC) 69kV line.

MN GIP Shared $223,884 10/1/2010 10/1/2010 In Service 69 B>A Y

A in MTEP11 West ITCM 3194 G798-Story County Upgrades Expand the ring bus at Story County. IA GIP Shared $422,664 7/31/2010 7/31/2010 In Service 161 B>A YA in MTEP11 West ITCM 3195 G870-Freeborn Tap the Hayward-Winnebago Jct 161kV and construct a

new Freeborn 161kV three terminal breaker station. Approximately 4 mile tap will connect Freeborn to the new G870 customer substation.

MN GIP Shared $3,516,163 10/1/2010 10/1/2010 In Service 161 B>A Y

A in MTEP11 West ITCM 3196 H007-Bond Breaker Station Tap the Hayward-Winnebago Jct 161kV and construct a new Bond 69kV three terminal breaker station.

IA GIP Shared $3,560,163 7/1/2011 7/1/2011 In Service 69 B>A Y

A in MTEP11 West ITCM 3406 Adams-Rochester Terminal Upgrades Upgrade the Adams terminal equipment to winter conductor limit

MN Other Not Shared Reliability $360,000 4/29/2011 4/29/2011 In Service 161 C>B>A Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP11 West ITCM 3407 Bluff Substation Additions Add 69kV breakers to the Bluff Substation 69kV and install associated relay equipment.

IA Other Not Shared Distribution $1,920,000 12/31/2011 12/31/2011 Planned 69 C>B>A Y

A in MTEP11 West ITCM 3408 BooneQuartz Sustation This project performs the conversion of the Boone Quartz substation from 34.5kV to 69kV as part of the overall rebuild and conversion of the 34.5kV system. The Boone Quartz substation was constructed with a dual high side transformer and the high side was laid out for 69kV operation in preparation for the conversion. Two 69kV line breakers will be installed at the Boone Quartz substation. Existing 69kV lines and 34.5kV lines already constructed for 69kV operation will be re-configured along with installation of 69kV taps into the Boone Quartz substation to make the change to 69kV. No new load is being added during the conversion to 69kV.

IA Other Not Shared Reliability $1,700,000 12/31/2011 12/31/2011 Planned 69 C>B>A Y

A in MTEP11 West ITCM 3409 Bricelyn-Walters Rebuild The recommended project is to completely rebuild a 5 mile section of the Bricelyn - Walters 69 kV line with standard T2-477 construction and shield wire.

IA Other Not Shared Condition $2,625,000 12/31/2013 12/31/2013 Planned 69 C>B>A Y

A in MTEP11 West ITCM 3410 Bridgeport Terminal Upgrades Upgrade the Bridgeport-Ottumwa 161kV terminal equipment

IA BaseRel Not Shared $200,000 12/31/2011 12/31/2011 Planned 161 C>B>A Y

A in MTEP11 West ITCM 3411 Bridgeport T8 Add a 69kV breaker to the Bridgeport North 69kV ring and install associated relay equipment.

IA Other Not Shared Distribution $360,000 12/31/2011 12/31/2011 Planned 69 C>B>A Y

A in MTEP11 West ITCM 3412 Fort Madison Interconnection Install tap capable of double circuit 69kV to Fort Madison substation and install associated relay equipment.


A in MTEP11 West ITCM 3413 Gladbrook 161kV tap Install a 161kV tap pole in the Marshalltown to Traer line with two line switches. Construct a 161kV tap line to the new Gladbrook substation.

IA Other Not Shared Distribution $300,000 12/31/2013 12/31/2013 Planned 161 161 C>B>A Y

A in MTEP11 West ITCM 3414 Magnolia 7.1 MVAR 69kV Cap ITCM will move the existing Lewisville 69kV 7.1 MVAR capacitor to the 69kV bus at Magnolia. Recent system changes have opened up a 69kV bay at Magnolia and this will be used for the capacitor bank and 69kV breaker.

IA Other Not Shared Reliability $480,000 12/31/2012 12/31/2012 Planned 69 C>B>A Y

A in MTEP11 West ITCM 3415 Marion Termianl Upgrades Uprate 115 kV breaker 3710 terminal equipment at Marion.

IA BaseRel Not Shared $10,000 12/31/2011 12/31/2011 In Service 115 C>B>A Y

A in MTEP11 West ITCM 3416 Marion Circuit 0410 Rebild to 69kV This project rebuilds the sections (approximately 25 miles) of Marion circuit 0410 that will be utilized in the overall 34.5kV to 69kV conversion plan but have not yet been constructed for 69kV operation.

IA Other Not Shared Distribution $10,500,000 12/31/2012 12/31/2012 Planned 34 34 C>B>A Y

A in MTEP11 West ITCM 3417 Marshalltown East Nevada Construct a 1-2 span 34.5kV tap, install new relays for Marshalltown circuits 1810 and 2620, and upgrade terminal limit to address overload during contingency. Remove two normally open switches to limit system configuration to address system protection coordination issues which can occur when rural and city circuits are tied together.

IA Other Not Shared Reliability $280,000 12/31/2011 12/31/2011 In Service 34 C>B>A Y

A in MTEP11 West ITCM 3418 Mount Vernon Circuit 6420 Rebild to 69kV This project rebuilds the sections (approximately 17 miles) of Mount Vernon circuit 6420 that will be utilized in the overall 34.5kV to 69kV conversion plan but have not yet been constructed for 69kV operation.

IA Other Not Shared Distribution $7,150,000 12/31/2013 12/31/2013 Planned 34 34 C>B>A Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP11 West ITCM 3419 Bertram161kV tap The new transformer high side voltage is 69/34.5kv; it will need a 0.5 mile tap line built to the substation from the existing 34.5kV system with the future plans of 69kV rebuild. Adding the double-circuit tap to the substation will allow connection to the new transformers. The double circuit tap will provide additional reliability, with switching, to have the ability to separate the parallel transformers in the situation a transformer fails, no load will be lost.


A in MTEP11 West ITCM 3420 OGS Breaker Install new 345kV breaker in the Ottumwa Generating Station substation to replace the failed 345kV circuit switcher. Replace the transformer lockout/breaker control panel. Replace the existing 345kV relay panel with two new panels and one lockout panel, which will allow for the retirement of an existing transfer trip scheme. The new line panels will implement a new redundant transfer trip scheme. Install second set of battery back up.

IA Other Not Shared Condition $1,350,000 12/31/2011 12/31/2011 Planned 345 C>B>A Y

A in MTEP11 West ITCM 3421 Centervile 7.1 MVAR 69kV Cap nstall a 7 MVAR 69 kV capacitor, breaker with synchronous closing control, switch, and 0.5 mH reactor. 69 kV breakers 0-6961-1 and 0-6921-2 will be replaced due to condition. A 69 kV bus tie breaker and switch will be added for reliability between transformers 2 and 3.

IA Other Not Shared Reliability $1,350,000 12/31/2011 12/31/2011 Planned 69 C>B>A Y

A in MTEP11 West ITCM 3422 South Broadway TEQ Install Sub IA Other Not Shared Distribution $150,000 12/31/2012 12/31/2012 Planned 69 C>B>A YA in MTEP11 West ITCM 3423 Truro Line Rebuild Rebuild the line between the Truro substation and the

White Oak tap and operate the line at 69 kV.IA Other Not Shared Reliability $3,360,000 12/31/2011 12/31/2011 Planned 69 C>B>A Y

A in MTEP11 West ITCM 3425 VMEU Interconnect Install line switches at the interconnection point. IA Other Not Shared Reliability $110,000 12/31/2011 12/31/2011 In Service 34 C>B>A YA in MTEP11 West ITCM 3426 DPC/ITC Interconnect move The recommended project is to move the existing

interconnection point approximately 0.6 miles south. ITC will install a laminate structure and associated equipment to accommodate DPC’s project.

IA Other Not Shared Distribution $0 12/31/2013 12/31/2013 Planned 69 C>B>A Y

A in MTEP11 West ITCM 3499 NERC Alert Facility Ratings for 2011 Verify and remediate facilities as required due to the industry-wide NERC alert

IA BaseRel Not Shared 12/31/2011 12/31/2011 Planned C>B>A Y

A in MTEP11 West MDU 3199 G359, 38073-01 230 kV line from project interconnection to Ellendale Jct substation and new 230/115 kV transformer at Ellendale

ND GIP Not Shared $19,130,000 3/21/2011 12/1/2011 Planned 230 115 B>A Y

A in MTEP11 West MEC 3268 Lehigh: 345 kV 50 MVAr Reactor Add a 345 kV, 50 MVAr reactor IA BaseRel Not Shared $2,750,000 11/1/2012 11/1/2012 Planned 345 C>B>A YA in MTEP11 West MEC 3270 CBEC-River Bend 161 kV Rebuild Increase 161 kV line rating. IA Other Not Shared Reliability $675,000 6/1/2011 6/1/2011 Planned 161 C>B>A YA in MTEP11 West MEC 3271 River Bend-Bunge 161 kV Rebuild Increase 161 kV line rating. IA Other Not Shared Reliability $700,000 6/1/2011 6/1/2011 Planned 161 C>B>A YA in MTEP11 West MEC 3272 Raun 345 kV Breaker Replacement Replace existing SFA 345 kV breaker 0170 with a new

unit.IA Other Not Shared Condition $500,000 6/1/2011 6/1/2011 Planned 345 C>B>A Y

A in MTEP11 West MEC, ITCM 3205 Candidate MVP Portfolio 1: Lakefield Jct. - Winnebago - Winco - Burt area & Sheldon - Burt Area - Webster 345 kV line

New 345 kV line from Lakefield Junction to Burt via Winnebago and Winco and a new 345 kV line from Sheldon to Webster via Burt. Includes 161 kV rebuild as underbuild along portions of the route.

IA MN/IA MVP Shared $514,069,787 12/31/2015 12/1/2016 Planned 345 161 B>A Y

A in MTEP11 West MEC, ITCM 3213 Candidate MVP Portfolio 1 - Winco to Hazelton 345 kV line

Winco to Lime Creek to Floyd to Blackhawk to Hazelton 345 kV line and Lime Creek, Floyd and Black Hawk transformers

IA MVP Shared $591,551,532 12/1/2015 12/31/2015 Planned 345 161 B>A Y

A in MTEP11 West MP 2549 15L Upgrade Thermal Upgrade of MP Line #15 MN Other Not Shared Reliability $3,179,000 6/1/2014 6/1/2014 Planned 115 C>B>A YA in MTEP11 West MP 3373 9 Line Thermal Upgrade MN BaseRel Shared $8,000,000 12/30/2012 12/30/2012 Planned 115 C>B>A YA in MTEP11 West MP 3374 Greenway Re-energize existing 115/23 kV substation MN Other Not Shared Distribution $700,000 11/1/2012 11/1/2012 Planned 115 23 C>B>A YA in MTEP11 West OTP 2856 Victor-New Effington 41.6 kV Line Upgrade Rebuild Existing 4-Mile 41.6 kV Line SD Other Not Shared Reliability $200,000 6/30/2011 6/30/2011 In Service 41.6 C>B>A YA in MTEP11 West OTP 3466 Project J-035 5 MW Wind Farm on OTP

Doran 41.6 kV line.Add 3 Way Switch on 41.6 kV line between Doran 41.6 kV substation to Doran Jct.

MN GIP Not Shared $140,000 8/1/2012 8/1/2012 Planned 41.6 B>A Y

A in MTEP11 West OTP 3481 Buffalo - Casselton 115 kV Line Construct 16 mile 115 kV line from Buffalo - Casselton (ND); Replace Buffalo 345/115 kV Transformer; Rebuild portion of Sheyenne - Mapleton 115 kV Line

ND BaseRel Shared $14,000,000 7/1/2013 12/31/2014 Planned 345 115 C>B>A Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP11 West OTP, MDU 2220 Candidate MVP Portfolio 1 - Ellendale to Big Stone South

Big Stone to Ellendale 345 kV double circuit line ND SD/ND MVP Shared $326,164,000 12/31/2019 12/31/2019 Planned 345 230 B>A Y

A in MTEP11 West OTP, XEL 2221 Candidate MVP Portfolio 1 - Big Stone South to Brookings

Brookings to Big Stone 345 kV double circuit SD MVP Shared $226,720,000 12/31/2017 12/31/2017 Planned 345 230 B>A Y

A in MTEP11 West XEL 3309 Buffalo Ridge Substation Equipment Upgrade

Upgrade the wave traps and line switches at Buffalo Ridge to 2000 A going to Lake Yankton and Pipestone. Retap the Pipestone CTs to 2000 A going to Buffalo Ridge.

MN BaseRel Not Shared $286,000 8/1/2011 8/1/2011 Planned 115 C>B>A Y

A in MTEP11 West XEL 3310 Highway 212 Corridor upgrade This project is to complete the conversion of 69 kV line between Scott County and West Waconia substation to 115 kV. The scope also involves building new West Creek distribution substation and converting the Chaska, Victoria and Augusta substations to 115 kV.

MN Other Not Shared Distribution $19,450,000 6/1/2012 6/1/2012 Planned 115 C>B>A Y

A in MTEP11 West XEL 3312 Minn Valley - Maynard - Kerkhoven tap upgrade

This project is to upgrade the Minn Valley - Maynard - Kerkhoven tap 115 kV line to 795 ACSS conductor

MN BaseRel Shared $13,660,000 6/1/2014 6/1/2014 Planned 115 C>B>A Y

A in MTEP11 West XEL 3313 New Prague switch This project is to install a 69 kV 1 way switch to provide SMMPA's New Prague substation a new interconnection point. The existing interconnection would require cutting the line jumpers phisically when the New Prague - Veslie line is out of service.

MN Other Not Shared Reliability $180,000 6/1/2012 6/1/2012 Planned 69 C>B>A Y

A in MTEP11 West XEL 3314 Kohlman Lake - Long Lake 2nd circuit This project is to convert the Kohlman Lake - Long Lake 115 kV bifurcated line to double circuit with separate line terminations at Kohlman Lake and Long Lake

MN BaseRel Not Shared $3,000,000 6/1/2014 6/1/2014 Planned 115 C>B>A Y

A in MTEP11 West XEL 3315 Chisago County 2nd 345/115 kV transformer

This project is to install a 2nd 345/115 kV transformer at Chisago County

MN BaseRel Not Shared $7,000,000 6/1/2014 6/1/2014 Planned 345 115 C>B>A Y

A in MTEP11 West XEL 3316 Riverside - Apache lie upgrade This project is to upgrade Riverside - Apache line to 360 MVA and upgrade Apache switch to 2000A


A in MTEP11 West XEL 3317 Goose Lake - Kohlman Lake 2nd circuit This project is to convert the single circuit line between Goose Lake and Kohlman Lake to double circuit.

MN BaseRel Shared $6,000,000 6/1/2014 6/1/2014 Planned 115 C>B>A Y

A in MTEP11 West XEL 3318 Parkers Lake Overstressed Breakers This project replaces some of the 115 kV breakers at Parkers Lake with 63 kA rated breakers


A in MTEP11 West XEL 3319 Split Rock Overstressed Breakers This project replaces some of the 115 kV breakers at Split Rock with 63 kA rated breakers

SD BaseRel Not Shared $1,344,000 12/1/2011 12/1/2011 Planned 115 C>B>A Y

A in MTEP11 West XEL 3320 Split Rock Reactor Replacement This project is needed to replace the failed 50 MVAR reactor and associated breaker.

SD BaseRel Not Shared $100,000 12/1/2011 12/1/2011 Planned 115 C>B>A Y

A in MTEP11 West XEL 3321 Chemolite Breaker Addition This project adds two breakers at Chemolite to insure only one line at a time will be removed from service during a breaker failure.

MN BaseRel Not Shared $580,000 1/14/2011 1/14/2011 In Service 115 C>B>A Y

A in MTEP11 West XEL 3322 Cedar Falls - Clear Lake Rebuild Rebuild 43 Miles of 69 kV line to 477 ACSR WI Other Not Shared Reliability $14,000,000 6/1/2013 6/1/2013 Planned 69 C>B>A YA in MTEP11 West XEL 3323 Park Falls Bio-Refinery Build radial 115 kV line from Park Falls sub to a new

customer and install a new distribution sub for the customer

WI Other Not shared Distribution $23,769,000 12/1/2012 6/1/2013 Planned 115 13.8 C>B>A Y

A in MTEP11 West XEL 3324 Eau Claire Overstressed Breakers Replace overstressed Eau Claire 69 kV breakers. 4E185, 4E186, 4E187, 4E188, 4E189, 4E190, 4E191, 4E192, 4E193, 4E195.


A in MTEP11 West XEL 3325 Orono 115 kV conversion This project will move the supply for Orono from its current 69 kV supply to the 115 kV line from Medina to Crow River

MN Other Not Shared Reliability $5,340,000 12/1/2012 12/1/2012 Planned 115 C>B>A Y

A in MTEP11 West XEL 3326 Black Dog Outlet This line will rebuild the 115 kV line from Black Dog to Savage to 795 ACSS conductor.


A in MTEP11 West XEL 3327 Eau Claire - Madison Street Rebuild This project will replace 1 mile of 4/0 Cu conductor with 795 ACSS on the 69 kV line between Eau Claire - Sterling - Madison St.


A in MTEP11 West XEL 3473 Sioux Falls 115 kV Phase 1 This project re-constructs 10 miles of existing 69 kV line in Sioux Falls, SD to 115 kV; 6 miles of the new line will be double circuit with existing 69 kV.

SD Other Not Shared Reliability $35,000,000 6/1/2014 6/1/2014 Planned 115 13.8 C>B>A Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP11 West XEL 3474 Adams 345 kV Reactor Installation Installing a 50 MVAR reactor at Adams substation on the Pleasant Valley line, along with a breaker and disconect switch

MN Other Not Shared Reliability $2,260,000 6/1/2012 6/1/2012 Planned 345 C>B>A Y

A in MTEP11 West XEL 3475 Prairie 3rd transformer This project is to install a 3rd 230/115 kV transformer at Prairie substation

ND BaseRel Not Shared $12,000,000 6/1/2014 6/1/2014 Planned 230 115 C>B>A Y

A in MTEP11 West XEL 3476 Maple River - Cass County 345 kV line This project is to build a new 4.5 mile 345 kV line from Maple River to Cass County substation along with the 345/115 kV transformer at Cass County substation.

ND BaseRel Not Shared $13,226,000 6/1/2014 6/1/2014 Planned 345 115 C>B>A Y

A in MTEP11 West XEL 3509 Stinson to Bayfront 115 kV line rebuild Rebuild approximately 33 miles of 115 kV line from 336 ACSR to 795 ACSR

WI Other Not Shared Condition $15,400,000 1/1/2013 1/1/2013 Planned 115 C>B>A Y

A in MTEP11 West XEL, GRE 1203 Candidate MVP Portfolio 1 - Brookings, SD - SE Twin Cities 345 kV

Brookings Cty-Lyon Cty (Single Ckt 345 kV); Lyon Cty-Cedar Mountain-Helena (Double Ckt 345 kV); Helena-Lake Marion-Hampton Corner (Single Ckt 345 kV); Lyon Cty-Hazel (Single Ckt 345 kV); Hazel-Minnesota Valley (Single Ckt 345 kV, initially operate at 230 kV); Cedar Mountain-Franklin (Single Ckt 115 kV)

MN SD/MNMVP Shared $738,400,000 6/1/2011 2/16/2015 Planned 345 69 B>A Y

A in MTEP11 West XEL, GRE 3454 Hollydale 115 kV upgrade This project will upgrade the 69 kV line from GRE's Medina to Plymouth substations. A new switching station will be added on GRE's 115 kV line between Parkers Lake and Elm Creek north or south of the Plymouth Substation depending on the permitted location. Joint project with GRE P3394 at Medina

MN Other Not Shared Reliability $24,676,164 5/1/2013 6/1/2013 Planned 115 13.8 C>B>A Y

A in MTEP10 Central AmerenIL 1528 Rising Substation - Increase Xfmr Rating Increase rating of existing 345/138 kV 450 MVA Transformer

IL $5,000,000 6/1/2012 6/1/2012 Proposed 345 138 A Y

A in MTEP10 Central AmerenIL 1535 Wood River-Stallings Replace terminal equipment at Stallings, reconductor 6 miles of 138 kV Line 1456 and upgrade Stallings bus conductor to a minimum capability of 1200 A

IL BaseRel Not Shared $2,036,000 6/1/2012 6/1/2012 Planned 138 A Y

A in MTEP10 Central AmerenIL 2064 South Bloomington - Old Danvers 138 kV line - Reconductor

S Bloomington-Old Danvers 138 kV Line 1364 Reconductor 3.33 miles from S. Bloomington to West Washington (S Bloomington to Diamond Star Tap)


A in MTEP10 Central AmerenIL 2288 Washington Street Substation 'In-Out' Re-Route S. Bloomington to Danvers Line 1364 through the West Washington St. Substation with an “in-and-out” arrangement Replace existing tap to 138 kV Line 1326 with 'in and out' arrangement.

IL Other Not Shared Reliability $4,155,000 6/1/2012 6/1/2012 Planned 138 A Y

A in MTEP10 Central AmerenIL 2957 Edwards-Tazewell 138 kV Line 1373 Edwards-Tazewell 138 kV Line 1373 - Reconductor 1.57 miles of 795 kcmil ACSR conductor and 7.5 miles of 927 kcmil ACAR conductor with conductor capable of carrying 1600 A under summer emergency conditions. Replace a 1200 A wavetrap and CT's at the Edwar

IL BaseRel Not Shared $121,000 12/31/2012 12/31/2012 Planned 138 A Y

A in MTEP10 Central AmerenIL 2986 North Alton Substation Supply North Alton 138-34.5 kV Substation Supply - Supply new 138-34.5 kV Substation from an in-out by tapping the existing Wood River to Stallings 138 kV line (“in and out”). Build approximately 4 miles of double-circuit 138 kV line to the new North Alton Substation connection to the Wood River-Stallings-1456 138 kV line. Approximately 4 miles of double-circuit 138 kV line needed.

IL Other Not Shared Distribution $12,891,000 6/1/2014 12/1/2015 Planned 138 A Y

A in MTEP10 Central AmerenIL 2992 Bondville-S.W. Campus Bondville-S.W. Campus 138 kV - Construct 8 miles of new 138 kV line. Construct 138 kV Ring Bus at Bondville (2 new PCB's) and a 138 kV Ring Bus at Champaign S.W. Campus (4 new PCB's).

IL Other Not Shared Distribution $10,000,000 6/1/2014 6/1/2014 Planned 138 A Y

A in MTEP09 Central AmerenIL 2273 Supply to LaFarge Customer Substation Provide 161 kV supply to customer substation IL Other Not Shared Distribution $570,000 6/1/2013 6/1/2013 Planned 161 A YA in MTEP09 Central AmerenIL 2279 'Grand Tower-Steeleville 138 kV

ReconductorReconductor 6.19 miles of 477 kcmil ACSR to carry 1200 A under summer emergency conditions



Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP09 Central AmerenIL 2472 New 345kV Supply at Fargo Substation Tap existing 345kV line from Duck Creek to Tazewell and create new Maple Ridge Substation ($6.5M)Build a new supply line to the Fargo Substation by extending 20 miles of 345kV from the new Maple Ridge Substation ($50.1M)Create Fargo Station and install 560 MVA 345/138kV Transformer ($9.4M)

IL BaseRel Shared $78,168,000 12/1/2016 12/1/2016 Planned 345 138 A Y

A in MTEP08 Central AmerenIL 1529 Brokaw-State Farm Line 1596 - Reconductor

Reconductor 3.3 miles of 138 kV line to 2000 A Summer Emergency capability


A in MTEP08 Central AmerenIL 2060 East Peoria - Flint : Increase Clerances to ground

Reconductor 4.54 miles of 477 kcmil ACSR with condcutor capable of carrying 1200 A under summer emergency conditions


A in MTEP08 Central AmerenIL 2068 Latham - Oreana 345 kV line Convert Oreana 345 kV Bus to 6-Position Ring Bus with 3000 A Capability; Construct 8.5 miles of 345 kV line (2-954 kcmil ACSR conductor or equivalent capability) from Oreana Substation to 345 kV Line 4571 tap to Latham Substation. 3-345 kV PCB's at Oreana Substation.

IL BaseRel Shared $35,077,000 12/1/2014 12/1/2014 Planned 345 A Y

A in MTEP08 Central AmerenIL 2069 South Bloomington - Install new 560 MVA 345 /138 Xfmr

South Bloomington Area 345/138 kV Substation - Install 345/138 kV, 560 MVA Transformer. Extend new 345 kV line approximately 5 miles from Brokaw Substation to South Bloomington Substation. Install 1-138 kV PCB at South Bloomington Substation, and 2-345 kV PCB's at Brokaw Substation

IL BaseRel Shared $20,029,000 12/1/2014 12/1/2014 Planned 345 138 A Y

A in MTEP06 Central AmerenIL 739 Franklin County Power Plant Connection Franklin County Power Plant Connection - Tap 345 kV Line 4561 Tap, and Install new 345 kV ring bus

IL Other Not Shared (Pre-RECB 1) $6,410,900 11/1/2012 11/1/2012 Planned 345 A Y

A in MTEP05 Central AmerenIL 725 LaSalle Area Development N. LaSalle-Wedron Fox River 138 kV - 24 miles new line, 2-138 kV breakers at N. LaSalle, 1 138 kV Breaker at Wedron Fox River

IL Other Excluded $21,357,530 4/26/2012 4/26/2012 Planned 138 A Y

A in MTEP05 Central AmerenIL 726 LaSalle Area Development Ottawa-Wedron Fox River 138 kV - Construct 9 miles new 138 kV line, 1 new 138 kV breaker at Ottawa

IL Other Excluded $8,962,967 7/30/2013 7/30/2013 Planned 138 A Y

A in MTEP10 Central AmerenMO 2972 Sandy Creek-Joachim Reconductoring Sandy Creek-Joachim-1 138 kV Line - Reconductor 6.2 miles of 795 kcmil ACSR with conductor having 1600 A summer emergency capability between Sandy Creek and Bailey Substations

MO BaseRel Not Shared $3,305,700 6/1/2012 6/1/2012 Planned 138 A Y

A in MTEP10 Central AmerenMO 2976 Central Substation Relocation Central 138-34.5 kV Substation - Move Central 138-34 kV Substation approximately one-half mile and reterminate existing 138 kV supply lines (Cahokia-Central-1&2 and Central-Watson-1)

MO Other Not Shared Relocation $4,632,900 12/1/2012 12/1/2012 Planned 138 A Y

A in MTEP10 Central AmerenMO 3107 Arnold Substatsion : Install 4-138 kV Breakers

Install 4-138 kV Breakers at Arnold Substation. Install 138 kV breaker on the Arnold-Meramec-3 line position. Establish 138 kV Bus #3, install 138 kV Bus 2-3 tie breaker, and rearrange the existing Tyson-Meramec-4 line connection to an in-out arrangement

MO BaseRel Not Shared $2,283,200 6/17/2011 6/17/2011 Planned 138 A Y

A in MTEP09 Central AmerenMO 1240 Reconductor Sioux-Huster-1 and -3 138 kV Reconductor 9.1 miles of 138kV line on Sioux-Huster 1 and 3 lines

MO BaseRel Shared $11,100,000 6/1/2012 6/1/2012 Planned 138 A Y

A in MTEP08 Central AmerenMO 1235 Fredericktown-AECI Fredericktown Increase ground clearance on 12 miles MO Other Not Shared $1,200,000 6/1/2016 6/1/2016 Planned 161 A YA in MTEP08 Central AmerenMO 1238 GM-Point Prairie 161 kV to AECI Enon Sub. Extend 1 mile of 161 kV to AECI Enon Substation MO BaseRel Not Shared $1,896,500 11/17/2011 11/17/2011 Planned 161 A Y

A in MTEP07 Central AmerenMO 152 Big River-Rockwood 138 kV Big River-Rockwood 138 kV - Construct new line MO BaseRel Shared $13,381,100 11/30/2011 11/30/2011 Planned 138 A YA in MTEP10 Central DEM 1520 Durbin 230/69 Construct a new Durbin 230/69kv 150mva substation

with 2 69kv line terminals.IN Other Not Shared Reliability $7,000,000 6/1/2017 6/1/2017 Planned 230 69 A Y

A in MTEP10 Central DEM 1903 Fishers N. to Fishers 69kV reconductor Reconductor 1.05 miles 69kV line from Fishers No to Fishers with 954ACSR@100C conductor

IN Other Not Shared Reliability $455,229 6/1/2014 6/1/2014 Planned 69 A NT

A in MTEP10 Central DEM 2050 Dresser 345/138kV Bank 3 addition Add a 3rd 345/138kV transformer at Dresser Sub IN BaseRel Shared $2,980,000 12/31/2011 12/31/2011 Under Constru 345 138 A YA in MTEP10 Central DEM 2123 Bloomington to Martinsville 69kV Rebuild Bloomington to Martinsville 69kV - 6903 ckt. - Rebuild

9.2 miles of 336ACSR with 954ACSR@100CIN Other Not Shared Reliability $2,020,000 6/1/2012 6/1/2012 Planned 69 A NT


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP10 Central DEM 2134 Bloomington 230 to Needmore Jct 69kV reconductor

Bloomington 230kV Sub to Needmore Jct (Pole #825-3379) reconductor 6949 line with 954ACSR 100C conductor and replace (2) Needmore Jct. 69kV - 600 amp switches with 1200 amp switches.

IN Other Not Shared Reliability $2,712,500 6/30/2013 6/30/2013 Planned 69 A NT

A in MTEP10 Central DEM 2136 Greenwood HE Honey Creek Jct to Frances Creek Jct 69kV uprate

Greenwood HE Honey Creek Jct to Frances Creek Jct uprate 69kV - 69102 line 1.12 mile for 100C


A in MTEP10 Central DEM 2137 Greenwood Averitt Rd Jct to HE Honey Creek Jct 69 kV Uprate

Greenwood Averitt Rd Jct to HE Honey Creek Jct 69 kV - 69102 Uprate 1.05 mile line section of 477acsr for 100C conductor temperature operation


A in MTEP10 Central DEM 2143 Frances Creek 345/69kV Bank 2 Add Frances Creek 345/69kV Bank 2 - 200MVA with LTC

IN Other Not Shared Reliability $6,887,000 6/1/2014 6/1/2014 Planned 345 69 A NT

A in MTEP10 Central DEM 2858 Geist to Fortville 69kv - 69130 ckt. Reconductor

Reconductor 69kV 3.62 mile line from Geist sub to Fortville sub with 954ACSR conductor.


A in MTEP10 Central DEM 2859 Peru Muni J to Wabash J 69kV - 6986 ckt. Reconductor

Peru Muni J to Wabash J 6986 Reconductor approx., 10.3 miles of 4/0 ACSR with 477 ACSR


A in MTEP10 Central DEM 2860 Brazil East to Reelsville J 69kV - 6938 ckt. Reconductor

Reconductor 6938 line from Brazil East to Reelsville Jct. with 477ACSR 100C conductor. Replace Reelsville Jct switches with 1200 amp switches.


A in MTEP10 Central DEM 2861 Greencastle Madison J to Greencastle East J 69kV - 6996 ckt. Reconductor

Reconductor 6996 line from Greencastle Madison Jct to Greencastle East Jct. with 954ACSR 100C conductor. Replace or upgrade 600 amp Greencastle East Jct switches to 1200amp.


A in MTEP10 Central DEM 2863 Carmel SE to new Jct in 69145 ckt - new 69kV line

Build new 69kV-954ACSR circuit from Carmel SE to new Jct in the 69145 line, completing a loop from Carmel 146th St to Geist.

IN Other Not Shared Distribution $4,274,200 6/2/2012 6/2/2012 Planned 69 A NT

A in MTEP10 Central DEM 2865 Frankfort Burlington to Middlefork 69kV - 69133 ckt Uprate

Frankfort Brlngtn St to Midfrk - 69133 ckt - uprate 11.5 miles of 4/0ACSR to 100C and reconductor 1.0 mile of 2/0CUB7 to 954ACSR@100C


A in MTEP10 Central DEM 2869 Zimmer 345kV Gas Insulated Sub. Repl. Replace 345kV gas insulated sub with an air insulated sub

OH Other Not Shared Condition $4,032,000 6/1/2012 6/1/2012 Under Constru 345 A Y

A in MTEP10 Central DEM 2871 EKPC Hebron - 138kV ring bus Add new EKPC Hebron 138/69kV transformer (outside DEM area 208). Includes 3 position – 138kV CB ring bus and associated Duke owned facilities (inside DEM area 208). 138kv Tie from DEM to EKPC is being revised slightly. 100% to be paid for by EKPC.

KY Other Not Shared Reliability $3,345,000 12/31/2011 12/31/2011 Planned 138 69 A Y

A in MTEP10 Central DEM 2872 Manhattan Dist Sub 138kV tap switches Install 1200A - 138kv line switching on both sides of proposed tap line to new joint use DEM/WVPA Manhattan distribution sub.

IN Other Not Shared Distribution $525,723 12/31/2011 12/31/2011 Planned 138 12 A Y

A in MTEP10 Central DEM 2874 Noblesville to Geist 230kV - 23007 line relocate

Relocate section of 23007 between Noblseville and Giest to new RoW around expanding mine operation - approx. 0.6 mile of added line length

IN Other Not Shared Relocation $1,766,218 12/1/2011 12/1/2011 Planned 230 A Y

A in MTEP10 Central DEM 2875 Edwardsville 138kV switches and tap line Construct new Edwardsville 138/12kV distribution substation - single 22.4 MVA transformer

IN Other Not Shared Reliability $467,387 12/31/2011 12/31/2011 Planned 138 12 A NT

A in MTEP10 Central DEM 2876 Redbank 345kV Gas Insulated Bus. Repl. Replace 345kV gas insulated bus with an air insulated bus

OH Other Not Shared Condition $3,467,832 6/1/2013 6/1/2013 Planned 345 A Y

A in MTEP10 Central DEM 2877 West End 138kV relocation for B.S. Bridge Modifications to West End Substation facilities, 138 kV transmission lines and distribution lines to accommodate Brent Spence Bridge project

OH Other Not Shared Relocation $13,780,000 12/31/2015 12/31/2015 Planned 138 13.2 A Y

A in MTEP10 Central DEM 2878 Miami Fort 345kV Gas Insulated Bus. Repl. Replace 345kV gas insulated bus with an air insulated bus

OH Other Not Shared Condition $1,440,000 6/1/2014 6/1/2014 Planned 345 A Y

A in MTEP10 Central DEM 2879 Brazil West 69kV tap switches and tap line Construct Brazil West 10.5MVA 69/12kV sub in the 6902 Line to be located on 900N east of 425W

IN Other Not Shared Reliability $150,000 12/31/2012 12/31/2012 Planned 69 12 A NT

A in MTEP10 Central DEM 2882 Lateral replace CB 840 Replace bus tie breaker #840 and associated disconnect sw's - new limits will be CB - 3000A and D/S's - 2000A.

OH Other Not Shared Reliability $445,302 12/31/2012 12/31/2012 Planned 138 A Y

A in MTEP09 Central DEM 1647 Carmel SE 69/12 KV new distribution substation

Construct Carmel SE Bank 1 22.4MVA bank with 2 exits -extend a new radial 69kv from Carmel 146th St (no new bkr - share dist bk terminal)

IN Other Not Shared Distribution $2,000,000 6/1/2012 6/1/2012 Planned 69 12 A NT


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP09 Central DEM 1880 Columbia 138kV-22.4MVA Sub Columbia 138kV-22.4MVA Sub - New site or purchase and rebuild existing Siemens Sub #537- in F5484 between Warren and Maineville

OH Other Not Shared Distribution $215,000 12/31/2012 12/31/2012 Planned 138 12 A Y

A in MTEP09 Central DEM 2127 Martinsville 69163-1 switch replacement 69163-1 switch replacement near tap to HE Cope with 1200A switch


A in MTEP09 Central DEM 2132 Frances Creek 69kV capacitor Frances Creek Install 36MVAR 69kV capacitor bank IN Other Not Shared Reliability $615,500 6/30/2012 6/30/2012 Planned 69 A NTA in MTEP09 Central DEM 2133 Franklin to Forsythe new 69kV line Franklin 230 sub to Forsythe 69 sub - Build new 3.5 mile

69kV line; new line terminal at Forsythe end onlyIN Other Not Shared Reliability $1,030,000 6/1/2012 6/1/2012 Planned 69 A NT

A in MTEP09 Central DEM 2148 Cadiz to Milner's Corner Jct 69kv reconductor

Cadiz to Markleville to Milner's Corner J - Reconductor 69kv - 69131 ckt - 9.24 mile section with 477ACSR@100C; Replace 69kv three way switch at Milner's Corner Jct with three one way 1200A switches; Upgrade the Markleville 600A switches #1 and #2 to 1200A


A in MTEP09 Central DEM 2149 West End 138kv bus tie and 1389 line bkrs West End substation - Install a 138kV circuit breaker to tie the east and west 138 kV busses together and a line breaker in the 1389 ckt

OH BaseRel Not Shared $1,040,000 12/31/2011 12/31/2011 Under Constru 138 A Y

A in MTEP09 Central DEM 2153 Mohawk to Lee Hanna 69kV reconductor Mohawk to Lee Hanna 69kV reconductor 69130 ckt (5.27 mi) with 954acsr@100C


A in MTEP09 Central DEM 2154 Carmel Rohrer Rd 69/12kv New Sub Carmel Rohrer Rd 69/12-22.4MVA sub to looped through the 6989 ckt. at or near the existing Carmel Shell Oil tap

IN Other Not Shared Distribution $591,143 12/31/2013 12/31/2013 Planned 69 12 A NT

A in MTEP09 Central DEM 2327 Speed to HE Bethany 69kV - 6955 Reconductor Ph1

Speed to HE Bethany 69kV - 6955 Reconductor Ph1 - Replace 5.2 miles of 3/0 ACSR with 477 ACSR (new limiter 4/0acsr)


A in MTEP09 Central DEM 2331 Shelbyville NE to Knauf 69kv - 6946 ckt. Reconductor

Shelbyville NE to Knauf Reconductor 1.75 miles of 397ACSR on 6946 ckt. with 954acsr@100C


A in MTEP09 Central DEM 2332 Zionsville Turkeyfoot to Zionsville 96th St Jct 69kV - 69155 ckt. Reconductor

Zionsville Turkeyfoot to Zionsville 96th St Jct Reconductor 1.59 mile 69kV - 69155 ckt with 954ACSR@100C


A in MTEP09 Central DEM 2334 Fishers 106th St 69/12kv New Sub New Fishers 106th St 69/12 kv sub: Construct 69kV line in and out of sub and 69kv bus including 69kv breaker

IN Other Not Shared Distribution $174,000 6/1/2012 6/1/2012 Planned 69 12 A NT

A in MTEP08 Central DEM 834 Kingman 69kV Cap Add 7.2 MVAR 69kV capacitor at Kingman. IN Other Not Shared $500,000 6/1/2014 6/1/2014 Planned 69 A NTA in MTEP08 Central DEM 835 Pittsboro 69kV Cap Add 14.4 MVAR 69kV capacitor at Pittsboro. IN Other Not Shared $422,362 6/1/2013 6/1/2013 Planned 69 A NTA in MTEP08 Central DEM 841 Westwood Bk1 Limiting Equipment Replace 1600A 138kV breaker with 3000A to allow full

xfr rating.IN BaseRel Not Shared $141,623 6/1/2015 6/1/2015 Planned 345 138 A Y

A in MTEP08 Central DEM 1245 Frankfort Jefferson to Potato Creek new 69kV Line

Construct new 69kV line from Frankfort Jefferson to new Potato Creek switching station.

IN Other Not Shared $2,094,115 6/1/2014 6/1/2014 Planned 69 A NT

A in MTEP08 Central DEM 1501 Carmel 146th St 69kV Cap 2 Added second 36 MVAR 69kV capacitor at Carmel 146th St

IN Other Not Shared $624,145 6/1/2014 6/1/2014 Planned 69 A NT

A in MTEP08 Central DEM 1512 Ashland to Rochelle 138 Install underground 138 kV circuit from Ashland to Ridgeway (New Dist Sub) to Rochelle.

OH BaseRel Not Shared $9,634,051 6/1/2012 12/31/2012 Planned 138 13.1 A Y

A in MTEP08 Central DEM 1513 Metea 69kV Cap Install 14.4MVAR 69kV capacitor at Metea. IN Other Not Shared $865,946 7/15/2011 7/15/2011 Under Constru 69 A NTA in MTEP08 Central DEM 1514 Wabash River to Staunton 230 100C Uprate Uprate Wabash River to Staunton 23002 to 100C

summer operating temperature and 80C winter (559MVA).

IN Other Not Shared $1,286,147 12/31/2011 12/31/2011 Under Constru 230 A Y

A in MTEP08 Central DEM 1519 Noblesville NE to Geist 69 Build a new 69kV line from Noblesville NE sub to tap the Fishers North - Geist 69kV line


A in MTEP08 Central DEM 1560 Edwardsport 138kV cap Install a 138kV 57.6MVAR capacitor at Edwardsport. IN BaseRel Not Shared $709,293 7/15/2011 7/15/2011 Under Constru 138 A YA in MTEP08 Central DEM 1561 Kokomo Webster St 230kv Ring bus Retire existing 1600A circuit switcher and complete the

Webster St ring in order to utilize the full capacity of the bundled 477 ACSS wire on the 23016 line.

IN Other Not Shared $399,580 6/1/2012 6/1/2012 Planned 230 A Y

A in MTEP08 Central DEM 1564 Roseburg Switching Station cap Install 69kV 21.6MVAR std capacitor IN Other Not Shared $518,503 12/31/2011 12/31/2011 Planned 69 A NTA in MTEP08 Central DEM 1568 Qualitech 345/138KV Transformer and

breakersQualitech Sub- Install one 345/138kv, 300Mva Xtr and 2-345kv Bkrs and 1-138kv Bkr to provide second 138kv source to proposed Hendricks Co 138kv system

IN Other Not Shared Reliability $4,561,674 6/1/2013 6/1/2013 Planned 345 138 A Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP08 Central DEM 1569 Qualitech to Pittsboro new 138kv line Construct new 138kv line, Qualitech to Pittsboro, and connect to the Pittsboro-Brownsbg line to provide new 954ACSR outlet line from Qualitech 345/138kV Bank

IN Other Not Shared Reliability $1,507,856 6/2/2013 6/2/2013 Planned 138 A Y

A in MTEP08 Central DEM 1570 Plainfield South to Pittsboro 69KV to 138KV Conversion

Convert the existing 69KV (69144) line from Plainfield S. to Pittsboro (and 4 distribution subs) over to 138KV operation and connect to the new Qualitech to Pittsboro 138KV line


A in MTEP08 Central DEM 1650 Fairview to HE Fairview 13854 Reconductor Fairview to HE Fairview 13854 Reconductor with 954ACSR @ 100C

IN BaseRel Not Shared $1,236,384 6/30/2014 6/30/2014 Planned 138 A Y

A in MTEP08 Central DEM 1881 Bloomington Rogers St - replace 13836 breaker

Bloomington Rogers St - replace 13836 breaker and WT; replace 13871 breaker, WT, and disc sw's - All 2000Amp rated; Replace relays for 13836, 13837, 13871

IN Other Not Shared $1,051,992 12/31/2011 12/31/2011 Planned 138 A Y

A in MTEP08 Central DEM 1889 Danville to Danville Jct 69kV reconductor Danville to Preswick Jct to Danville Jct - recond. 5.2 mi of the 6945 ckt. with 954acsr OVAL @100C and replace the 600 amp, two way switches at Danville Jct with two 1200 amp one way switches and replace the 600 amp switch at Prestwick Jct with a 1200 amp

IN Other Not Shared Reliability $1,622,359 6/23/2011 6/23/2011 Under Constru 69 A NT

A in MTEP08 Central DEM 1890 Geist to new Fishers N. Jct. 69kV line Build new 69kV line - 69181 - 4 miles with 954ACSR along 126th St. (completes approx 5.9 mile line section)

IN Other Not Shared Reliability $1,977,421 8/16/2011 8/16/2011 Under Constru 69 A NT

A in MTEP08 Central DEM 1893 Mitchell Lehigh Portland to Bedford 25th St 6995 rebuild

Reconductor 10.3 miles of 69kV - 6995 line with 477 ACSR@100C


A in MTEP08 Central DEM 1895 Brownsburg to Avon East 138kV Reconductor

Brownsburg to Avon East 138kV Reconductor 4.2 miles of 138kV line with 954 ACSR - AFTER 138KV CONVERSION


A in MTEP08 Central DEM 1896 Connersville 138 sub to Connersville 30th St 69kV uprate

Connersville 138 sub to Connersville 30th St 69kV Uprate to 100C - 4/0 acsr sections – 1.2 miles - 6981 ckt


A in MTEP08 Central DEM 1897 Deedsville to Macy 69kV Reconductor Reconductor Deedsville to Macy section of 6957 circuit with 477ACSR approx 2.5 miles; and replace Macy #1 and #2 - 600A line switches (1955 vintage) with 1200A


A in MTEP08 Central DEM 1899 Macy to Rochester Metals Jct 69kV reconductor

Reconductor Macy to Rochester Metals Jct section of 6957 circuit with 477ACSR - approx 9.1 miles


A in MTEP08 Central DEM 1901 Noblesville Station to Noblesville Jct 69kV line rebuild

Reconductor 69kV - 6984 & 6916 ckt. Noblesville Plant to Noblesville 8th St. to Noblesville Jct with 954ACSS @ 200C (5.47 miles)


A in MTEP08 Central DEM 1902 Zionsville 69 to Zionsville 96th Jct 69kV reconductor

Reconductor .32 miles of the 69kV - 69155 line from Zionsville 69 sub to Zionsville 96th Jct with 954ACSR conductor; replace/upgrade 69kV switches, jumpers and bus at Zionsvile 69 sub for a min. capacity of 152MVA (502G6709)


A in MTEP07 Central DEM 852 Crawfordsville to Tipmont Concord to Lafayette SE 138 Reconductor

Reconductor 13819 circuit with 954ACSR 100C. IN BaseRel Shared $8,919,730 6/1/2013 6/1/2013 Planned 138 A Y

A in MTEP06 Central DEM 851 Laf Cumberland to Laf AE Staley 138 Reconductor

Reconductor section of 13806 circuit with 954ACSR 100C.

IN BaseRel Not Shared $349,357 6/1/2013 6/1/2013 Planned 138 A Y

A in MTEP06 Central DEM 853 West Lafayette to Cumberland 138 Reconductor

Reconductor section of 13806 circuit with 954ACSR 100C.


A in MTEP06 Central DEM 1244 Cayuga to Frankfort 23013 Wave Trap Upgrade

Upgrade wave traps at Cayuga and Frankfort to increase line rating to 797 MVA.

IN BaseRel Not Shared $167,560 6/1/2013 6/1/2013 Planned 230 A Y

A in MTEP10 Central HE 3080 Rocklane Tie to Duke 69kV Build 69kV Transmission from HE Rocklane to Duke 69kV Transmission


A in MTEP08 Central HE 1927 Hubbell Primary Ring Bus 138kV Ring Bus addition / Modification to Hubbell Primary


A in MTEP08 Central HE 1928 Fairview Primary Ring Bus 138kV Ring Bus addition / Modification to Fairview Primary


A in MTEP08 Central HE 1929 Georgetown Primary Ring Bus 138kV Ring Bus addition / Modification to Georgetown Primary


A in MTEP08 Central HE 2082 Shelbyville Intel Park 138kV Substation and Tapline IN Other Not Shared Reliability $1,000,000 9/1/2009 9/1/2009 Planned 138 12.5 A Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP08 Central HE 2083 Wayne County Industrial Park 69kV Substation and Tapline IN Other Not Shared $750,000 9/1/2009 9/1/2009 Planned 69 12.5 A NTA in MTEP10 Central IPL 2900 Northwest - Southwest 138 kV line rating

upgradeIncrease line rating from 242 to 382 MVA IN BaseRel Not Shared $1,500,000 6/1/2011 6/1/2011 Planned 138 A Y

A in MTEP09 Central IPL 2053 Petersburg 345/138kV East and West Autotransformers and 345 kV breaker

Replace and upgrade existing East and West 345/138kV autotransformer at Petersburg Substation. Add 345kV breaker.

IN BaseRel Shared $15,400,000 6/1/2012 6/1/2012 Planned 345 138 A Y

A in MTEP08 Central IPL 1639 General IPL Capacitor Additions Add capacitors to the IPL General Distribution System IN Other Not Shared $50,000 6/1/2013 6/1/2013 Planned A YA in MTEP08 Central SIPC 1778 Hamilton 138KV Interconnect Construct a 138KV line connecting SIPC Hamilton

Substation to Ameren Norris City Substation. This project includes the construction of 18 miles of 138KV line.

IL Other Not Shared $5,000,000 7/1/2008 7/1/2008 Planned 138 A Y

A in MTEP03 Central SIPC 81 Carrier Mills 161kV A new 25-mile 161kV transmission line from Southern Illinois Power Cooperative's power plant to a new 161/69kV substation located north of Carrier Mills, IL.

IL Other Excluded $10,200,000 9/1/2012 9/1/2012 Planned 161 69 A Y

A in MTEP09 Central Vectren (SIGE) 2461 Dubois Sub Z84 terminals Add 1 new 138kV terminal to existing sub to avoid 3 term line, breaking up Duff - Dubois - Culley 138kV line


A in MTEP09 Central Vectren (SIGE) 2465 Leibert Rd 138/12kV Substation New 138/12kV Substation for load growth IN Other Not Shared Distribution $2,622,781 10/1/2011 10/1/2011 Planned 138 12.47 A NTA in MTEP09 Central Vectren (SIGE) 2466 Roesner Rd 138/12kV Substation New 138/12kV Substation for load growth IN Other Not Shared Distribution $3,000,000 6/1/2013 6/1/2013 Planned 138 12.47 A NTA in MTEP08 Central Vectren (SIGE) 1002 New Northeast to Oak Grove to Culley Line

138 kVNew Northeast to Oak Grove to Culley Line 138 kV IN Other Not Shared Reliability $4,368,926 6/1/2012 6/1/2012 Under Constru 138 A Y

A in MTEP08 Central Vectren (SIGE) 1782 NorthEast Sub Bus re-config Rebuild existing straight bus with more reliable breaker and half scheme


A in MTEP08 Central Vectren (SIGE) 1784 Jasper#3 Sub Exp-Victory Line Extend existing Victory line to new term at existing sub IN Other Not Shared $3,625,000 6/1/2016 6/1/2016 Planned 69 A NTA in MTEP08 Central Vectren (SIGE) 1785 Z83 Upgrade Upgrade terminal equipment at NE and NW. IN Other Not Shared $100,000 12/31/2012 12/31/2012 Planned 138 A YA in MTEP08 Central Vectren (SIGE) 1787 Y75 - Dale to Santa Clause New 69kV line from Dale Sub to Santa Clause Sub IN Other Not Shared Reliability $5,000,000 6/1/2014 6/1/2014 Planned 69 A NTA in MTEP08 Central Vectren (SIGE) 1788 Y34 - St. Wendel to Mohr Rd New 69kV line from St. Wendel Sub to Mohr Rd Sub IN Other Not Shared Reliability $2,750,000 6/1/2014 6/1/2014 Planned 69 A NTA in MTEP08 Central Vectren (SIGE) 1789 Y56 - City of Boonville Loop New 69kV line from Boonville Sub to Boonville Pioneer

SubIN Other Not Shared Reliability $1,400,000 6/1/2014 6/1/2014 Planned 69 A NT

A in MTEP08 Central Vectren (SIGE) 1790 Y52 rebuild and Sunbeam loop Rebuild/Reconductor existing Y52 and loop into Sunbeam


A in MTEP08 Central Vectren (SIGE) 1791 Y66-2 Angel Mounds to Eastside uprate Uprate Y66-2 from Angel Mounds to East Side to increase transfer capacity


A in MTEP06 Central Vectren (SIGE) 1257 New Transmission Line Gibson (Cinergy) to AB Brown (Vectren) to Reid (BREC)

New 345 kV transmission line Gibson (Cinergy) to AB Brown (Vectren) to Reid (BREC)

IN KY BaseRel Shared $46,284,114 6/1/2012 6/1/2012 Under Constru 345 A Y

A in MTEP10 East ITC 2918 Breaker Replacement Program 2012 Replace defective, damaged, or over dutied breakers throughout system.

MI Other Not Shared Condition $6,000,000 12/31/2012 12/31/2012 Planned 345 120 A Y

A in MTEP10 East ITC 2919 NERC Relay Loadability Compliance 2012 Upgrade relays throughout system MI Other Not Shared Reliability $2,400,000 12/31/2012 12/31/2012 Planned 345 120 A YA in MTEP10 East ITC 2920 Potential Device Replacement 2012 Replace aging potential devices MI Other Not Shared Condition $300,000 12/31/2012 12/31/2012 Planned 345 120 A YA in MTEP10 East ITC 2921 Relay Betterment Program 2012 Replace aging and electromechanical relays throughout

the system. Add OPGW where needed.MI Other Not Shared Condition $1,200,000 12/31/2012 12/31/2012 Planned 345 120 A Y

A in MTEP10 East ITC 2922 Wood Pole Replacement 2012 Replace deteriorating wood pole MI Other Not Shared Condition $4,800,000 12/31/2012 12/31/2012 Planned 120 A YA in MTEP10 East ITC 2923 Capacitor Replacement 2012 Replace capacitor banks MI Other Not Shared Condition $600,000 12/31/2012 12/31/2012 Planned 120 A YA in MTEP10 East ITC 2925 Blanket for Customer Interconnection 2011 Throughout system MI Other Not Shared Distribution $2,000,000 12/31/2011 12/31/2011 Planned 120 A YA in MTEP10 East ITC 2926 Blanket for Customer Interconnection 2012 Throughout system MI Other Not Shared Distribution $2,000,000 12/31/2012 12/31/2012 Planned 120 A YA in MTEP10 East ITC 2927 Blanket for Customer Interconnection 2013 Throughout system MI Other Not Shared Distribution $2,000,000 12/31/2013 12/31/2013 Planned 120 A YA in MTEP10 East ITC 2928 Blanket for Customer Interconnection 2014 Throughout system MI Other Not Shared Distribution $2,000,000 12/31/2014 12/31/2014 Planned 120 A YA in MTEP10 East ITC 2929 Ariel Substation (formerly Holland) Distribution Interconnection to add two new 120/13.2kV

transformers at Holland. Connects to the Wheeler to Troy 120kV circuit.


A in MTEP10 East ITC 2930 Upper Rouge Distribution Interconnection to add a new 120/4.8kV transformer at Upper Rouge.


A in MTEP10 East ITC 3168 Candidate MVP Portfolio 1 - Michigan Thumb Wind Zone

The proposed transmission line will connect into a new staMI MVP Shared $510,000,000 12/31/2013 12/31/2015 Planned 345 120 A Y

A in MTEP09 East ITC 1872 Scio Distribution Interconnection to add new 120/41kV transformer. Loops the Lark-Spruce 120kV circuit into the station.


A in MTEP09 East ITC 2519 Breaker Replacement Program 2011 Replace defective, damaged, or over dutied breakers throughout system.

MI Other Not Shared Condition $5,650,000 12/31/2011 12/31/2011 Planned A Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP09 East ITC 2520 Cable Termination Replacement 2011 Replace high pressure gas filled underground cable terminations throughout system.


A in MTEP09 East ITC 2521 Relay Betterment Program 2011 Replace aging and electromechanical relays throughout the system. Add OPGW where needed.


A in MTEP09 East ITC 2525 Capacitor Replacement 2011 Replace capacitor banks MI Other Not Shared Condition $565,000 12/31/2011 12/31/2011 Planned A YA in MTEP09 East ITC 2528 Potential Device Replacement 2011 Replace aging potential devices MI Other Not Shared Condition $300,000 12/31/2011 12/31/2011 Planned A YA in MTEP09 East ITC 2531 Power Plant Control Relocation 2011 Relocate substation controls currently located in power

plant control roomsMI Other Not Shared Condition $1,200,000 12/31/2011 12/31/2011 Planned A Y

A in MTEP09 East ITC 2534 Wood Pole Replacement 2011 Replace deteriorating wood pole MI Other Not Shared Condition $9,000,000 12/31/2011 12/31/2011 Planned A YA in MTEP09 East ITC 2537 Synchronizing Sites 2011 New 120kV synchronizing sites MI Other Not Shared Operations $565,000 12/31/2011 12/31/2011 Planned A YA in MTEP09 East ITC 2539 NERC Relay Loadability Compliance 2011 Upgrade relays throughout system MI BaseRel Not Shared $2,250,000 12/31/2011 12/31/2011 Planned 120 A YA in MTEP09 East ITC 2541 Hunters Creek - Robin - Wabash Install double groundwire peaks and second shield wire. MI Other Not Shared Condition $2,400,000 7/22/2011 7/22/2011 Under Constru 120 A Y

A in MTEP09 East ITC 2545 Marathon/Navarre New distribution interconnection served from Navarre substation

MI Other Not Shared Distribution $640,000 9/1/2011 9/1/2011 Planned 120 A Y

A in MTEP08 East ITC 1870 Clyde Distribution Interconnection to add a new 120/41kV transformer at Clyde. Taps the Placid-Durant 120kV circuit

MI Other Not Shared $2,750,000 6/1/2013 6/1/2013 Planned 120 A Y

A in MTEP08 East ITC 1873 Tahoe Distribution Interconnection to add a new 120/13.2kV transformer at Tahoe.


A in MTEP06 East ITC 1308 B3N Interconnection Returns the Bunce Creek to Scott 220 kV circuit to service, and replaces the Phase Angle Regulator with 2 new phase angle regulating transformers in series


A in MTEP06 East ITC 1310 Breaker Replacement Program Targets the replacement of breakers nearing their end of life where maintenance costs will be just as high as new breakers

MI Other Not Shared $150,000 9/30/2011 9/30/2011 Planned 120 A Y

A in MTEP10 East METC 2502 McGulpin Shunt Reactor Install shunt reactor McGulpin MI BaseRel Not Shared $3,000,000 12/31/2011 12/31/2011 Planned 138 A YA in MTEP10 East METC 2903 Battery Replacement 2012 Replace batteries and chargers MI Other Not Shared Condition $300,000 12/31/2012 12/31/2012 Planned A YA in MTEP10 East METC 2904 Breaker Replacement Program 2012 Replace defective, damaged, or over dutied breakers

throughout system.MI Other Not Shared Condition $6,000,000 12/31/2012 12/31/2012 Planned A Y

A in MTEP10 East METC 2905 NERC Relay Loadability Compliance 2012 Upgrade relay throught system MI Other Not Shared Reliability $2,400,000 12/31/2012 12/31/2012 Planned A YA in MTEP10 East METC 2906 Potential Device Replacement 2012 Replace aging potential devices MI Other Not Shared Condition $300,000 12/31/2012 12/31/2012 Planned A YA in MTEP10 East METC 2907 'Power Plant Control Relocation 2012 Relocate substation controls currently located in power

plants control roomsMI Other Not Shared Condition $1,200,000 12/31/2012 12/31/2012 Planned A Y

A in MTEP10 East METC 2908 Relay Betterment Program 2012 Replace aging and electromechanical relays throughout the system. Add OPGW where needed.


A in MTEP10 East METC 2909 Sag clearance 2012 Identify and remediate inherent sag limitations on heavily loaded METC trasmission lines throughout the system.

MI Other Not Shared clearance $3,600,000 12/31/2012 12/31/2012 Planned 345 138 A Y

A in MTEP10 East METC 2910 Wood Pole Replacement 2012 Replace deteriorating wood pole MI Other Not Shared Condition $4,800,000 12/31/2012 12/31/2012 Planned 138 A YA in MTEP10 East METC 2912 Blanket for Customer Interconnections 2011 Throughout system MI Other Not Shared Distribution $2,500,000 12/31/2011 12/31/2011 Planned 138 A Y

A in MTEP10 East METC 2913 Blanket for Customer Interconnections 2012 Throughout system MI Other Not Shared Distribution $2,500,000 12/31/2012 12/31/2012 Planned 138 A Y



A in MTEP10 East METC 2916 Livingston - Vanderbilt 138 kV Rebuild Rebuild 9.7 miles of 138 kV 266 ACSR to 954 ACSR FDC 230 kV construction.

MI BaseRel Shared $12,734,400 6/1/2012 6/1/2012 Planned 138 A Y

A in MTEP10 East METC 2917 David Jct - Hubbardson Jct - Bingham Sag Remediation

Improve sag clearance by replacing 16 wood poles with 138 kV FDC steel poles.

MI BaseRel Not Shared $1,216,860 11/30/2011 11/30/2011 Planned 138 A Y

A in MTEP09 East METC 646 Edenville Jct. - Warren 138kV Replace poles on the Edenville-Warren 138kV line to future-double-circuit, prebuilt to 230kV.

MI Other Not Shared Reliability $12,500,000 12/1/2011 12/1/2012 Planned 138 A Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP09 East METC 662 Weeds Lake Loop the 345kV Argenta - Robinson Park 345kV circuit into a new 345/138kV EHV substation called Weeds Lake. Build 4 new (approximately 6 miles) 138kV circuits to loop the two Argenta-Milham 138kV lines into the substation.

MI BaseRel Shared $45,026,457 6/1/2013 6/1/2013 Planned 345 138 A Y

A in MTEP09 East METC 1810 Iosco - East Tawas 138kV Rebuild 12 miles of 138kV to 954 ACSR. MI Other Not Shared Condition $9,818,854 12/31/2011 12/31/2011 Planned 138 A YA in MTEP09 East METC 1833 Sag clearance 2011 Identify and remediate inherent sag limitations on

heavily loaded METC trasmission lines throughout the system.

MI Other Not Shared Clearance $3,400,000 12/31/2011 12/31/2011 Planned A Y

A in MTEP09 East METC 2475 Titus Lake Distribution interconnection to add a second transformer at Titus Lake.


A in MTEP09 East METC 2478 Capital Ave New distribution interconnection served from Battle Creek - Verona #2 138kV (Line connection change to Battle Creek to Island Road)


A in MTEP09 East METC 2481 Forrest Grove New distribution interconnection served from Campbell-Ransom 138kV circuit.


A in MTEP09 East METC 2482 Hawthorne New distribution interconnection served from Four Mile - Blendon 138kV circuit.


A in MTEP09 East METC 2483 Maines Road New distribution interconnection served from Marshall - Blackstone 138kV circuit


A in MTEP09 East METC 2484 Scenic Lake New distribution interconnection served from Cornell-Tihart 138kV circuit


A in MTEP09 East METC 2485 Ironwood New distribution interconnection served from CE's 138kV spur on the Ransom-Buck Creek 138kV.


A in MTEP09 East METC 2486 Haakwood New distribution interconnection served from Riggsville-Livingston 138kV (on the Rondo-Vanderbilt section)


A in MTEP09 East METC 2487 Birchwood New distribution interconnection served from Spaulding-Plaster Creek 138kV (on the Spaulding-Kraft section)


A in MTEP09 East METC 2489 Terminal Equipment upgrade at Tippy Terminal Equipment upgrade at Tippy on the Tippy-Keystone 138kV line

MI BaseRel Not Shared $60,215 9/30/2011 9/30/2011 Planned 138 A Y

A in MTEP09 East METC 2492 Battle Creek - Verona 138kV ckt. #2 Upgrade terminal equipment. MI BaseRel Not Shared $200,000 6/1/2013 6/1/2013 Planned 138 A YA in MTEP09 East METC 2496 Bullock - Tittabawassee 138kV Upgrade terminal equipment. MI BaseRel Not Shared $360,000 6/1/2013 6/1/2013 Planned 138 A YA in MTEP09 East METC 2498 Breaker Replacement Program 2011 Replace defective, damaged, or over dutied breakers

throughout system.MI Other Not Shared Condition $5,650,000 12/31/2011 12/31/2011 Planned A Y

A in MTEP09 East METC 2499 Relay Betterment Program 2011 Replace aging and electromechanical relays throughout the system. Add OPGW where needed.


A in MTEP09 East METC 2501 Northern Reactive Install 3 capacitors in the northern part of Michigan MI BaseRel Not Shared $2,700,001 6/1/2012 6/1/2012 Planned A YA in MTEP09 East METC 2507 Alcona - Mio 138kV Rebuild the line to 954 ACSR future-double-circuit (pre-

built to 230kV)MI Other Not Shared Condition $24,500,000 6/1/2013 6/1/2013 Planned 138 A Y

A in MTEP09 East METC 2510 Wood Pole Replacement 2011 Replace deteriorating wood pole MI Other Not Shared Condition $6,000,000 12/31/2011 12/31/2011 Planned 138 A YA in MTEP09 East METC 2515 Tihart - Oakland (Genoa) 138kV Replace all line structures and insulators. MI Other Not Shared Condition $18,871,627 8/1/2011 8/1/2011 Planned 138 A YA in MTEP09 East METC 2517 NERC Relay Loadability Compliance 2011 Upgrade relay throught system MI BaseRel Not Shared $2,250,000 12/31/2011 12/31/2011 Planned 138 A YA in MTEP09 East METC 2522 Power Plant Control Relocation 2011 Relocate substation controls currently located in power

plants control roomsOther Not Shared Condition $1,200,000 12/31/2011 12/31/2011 Planned A Y

A in MTEP08 East METC 1448 Simpson Project to connect a distribution transformer at Simpson MI Other Not Shared $2,200,000 6/1/2016 6/1/2016 Planned 138 12.5 A YA in MTEP08 East METC 1655 Breaker Repair or Replace Program throughout system MI Other Not Shared $480,000 12/31/2011 12/31/2011 Planned 138 A YA in MTEP08 East METC 1796 Twining - Almeda 138kV Rebuild 22 miles of 138kV of 110 Cu to 954 ACSR.

Prebuild to 230kV construction.MI BaseRel Shared $22,819,200 12/31/2011 12/31/2011 Planned 138 A Y

A in MTEP08 East METC 1814 Tippy - Chase 138kV Rebuild 30 miles of 138kV 110 CU to 954 ACSR. Prebuild to 230kV construction.


A in MTEP08 East METC 1820 METC Communication and Relaying Upgrade

Throughout system MI Other Not Shared $10,000,000 12/31/2011 12/31/2011 Planned A Y

A in MTEP08 East METC 1834 Tirrell Road New Distrbution Interconnection served from Battle Creek - Island Rd. 138kV circuit


A in MTEP08 East METC 1841 Eagles Landing New Distrbution Interconnection served from Iosco - Karn 138kV circuit


A in MTEP06 East METC 988 Simpson - Batavia 138 kV line Simpson - Batavia 138 kV line - Build 30 miles new 138 kV line, 795 ACSS



Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP06 East METC 1408 RTU / SCADA Re-direction Program Install and/or upgrade RTU's and SCADA points throughout system

MI Other Not Shared $801,000 6/30/2013 6/30/2013 Under Constru 345 138 A Y

A in MTEP06 East METC 1434 Five Mile Install bulk substation served from the Spaulding 138kV ring bus


A in MTEP06 East METC 1445 Emmet Install a second distribution transformer at Emmet MI Other Not Shared $2,750,000 12/31/2016 12/31/2016 Planned 138 A YA in MTEP06 East METC 1447 Horseshoe Creek (Deja) Install bulk substation served from the Eureka-Deja-

Vestaburg 138kV LineMI Other Not Shared $2,200,000 6/1/2012 6/1/2012 Planned 138 A Y

A in MTEP10 East MPPA 3074 TC East - Parsons TLine New 4.1 mi 69kV transmission line from new TC East Sub to existing Parsons Sub

MI Other Not Shared Reliability $1,600,000 12/31/2012 12/31/2012 Planned 69 A NT

A in MTEP10 East MPPA, METC 3073 TC East Substation New 138/69kV Substation Interconnection MI Other Not Shared Reliability $8,413,791 12/31/2011 12/31/2012 Planned 138 69 A YA in MTEP10 East NIPS 2322 Green Acres Sub.- 345-138kV Transformer Install a 560 MVA 345/138 kV transformer, (1) 345 kV

and (1) 138 kV circuit breaker and associated equipment at Green Acres Substation.

IN BaseRel Shared $7,417,000 6/1/2011 6/1/2011 Planned 345 138 A Y

A in MTEP08 East NIPS 1996 Circuit 6980 - Angola Sub to Sw #644 - Rebuild w 336 KCM ACSR

Rebuild and upgrade 12 miles of Circuit 6980's existing 2/0 Cu to 336.4 kCM ACSR.

IN Other Not Shared $2,465,948 12/1/2012 12/1/2012 Under Constru 69 A Y

A in MTEP08 East NIPS 1997 Circuit 6977 - Goshen Jct to Model Sub Tap - Recond. 1.5 Miles

Upgrade (reconductor) 1.5 miles of 69 KV line to 336.4 KCM ACSR.


A in MTEP10 East WPSC 3060 Morley Capacitor Bank Install a Capacitor Bank tap at the Morley substation MI Other Not Shared Reliability $260,000 12/31/2020 12/31/2020 Planned 69 A YA in MTEP10 East WPSC 3061 Tremaine New Distribution Interconnection from the Burnips to

Portland circuitMI Other Not Shared Distribution $200,000 6/1/2012 6/1/2012 Planned 69 A Y

A in MTEP10 East WPSC 3062 Blendon Transformer Upgrade Replace Blendon Transformer with a larger transformer MI Other Not Shared Reliability $3,750,000 12/31/2013 12/31/2013 Planned 138 69 A YA in MTEP10 East WPSC 3063 Redwood to Baseline Rebuild Rebuild the Redwood to Baseline line section with a

larger conductorMI Other Not Shared Reliability $2,500,000 12/31/2011 12/31/2011 Under Constru 69 A Y

A in MTEP10 East WPSC 3068 South Boardman Capacitor Bank Install a Capacitor Bank at the South Boardman substation

MI Other Not Shared Reliability $260,000 12/31/2014 12/31/2014 Planned 69 A Y

A in MTEP10 East WPSC 3069 Weidman Capacitor Bank Install a Capacitor Bank at the Weidman substation MI Other Not Shared Reliability $260,000 12/31/2020 12/31/2020 Planned 69 A YA in MTEP09 East WPSC 2735 Alba-Westwood Line Rebuild Alba - Mancelona - Westwood 69 kV line rebuild (11

miles) to 143 MVAMI Other Not Shared Reliability $4,800,000 12/31/2013 12/31/2013 Planned 69 A Y

A in MTEP09 East WPSC 2736 East Bay-South Boardman Line Rebuild East Bay - South Boardman Dist - South Boardman 69 kV line rebuild (16 miles) to 143 MVA

MI Other Not Shared Reliability $6,500,000 12/31/2014 12/31/2014 Planned 69 A Y

A in MTEP09 East WPSC 2770 Gilmore New distribution interconnection served from Hersey to Vestaburg circuit.


A in MTEP08 East WPSC 1222 Lake County 69kV Ring Bus and Transformer

Convert 4 breaker bus at Lake County to Ring Bus and add 168MVA transformer

MI Other Not Shared Reliability $6,050,000 12/31/2011 12/31/2011 Under Constru 138 69 A Y

A in MTEP08 East WPSC 1274 Blendon to Osipoff Blendon to Osipoff line rebuild MI Other Not Shared Reliability $7,400,000 12/31/2012 12/31/2014 Planned 69 A YA in MTEP08 East WPSC 1311 Copemish to Grawn Copemish to Grawn line rebuild MI Other Not Shared Reliability $9,100,000 12/31/2012 12/31/2014 Planned 69 A YA in MTEP08 East WPSC 1313 Plains X to Hersey Plains X to Hersey line rebuild MI Other Not Shared Reliability $11,450,000 12/31/2012 12/31/2015 Planned 69 A YA in MTEP08 East WPSC 1581 Alba to Advance 69 rebuild Alba to Advance 69 kV line rebuild MI Other Not Shared Reliability $7,300,000 12/31/2011 12/31/2012 Planned 69 A YA in MTEP08 East WPSC 1586 Gaylord to Advance 69 kV line rebuild,

Advance to Petoskey 69 kV line rebuild, Petoskey to Oden 69 kV line rebuild

Rebuild Overloaded line MI Other Not Shared Reliability $7,200,000 12/31/2015 12/31/2015 Planned 69 A Y

A in MTEP08 East WPSC 1967 Wayland to Portland Rebuild Outdated line MI Other Not Shared Reliability $14,542,000 12/31/2020 12/31/2020 Planned 69 A YA in MTEP06 East WPSC 1272 Redwood 75MVA Transformer Add 75MVA Transformer at Redwood Substation

a separate line from Redwood Junction will be ran to energize the transformer.

MI Other Not Shared Reliability $3,000,000 12/31/2012 12/31/2012 Planned 138 69 A Y

A in MTEP10 West ATC LLC 2451 Brodhead-S Monroe 69kV Rebuild Rebuild Brodhead- S Monroe 69kV line with T2 477 kcmil ACSR

WI Other Not Shared Reliability $11,800,000 3/1/2012 3/1/2012 Planned 69 A Y

A in MTEP10 West ATC LLC 2819 Replace Bluemound 230/138kV transformerT3


WI Other Not Shared Condition $8,000,000 12/27/2011 12/27/2011 Planned 230 138 A Y

A in MTEP10 West ATC LLC 3122 Reconductor a portion of Dam Heights-Okee Tap 69kV

Reconductor 1.94 mi of 3-0 and 336 ACSR line conductor with T-2 4-0 ACSR keeping the T-2 3-0 ACSR for the DHT-Okee Tap section of line Y-8, replace 26 1919 vintage lattice towers and 4 wood poles

WI Other Not Shared Condition $2,177,421 6/19/2012 6/19/2012 Planned 69 A Y

A in MTEP09 West ATC LLC 2452 G706 Glacier Hills Wind Farm G706 Glacier Hills Wind Farm; taps Friesland-Hamilton 138 kV line

WI GIP Shared 12/31/2011 12/31/2011 Planned 0.69 A Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP08 West ATC LLC 356 Rockdale-West Middleton 345 kV Construct a new 345/138 kV substation at Cardinal (next to the existing West Middleton sub), install a 345/138 kV 500 MVA transformer at Cardinal, construct 47.9 miles overhead 345 kV line from Albion to Cardinal/West Middleton, modifications to the existing West Middleton substation, construct a new Albion 345 kV switching station. Facility costs listed in the facility table are for the southern route.

WI BaseRel Shared $219,124,872 6/1/2013 6/1/2013 Planned 345 138 A Y

A in MTEP08 West ATC LLC 574 Monroe County - Council Creek 161 kV line projects

Monroe County - Council Creek 161 kV line, Council Creek 161/138 kV transformer; Council Creek-Petenwell uprate 138 kV

WI Other Not Shared $34,703,000 6/1/2014 6/1/2014 Planned 161 69 A Y

A in MTEP08 West ATC LLC 1683 Rebuild Sunset Point-Pearl Ave 69 kV line Rebuild 2.37 miles of 69 kV from Sunset Point-Pearl Ave with 477 ACSR


A in MTEP10 West GRE 1018 Little Falls - Pierz conversion to 115 kV CWP Little Falls-MP Little Falls 115 kV line MN Other Not Shared Distribution $1,705,514 11/30/2012 11/30/2012 Planned 115 A YA in MTEP10 West GRE 2564 Sartell (SEA) 3.0 mile, 115 kV line Sartell (SEA) 3.0 mile, 115 kV line MN Other Not Shared Distribution $1,385,861 10/28/2012 10/28/2012 Planned 115 A YA in MTEP10 West GRE 2565 Frazer Bay Development Frazer Bay Development MN Other Not Shared Distribution $19,275,099 11/5/2012 11/5/2012 Planned 115 69 A YA in MTEP10 West GRE 2566 Potato Lake (IM) 7 mile, 115 kV line Potato Lake (IM) 7 mile, 115 kV line MN Other Not Shared Distribution $4,401,144 10/14/2011 10/14/2011 Under Constru 115 A YA in MTEP10 West GRE 2567 Northport (BENCO) 1 mile, dbl ckt 115 kV

lineNorthport (BENCO) 1 mile, dbl ckt 115 kV line MN Other Not Shared Distribution $1,149,664 10/31/2012 10/31/2012 Planned 115 A Y

A in MTEP10 West GRE 2570 Ravenna (DEA) 161 kV Substation Ravenna (DEA) 161 kV Substation MN Other Not Shared Distribution $821,206 6/2/2014 6/2/2014 Planned 161 A YA in MTEP10 West GRE 2574 St. Lawrence Substation and Tap - MVEC St. Lawrence Substation and Tap - MVEC MN Other Not Shared Distribution $374,182 5/1/2017 5/1/2017 Planned 115 A YA in MTEP10 West GRE 2576 Pokegama (LCP) 8.0 mile, 115 kV line Pokegama (LCP) 8.0 mile, 115 kV line MN Other Not Shared Distribution $4,079,993 11/1/2011 11/1/2011 Under Constru 115 A YA in MTEP10 West GRE 2577 Elmcrest (CE) 69 kV Substation Elmcrest (CE) 69 kV Substation MN Other Not Shared Distribution $140,000 6/1/2012 6/1/2012 Planned 69 A YA in MTEP10 West GRE 2579 Foster Lake (WH) 69 kV Substation Foster Lake (WH) 69 kV Substation MN Other Not Shared Distribution $140,000 5/29/2015 5/29/2015 Planned 69 A YA in MTEP10 West GRE 2589 Barnes Grove (DEA) 2.0 mile, 69 kV line Barnes Grove (DEA) 2.0 mile, 69 kV line MN Other Not Shared Distribution $115,001 3/25/2014 3/25/2014 Planned 69 A YA in MTEP10 West GRE 2605 Bunker Lake #2 (CE at GRE) 69 kV

SubstationBunker Lake #2 (CE at GRE) 69 kV Substation MN Other Not Shared Distribution $208,450 4/30/2012 4/30/2012 Planned 69 A Y

A in MTEP10 West GRE 2621 Effie 230/69 kV source Effie 230/69 kV transformer, Effie-Big Fork 69 kV line, Wirt Tap 3-way switch, Jessie Lake 3-way switch, Big Fork 3-way switch

MN Other Not Shared Reliability $10,527,919 11/1/2013 11/1/2013 Planned 230 69 A Y

A in MTEP10 West GRE 2624 Hudson 115 kV conversion 115 kV conversion MN Other Not Shared Distribution $381,006 2/29/2012 2/29/2012 Under Constru 115 A YA in MTEP10 West GRE 2630 Resag Big Fork-Wirt Tap-Jessie Lake

RetempResag Big Fork-Wirt Tap-Jessie Lake Retemp MN Other Not Shared Reliability $1,289,999 4/24/2013 4/24/2013 Planned 69 A Y

A in MTEP10 West GRE 2631 Resag Deer River-Jessie Lake Retemp Resag Deer River-Jessie Lake Retemp MN Other Not Shared Reliability $1,339,996 4/24/2013 4/24/2013 Planned 69 A YA in MTEP10 West GRE 2667 Rush City-Adrian Robinson Rush City Dist

RetempRush City-Adrian Robinson Rush City Dist Retemp MN Other Not Shared Reliability $299,001 9/30/2011 9/30/2011 Planned 69 A Y

A in MTEP10 West GRE 2670 Schuster Lake 115/41.6 Source Schuster Lake115/41.6 Source MN Other Not Shared Reliability $4,480,714 4/14/2020 4/14/2020 Planned 115 41.6 A YA in MTEP10 West GRE 2671 Soderville-Ham Lake-Johnsville (6.18 mi.)

RetempSoderville-Ham Lake-Johnsville (6.18 mi.) Retemp MN Other Not Shared Reliability $282,809 12/30/2011 12/30/2011 Planned 69 A Y

A in MTEP10 West GRE 2672 Rush City - Bear Creek - Effie Transformer Swap

Rush City - Bear Creek - Effie Transformer Swap MN Other Not Shared Reliability $500,000 11/1/2011 6/1/2012 Planned 230 69 A Y

A in MTEP10 West GRE 2731 Blomkest (KEPCA) 3.0 mile, 69 kV line Blomkest (KEPCA) 7.0 mile, 69 kV line MN Other Not Shared Distribution $1,140,342 9/3/2012 9/3/2012 Planned 69 A YA in MTEP10 West GRE 2833 Lake Caroline Lake Caroline (WH) 69 kV Distribution Substation MN Other Not Shared Distribution $675,000 10/21/2013 10/21/2013 Planned 69 A NTA in MTEP10 West GRE 2834 Rice Lake Rice Lake (MKR) 69 kV Distribution Substation MN Other Not Shared Distribution $5,138,000 9/10/2013 9/10/2013 Planned 69 A NTA in MTEP10 West GRE 3106 Tamarac MISO Interconnection (G619) Tamarac-Cormorant Junction MN GIP Shared $728,000 9/3/2012 9/3/2012 Planned 115 A YA in MTEP09 West GRE 2562 G362 - Pleasant Valley 345/161 KV

transformerG362 Network Upgrades: Pleasant Valley 345/161 kV transformer (GRE part of G362)

MN GIP Shared $1,006,365 3/30/2012 3/30/2012 Planned 161 A Y

A in MTEP09 West GRE 2563 Athens to Martin Lake 69kV System Upgrades and Permitting

Athens to Martin Lake 69kV System Upgrades and Permitting

MN Other Not Shared Reliability $6,234,719 11/30/2012 11/30/2012 Planned 69 A NT

A in MTEP05 West GRE 599 Crooked Lake - Enterprise Park 115 kV line Crooked Lake - Enterprise Park 115 kV line MN Other Excluded $8,616,069 6/1/2013 6/1/2013 Planned 115 A Y

A in MTEP08 West GRE, OTP 1033 Silver Lake 230/41.6 kV transformer Silver Lake 230/41.6 kV transformer MN Other Not Shared Reliability $3,230,626 10/28/2011 10/28/2011 Under Constru 230 41.6 A YA in MTEP08 West GRE, XEL, OTP,

MP, MRES286 Fargo, ND - St Cloud/Monticello, MN area

345 kV projectBison - AlexandriaSS - Waite Park - Monticello 345 ckt 1, Sum rate 2085

MN ND BaseRel Shared $564,747,000 12/15/2011 3/31/2015 Planned 345 115 A Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP10 West ITCM 3046 SW Cedar Rapids 69kV System Upgrade (Phase 1) Near ADM

Re-route 69kV lines near the load to connect to the 161/69kV transformer at the Beverly substation. Install two breaker terminals and a main breaker to connect the re-routed lines. This adds significant capacity to the 69kV system with minimal line construction and no new transformer purchases.

IA Other Not Shared Reliability $1,800,000 12/31/2012 12/31/2012 Planned 69 A Y

A in MTEP10 West ITCM 3047 IA Falls Industrial TRF Upgrade the IA Falls Ind 115/69kV TRF with a dual high side (161-115kV)/69kV TRF.

IA Other Not Shared Reliability $1,980,000 8/30/2011 8/30/2011 Planned 161 69 A Y

A in MTEP10 West ITCM 3048 Jefferson Co-Perlee 69kV Rebuild Rebuild the Jefferson Co-Perlee 69kV line section. IA Other Not Shared Condition $2,700,000 12/31/2013 12/31/2013 Planned 69 69 A YA in MTEP10 West ITCM 3049 Huxley Industrial Park Terminal Addition Add a 161kV line terminal to tie to the rerouted Boone

Jct-Huxley Park Ind 161kV line.IA Other Not Shared Reliability $750,000 12/31/2012 12/31/2012 Planned 161 161 A Y

A in MTEP10 West ITCM 3050 Alden-Buckeye dist. Sub tap Constuct a new 3 mile 69kV tap to the new Alden-Buckeye dist. Sub from the CBPC Alden sub site.

IA Other Not Shared Distribution $1,080,000 12/31/2011 12/31/2011 Planned 69 69 A Y

A in MTEP10 West ITCM 3052 Washington 69kV Upgrades Replace 69kV bus, 2 breakers, relays, and improve breaker configuration, add bus tie breaker, and install a new control building.


A in MTEP10 West ITCM 3053 Keokuk Hydro-Carbide 69kV Dbl Ckt Build a new 69kV circuit from Keokuk Hydro-Carbide. IA Other Not Shared Reliability $3,240,000 12/31/2013 12/31/2013 Planned 69 69 A YA in MTEP10 West ITCM 3054 Swisher Breaker Station Construct a new 3 terminal breaker station. IA Other Not Shared Reliability $2,152,000 12/31/2011 12/31/2011 Planned 69 69 A YA in MTEP10 West ITCM 3055 Cedar Rapids 34kV Conversion Plan ITCM, working with IP & L, has formed a plan to better

serve Cedar Rapids load with new larger, 2-transformer substations that will allow retirement of the 4kV system along with several other small distribution substations. Most of these new substations will be served from a new 69 kV and 161 kV Cedar Rapids transmission system that will use the existing 34.5 kV system right-of-way. This will allow retirement of several existing 34.5kV lines while shifting distribution load to a higher voltage to allow better normal and contingency performance.


A in MTEP10 West ITCM 3056 Grundy Center-Reinbeck-Hicks tap 69kV line.

Construct a 16 mile 69kV line between Grundy Center and the Hicks tap 69kV line. Constructing this line will allow consolidation of the Dike and Morrison substations into a single new distribution substation and will allow retirement of more than 30 miles of 50 year old 34.5kV line.


A in MTEP10 West ITCM 3057 West Branch 34kV Load Shift Projects Construct 69kV taps for the Moscow & New Liberty dist. Subs


A in MTEP10 West ITCM 3058 Vinton-Hazleton 34kV Conversion Plan The plan includes rebuilding a line between Dundee and Vinton substations and converting this line to 69 kV operation. In order to operate this line at 69 kV a 161/69 kV transformer will need to be installed at Vinton. Also, an approximatley 6 mile line will be built to connect the Hazleton source to the Dundee - Vinton line. This plan also includes rebuilding a line between Coggon and Hiawatha substations and converting this line to 69 kV operation. A 161/69 kV transformer will need to be installed at Coggon.


A in MTEP10 West ITCM 3059 West Branch & West Liberty Switch Stations

Construct two new 3 terminal 69kV breaker stations at West Branch and at West Liberty.


A in MTEP09 West ITCM 2339 G612-Marshalltown-Boone 115kV to 161kV Construct a new Story Co 161kV switching station and rebuild the Marshalltown-Boone 115kV to 161kV.

IA GIP Shared $13,720,000 9/30/2011 5/30/2012 Planned 161 A Y

A in MTEP09 West ITCM 2340 Grand Junction-Paton REC tap 34kV Rebuild

Rebuild the 34kV line from Grand Jct-Paton REC tap to 69kV. Retire Dana 34kV/dist sub and construct in & out taps for new Grand Jct North 69kV/dist. Sub. (still operate at 34kV)

IA Other Not Shared Condition $1,103,527 12/31/2011 12/31/2011 Planned 34 A NT


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP09 West ITCM 2341 Monticello-Amber Conversion & Lovell REC Rebuild

Rebuild 8.5 miles Monticello-Amber 34kV to 69kV, add 69kV bkr at Sand Springs, Monticello Industrial, & Amber. Operate Sand Springs-Amber at 69kV. Also rebuild 2.21 miles of 34kV to 69kV east of Lovell REC but continue operation of this portion at 34kV in 2009.

IA Other Not Shared Condition $3,775,000 9/1/2011 10/30/2011 Under Constru 69 A NT

A in MTEP09 West ITCM 2342 Boone-Jewell 34kV Rebuild Rebuild 25.3 miles of 34kV line from Jewell to approximately 6 miles south of the Ridgeport dist. substation to 69kV standards. This line will continue to be operated at 34kV.


A in MTEP09 West ITCM 2343 West Branch-West Liberty 34kV Rebuild Rebuild 15.1 miles of 34kV line from West Branch-West Liberty to 69kV standards. This line will continue to be operated at 34kV.


A in MTEP09 West ITCM 2344 Wyoming-Massillon 34kV Rebuild Rebuild 12 miles of 34kV line from Wyoming-Massilon to 69kV standards. This line will continue to be operated at 34kV.


A in MTEP09 West ITCM 2345 Eldora Area Rebuild & Breaker Station Rebuild approx 20 miles of 34kV to 69kV from the Hubbard Rural sub to a new 4-terminal Eldora North 69kV switching station and operate at 69kV. The new switching station will tap the CBPC Pleaseant-CBPC Eldora 69kV line. The 4th terminal will be needed in the near future to feed the Eldora North-Union-Conrad 69kV line after substaitons are ready for conversion. This line will be rebuilt to 69kV standard in 2009.


A in MTEP09 West ITCM 2348 Beaver Rock 69kV Switching Station Construct a new 3-terminal 69kV switching station along the Beaver Channel-Rock Creek 69kV line.

IA Other Not Shared Reliability $1,593,178 12/31/2011 12/31/2011 Under Constru 69 A NT

A in MTEP09 West ITCM 2353 Big River 69kV 3-terminal Switching Station Construct a new 3-terminal 69kV switching station where the Big River REC line taps the Agency-Sawyer 69kV line.

IA Other Not Shared Reliability $1,666,427 12/31/2011 12/31/2011 Planned 69 A NT

A in MTEP09 West ITCM 2357 Hazleton-Fairbank REC 69kV line & breaker station

Construt a 69kV Hazleton-Fairbank line and a new 3-terminal 69kV switching station.

IA Other Not Shared Distribution $5,731,385 12/31/2013 12/31/2013 Planned 69 A NT

A in MTEP09 West ITCM 2358 Hazleton-Blackhawk 161kV Rebuild Rebuild 12 miles of the Hazleton-Blackhawk 161kV line (ITC owned portion)

IA BaseRel Shared $5,400,000 12/31/2013 12/31/2013 Planned 161 A Y

A in MTEP09 West ITCM 2363 Glenworth 161/69kV (Glenville Area) Construct a new 161/69kV 100 MVA substation tapping the Hayward-Worth County 161 kV line. ITC will construct the 161kV portion including the TRF and low side protection. DPC will construct the 69kV portion.

MN Other Not Shared Reliability $7,240,605 8/30/2011 8/30/2011 Under Constru 161 69 A Y

A in MTEP09 West ITCM 2364 Thompson 2 mile 69kV dbl ckt Rebuild 69kV double circuit line near Thompson, IA IA Other Not Shared Reliability $460,000 12/31/2011 12/31/2011 Planned 69 A NTA in MTEP09 West ITCM 2367 Anita Area 34kV to 69kV Rebuilds Rebuild 5 miles from the Anita-Exira REC to 69kV. Also

rebuild 4.7 miles of the Anita to th e Anita-Wiota Joint sub. Rebuild 21.9 miles from Thompson- Redfield. These lines will continue to opeate at 34kV.


A in MTEP09 West ITCM 2369 Fairfax-Williamsburg 34kV to 69kV Rebuilds Rebuild 26.6 miles of 34kV line from the Fairfax sub to the Williamsburg115kV sub to 69kV. These lines will continue to opeate at 34kV.


A in MTEP09 West ITCM 2370 Andrew Tap & Monmouth Rebuilds Rebuild the 5.75 mile Andrew Tap & 2 miles of line in the Monmouth area. These lines will continue to opeate at 34kV.


A in MTEP09 West ITCM 2371 New Marengo 69kV Switching Station Construct a new 3-terminal 69kV switching station at the existing Marengo 34kV sub.


A in MTEP08 West ITCM 1340 Hazleton - Salem 345 kV line with a 2nd Salem 345/161 kV 448 MVA transformer.

Build a new Hazleton - Salem 345 kV line. Expand the Hazleton 345kV bus to a 5 position ring and expand the Salem 345kV ring to allow for a 2nd Salem 345/161 kV 448 MVA transformer. (option 1) The route will follow the existing Hazleton-Dundee-Liberty-Lore 161kV route.

IA Other Not Shared $119,010,000 12/31/2012 12/31/2012 Planned 345 161 A Y

A in MTEP08 West ITCM 1618 Hrn Lk-Lkfld 161kV Ckt 1 Rbld Rebuild Heron Lake-Lakefield 161kV line, sum rate 446 MVA

MN BaseRel Shared $14,000,000 6/1/2013 6/1/2013 Planned 161 A Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP08 West ITCM 1619 Grnd Mnd 161-69kV 2nd Xfmr & 161kV loop Install a 2nd Grand Mound 161-69kV Xfmr (75 MVA) & build a 2.0 miles of new line from the Grand Mound sub to tap the E. Calamus-Maquoketa line (approx. 87% from Maq-E.Cal). The E. Calamus-new tap portion of line will be retired. Existing E.Cal-Maq bkr will feed to GMnd and a new GMnd bkr will feed to Maq. The three terminal line at E.Calamus will be eliminated.

IA Other Not Shared Reliability 12/31/2011 12/31/2011 Planned 161 A Y

A in MTEP08 West ITCM 1640 Marshalltown-Franklin 115kV conversion to 161kV.

Rebuild Marshalltown-Wellsburg-Eldora-Iowa Falls Industrial-Iowa Falls-Franklin 115kV to 161kV. This will also convert the Wellsburg, Eldora, Iowa Falls Industrial, and Iowa Falls substations to 161kV operation on the high side. The 161-115kV source at Franklin will be eliminated.


A in MTEP08 West ITCM 1645 Leon 7.2 MVAR Cap Bank Install a 69kV 7.2 MVAR cap bank at the Leon substation.

IA Other Not Shared Reliability $2,511,808 12/31/2011 12/31/2011 Planned 69 A NT

A in MTEP08 West ITCM 1744 Maquoketa-Grand Mound 161kV Reconductor

Reconductor 161kV from Maquoketa to Grand Mound (old East Calamus-Maquoketa 161kV line)

IA BaseRel Not Shared $10,150,000 12/31/2016 12/31/2016 Planned 161 A Y

A in MTEP08 West ITCM 1747 Elk 161/69kV upgrades Upgrade both Elk 161/69kV transformers and add a 161kV BKR between the new units. A 161kV breaker will be added looking toward Brewster

MN Other Not Shared Reliability $6,998,396 5/31/2011 12/31/2011 Under Constru 161 69 A Y

A in MTEP08 West ITCM 2108 G358-Fairbault County Network upgrades for tariff service request MN GIP Shared $4,216,848 10/31/2011 10/31/2011 Planned 161 34.5 A YA in MTEP06 West ITCM 1289 Marshalltown - Toledo - Belle Plaine -

Stoney Point 115 kV line rebuildMarshalltown - Toledo - Belle Plaine - Stoney Point 115 kV line will be rebuilt/upgraded between 2008 and 2011

IA Other Not Shared $13,653,000 3/30/2012 12/31/2013 Planned 161 A Y

A in MTEP06 West ITCM 1342 Lewis Fields 161 kV substation which taps the SwampFX - Coggon 115 kV line

Build a new 161 kV substation Lewis Fields to be tapped to the 115 kV line Swamp Fox - Coggon at 5% distance via a new 161/115 kV transformer. Also build a new 161 kV line from Hiawatha to Lewis Fields

IA BaseRel Not Shared $21,051,600 12/31/2014 12/31/2014 Planned 161 115 A Y

A in MTEP06 West ITCM 1344 Build a new 345 kV Morgan Valley (Beverly) substation which taps the Arnold -Tiffin 345 kV line

Build a new 345 kV Morgan Valley (Beverly) Tap substation and tapped to 345 kV line Arnold -Tiffin at 40% distance away from Arnold. Add a new 335 MVA 345/161 kV transformer and build a new 161 kV line connecting the new substation to Beverly 161 kV bus. Tap Arnold-Fairfax 161kV line for in and out feeds from Morgan Valley


A in MTEP09 West MDU 1355 Heskett - Additional 230/115 kV Switchyard and 115 kV Capacitor

Heskett - Additional 230/115 kV Switchyard 230 115 Switchyard in parallel w/ existing Heskett switchyard and Cap Bank

ND BaseRel Shared $11,000,000 9/30/2011 12/31/2014 Planned 230 115 A Y

A in MTEP10 west MP 2547 Essar Essar project adds a 95 MW new mine and taconite plant load in fall 2011 with 50 MW DRI facility fall of 2012 total demand to 145 MW. Future load additions could increase total demand to 300 MW

MN Other Not Shared Distribution $34,100,000 6/30/2012 7/30/2014 Planned 230 14 A Y

A in MTEP10 West MP 2761 Polymet add new 138/14 kV substaion off MP 138 KV Line #1 MN Other Not Shared Distribution $3,000,000 12/30/2012 12/30/2012 Planned 115 14 A YA in MTEP10 West MP 2762 Airpark New 115/34.5 and 115/14 kV Substation MN Other Not Shared Distribution $4,105,000 12/16/2012 6/30/2013 Under Constru 115 14 A YA in MTEP10 West MP 3091 28L reroute MP’s 115 kV Line #28 (28L) must be moved as it

crosses the area that Essar will be mining.MN Other Not Shared Relocation $3,190,000 5/30/2012 5/30/2012 planned 115 A Y

A in MTEP09 West MP 2552 Skibo Skibo-Hoyt Lakes 138 ckt 1, Sum rate 202 MN BaseRel Not Shared $2,540,000 12/1/2012 12/1/2012 Proposed 138 A YA in MTEP09 West MP 2759 Laskin Move Virginia 115/46 kV Transformer to Laskin MN Other Not Shared Distribution $500,000 6/1/2012 6/1/2012 Planned 115 46 A YA in MTEP09 West MP 2763 LSPI 34.5 Add 115/34.5 kV Transformer and line exit to LSPI

115/14 kV SubMN Other Not Shared Distribution $600,000 8/30/2011 8/30/2011 Under Constru 115 34.5 A Y

A in MTEP07 West MP 1025 G519 - Mesaba Network Upgrades associated with 600 MW coal gasification generating facility at the propsoed Mesaba generating station. There is a G477 alternate site which is not described here.

MN GIP Shared $76,319,541 7/1/2012 7/1/2012 Planned 230 115 A Y

A in MTEP05 West MP, GRE 600 Baxter - Southdale 115 kV line Southdale-Scearcyville 115 kV line MN Other Excluded $8,045,969 2/28/2012 6/1/2012 Under Constru 115 A YA in MTEP06 West MPC, XEL, OTP,

MP279 Bemidji-Grand Rapids 230 kV Line Boswell - Wilton 230 ckt 1, Sum rate 495,

Addition of a 187 MVA 230/115 kV transformer at Cass Lake



Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP10 West MPW 2934 Replace South 161/69 kV Transformer Replace the existing 161/69 kV, 75 MVA transformer at South Sub with at least a 134 MVA transformer by 2011 (633301-633501). Also the 161 kV bus at South Sub will become a ring bus, splitting the three terminal 161 kV line into two sections between 633209 MPW Unit 9 – 633301 MPW South Sub and 633301 MPW South Sub – 636670 MEC Sub 18.


A in MTEP10 West NWE 3092 Webb Lake 69KV line Rebuild 34.5KV line to Webb Lake at 69KV with horizontal post construction and #4/0 ACSR

WI Other Not shared Condition $425,000 6/1/2011 6/1/2011 Planned 69 A Y

A in MTEP08 West NWE 2011 Frederic-Lewis 34.5KV Rebuild Rebuild the 34.5Kv system between Frederic and Lewis sub at 69KV with 477ASCR and horizontal post construction.

WI Other Not Shared $350,000 6/1/2011 6/1/2011 Planned 69 A Y

A in MTEP08 West NWE 2012 Falun-Penta 34.5KV Rebuild Rebuild the 34.5Kv system between Falun and Penta sub at 69KV with 477ASCR and horizontal post construction.

WI Other Not Shared $538,000 9/1/2011 9/1/2011 Under Constru 69 A Y

A in MTEP08 West NWE 2013 Penta-Siren Tap 34.5KV Rebuild Rebuild the 34.5Kv system between Penta sub and Siren Tap at 69KV with 477ASCR and horizontal post construction.

WI Other Not Shared $175,000 6/1/2011 6/1/2011 Planned 69 A Y

A in MTEP08 West NWE 2016 Frederic-Coffee Cup 69KV reconductor Reconductor 69KV line with 477ACSR WI Other Not Shared $100,000 1/1/2012 1/1/2012 Planned 69 A YA in MTEP08 West NWE 2018 Balsam Lake-Centuria 69KV line Build new 69KV line to Centuria and build Distribution

SubWI Other Not Shared $1,200,000 6/1/2011 6/1/2011 Planned 69 12.47 A Y

A in MTEP10 West OTP 3156 Cass Lake -Nary-Helga -Bemidji 115 MN BaseRel Shared $10,399,000 12/31/2012 12/31/2013 Planned 230 115 A YA in MTEP09 West OTP 2751 New Perham 115/12.5 kV Substation Build New 115/12.5 kV Substation at Perham to Serve

as a Back-up Source for Outage of Primary SourceMN Other Not Shared Distribution $400,000 12/31/2013 12/31/2013 Planned 115 12.5 A Y

A in MTEP10 West OTP, MPC 2826 Enbridge Load Expansion Support Install Capacitor Bank on 115 kV at Clearbrook, MN. One 34 MVAR. Install Capacitor Bank on 115 kV at Karlstad. One 14 MVAR.Install Capacitor Bank on 115 kV at Thief River Falls. One 15 MVAR.

ND BaseRel Not Shared $1,900,000 12/31/2012 12/31/2015 Planned 115 A Y

A in MTEP10 West SMP 2166 City of St Peter, MN load serving upgrades Adding approx 7.0 mimles of new 69kV transmission line and a new load serving substation (Estimated in service June 2011)

MN Other Not Shared Distribution $6,000,000 12/1/2011 12/1/2011 Under Constru 69 69 A NT

A in MTEP10 West SMP 2167 City of Redwood Falls, MN load serving upgrades

Adding approx 5.2 miles of new 115kV transmission line and a new load serving substation (Estimated in service Dec 2011)

MN Other Not Shared Distribution $4,000,000 12/1/2011 12/1/2011 Planned 115 115 A NT

A in MTEP10 West SMP 2171 Mora Land Fill Gas Generator Addition of 3 MW landfill gas generation and construction of approx 7.0 miles of 12.47kV distrbution line.

MN TDSP Direct Assigned $3,700,000 8/1/2011 8/1/2011 Under Constru 12.47 A Y

A in MTEP10 West XEL 2767 Fenton 115/69 kV Interconnection This project is to install a new 115/69 kV transformer at Fenton substation. Break the existing 69 kV line between Chandler Tap and Lake Wilson to create an in and out to the Fenton substation.


A in MTEP10 West XEL 3097 Monroe County 2nd Transformer Install second 161/69 kV 70 MVA transformer at Monroe County substation

WI Other Not Shared Reliability $3,680,000 6/1/2012 6/1/2012 Planned 161 69 A Y

A in MTEP10 West XEL 3100 Westgate 115/69 kV TR upgrade Upgrade Westgate 115/69 kV transformer #2 to 70 MVA MN Other Not Shared Distribution $2,070,000 6/1/2012 6/1/2012 Planned 115 69 A Y

A in MTEP09 West XEL 2156 North Mankato 115 kV project 1) New 345/115 kV TR at the proposed Helena 345 kV switching station. 2) New 115 kV line from Helena - St. Thomas. 3) New 115/69 kV substation near St. Thomas. 4) New 69 kV switchig station at Lesueur Tap.


A in MTEP09 West XEL 2157 Douglas Co 2nd TR 2nd Douglas Co 115/69 kV transfromer MN Other Not Shared Reliability $4,435,000 11/1/2011 11/1/2011 Planned 115 69 A NTA in MTEP09 West XEL 2158 Upgrade Sauk Center - Osakis 69 kV line Upgrade Sauk Center - Osakis 69 kV line to a lower

impedance.MN Other Not Shared Reliability $4,514,000 9/30/2011 9/30/2011 Planned 69 A NT

A in MTEP09 West XEL 2160 Park Falls TR upgrade Upgrade the Park Falls 115/34.5 kV TR to 47 MVA WI Other Not Shared Reliability $3,355,800 6/1/2012 6/1/2012 Planned 115 34.5 A NTA in MTEP09 West XEL 2178 G362 Pleasant Valley XEL G362 Network upgrades: New 161 kV line from

Pleasant Valley - Byron 161 kV lineMN GIP Shared $10,007,181 12/1/2011 6/1/2012 Planned 161 A Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP09 West XEL 2307 St. Cloud Loop (1) New 4 mile 115 kV line from St. Cloud tap tap to Mayhew Lake substation.(2) Convert Benton Co - St. Cloud double circuit to bifurcated line and reterminarte into Mayhew Lake substation (3) Convert St. Cloud tap to Granite City into bifurcated line (this results in single 115 kV circuit from St. Cloud to Granite City).


A in MTEP09 West XEL 2308 Grove Lake - Glenwood line rebuild This project is to rebuild 13 miles of 69 kV line from Grove Lake switching station to Glenwood to 477 ACSR


A in MTEP09 West XEL 2309 Maple Lake - Watkins line rebuild This project is to rebuild 20 miles of 69 kV line from Maple Lake to Watkins in west Central Minnesota


A in MTEP09 West XEL 2772 South Minneapolis New 115 kV distribution substation with four terminations tapping the Elliot Park - Southtown line, 1.25 new miles of double circuit 795 SAC to a new 115 kV distribution sustation

MN Other Not Shared Distribution $26,890,000 6/1/2012 6/1/2012 Planned 115 13.8 A Y

A in MTEP08 West XEL 675 Rebuild Westgate to Scott County 69 kV to 115 kV

Upgrade 20.1 miles Westgate-Deephaven-Excelsior-Scott County 69kV to 115 kV using 795 ACSS conductor, Upgrade 2 miles Westgate-Eden Prairie 115kV #1 and #2 to 400MVA (PrjID 606), Substation work at Deephaven, Excelsior and Scott County.

MN Other Not Shared $14,000,000 6/1/2014 6/1/2014 Planned 115 A Y

A in MTEP08 West XEL 1487 Somerset - Stanton 69 kV line 84 MVA Construct 7 miles of 69 kV line using 477 SSAC conductor traveling north along 210th Avenue, interconnecting with a new stanton 69 kV substion on the Clear Lake - New Richmond 69 kV line and the New Summerset substation on the DPC Roberts - St. Criox Falls 69 kV line

WI Other Not Shared Reliability $9,247,500 12/31/2011 12/31/2011 Planned 69 A NT

A in MTEP08 West XEL 1549 Eau Claire - Hydro Lane 161 kV Conversion 1.)Eau Claire 161 kV circuit breaker. 2.Bring Wheaton-Presto Tap 161 kV line into Eau Claire substation.3.) Reconductor Wheaton to Eau Claire 161 kV line to 795 ACS.4.) Construct second circuit from Wheaton Tap to Wheaton substation.5.New 50th Avenue substation near where Red Cedar to Wissota 161 kV line intersects 69 kV corridor from Eau Claire to Chippewa Falls. Construct a 4 breaker 161 kV ring bus, add two 161-69 kV transformers with at least 60 MVA capacity. Construct a strait bus 69 kV with a bus tie breaker between the transformers.6.) Where the 161 kV line from Eau Claire to Presto crosses the double-circuit 69 kV line to Hallie, tap the 161 kV line and convert the 69 kV lines to one 161 kV line with 795 ASCC conductor up to the new 50th Ave substation.7.)Convert Hallie Substation from 69 kV to 161 kV operation.


A in MTEP08 West XEL 1957 New 161/69 kV Sub SW of Eau Claire where Alma – Elk Mound 161 kV intersects Shawtown – Naples 69 kV line. Rebuild 69 kV London/Madison to new substation. New 69 kV from new substation - DPC Union Sub. New 69 kV to DPC Brunswick Sub

New 161/69 kV Substation southwest of Eau Claire where Alma – Elk Mound 161 kV line intersects with Shawtown – Naples 69 kV line. Rebuild 69 kV line from London/Madison Tap to new substation. Construct 69 kV line from new substation to DPC Union Substation. Construct 69 kV line from new substation to DPC Brunswick Substation

WI Other Not Shared Reliability $7,080,000 6/1/2012 6/1/2012 Planned 161 69 A Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

A in MTEP08 West XEL 1958 Stone Lake-Edgewater 161 kV line. A new radial 161 kV line and substation in Sawyer County, Wisconsin

Expand 161 kV ring bus at Stone Lake to accept new line termination. Construct 161 kV line from Stone Lake to Couderay Substation. Install 161/69 kV transformer at Couderay Substation. Install the following substation equipment at Couderay: -161 kV MOD -69 kV low-side transformer breaker -69 kV line breaker


A in MTEP06 West XEL 1458 G349, 37774-01. Upgrades for G349 G349 Upgrades: Yankee substation, Brookings Co 345/115 substation, Hazel Run 53 Mvar capacitor, Brookings-Yankee 115 kV line

MN GIP Shared $2,202,000 11/30/2011 11/30/2011 Planned 34.5 A Y

A in MTEP09 West XEL, GRE 1952 Plato capacitor bank 'This project is to add a 10 MVAR cap bank at Plato. This project is required to convert the existing 69 kv line from Young America - Glencoe to 115 kV (part of Glencoe - West Waconia 115 kV line project).

MN Other Not Shared Reliability $700,000 12/1/2011 12/1/2011 Planned 69 A NT

A in MTEP08 West XEL, SMP, Non-MISO

1024 SE Twin Cities - Rochester, MN - LaCrosse, WI 345 kV project

Construct Hampton Corner-North Rochester-Chester-North LaCrosse 345 kV line, North Rochester - N. Hills 161 kV line, North Rochester-Chester 161 kV line, Hampton Corner 345/161 transformer, North Rochester 354/161 transformer, North LaCrosse 345/161 transformer

MN WI BaseRel Shared $444,999,999 12/15/2012 9/30/2015 Planned 345 161 A Y


Facility Table Field Legend


Facilty Table Field Legend





PrjID Indicates the Facility's Project. Projects may have multiple facilities.Facility ID Facility ID: Midwest ISO facility identifierExpected ISD Expected In Service Date for this facilityFrom Sub From substation for transmission line or location of transformer or other equipmentTo Sub To substation for transmission line or transformer designationCkt Circuit identifierMax kV Maximum voltage of this facilityMin kV Minumum voltage of this facility (transformer low-side voltage)Facility Rating Rating of the facility in applicable units. Typically Summer rateFacility Description Brief description of transmission facilityState State the facility is located inMiles Upg. Transmission line miles on existing rights of way (ROW)Miles New Transmission line miles on new rights of way (ROW)Plan Status Indicates status of project in planning or implementation. Alternative, Conceptual, Proposed, Planned,

Under Construction, In Service.Estimated Cost Total estimated facility costCost Shared Y if facility is cost shared per Attachment FFPostage Stamp Y if facility has postage stamp cost allocation per Attachment FFMISO Facility Y for facilities under Midwest ISO functional control. NT for non-transferred facilities under Agency

AgreementsApp ABC Appendix the project is in. B>A or C>B for projects moving during this planning cycle.

MTEP11 MISO Transmission Expansion Plan 2011 Appendix AAppendix A: Project Facility Table 9/7/2011

Target Appendix Region

Geographic Location by TO Member System PrjID

Facility ID Expected ISD From Sub To Sub Ckt

Max kV

Min kV Facility Rating Facility Description State

Miles Upg.

Miles New Plan Status Estimated Cost

Cost Shared

Postage Stamp

MISO Facility App ABC

A in MTEP11 Central AmerenIL 2065 3961 6/1/2012 Stallings Stallings Tap (Wood River - Venice 138 line)

1 138 280 Replace terminal equipment at Stallings on Wood River - Venice 138 kV line (Line # 1452)

IL Planned $185,000 Y Y B>A

A in MTEP11 Central AmerenIL 2065 3960 6/1/2012 Stallings Stallings substation 1 345 138 700 Stallings 345/138 kV Substation-Replace 560 MVA, 345/138 kV Transformer with 700 MVA unit

IL Planned $9,890,000 Y Y B>A

A in MTEP11 Central AmerenIL 2237 4104 11/15/2018 Pana Mt. Zion 1 345 1793 new line - 28 miles of 345 kV IL 28 Planned $66,610,000 Y Y Y B>AA in MTEP11 Central AmerenIL 2237 5210 11/15/2018 Kansas Sub 2nd. 345/138 kV Xfmr 2 345 138 560 Kansas 345/138 kV Substation - Add 2nd

345/138 kV, 560 MVA Transformer, 345 kV Breaker-and-a-half arrangement.

IL Planned $25,610,000 Y Y Y B>A

A in MTEP11 Central AmerenIL 2237 4151 11/15/2018 Mt. Zion Transformer 1 345 138 560 new transformer - 560 MVA, 345/138 kV, plus 345 kV ring bus


A in MTEP11 Central AmerenIL 2237 4152 11/15/2018 Mt. Zion Kansas 1 345 1793 new line - 52 miles 345 kV IL 52 Planned $123,710,000 Y Y Y B>AA in MTEP11 Central AmerenIL 2237 4154 11/15/2019 Kansas Sugar Creek 1 345 1793 New 35 mi. single-circuit line, 3000 A SE

capabilityIL 35 Planned $84,710,000 Y Y Y B>A

A in MTEP11 Central AmerenIL 2239 6595 6/1/2016 Sidney 1 345 1793 Substation work for new Sidney-Risng 345 kV line

IL Planned Y Y Y B>A

A in MTEP11 Central AmerenIL 2239 6594 6/1/2016 Rising 1 345 1793 Substation work for new Sidney-Risng 345 kV line


A in MTEP11 Central AmerenIL 2239 4153 11/15/2016 Rising Sidney 1 345 1793 New 28 mile, 345 kV line from Sidney to Rising Substations with 3000 A summer emergency capability. Establish ring bus at Rising and breaker-and-a-half arrangement at Sidney.

IL 28 Planned $83,230,000 Y Y Y B>A

A in MTEP11 Central AmerenIL 2980 5183 6/1/2013 Tazewell San Jose Rail 1 138 269 Tazewell-San Jose Rail Substation section of East Springfield-Tazewell-1384 138 kV Line - Reconductor 3.67 miles of 927 kcmil ACAR conductor at the Tazewell end of the line with conductor capable of carrying at least 1278 A under summer emergency conditio

IL 3.67 Planned $3,251,000 Y B>A

A in MTEP11 Central AmerenIL 2981 5184 9/1/2013 McLean El Paso Tap 1 138 160 Replace 9.72 miles of 138 kV line on L1382, from McLean County Substation to El Paso Tap to a minimum 1200A SE capability

IL 9.72 Planned $5,100,000 Y B>A

A in MTEP11 Central AmerenIL 2989 5193 6/1/2013 Sidney Sustation Transformer Addition 345 138 560 Sidney 345/138 kV Substation - Install 2nd. 345/138 kV, 560 MVA Transformer.and 345 kV Ring Bus

IL Planned $14,200,000 Y C>B>A

A in MTEP11 Central AmerenIL 3017 6596 6/1/2016 Palmyra tap 1 345 1793 Build new 345 kV switching station at the Palmyra tap location


A in MTEP11 Central AmerenIL 3017 6598 6/1/2016 Meredosia 1 345 1793 Substation work for new Meredosia-Ipava 345 kV line


A in MTEP11 Central AmerenIL 3017 5616 11/15/2016 Meredosia Install 345/138 kV Xfmr 1 345 138 560 Meredosia 345/138 kV Substation - Install 345/138 kV Xfmr, 345 kV ring bus.


A in MTEP11 Central AmerenIL 3017 5202 11/15/2016 Palmyra Quincy 1 345 1793 New 14-mi. 345 kV 3000 A summer emergency capability line from Palmyra to Quincy.


A in MTEP11 Central AmerenIL 3017 5227 11/15/2016 Quincy Area Meredosia 1 345 1793 New 47 m. single circuit line IL 47 Planned $108,020,000 Y Y Y B>AA in MTEP11 Central AmerenIL 3017 5203 11/15/2016 Quincy Area Xfmr Addition 1 345 138 560 Quincy Area 345/138 kV Substation - 1-560

MVA transformer, 345 kV ring bus.IL Planned $19,950,000 Y Y Y B>A

A in MTEP11 Central AmerenIL 3017 6597 6/1/2017 Ipava 1 345 1793 Substation work for new Meredosia-Ipava 345 kV line


A in MTEP11 Central AmerenIL 3017 4149 11/15/2017 Meredosia Ipava 1 345 1793 new line - 41 miles 345 kV. Establish 345 kV ring bus at Ipava Sub.

IL 41 Planned $107,900,000 Y Y Y B>A

A in MTEP11 Central AmerenIL 3017 4150 11/15/2017 Meredosia Pawnee 1 345 1793 New 55 mi. single-circuit line, 345 kV line IL 55 Planned $128,610,000 Y Y Y B>AA in MTEP11 Central AmerenIL 3017 6430 11/15/2017 Pawnee Transformer 2 345 138 560 2nd. 345/138, 560 MVA Xfmr, establish 345

kV breaker-and-a-half arrangement at Pawnee


MTEP11_Appendices_ABC_2011-09-07 DRAFT.xlsx 1





Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP11 Central AmerenIL 3022 6599 6/1/2019 Fargo 1 345 Fargo substation work - add a new 345 kV position


A in MTEP11 Central AmerenIL 3169 5600 11/15/2018 Pana Pawnee 1 345 1793 New 31 mi. single-circuit line, 3000 A SE capability.


A in MTEP11 Central AmerenIL 3169 6431 11/15/2018 Pana Transformer 2 345 138 560 Install 2nd. 345/138 kV Xfmr at Pana Sub., 345 kV breaker-and-a-half arrangement at Pana.


A in MTEP11 Central AmerenIL 3337 6202 12/1/2013 Paxton, East Gilman 1 138 240 Reconductor to 1200 A summer emergency capability

IL 22.1 Planned $7,390,000 Y C>B>A

A in MTEP11 Central AmerenIL 3357 6223 12/31/2012 E. Kewanee Princeton Tap L1552 1 138 160 Increase ground clearance on 477 kcmil ACSR conductor to permit operation at 120 degrees C. Upgrade E. Kewanee breaker and terminal equipment to 1200 A capability

IL 15.33 Planned $3,180,000 Y C>B>A

A in MTEP11 Central AmerenIL 3358 6224 10/15/2012 E. Kewanee Generator connection and bus rearrangement

138 287 Rearrange 138 kV bus at E. Kewanee and install terminal equipment (including 1200 A breaker) to connect wind farm (G545)


A in MTEP11 Central AmerenIL 3359 6225 10/1/2012 E. Galesburg Generator connection and bus upgrade

138 287 Upgrade 138 kV bus at E. Galesburg and install terminal equipment, including 1200 A breaker, to facilitate connection of wind farm (G569).

IL Planned $834,000 Y C>B>A

A in MTEP11 Central AmerenIL 3360 6227 5/6/2011 Sheldon South Sw. Station

Watseka 1 138 240 Replace or reset relaying as required to obtain 1200 A capability at the Watseka terminal

IL 10 In Service $100,000 Y C>B>A

A in MTEP11 Central AmerenIL 3360 6226 5/6/2011 Sheldon South Sw. Station

Install ring bus with 3 - 1200 A breakers

138 287 Construct a new 138 kV switching station to connect a new wind farm (G931) to the Watseka-Morrison Ditch-1 138 kV line.

IL In Service $4,325,000 Y C>B>A

A in MTEP11 Central AmerenIL 3361 6228 7/26/2011 Paxton, East Generator connection 138 478 Install terminal equipment, including 2000 A breaker, to facilitate connection of wind farm (G996). Install 2000 A bus-tie breaker


A in MTEP11 Central AmerenIL 3370 6241 6/1/2012 Oreana Sub. Install 1-2000 A breaker and 2-2000 A disconnect switches.

138 112 Installation of a new 138-69 kV transformer at Oreana, install 1-2000 A breaker and 2-2000 A disconnect switches to expand ring bus. Install 138 kV, 600 A MOD switch at high-side of new 138-69 kV transformer.

IL Planned $750,000 Y C>B>A

A in MTEP11 Central AmerenIL, MEC 3022 5232 11/15/2019 Fargo Oak Grove 1 345 1793 Fargo-Galesburg-Oak Grove (MEC) 345 kV Line - New 70 mile, 3000 A summer emergency capability line. 345 kV ring bus at Fargo.

IL 70 Planned $200,530,000 Y Y Y B>A

A in MTEP11 Central AmerenMO 2248 5187 11/15/2020 West Adair Substation Install Transformer 1 345 161 560 West Adair Substation - New 560 MVA, 345/161 kV Transformer, 345 kV ring bus.

MO Planned $18,920,000 Y Y Y B>A

A in MTEP11 Central AmerenMO 2306 4222 6/1/2016 Lutesville Northwest Cape 1 345 1793 Install approximately 11 miles of new line to supply substation

MO 11 Planned $18,181,000 Y Y Y B>A

A in MTEP11 Central AmerenMO 2306 4221 6/1/2016 Northwest Cape 345/161 kV

New Substation 345 161 560 Install 560 MVA, 345/161 kV Transformer, 3-161 kV outlet lines

MO Planned $12,570,000 Y Y B>A

A in MTEP11 Central AmerenMO 3170 6603 11/15/2016 Palmyra Tap Establish 345 kV Sub 345 1793 New Palmyra Tap Substation - Establish with breaker-and-a-half arrangement

MO Planned $17,660,000 Y Y Y B>A

A in MTEP11 Central AmerenMO 3170 5601 11/15/2020 West Adair Palmyra Tap 1 345 1793 Construct new 58 mile, 345 kV Line MO 58 Planned $95,130,000 Y Y y B>AA in MTEP11 Central AmerenMO 3355 6220 12/31/2011 Labadie Bland 3 345 1200 Replace breaker at Labadie with 3000 A, 50

kA breakerMO Planned $1,305,000 Y C>B>A

A in MTEP11 Central AmerenMO 3355 6221 12/31/2011 Labadie Montgomery 4 345 1200 Replace breaker at Labadie with 3000 A, 50 kA breaker

MO Planned $1,305,000 Y C>B>A

A in MTEP11 Central AmerenMO 3368 6239 6/1/2012 Bailey Install 2-2000 A breakers and circuit switchers

138 214 Install 2-2000 A bus-tie breakers and 2-138 kV circuit switchers

MO Planned $4,000,000 Y C>B>A

A in MTEP11 Central AmerenMO, ITCM 2248 4160 11/15/2020 Ottumwa West Adair 1 345 1793 New line - 345 kV, 71 mile single circuit IA/MO 71 Planned $154,790,000 Y Y Y B>A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP11 Central DEM 3377 6250 12/31/2015 Scottsburg Capacitor 69 28.8 MVAR Replace Scottsburg 69kV - 7.2Mvar capacitor with a 28.8 Mvar capacitor and upgrade 69kV capacitor switching equipment

IN Planned $500,000 Y C>B>A

A in MTEP11 Central DEM 3378 6251 6/1/2012 Canal Road new distribution sub 69 12 Canal Sub - Purchase land and build 22.4MVA, 69/12kV sub near Canal Road and Allison Street in the 5762 ckt.

OH Planned $756,196 Y C>B>A

A in MTEP11 Central DEM 3379 6252 6/1/2014 Shelbyville McKay Rd. new distribution sub 69 12 Shelbyville McKay Rd. - add new 69/12kV distribution sub in the 6976 ckt. Loop through with 954acsr and a set of 1200A line switches.


A in MTEP11 Central DEM 3380 6253 12/31/2011 Noblesville Gen. Station breakers 345 138 Noblesville Gen. Sta. - Replace 138KV OB OCB: 138TR, 13869-9, 138230-7, 13886 and Circuit Switchers: 345230-11, 34519.

IN Planned $2,909,606 Y C>B>A

A in MTEP11 Central DEM 3383 6256 2/6/2011 Sherman Rd. Jct (new) H.E. Rocklane 1 69 Ckt. 6999 new Sherman Rd. Jct. to H.E. Rocklane line section. Replace DEM 69kV poles to accommodate new H.E. tap line. This will be an alternate feed to Rocklane - operated N.O. - built and owned by HE, inside DEM area.

IN In Service $64,568 Y C>B>A

A in MTEP11 Central DEM 3384 6257 12/1/2012 Hortonville Marathon Jct. 1 69 143 Hortonville to Marathon Jct. section of ckt. 6917 - Replace 336ACSR and 477ACSR with 954ACSS@200C. Upgrade Marathon Jct 600A switches to 1200A.

IN 3.86 Planned $1,409,099 Y C>B>A

A in MTEP11 Central DEM 3385 6258 12/31/2012 Carmel Homeplace Springmill Jct. 1 69 143 Carmel Homeplace to Springmill Jct. section of ckt. 69155 - Reconductor with 954ACSS@200C

IN 3.66 Planned $1,691,315 Y C>B>A

A in MTEP11 Central DEM 3386 6259 6/1/2016 Carmel Springmill Rd. Hortonville 1 69 143 Carmel Springmill Rd. Sub - Add 3-69kV breakers; straight bus config; build .23 mi 69kV 954ACSS@200C from Springmill to old Springmill Jct. Completes circuit to Hortonville. Change operating mode at Homeplace to close loop from 146th to Springmill.

IN 0.23 Planned $3,000,000 Y C>B>A

A in MTEP11 Central DEM 3387 6260 6/1/2013 Tri-County Wind Energy 230kV Station - DPP J028

new gen i-connect 1 230 J028 - 230kV - Gen. interconnect sub - install three brkr ring bus for 200MW wind farm between Attica and Lafayette in the 23027 ckt.

IN Planned $3,778,246 Y C>B>A

A in MTEP11 Central DEM 3388 6261 6/1/2015 Walton Logansport South 1 69 100 Walton to Logansport S. - Reconductor 69kV -69110 line with 477acsr at 100C

IN 5.9 Planned $1,900,000 Y C>B>A

A in MTEP11 Central DEM 3389 6262 12/1/2011 WVPA Center Valley new WVPA distribution sub

138 12 DEM to install new line switching in the 138kV - 13867 ckt. at intersection with SR39 for tap line to radially feed new WVPA Center Valley dist sub


A in MTEP11 Central DEM 3390 6263 12/31/2011 Inland Container Hillsdale 1 69 100 Rebuild 69kV - 6906 line from Inland Container to WROW Jct. to Hillsdale - 477acsr26x7 at 100C

IN 10.8 Planned $3,663,434 Y C>B>A

A in MTEP11 Central DEM 3391 6264 12/31/2011 Elnora Newberry 1 69 100 Rebuild 69kV - 6959 line section from Elnora to Newberry - 477acsr26x7 at 100C

IN 5.4 Planned $1,716,818 Y C>B>A

A in MTEP11 Central DEM 3392 6265 12/31/2012 Speed LGEE Paddys West 1 345 1529 New DEM Speed to LGEE Paddys West 345kV tie line

IN 16.66 Planned $15,000,000 Y C>B>A

A in MTEP11 Central DEM, NIPS 2202 4074 6/1/2018 Reynolds Greentown 1 765 3576 new line IN 66 Planned $171,875,000 Y Y Y B>AA in MTEP11 Central IPL 3273 6105 6/1/2011 Southwest Stout CT 1 138 350 Line Survey and Potential Modifications IN 2.9 Planned $300,000 Y C>B>AA in MTEP11 Central IPL 3274 6106 6/1/2011 South Stout S 1 138 287 Line Survey and Potential Modifications IN 3.34 Planned $350,000 Y C>B>AA in MTEP11 Central NIPS 2202 4073 8/1/2018 New Reynolds Transformer 1 765 345 2767.5 new transformer IN Planned $15,000,000 Y Y Y B>AA in MTEP11 Central Vectren 2460 4424 6/1/2013 Leonard Rd 69kV

Substation1 69 Add new 69kV switching substation near

Leonard RdIN Planned $2,150,000 NT C>B>A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP11 Central Vectren 2462 4426 6/1/2013 Stringtown Folz 50-3 69 Reconductor existing 69kV line for more capacity

IN Planned $2,500,000 NT C>B>A

A in MTEP11 Central Vectren 2463 4427 6/1/2013 Givens North West 31 69 Reconductor existing 69kV line for more capacity


A in MTEP11 Central Vectren 2464 4428 6/1/2014 Mt Vernon New Harmony 33 69 Reconductor existing 69kV line for more capacity


A in MTEP11 East ATC LLC 3396 6271 11/15/2010 Blue River Tap Muscoda 1 69 67 Improve line clearance WI 9 In Service $580,000 Y C>B>AA in MTEP11 East ITC 1868 3755 12/1/2012 Cato 120 kV Substation Equipment 120 Rebuild GIS Bus and Replace 120 kV

breakerMI Planned $5,400,000 Y C>B>A

A in MTEP11 East ITC 2931 5103 6/30/2012 Burns1 Jewel 1 120 Rebuild 2.4 miles of DC 3/0 Cu 120 kV lin to 1431 ACSR 230 kV construction.

MI 2.4 Planned $1,600,000 Y C>B>A

A in MTEP11 East ITC 2931 5102 6/30/2012 Adams Spokane 1 120 Rebuild 2.4 miles of DC 3/0 Cu 120 kV lin to 1431 ACSR 230 kV construction.

MI 2.4 Planned $1,600,000 Y C>B>A

A in MTEP11 East ITC 3276 6108 12/31/2013 Replace Damaged or Defective Breakers Mi Planned $9,000,000 Y C>B>AA in MTEP11 East ITC 3277 6109 12/31/2013 Meet NERC PRC-023 Compliance Mi Planned $2,400,000 Y C>B>AA in MTEP11 East ITC 3278 6110 12/31/2013 Replace Damaged or Defective Potential

DevicesMi Planned $300,000 Y C>B>A

A in MTEP11 East ITC 3279 6111 12/31/2013 Replace Damaged or Defective Relays Mi Planned $1,800,000 Y C>B>AA in MTEP11 East ITC 3280 6112 12/31/2013 Replace Damaged or Defective Wood Poles Mi Planned $3,000,000 Y C>B>AA in MTEP11 East ITC 3281 6113 12/31/2012 Majestic Lima 1 120 305 Construct new 120 kV line between Majestic

and Lima, along with associated breakers and terminal equiment at each termination.

Mi 5 Planned $8,400,000 Y C>B>A

A in MTEP11 East ITC 3283 6115 11/1/2012 Dexter Twp Madrid 1 120 300 Loop Madrid to Majestic 120 kV line and new breaker station

Mi 0.1 Planned $1,338,000 Y C>B>A

A in MTEP11 East ITC 3283 6116 11/1/2012 Dexter Twp Majestic 1 120 300 Loop Madrid to Majestic 120 kV line and new breaker station

Mi 0.1 Planned $1,338,000 Y C>B>A

A in MTEP11 East ITC 3284 6117 12/31/2015 Distribution Interconnection Request Mi Planned $2,000,000 Y C>B>AA in MTEP11 East ITC 3285 6516 6/1/2013 Shoal 33.3 Mvar capacitor 120 33.3 Mvar Capacitor at Shoal 120kV Mi Planned $2,200,000 Y C>B>AA in MTEP11 East ITC 3285 6118 6/1/2014 Fermi 33.3 Mvar capacitor 120 33.3 Mvar Capacitor at Fermi 120kV Mi Planned $1,600,000 Y C>B>AA in MTEP11 East ITC 3286 6519 4/30/2012 Fermi 345 Add 3rd Fermi 345kV row Mi Planned $4,100,000 Y C>B>AA in MTEP11 East ITC 3286 6119 12/31/2013 Fermi 345 Replace 345kV Disconnects Mi Planned $950,000 Y C>B>AA in MTEP11 East ITC 3495 6455 12/31/2011 NERC Alert Facility

Ratings for 2011Throughout system Verify facilities as required due to the industry-

wide NERC alertMI Planned $1,700,000 Y C>B>A

A in MTEP11 East ITC 3503 6463 12/31/2012 Air Flow Spoilers Installation

345 Install Air Flow Spoilers on Belle River-Greenwood-Pontiac and Belle River-Blackfoot 345 kV lines

MI Planned $1,620,000 Y C>B>A

A in MTEP11 East ITC 3516 6500 9/1/2011 St. Clair P.P. substation 120 Install a RFL 9745 Transmitter at St. Clair P.P. end of ITC line.

MI Planned $5,000 Y Y C>B>A

A in MTEP11 East ITC 3516 6497 9/1/2011 Carbon Carbon Tap 120 Tap the existing LES/Sumpter Energy Associates Carbon to Carbon Tap 120 kV radial line connecting to ITC's Jewell - St. Clair 120kV line with a new J025 Tap for the new customer. Install a one way disconnect switch and tap structure at the POI on the Car


A in MTEP11 East ITC 3516 6498 9/1/2011 J025 Tap J025 Customer Sub 120 Install a one way disconnect switch and tap structure at the Point of Change of Ownership at the new J025 Tap on the radial line from the J025 Customer Substation.


A in MTEP11 East ITC 3516 6499 9/1/2011 Jewell substation 120 Install a RFL 9745Transmitter at Jewell end of ITC line.


A in MTEP11 East METC 1809 3632 12/31/2013 Keystone Hodenpyl 1 138 351 Rebuild 26.4 miles 138 kV line Mi 26.4 Planned $32,600,000 Y Y C>B>AA in MTEP11 East METC 2812 4507 5/31/2012 Twining Whittemore 1 138 215 Rebuild the 12.7 mile Twining-Whittemore

138kV section to 954 ACSR future-double-circuit (pre-built to 230kV)

MI 12.7 Planned $14,200,000 Y Y C>B>A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP11 East METC 2812 4508 5/31/2012 Whittemore Loud Dam 1 138 86 Rebuild the 15.6 mile Twining-Mio 138kV section to 954 ACSR future-double-circuit (pre-built to 230kV)

MI 15.6 Planned $17,500,000 Y Y C>B>A

A in MTEP11 East METC 2812 4509 5/31/2012 Loud Dam Alcona 1 138 86 Rebuild the 9.9 mile Twining-Mio 138kV section to 954 ACSR future-double-circuit (pre-built to 230kV)

MI 9.9 Planned $11,600,000 Y Y C>B>A

A in MTEP11 East METC 3139 5517 6/1/2012 Tippy Wexford 1 138 Replace terminal equipment at Tippy MI Planned $20,000 Y C>B>AA in MTEP11 East METC 3287 6120 9/30/2011 Riggsville 138 Replace 138 kV Terminal Equipment Mi Planned $4,600,000 Y C>B>AA in MTEP11 East METC 3288 6121 12/31/2013 Replace Damaged or Defective Breakers Mi Planned $6,000,000 Y C>B>AA in MTEP11 East METC 3289 6122 12/31/2013 Meet NERC PRC-023 Compliance Mi Planned $2,400,000 Y C>B>AA in MTEP11 East METC 3290 6123 12/31/2013 Replace Damaged or Defective Potential

DevicesMi Planned $300,000 Y C>B>A

A in MTEP11 East METC 3291 6124 12/31/2013 Replace Damaged or Defective Relays Mi Planned $1,200,000 Y C>B>AA in MTEP11 East METC 3292 6125 12/31/2013 Replace Damaged or Defective Wood Poles Mi Planned $4,800,000 Y C>B>AA in MTEP11 East METC 3293 6126 12/31/2013 Replace Damaged or Defective Batteries Mi Planned $100,000 Y C>B>AA in MTEP11 East METC 3294 6127 12/31/2013 Relocate Power Plant Controls for better

accessMi Planned $3,120,000 Y C>B>A

A in MTEP11 East METC 3295 6128 12/31/2013 Address NECS Code Clearance Issues Mi Planned $3,600,000 Y C>B>AA in MTEP11 East METC 3296 6129 12/31/2011 Install or upgrade secondary oil containment Mi Planned $3,100,000 Y C>B>AA in MTEP11 East METC 3297 6130 12/31/2012 Install or upgrade secondary oil containment Mi Planned $3,100,000 Y C>B>AA in MTEP11 East METC 3298 6131 12/31/2013 Install or upgrade secondary oil containment Mi Planned $3,100,000 Y C>B>AA in MTEP11 East METC 3299 6132 12/31/2015 Distribution Interconnection Request Mi Planned $2,500,000 Y C>B>AA in MTEP11 East METC 3303 6136 6/1/2015 Cottage Grove East Tawas 1 138 287 Rebuild 12.3 miles of 138kV to 954 ACSR. MI 12.3 Planned $11,400,000 Y Y C>B>AA in MTEP11 East METC 3304 6137 12/31/2013 Croton Nineteen Mile Rd 1 138 196 Rebuild 21.5 miles 138 kV line Mi 21.5 Planned $26,600,000 Y Y C>B>AA in MTEP11 East METC 3306 6139 6/1/2012 Karn 138 Replace relays Mi Planned $200,000 Y C>B>AA in MTEP11 East METC 3308 6143 12/31/2012 Gaylord Livingston 1 138 Install new dual pilot relay scheme on 138kV

circuitMi Planned $315,000 Y C>B>A

A in MTEP11 East METC 3491 6451 12/31/2011 NERC Alert Facility Ratings for 2011

Throughout system Verify facilities as required due to the industry-wide NERC alert


A in MTEP11 East METC 3505 6472 1/1/2013 Clinton Jct. 1 138 New Switching Station at existing Clinton Jct. Tap point on Delhi - Island Rd. circuit. Will connect exsiting 3 circuits plus new circuit to Eaton Rapids area.

MI Planned $4,500,000 Y A

A in MTEP11 East METC 3505 6466 1/1/2013 URV Junction 138 New Switching Station looping in Tompkins-Kipp Rd 138kV circuit


A in MTEP11 East METC 3505 6467 1/1/2013 Tompkins Kipp Rd 1 138 Loop Tompkins-Kipp Rd into new URV Jct. Station

MI Planned $500,000 Y A

A in MTEP11 East METC 3505 6468 1/1/2013 Eaton Rapids North URV 1 138 New Line. On same structures as URV to Eaton Rapids Wolv.

MI 2 Planned $1,800,000 Y A

A in MTEP11 East METC 3505 6469 1/1/2013 URV 1 138 New Substation to serve Eaton Rapids load (URV-USA)


A in MTEP11 East METC 3505 6470 1/1/2013 URV Eaton Rapids Wolv 1 138 New Line from URV to potential Wolverine Tap point. On same structures as Eaton Rapids North to URV.


A in MTEP11 East METC 3505 6471 1/1/2013 Eaton Rapids Wolv Clinton Jct 1 138 New Line from Clinton Jct. to potential Wolverine Tap point.

MI 10.4 Planned $13,200,000 Y A

A in MTEP11 East METC 3517 6502 10/31/2011 Redstone Tittabawassee 1 138 159 MVA Line created when the existing Tittabawassee-Begole line is cut into Redstone

MI Planned $226,000 Y C>B>A

A in MTEP11 East METC 3517 6503 10/31/2011 Redstone 138 New Redstone substation will be layed out in a 3-breaker ring bus configuration.


A in MTEP11 East METC 3517 6510 10/31/2011 Redstone Gratiot Wind 1 138 Install a METC owned 138 kVdisconnect switch at the Redstone end of the interconnection customers radial line


A in MTEP11 East METC 3517 6509 12/31/2012 Summerton Begole 1 138 159 MVA New line created by looping the existing Alma-Summerton 138 kV line into Begole

MI 2.4 Planned $1,775,000 Y Y C>B>A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP11 East METC 3517 6508 12/31/2012 Alma Begole 2 138 159 MVA New line created by looping the existing Alma-Summerton 138 kV line into Begole

MI 2.4 Planned $1,775,000 Y Y C>B>A

A in MTEP11 East METC 3517 6501 12/31/2012 Redstone Begole 1 138 386 MVA Rebuild the existing line between Redstone and Begole to 1431 ACSR

MI 10.7 Planned $8,109,000 Y Y C>B>A

A in MTEP11 East METC 3517 6507 12/31/2012 Alma Vestaburg 1 138 159 MVA Replace terminal equipment at the Alma end of the Alma-Vestaburg 138 kV line


A in MTEP11 East METC 3517 6506 12/31/2012 Alma Begole 1 138 159 MVA Replace terminal equipment at the Alma end of the Alma-Begole 138 kV line


A in MTEP11 East METC 3517 6505 12/31/2012 Cornell Bennington 1 138 159 MVA Replace terminal equipment at the Cornell end of the Cornell-Bennington 138 kV line


A in MTEP11 East METC 3517 6504 12/31/2012 Begole 138 Reconfigure and expand the existing Begole substation into a 5-breaker ring bus layout


A in MTEP11 East METC 3518 6511 6/1/2012 MCV Tittabawassee 1 345 1239 MVA Remove 345 kV Disconnect switch from the Tittabawassee end of the MCV-Tittabawassee #1 345 kV line and extend the line entrance into the bus


A in MTEP11 East METC 3518 6512 6/1/2012 MCV Tittabawassee 2 345 1239 MVA Remove 345 kV Disconnect switch from the Tittabawassee end of the MCV-Tittabawassee #2 345 kV line and extend the line entrance into the bus


A in MTEP11 East METC 3520 6517 6/1/2012 Eureka 138kV Vestaburg 138kV 1 138 Remediate sag limits to conductor rating of circuit

Mi Planned $1,100,000 Y C>B>A

A in MTEP11 East METC 3521 6518 6/1/2012 Bullock 138kV Summerton 138kV 1 138 Remediate sag limits to conductor rating of circuit

Mi Planned $3,600,000 Y C>B>A

A in MTEP11 East NIPS 3203 5949 12/31/2019 New Reynolds Hiple 2 345 new line tap at Burr Oak IN Planned $271,000,000 Y Y Y B>AA in MTEP11 East WPSC 3328 6191 12/31/2011 Hersey Barryton 1 69 Barryton Taps the Hersey to Weidman 69kV

circuitMI Planned $100,000 Y C>B>A

A in MTEP11 East WPSC 3329 6192 12/31/2011 Barryton Weidman 1 69 Barryton Taps the Hersey to Weidman 69kV circuit


A in MTEP11 East WPSC 3329 6194 12/31/2013 Goodwin Wayland 1 69 143.4MVA Rebuild Overloaded Line to 795ACSS MI 4.58 Planned $1,900,000 Y C>B>AA in MTEP11 East WPSC 3329 6193 12/31/2013 Burnips Goodwin 1 69 143.4MVA Rebuild Overloaded Line to 795ACSS MI 13.09 Planned $5,250,000 Y C>B>AA in MTEP11 East WPSC 3330 6195 12/31/2011 Casnovia Capacitor Bank 69 Install a Capacitor Bank MI Planned $260,000 Y C>B>AA in MTEP11 East WPSC 3331 6196 12/31/2015 Redwood Hart 1 69 143.4MVA Rebuild Overloaded Line to 795ACSS MI 1.77 Planned $750,000 Y C>B>AA in MTEP11 East WPSC 3332 6197 2/28/2011 Bass Lake Substation Upgrade 69 Install Relaying at the current single breaker

stationMI In Service $250,000 Y C>B>A

A in MTEP11 East WPSC 3333 6198 12/31/2011 Lemon Junction Substation Upgrade 69 Install a Single Breaker Station MI Planned $350,000 Y C>B>AA in MTEP11 East WPSC 3334 6199 6/30/2011 Casnovia Sternberg 1 69 143.4MVA Rebuild a portion of the line to accommodate

work on the distribution underbuildMI 1.5 In Service $400,000 Y C>B>A

A in MTEP11 East WPSC 3335 6200 12/31/2013 Burnips Substation Upgrade 69 Replace bus work, breakers, relays, and any other necessary components


A in MTEP11 West AmerenMO, ITCM 2248 6584 6/1/2017 Ottumwa Adair 1 345 1739 New Ottumwa-Adair 345 kV line. ITCM & MEC to own Iowa portion, Ameren to own Missouri portion.

IA 64 Planned $32,164,000 Y Y Y B>A

A in MTEP11 West ATC LLC 174 3477 3/1/2012 Dunn Road Transformer 1 138 69 56 Install 56 MVA 138/69 kV transformer at Dunn Road

WI Planned Y B>A

A in MTEP11 West ATC LLC 174 442 3/1/2012 Canal Dunn Road 1 138 290 New 138kV line from Canal to Dunn Rd WI 7.64 Planned $24,763,300 Y B>AA in MTEP11 West ATC LLC 333 596 6/1/2013 Hiawatha Indian Lake (string

second 138 kV circuit)2 138 277 terminate and energize unused 2nd 138 kV

circuitMI 40 Planned $4,900,000 Y B>A

A in MTEP11 West ATC LLC 333 474 6/1/2013 Hiawatha Indian Lake (convert double circuit 138 kV from 69 kV operation to 138 kV o

2 138 277 Convert from 69kV operation to 138kV operation

MI 40 Planned Y B>A

A in MTEP11 West ATC LLC 1143 1793 12/31/2012 Lafayette (aka Darlington Wind)

generator 0.6 99 MW new generator WI Planned $4,200,000 Y B>A

A in MTEP11 West ATC LLC 1699 5979 7/31/2011 Chaffee Ck Capacitor Bank 69 14.4 MVAR Upgrade Chaffee Ck 10.8 MVAR capacitor bank to 14.4 MVAR

WI Planned $282,779 Y C>B>A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP11 West ATC LLC 1699 3478 7/31/2011 Mckenna Capacitor bank 69 15.3 MVAR Upgrade Mckenna 6.3 MVAR capacitor bank to 15.3 MVAR

WI Planned $403,971 Y C>B>A

A in MTEP11 West ATC LLC 1705 3487 4/1/2011 Townline Road Bass Creek 1 138 146 MVA Uprate Townline Road-Bass Creek 138 kV line

WI 11.7 In Service $935,946 Y B>A

A in MTEP11 West ATC LLC 1705 3486 4/1/2011 Bass Creek Transformer 1 138 69 100 MVA Install a 138/69 kV transformer at Bass Creek substation

WI In Service $6,040,000 Y B>A

A in MTEP11 West ATC LLC 1729 3518 4/20/2011 Straits McGulpin 1 138 127 MVA Uprate the Straits-McGulpin 138 kV line 9901 for Frontier T-D

MI 2.5 In Service $150,000 Y C>B>A

A in MTEP11 West ATC LLC 1729 3519 4/20/2011 Straits McGulpin 3 138 127 MVA Uprate the Straits-McGulpin 138 kV line 9903 for Frontier T-D

MI 2.5 In Service $150,000 Y C>B>A

A in MTEP11 West ATC LLC 1950 3831 3/17/2011 Kewaunee transformer 2 345 138 500 MVA Add a 2nd Kewaunee 345-138 kV transformer

WI In Service $17,697,000 Y Y B>A

A in MTEP11 West ATC LLC 2036 3916 12/15/2011 Wauzeka Boscobel 1 69 64 MVA Increase line clearance to 200/300 deg F SN/SE

WI 12 Planned $3,289,758 Y B>A

A in MTEP11 West ATC LLC 2036 3915 12/15/2011 Gran Grae Wauzeka 1 69 73 MVA Increase line clearance to 200/300 deg F SN/SE

WI 7.3 Planned $2,001,270 Y B>A

A in MTEP11 West ATC LLC 2037 3917 6/19/2012 Dane Lodi Tap 1 69 95 MVA Rebuild Dane-Lodi Tap 69 kV WI 4.39 Planned $6,798,033 Y C>B>AA in MTEP11 West ATC LLC 2055 3942 6/1/2012 Woodmin Substation 115 175 MVA Construst a new Woodmin distribution

substationWI Planned Y B>A

A in MTEP11 West ATC LLC 2055 3941 6/1/2012 Clear Lake Woodmin 1 115 175 MVA Construst a 7.5 mile 115 kv line from Clear Lake to a new Woodmin distribution substation

WI 7.5 Planned $21,331,000 Y B>A

A in MTEP11 West ATC LLC 2800 4930 9/10/2010 Arpin Hume 1 115 236 MVA Marshfield Electric & Water Department project to increase ground clearance to operate the line at 200 Deg F

WI 13.5 In Service $191,000 Y B>A

A in MTEP11 West ATC LLC 2820 4958 5/31/2012 Bluemound transformer 1 230 138 400 MVA Replace Bluemound 230/138kV transformer T1 with a 400 MVA unit

WI Planned $8,200,000 Y B>A

A in MTEP11 West ATC LLC 2842 5050 4/8/2011 Stage Coach Black Earth 1 69 83 MVA Uprate Stage Coach-Black Earth 69 kV WI 6.7 In Service $3,554,873 Y B>AA in MTEP11 West ATC LLC 2842 5049 4/8/2011 Spring Green Arena 1 69 84 MVA Uprate Spring Green-Arena 69kV line WI 7 In Service $3,402,521 Y B>AA in MTEP11 West ATC LLC 2844 4998 3/16/2014 Pleasant Prairie Zion Energy Center 1 345 1462 Construct a new Pleasant-Zion Energy

Center 345-kV lineWI/IL 5.3 Planned $28,856,000 Y Y Y C>B>A

A in MTEP11 West ATC LLC 2846 5068 5/1/2014 Straits power flow control

1 138 138 Install AC-DC-AC Back to Back Voltage Source Converter (VSC) power flow controller at the Straits 138-kV substation

MI Planned $90,000,000 Y Y A

A in MTEP11 West ATC LLC 3095 5420 4/1/2012 Hulbert Roberts 1 69 37 MVA Increase ground clearance for the 9Mile-Roberts 69 kV line 6952 to 176 deg f clearance for all seasons & Install Arresters, Replace Select Components

MI 17.3 Planned $6,034,531 Y B>A

A in MTEP11 West ATC LLC 3095 5418 4/1/2012 Raco Eckerman 1 69 37 MVA Increase ground clearance for the 9Mile-Roberts 69 kV line 6952 to 176 deg f clearance for all seasons & Install Arresters, Replace Select Components

MI 12.1 Planned $4,220,684 Y B>A

A in MTEP11 West ATC LLC 3095 5419 4/1/2012 Eckerman Hulbert 1 69 37 MVA Increase ground clearance for the 9Mile-Roberts 69 kV line 6952 to 176 deg f clearance for all seasons & Install Arresters, Replace Select Components

MI 6.4 Planned $2,232,428 Y B>A

A in MTEP11 West ATC LLC 3095 5416 4/1/2012 9Mile Brimley 1 69 37 MVA Increase ground clearance for the 9Mile-Roberts 69 kV line 6952 to 176 deg f clearance for all seasons & Install Arresters, Replace Select Components

MI 10.7 Planned $3,732,340 Y B>A

A in MTEP11 West ATC LLC 3095 5417 4/1/2012 Brimley Raco 1 69 37 MVA Increase ground clearance for the 9Mile-Roberts 69 kV line 6952 to 176 deg f clearance for all seasons & Install Arresters, Replace Select Components

MI 10.1 Planned $3,523,050 Y B>A

A in MTEP11 West ATC LLC 3108 5450 6/1/2014 Evergreen Pine River 1 69 174 MVA Rebuild Straits-Pine River dbl ckt line with T2-477 ACSR

MI 23.46 Planned $19,145,477 Y B>A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP11 West ATC LLC 3108 5448 6/1/2014 Straits Pine River 1 69 174 MVA Rebuild Straits-Pine River dbl ckt line with T2-477 ACSR

MI 25 Planned $20,402,257 Y B>A

A in MTEP11 West ATC LLC 3108 5449 6/1/2014 Straits Evergreen 1 69 174 MVA Rebuild Straits-Pine River dbl ckt line with T2-477 ACSR

MI 1.54 Planned $1,256,779 Y B>A

A in MTEP11 West ATC LLC 3126 5477 12/9/2012 Chandler transformer 2 138 69 60 MVA Install a 2nd Chandler Transformer & reconfigure bus to 138 kV Ring bus


A in MTEP11 West ATC LLC 3127 5628 12/31/2018 North Madison Cardinal 1 345 2110 Construct a North Madison - Cardinal 345-kV line

WI 20.55 Planned $45,300,000 Y Y Y B>A

A in MTEP11 West ATC LLC 3127 5627 12/31/2018 North Madison Cardinal 1 138 348 Reconductor with T2-477 HAWK ACSR WI 20.546 Planned $6,400,000 Y Y Y B>AA in MTEP11 West ATC LLC 3127 5060 12/31/2020 Arena Mazomanie West 1 138 348 MVA Convert Arena-Mazomanie West from 69-kV

to 138 kVWI 5 Planned $4,400,000 Y Y Y B>A

A in MTEP11 West ATC LLC 3127 5065 12/31/2020 Stage Coach Cardinal 1 138 348 MVA Convert Stage Coach-West Middleton from 69-kV to 138 kV

WI 4 Planned $9,200,000 Y Y Y B>A

A in MTEP11 West ATC LLC 3127 5064 12/31/2020 Black Earth Stage Coach 1 138 348 MVA Convert Black Earth-Stage Coach from 69-kV to 138 kV


A in MTEP11 West ATC LLC 3127 5063 12/31/2020 Mazomanie Black Earth 1 138 348 MVA Convert Mazomanie-Black Earth from 69-kV to 138 kV


A in MTEP11 West ATC LLC 3127 5062 12/31/2020 Mazomanie Industrial Mazomanie 1 138 348 MVA Convert Mazomanie Industrial-Mazomanie from 69-kV to 138 kV

WI 2 Planned $800,000 Y Y Y B>A

A in MTEP11 West ATC LLC 3127 5061 12/31/2020 Mazomanie West Mazomanie Industrial 1 138 348 MVA Convert Mazomanie West-Mazomanie Industrial from 69-kV to 138 kV

WI 1 Planned $800,000 Y Y Y B>A

A in MTEP11 West ATC LLC 3127 4978 12/31/2020 Spring Green Transformer 1 345 138 500 new transformer WI Planned $0 Y Y Y B>AA in MTEP11 West ATC LLC 3127 5059 12/31/2020 Spring Green Arena 1 138 348 MVA Convert Spring Green-Arena from 69-kV to

138 kVWI 7 Planned $5,300,000 Y Y Y B>A

A in MTEP11 West ATC LLC 3127 5480 12/31/2020 Nelson Dewey Cassville 1 161 342 MVA Reconductor Nelson Dewey-Cassville WI 2.34 Planned $5,200,000 Y Y Y B>AA in MTEP11 West ATC LLC 3127 5481 12/31/2020 Cassville Turkey River 1 161 445 MVA Reconductor Cassville-Turkey River WI/IA 4 Planned $3,700,000 Y Y Y B>AA in MTEP11 West ATC LLC 3127 5483 12/31/2020 Spring Green Substation 345 138 Spring Green substation modifications WI Planned $23,100,000 Y Y Y B>AA in MTEP11 West ATC LLC 3127 5484 12/31/2020 Cardinal Substation 345 138 Cardinal substation modifications WI Planned $9,700,000 Y Y Y B>AA in MTEP11 West ATC LLC 3127 4977 12/31/2020 Spring Green Cardinal 1 345 2110 new line WI 28 Planned $59,900,000 Y Y Y B>AA in MTEP11 West ATC LLC 3157 5543 6/17/2011 Red Granite Tap ACEC Spring Lake Tap 1 69 69 Uprate Red Granite Tap to ACEC Spring

Lake Tap 69 kV LineWI 2.5 In Service $39,146 Y C>B>A

A in MTEP11 West ATC LLC 3157 5542 6/17/2011 Fountain Valley Tap Red Granite Tap 1 69 69 Uprate Founain Valley Tap to Red Granite Tap 69 kV Line

WI 3.6 In Service $56,182 Y C>B>A

A in MTEP11 West ATC LLC 3157 5541 6/17/2011 Fountain Valley Fountain Valley Tap 1 69 69 Uprate Founain Valley to Fountain Valley Tap 69 kV Line


A in MTEP11 West ATC LLC 3157 5545 6/17/2011 Silver Lake Tap Wautoma 1 69 69 Uprate Silver Lake Tap to Wautoma 69 kV Line


A in MTEP11 West ATC LLC 3157 5544 6/17/2011 ACEC Spring Lake Tap Silver Lake Tap 1 69 69 Uprate ACEC Spring Lake Tap to Silver Lake Tap 69 kV Line


A in MTEP11 West ATC LLC 3160 5550 12/31/2011 Staff Hamilton 1 138 258 Uprate Staff to Hamilton 138 kV Line for G706/H012

WI 12.7 Planned $471,114 Y C>B>A

A in MTEP11 West ATC LLC 3160 5551 12/31/2011 Staff Friesland 1 138 348 Uprate Staff to Friesland 138 kV Line WI 6 Planned $222,733 Y C>B>AA in MTEP11 West ATC LLC 3160 5552 12/31/2011 Friesland North Randolph 1 138 293 Uprate Friesland to North Randolph 138 kV

Line for G706/H012WI 1.4 Planned $347,573 Y C>B>A

A in MTEP11 West ATC LLC 3160 5553 12/31/2011 Hamilton Portage 1 138 293 Uprate Hamilton to Portage 138 kV Line for G706/H012


A in MTEP11 West ATC LLC 3161 5556 11/30/2012 EcoMont Rewey Tap 1 69 78 New EcoMont substation is tapped into Belmont Tap-Rewey Tap 69 kV Line & remote end terminal work for G749


A in MTEP11 West ATC LLC 3161 5555 11/30/2012 Belmont Tap EcoMont 1 69 78 New EcoMont substation is tapped into Belmont Tap-Rewey Tap 69 kV Line & remote end terminal work for G749


A in MTEP11 West ATC LLC 3161 5554 11/30/2012 EcoMont Substation 69 New EcoMont substation G749 WI Planned $3,689,667 Y C>B>AA in MTEP11 West ATC LLC 3188 5629 3/25/2011 Pleasant Prairie Zion 1 345 1334 Replace 345kV Wave trap and jumpers at the

ComEd Zion SSWI/IL In Service $1,544,571 Y Y B>A

A in MTEP11 West ATC LLC 3206 5970 6/1/2018 Branch River Point Beach 1 345 883 Loop the Point Beach-Forest Juction into the Branch River SS

WI Planned $5,314,000 Y Y Y B>A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP11 West ATC LLC 3206 5971 6/1/2018 Branch River Forest Jct 1 345 883 Loop the Point Beach-Forest Juction into the Branch River SS


A in MTEP11 West ATC LLC 3206 5969 6/1/2018 Barnhart Holland 1 138 283 Terminate the not-converted Holland 138 kV line at Barnhart 138 kV

WI Planned $142,000 Y B>A

A in MTEP11 West ATC LLC 3206 5968 6/1/2018 Branch River Forest Jct 2 345 883 Convert the existing Forest Junction-Howards Grove-Plymouth #4 138 kV line and the Branch Riverern portion of the existing Plymouth #4-Holland 138 kV line to 345 kV and loop into the Barnhart and Branch River substations

WI 12.88 Planned $9,397,000 Y Y Y B>A

A in MTEP11 West ATC LLC 3206 5966 6/1/2018 Howards Grove Erdman 1 138 348 Construct a new 138 kV line from Howards Grove to Erdman

WI 6.6 Planned $11,824,000 Y B>A

A in MTEP11 West ATC LLC 3206 5959 6/1/2018 Barnhart Cedarsauk 1 345 960 Loop Edgewater-Cedarsauk into the new Barnhart SS and uprate the Barnhart to Cedarsauk secton to 960 MVA


A in MTEP11 West ATC LLC 3206 5967 6/1/2018 Barnhart Branch River 1 345 1096 Convert the existing Forest Junction-Howards Grove-Plymouth #4 138 kV line and the Branch River portion of the existing Plymouth #4-Holland 138 kV line to 345 kV and loop into the Barnhart and Branch River substations

WI 35.5 Planned $20,057,000 Y Y Y B>A

A in MTEP11 West ATC LLC 3206 5958 6/1/2018 Barnhart Edgewater 1 345 653 Loop Edgewater-Cedarsauk into the new Barnhart SS


A in MTEP11 West ATC LLC 3206 5957 6/1/2018 Barnhart South Fond du Lac 1 345 1198 Loop Edgewater-South Fond du Lac into the new Barnhart SS


A in MTEP11 West ATC LLC 3206 5964 6/1/2018 Barnhart Plymouth #4 1 138 348 Construct a new 138 kV line from Barnhart to Plymouth #4

WI 5.87 Planned $8,529,000 Y B>A

A in MTEP11 West ATC LLC 3206 5963 6/1/2018 Barnhart Mullet River 138 kV 1 138 488 Loop the South Sheboygan Falls-Mullet River 138 kV line into Barnhart SS

WI Planned $6,843,000 Y B>A

A in MTEP11 West ATC LLC 3206 5978 6/1/2018 Barnhart Substation 1 345 500 New 345 kV Substation, including bus work and new 345/138 kV transformer


A in MTEP11 West ATC LLC 3206 5955 6/1/2018 Branch River substation 345 Construct a new Branch River substation WI Planned $25,921,500 Y Y Y B>AA in MTEP11 West ATC LLC 3206 5962 6/1/2018 Barnhart South Sheboygan Falls 1 138 293 Loop the South Sheboygan Falls-Mullet River

138 kV line into Barnhart SSWI Planned $3,839,000 Y B>A

A in MTEP11 West ATC LLC 3206 5960 6/1/2018 Barnhart Sheboygan Energy Center

1 345 1096 Loop Sheboygan Energy Center-Granville into the new Barnhart SS


A in MTEP11 West ATC LLC 3206 5965 6/1/2018 Plymouth #4 Howards Grove 1 138 348 Construct a new 138 kV line from Plymouth #4 to Howards Grove

WI 3.13 Planned $2,938,000 Y B>A

A in MTEP11 West ATC LLC 3206 5973 6/1/2018 Branch River Sheboygan Energy Center

1 345 1096 Loop the Point Beach-Sheboygan Energy Center 345 kV line into the Branch River SS


A in MTEP11 West ATC LLC 3206 5961 6/1/2018 Barnhart Granville 1 345 1096 Loop Sheboygan Energy Center-Granville into the new Barnhart SS


A in MTEP11 West ATC LLC 3206 5956 6/1/2018 Barnhart Edgewater 2 345 937 Loop Edgewater-South Fond du Lac into the new Barnhart SS


A in MTEP11 West ATC LLC 3206 5972 6/1/2018 Branch River Point Beach 1 345 1096 Loop the Point Beach-Sheboygan Energy Center 345 kV line into the Branch River SS


A in MTEP11 West ATC LLC 3395 6270 4/1/2015 Milwaukee Co 138 13.2 added distribution substation with 2 line breakers and a bus tie breaker

WI Planned $3,500,000 Y C>B>A

A in MTEP11 West ATC LLC 3395 6269 4/1/2015 Parkhill Milwaukee Co 1 138 321 Tap Bluemound-Parkhill line and install 1.9 miles of new 138kV line to the new Milwaukee Co substation

WI 1.9 Planned $15,000,000 Y C>B>A

A in MTEP11 West ATC LLC 3395 6268 4/1/2015 Bluemound Milwaukee Co 1 138 321 Tap Bluemound-Tosa line and install 2.0 miles of new 138kV line to the new Milwaukee Co substation

WI 2 Planned $15,000,000 Y C>B>A

A in MTEP11 West ATC LLC 3427 6322 3/7/2011 Nordic Perch Lk 1 138 191 Increase ground clearance for the Nordic-Perch Lk 138 kV line

MI 29.6 In Service $1,543,040 Y C>B>A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP11 West ATC LLC 3428 6323 4/8/2011 Stage Coach Timberlane 1 69 80 Increase ground clearance for the Stage coach-Timberlane 69 kV line


A in MTEP11 West ATC LLC 3432 6330 4/21/2011 Stoughton Stoughton South Tap 1 69 69 Uprate the Stoughton-Stoughton South Tap-Oregon 69 kV line Y-127

WI 8 In Service $456,000 Y C>B>A

A in MTEP11 West ATC LLC 3432 6331 4/21/2011 Stoughton South Tap Oregon 1 69 69 Uprate the Stoughton-Stoughton South Tap-Oregon 69 kV line Y-127

WI 2 In Service $114,000 Y C>B>A

A in MTEP11 West ATC LLC 3433 6332 12/31/2011 Stagecoach Mt Horeb NE 1 69 69 Uprate the Stagecoach-Mt Horeb NE-Mt Horeb 69 kV line Y-128

WI 0.5 Planned Y C>B>A

A in MTEP11 West ATC LLC 3433 6333 12/31/2011 Mt Horeb NE Mt Horeb 1 69 69 Uprate the Stagecoach-Mt Horeb NE-Mt Horeb 69 kV line Y-128


A in MTEP11 West ATC LLC 3447 6350 12/7/2010 Ontonagon 1 138 69 28 Retap CT related to Ontonagon 138/69 kV Tr to obtain a higher rating

MI In Service $12,410 Y C>B>A

A in MTEP11 West ATC LLC 3448 6351 12/1/2011 Ontonagon 1 138 69 47 Replace the Ontonagon 138/69 kv Tr with a larger unit


A in MTEP11 West ATC LLC 3449 6352 12/31/2013 Atlantic M38 1 69 146 Rebuild the Atlantic-M38 69kV line MI Planned $18,878,963 Y C>B>AA in MTEP11 West ATC LLC 3451 6356 11/1/2011 Mt Horeb Verona 1 69 69 Increase ground clearance on the Mt Horeb-

Verona 69kV lineWI 13 Planned $710,000 Y C>B>A

A in MTEP11 West ATC LLC 3452 6359 11/1/2011 RCEC Center Union Town Line 1 69 69 Increase ground clearance on the Bass Ck-Sheepskin 69kV line


A in MTEP11 West ATC LLC 3452 6360 11/1/2011 Union Town Line Evansville Tap 1 69 69 Increase ground clearance on the Bass Ck-Sheepskin 69kV line


A in MTEP11 West ATC LLC 3452 6358 11/1/2011 Footville RCEC Center 1 69 69 Increase ground clearance on the Bass Ck-Sheepskin 69kV line


A in MTEP11 West ATC LLC 3452 6357 11/1/2011 Bass Ck Footville 1 69 69 Increase ground clearance on the Bass Ck-Sheepskin 69kV line


A in MTEP11 West ATC LLC 3452 6361 11/1/2011 Evansville Tap Sheepskin 1 69 69 Increase ground clearance on the Bass Ck-Sheepskin 69kV line

WI 13 Planned $538,739 Y C>B>A

A in MTEP11 West ATC LLC 3453 6362 2/28/2012 Waupun Koch Tap 1 69 59 Increase ground clearance on the Waupun-S Fond du Lac 69kV line


A in MTEP11 West ATC LLC 3453 6363 2/28/2012 Koch Tap S Fond du Lac 1 69 59 Increase ground clearance on the Waupun-S Fond du Lac 69kV line

WI 15.5 Planned $1,872,528 Y C>B>A

A in MTEP11 West ATC LLC 3457 6371 12/30/2011 Highway 2 SUB 138 GIC-J060 Highway 2 SS tapped in the Indian Lk-Perkins #1 line


A in MTEP11 West ATC LLC 3457 6372 12/30/2011 Highway 2 Garden City Wind 1 138 211 GIC-J060 Highway 2 - Garden City Wind SS 138kV line

MI 17 Planned Y C>B>A

A in MTEP11 West ATC LLC 3457 6373 12/30/2011 Garden City Wind Transformer 1 138 34.5 30 GIC-J060 Garden City Wind 138/34.5 kV step up transformer

MI Planned Y C>B>A

A in MTEP11 West ATC LLC 3457 6374 12/30/2011 Garden City Wind Transformer 1 34.5 0.69 35 GIC-J060 Garden City Wind 34.5/0.69 kV generator step up transformer

MI Planned Y C>B>A

A in MTEP11 West ATC LLC 3458 6375 6/3/2011 Aurora Transformer 1 115 69 60 Aurora 115-69kV T3 Replacement WI In Service $2,958,914 Y C>B>AA in MTEP11 West ATC LLC 3459 6376 4/12/2011 Hume Wildwood 1 115 207 Increase ground clearance on the Hume-

Wildwood 115kV lineWI 2.7 In Service $50,000 Y C>B>A

A in MTEP11 West ATC LLC 3460 6377 2/28/2011 Berlin Dartford Tap 1 69 72 Increase ground clearance on the Y-93 Berlin-Ripon 69kV line


A in MTEP11 West ATC LLC 3460 6378 2/28/2011 Dartford Tap NW Ripon 1 69 72 Increase ground clearance on the Y-93 Berlin-Ripon 69kV line


A in MTEP11 West ATC LLC 3460 6379 2/28/2011 NW Ripon Ripon 1 69 72 Increase ground clearance on the Y-93 Berlin-Ripon 69kV line


A in MTEP11 West ATC LLC 3461 6380 2/28/2011 McMillan Wildwood 1 115 138 Increase ground clearance on the McMillan-Wildwood 115kV line


A in MTEP11 West ATC LLC 3488 6446 3/1/2012 Brick Church Walworth 1 69 84 Fix clearance on Brick Church-Walworth 69 kV line to bring rating up


A in MTEP11 West ATC LLC 3489 6448 3/1/2012 Wiota Gratiot Tap 1 69 66 Fix clearance on Wiota-Gratiot Tap 69 kV line to bring rating up


A in MTEP11 West ATC LLC 3489 6447 3/1/2012 Jennings Road Wiota 1 69 60 Fix clearance on Jennings Road-Wiota 69 kV line to bring rating up







Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP11 West ATC LLC 3489 6449 3/1/2012 Gratiot Tap Darlington 1 69 64 Fix clearance on Gratiot Tap-Darlington 69 kV line to bring rating up


A in MTEP11 West ATC LLC 3504 6464 12/1/2012 Omro Winneconne 1 69 64 Rerate Line Y-80 conductor from Omro sub to Winneconne sub to a rating of 580 amps

WI 5 Planned $205,000 Y C>B>A

A in MTEP11 West ATC LLC, ITCM 3127 5482 12/31/2020 Dubuque Co Substation 345 Construct the Dubuque Co switching station IA Planned $13,400,000 Y Y Y B>AA in MTEP11 West ATC LLC, ITCM 3127 4976 12/31/2020 Spring Green Dubuque Co 1 345 2110 new line WI 75.13 Planned $159,300,000 Y Y Y B>AA in MTEP11 West ATC LLC, XEL 3127 5626 12/31/2018 North LaCrosse North Madison 1 345 2110 Construct a North LaCrosse - North Madison

345-kV lineWI 136.3 Planned $301,800,000 Y Y Y B>A

A in MTEP11 West ATC LLC, XEL 3127 6573 12/31/2018 North LaCrosse (Briggs Road)

Substation 345 161 448 MVA Terminate North Madison - North LaCrosse 345 kV line into Briggs Road, create 345 kV breaker ring bus, add second 345/161 kV transformer, and 50 MVAR of 34.5 kV reactors on the tertiary


A in MTEP11 West ATCLLC 3472 6399 3/22/2013 Pleasant Prairie 345 Construct a new 6 ring breaker and a half 345 kV bus at the P4 site adjacent to the existing P4 yard.


A in MTEP11 West ATCLLC 3479 6428 3/1/2012 Progress Aviation 1 138 230 MVA Increase ground clearance for the Progress-Aviation line to 187 degrees F


A in MTEP11 West ATCLLC 3480 6429 10/1/2012 Engadine Tap Engadine 1 138 57 MVA Construct a new radial 69-kV tap from the existing Indian Lake-Hiawatha 69-kV line 6913 to the Engadine Substation


A in MTEP11 West DPC 3397 6272 6/1/2014 Genoa La Crosse Tap 1 161 400 Rebuild line WI 20.9 Planned $18,000,000 Y Y C>B>AA in MTEP11 West DPC 3434 6337 9/1/2012 Alma Elk Mound 161 New Substation WI Planned $2,164,000 Y C>B>AA in MTEP11 West GRE 1203 2649 6/17/2013 Cedar Mountain Transformer 1 345 115 448 new transformer MN Planned $19,300,000 Y Y Y B>AA in MTEP11 West GRE 1203 1885 8/15/2013 Cedar Mountain Helena 2 345 2066 new line MN 62.2 Planned $0 Y Y Y B>AA in MTEP11 West GRE 1203 1884 8/15/2013 Cedar Mountain Helena 1 345 2066 new line MN 62.2 Planned $141,700,000 Y Y Y B>AA in MTEP11 West GRE 1203 1893 10/9/2013 Lyon County Transformer 1 345 115 448 new transformer MN Planned $20,700,000 Y Y Y B>AA in MTEP11 West GRE 1203 1883 11/5/2013 Lyon County Cedar Mountain 2 345 2066 new line MN 51.9 Planned $0 Y Y Y B>AA in MTEP11 West GRE 1203 1882 11/5/2013 Lyon County Cedar Mountain 1 345 2066 new line MN 51.9 Planned $111,500,000 Y Y Y B>AA in MTEP11 West GRE 1203 5624 2/10/2014 Cedar Mountain Franklin 1 115 336 new line MN 5 Planned $22,600,000 Y Y Y B>AA in MTEP11 West GRE 1203 1894 3/31/2014 Lake Marion Transformer 1 345 115 448 new transformer MN Planned $25,900,000 Y Y Y B>AA in MTEP11 West GRE 1203 1886 4/29/2014 Helena Lake Marion 1 345 2066 new line MN 26.6 Planned $87,800,000 Y Y Y B>AA in MTEP11 West GRE 1203 1887 6/16/2014 Lake Marion Hampton Corner 1 345 2066 new line MN 18.5 Planned $55,600,000 Y Y Y B>AA in MTEP11 West GRE 1203 1881 1/12/2015 Brookings County Lyon County 345 kV 1 345 2066 new line SD/MN 48.1 Planned $134,700,000 Y Y Y B>AA in MTEP11 West GRE 1203 1895 1/22/2015 Hazel Transformer 1 345 230 336 new transformer MN Planned $25,700,000 Y Y Y B>AA in MTEP11 West GRE 1203 1888 2/2/2015 Lyon County Hazel 1 345 2066 new line MN 23.5 Planned $59,000,000 Y Y Y B>AA in MTEP11 West GRE 1203 1889 2/16/2015 Hazel Creek Minnesota Valley 1 230 1558 new line MN 6 Planned $20,500,000 Y Y Y B>AA in MTEP11 West GRE 2571 4582 11/15/2014 MN Pipeline Menahga 1 115 42 MN Pipeline-Menahga 115 kV line operated

at 34.5 kV, Menahga 2-way switchMN 8 Planned $4,199,990 Y C>B>A

A in MTEP11 West GRE 2599 4610 10/31/2014 Shell Lake Shell Lake Tap 1 115 New Distribution MN 5 Planned $4,201,000 Y C>B>AA in MTEP11 West GRE 2634 6292 11/2/2012 Savanna Cedar Valley 1 115 310 Cedar Valley conversion to 115 kV from 69

kVMN 8 Planned $3,900,225 Y Y B>A

A in MTEP11 West GRE 2634 4645 11/28/2014 Savanna Cromwell 1 115 310 New 115 kV Cromwell-Floodwood Line MN 29 Planned $22,000,000 Y Y B>AA in MTEP11 West GRE 2643 4659 5/1/2013 Parkers Prairie Parkers Prairie Tap 1 115 141.6 Parkers Prairie Conversion from 41.6 to 115

kVMN 2 Planned $1,220,998 Y C>B>A

A in MTEP11 West GRE 2679 4696 11/1/2019 Ramsey Grand Forks 1 230 230 kV rebuild MN 81.02 Planned $40,500,000 Y C>B>AA in MTEP11 West GRE 3454 6267 5/1/2013 Medina 115 kV breaker station 115 0 Convert WHCEA’s Median 69 kV distribution

substation to 115 kV. Retire the 69 kV portion of the Medina 115/69 kV substation, reconfigure Medina to a straight bus breaker station and re-terminate the existing 115kV lines and the new Median – Pomerleau Lake 115 kV line at the Medina breaker station. Medina is recommended to have additional positions for future 115 kV line terminations.

MN 0 0 Planned $1,386,164 N Y C>B>A

A in MTEP11 West GRE 3467 6394 7/1/2011 Oak Glen Wind Riverpoint 1 69 SW-RB rebuild to double circuit line MN 4 0 Under Construction

$1,722,464 Y B>A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP11 West GRE 3468 6395 9/1/2011 Claybank Substation 1 69 Claybank breaker station MN 0 0 Under Construction

$1,312,741 Y B>A

A in MTEP11 West GRE 3469 6396 10/1/2011 H061 Tap Switch 1 69 H061 switch on the Vasa Tap line MN 0 0 Planned $192,530 Y B>AA in MTEP11 West GRE, XEL 1203 1898 6/1/2011 Morris Transformer 2 230 115 150 Upgrade 100 MVA to 150 MVA MN Planned $4,000,000 Y Y Y B>AA in MTEP11 West GRE, XEL 1203 1899 6/1/2011 Willmar Transformer 2 115 69 112 MN Planned $3,000,000 Y Y NT B>AA in MTEP11 West ITCM 3191 5635 4/29/2011 Lakefield Jct Substation 1 345 Convert the Lakefield 345kV ring bus to

breaker and a half.MN In Service $8,148,000 Y Y Y B>A

A in MTEP11 West ITCM 3192 5636 8/15/2010 Ellendale Breaker Station 1 69 143 MVA Construct a new Ellendale 69kV four terminal breaker station near the existing River Point Tap.

MN In Service $1,854,906 Y B>A

A in MTEP11 West ITCM 3192 5638 12/31/2011 Ellendale County Line 1 69 77 MVA Change the N.O. switch to normally closed after breaker station is operational.

MN Under Construction

$58,800 Y Y B>A

A in MTEP11 West ITCM 3192 5637 12/31/2011 Ellendale G604 customer sub 1 69 77 MVA Construct a new Ellendale-G604 customer 69kV tap.

MN 3.5 Under Construction

$0 Y Y B>A

A in MTEP11 West ITCM 3193 5639 10/1/2010 Trimont G741 Tap 1 69 Tap Trimont(IPL)-Sherburn(SCREC) 69kV line for the new tap to G741 customer.

MN In Service $10,000 Y Y B>A

A in MTEP11 West ITCM 3193 5640 10/1/2010 Sherburn(SCREC) G741 Tap 1 69 Tap Trimont(IPL)-Sherburn(SCREC) 69kV line for the new tap to G741 customer.


A in MTEP11 West ITCM 3193 5641 10/1/2010 G741 Tap G741 Customer Sub 1 69 Radial tap from G741 Tap-G741Customer sub

MN 2.5 In Service $197,884 Y Y B>A

A in MTEP11 West ITCM 3193 5642 10/1/2010 Fox Lake Relay Upgrade 1 69 Adjust relays at Fox Lake 69kV breaker730. MN 2.5 In Service $6,000 Y Y B>AA in MTEP11 West ITCM 3194 5643 7/31/2010 Story County Breaker Station 1 161 558 MVA Expand the 161kV ring bus at Story County. IA In Service $422,664 Y Y B>AA in MTEP11 West ITCM 3195 5647 10/1/2010 Freeborn G870 Wind Sub 1 161 Radial tap from Freeborn-G870 MN 4 In Service $0 Y Y B>AA in MTEP11 West ITCM 3195 5644 10/1/2010 Freeborn Breaker Station 1 161 558 MVA Construct a new Freeborn 161kV three

terminal breaker station.MN In Service $3,076,795 Y Y B>A

A in MTEP11 West ITCM 3195 5646 10/1/2010 Freeborn Winnebago 1 161 Tap Hayward-Winnebago Jct 161kV line for the new Freeborn Breaker Station.


A in MTEP11 West ITCM 3195 5645 10/1/2010 Freeborn Hayward 1 161 Tap Hayward-Winnebago Jct 161kV line for the new Freeborn Breaker Station.


A in MTEP11 West ITCM 3196 5648 7/1/2011 Bond Breaker Station 1 69 143 MVA Construct a new Bond 69kV four terminal breaker station near the existing Greely T.

IA In Service $1,897,882 Y B>A

A in MTEP11 West ITCM 3196 5649 7/1/2011 Bond Backbone Tap 1 69 69 MVA Construct 2 miles of 69kV double circuit. IA In Service $831,141 Y Y B>AA in MTEP11 West ITCM 3196 5650 7/1/2011 Bond Manchester REC Tap 1 69 69 MVA Construct 2 miles of 69kV double circuit. IA In Service $831,140 Y Y B>AA in MTEP11 West ITCM 3205 6526 12/31/2015 Rutland Winnebago 1 161 446 MVA Construct 345-161kV double circuit MN 15.24 Planned $0 Y Y Y B>AA in MTEP11 West ITCM 3205 6535 12/31/2015 Winnebago Fairbault Co 1 161 446 MVA Construct 345-161kV double circuit IA 15.13 Planned $0 Y Y Y B>AA in MTEP11 West ITCM 3205 6534 12/31/2015 Winnco Fairbault Co 1 161 446 MVA Construct 345-161kV double circuit MN/IA 22 Planned $0 Y Y Y B>AA in MTEP11 West ITCM 3205 6533 12/31/2015 Winnco West Burt 1 345 1800 MVA Construct 345kV circuit IA 19 Planned $41,225,660 Y Y Y B>AA in MTEP11 West ITCM 3205 6532 12/31/2015 Winnebago Winnco West 1 161 Retire existing 161kV H frame circuit MN/IA Planned $1,105,632 Y Y Y B>AA in MTEP11 West ITCM 3205 6531 12/31/2015 Winnebago Winnco West 1 345 1800 MVA Construct 345-161kV double circuit MN/IA 22 Planned $47,734,975 Y Y Y B>AA in MTEP11 West ITCM 3205 6530 12/31/2015 Winnco West substation 1 345 1800 MVA Construct a new Winnco West 3-terminal

345kV switch station.IA Planned $10,980,000 Y Y Y B>A

A in MTEP11 West ITCM 3205 6529 12/31/2015 Lakefield Substation 345 1800 MVA Add a 345kV terminal at Lakefield including 2 new 345kv bkrs

IA Planned $5,000,000 Y Y Y B>A

A in MTEP11 West ITCM 3205 6527 12/31/2015 Fox Lake Rutland 1 161 Retire existing 161kV H frame circuit MN Planned $804,097 Y Y Y B>AA in MTEP11 West ITCM 3205 6525 12/31/2015 Fox Lake Rutland 1 161 446 MVA Construct 345-161kV double circuit MN 16.5 Planned $0 Y Y Y B>AA in MTEP11 West ITCM 3205 6524 12/31/2015 Lakefield Fox Lake 1 161 446 MVA Construct 345-161kV double circuit MN 23 Planned $0 Y Y Y B>AA in MTEP11 West ITCM 3205 6523 12/31/2015 Lakefield Fox Lake 1 161 Retire existing 161kV H frame circuit MN Planned $1,155,888 Y Y Y B>AA in MTEP11 West ITCM 3205 6521 12/31/2015 Winnebago transformer 345 161 450 MVA Add a 345/161kV TRF IA Planned $0 Y Y Y B>AA in MTEP11 West ITCM 3205 6520 12/31/2015 Winnebago Substation 345 161 1800 MVA Construt a new sub with a 345kV ring bus

with 2 line terminals and one 345/161kV TRFIA Planned $27,360,000 Y Y Y B>A

A in MTEP11 West ITCM 3205 6528 12/31/2015 Rutland Winnebago 1 161 Retire existing 161kV H frame circuit MN Planned $804,097 Y Y Y B>AA in MTEP11 West ITCM 3205 6522 12/31/2015 Lakefield Winnebago 1 345 1800 MVA Construct 345-161kV double circuit MN 55 Planned $119,337,438 Y Y Y B>AA in MTEP11 West ITCM 3213 6547 12/31/2015 Lime Creek Emery 1 161 Retire existing 161kV H frame circuit IA Planned $804,096 Y Y Y B>AA in MTEP11 West ITCM 3213 6545 12/31/2015 Lime Creek Emery 1 345 1800 MVA Construct 345-161kV double circuit IA 16 Planned $34,716,345 Y Y Y B>AA in MTEP11 West ITCM 3213 6544 12/31/2015 Emery transformer 345 161 450 MVA Add a 345/161kV TRF IA Planned $0 Y Y Y B>A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP11 West ITCM 3213 6543 12/31/2015 Emery Substation 345 161 1800 MVA Construt a new sub with a 345kV ring bus with 2 line terminals and one 345/161kV TRF


A in MTEP11 West ITCM 3213 6541 12/31/2015 Lime Creek Substation 345 161 1800 MVA Construt a new sub with a 345kV ring bus with 2 line terminals and one 345/161kV TRF


A in MTEP11 West ITCM 3213 6546 12/31/2015 Lime Creek Emery 1 161 335 MVA Construct 345-161kV double circuit IA 16 Planned $0 Y Y Y B>AA in MTEP11 West ITCM 3213 6542 12/31/2015 Lime Creek transformer 345 161 450 MVA Add a 345/161kV TRF IA Planned $0 Y Y Y B>AA in MTEP11 West ITCM 3213 6553 12/31/2015 Hazleton Substation 345 161 1800 MVA Convert the 345kV ring bus to a breaker and

half and add a 345kV line terminal.IA Planned $14,200,000 Y Y Y B>A

A in MTEP11 West ITCM 3213 6552 12/31/2015 Blackhawk Hazleton 1 161 Retire existing 161kV H frame circuit IA Planned $603,072 Y Y Y B>AA in MTEP11 West ITCM 3213 6537 12/31/2015 Lime Creek Worth County 1 161 200 MVA Construct 345-161kV double circuit IA 7 Planned $0 Y Y Y B>AA in MTEP11 West ITCM 3213 6536 12/31/2015 Winnco West Lime Creek 1 345 1800 MVA Construct 345-161kV double circuit IA 61 Planned $132,356,067 Y Y Y B>AA in MTEP11 West ITCM 3213 6538 12/31/2015 Winnco West Winnco 1 161 Retire existing 161kV H frame circuit IA Planned $804,096 Y Y Y B>AA in MTEP11 West ITCM 3213 6539 12/31/2015 Worth County Lime Creek tap 1 161 Retire existing 161kV H frame circuit IA Planned $251,280 Y Y Y B>AA in MTEP11 West ITCM 3213 6540 12/31/2015 Lime Creek tap Lime Creek 1 161 Retire existing 161kV H frame circuit IA Planned $226,152 Y Y Y B>AA in MTEP11 West ITCM 3406 6293 4/29/2011 Adams Rochester 1 161 501 MVA Upgrades terminal equipment MN In Service $360,000 Y C>B>AA in MTEP11 West ITCM 3407 6294 12/31/2011 Bluff Substation 1 69 Expand the Bluff sub IA Planned $1,920,000 Y C>B>AA in MTEP11 West ITCM 3408 6295 12/31/2011 Boone Quartz Substation 1 69 Construct the 69/dist sub IA Planned $1,700,000 Y C>B>AA in MTEP11 West ITCM 3409 6296 12/31/2013 Bricelyn Walters 1 69 Rebuild 5 miles to T2-477 IA 5.03 Planned $2,625,000 Y C>B>AA in MTEP11 West ITCM 3410 6297 12/31/2011 Bridgeport Ottumwa 1 161 Upgrades terminal equipment IA Planned $200,000 Y C>B>AA in MTEP11 West ITCM 3411 6298 12/31/2011 Bridgeport Substation 1 69 Add new T8 69/dist TRF IA Planned $360,000 Y C>B>AA in MTEP11 West ITCM 3412 6299 12/31/2012 Fort Madison Substation 1 69 Add new 69/dist TRF IA Planned $360,000 Y C>B>AA in MTEP11 West ITCM 3413 6300 12/31/2013 Gladbrook Gladbrook Tap 1 161 161 Add new 69/dist TRF IA Planned $300,000 Y C>B>AA in MTEP11 West ITCM 3413 6301 12/31/2013 Marshalltown Gladbrook Tap 1 161 161 Add new 69/dist TRF IA Planned $0 Y C>B>AA in MTEP11 West ITCM 3413 6302 12/31/2013 Traer Gladbrook Tap 1 161 161 Add new 69/dist TRF IA Planned $0 Y C>B>AA in MTEP11 West ITCM 3414 6303 12/31/2012 Magnolia capacitor 1 69 Add a 7.1 MVAR cap at Magnolia IA Planned $480,000 Y C>B>AA in MTEP11 West ITCM 3415 6304 12/31/2011 Marion Prairie Creek 1 115 195 MVA Upgrades terminal equipment IA In Service $10,000 Y C>B>AA in MTEP11 West ITCM 3416 6305 12/31/2012 Marion 0410 circuit 1 34 34 Rebild to doulbe ckt 69kV IA Planned $10,500,000 Y C>B>AA in MTEP11 West ITCM 3417 6306 12/31/2011 Marshalltown East

NevadaSubstation 1 34 Add new 34/dist TRF IA In Service $280,000 Y C>B>A

A in MTEP11 West ITCM 3418 6307 12/31/2013 Mt Vernon 6420 6420 circuit 1 34 34 Rebild ckt 69kV IA Planned $7,150,000 Y C>B>AA in MTEP11 West ITCM 3419 6308 12/31/2012 Bertram Sewage Bertram Sewage Tap 1 69 Add new 69/dist sub and tap IA Planned $270,000 Y C>B>AA in MTEP11 West ITCM 3420 6309 12/31/2011 Ottumwa Generating

StationSubstation 1 345 Replace the failed circuit switcher with a new

breakerIA Planned $1,350,000 Y C>B>A

A in MTEP11 West ITCM 3421 6310 12/31/2011 South Centerville capacitor 1 69 Add a 7 MVAR cap at South Centerville IA Planned $1,350,000 Y C>B>AA in MTEP11 West ITCM 3422 6311 12/31/2012 South Broadway Substation 1 69 195 MVA Upgrades terminal equipment IA Planned $150,000 Y C>B>AA in MTEP11 West ITCM 3423 6313 12/31/2011 Truro tap White Oak REC 1 69 Tap White Oak-Medora IA Planned $0 Y C>B>AA in MTEP11 West ITCM 3423 6312 12/31/2011 Truro Truro tap 1 69 77 MVA Add new 69kV tap IA 10.03 Planned $3,360,000 Y C>B>AA in MTEP11 West ITCM 3423 6314 12/31/2011 Truro tap Medora 1 69 Tap White Oak-Medora IA Planned $0 Y C>B>AA in MTEP11 West ITCM 3425 6318 12/31/2011 VMEU VMEU tap 1 34 Add new switches for tap IA In Service $110,000 Y C>B>AA in MTEP11 West ITCM 3426 6319 12/31/2013 Osage Osage 1 69 Move interconnect point IA Planned $0 Y C>B>AA in MTEP11 West ITCM 3499 6459 12/31/2011 NERC Alert Facility

Ratings for 2011Throughout system Verify and remediate facilities as required

due to the industry-wide NERC alertIA Planned Y C>B>A

A in MTEP11 West ITCM,MEC 2248 6585 6/1/2017 Ottumwa 1 345 New terminal at Ottumwa for Adair - Ottumwa 345 kV line. Add three 345 kV circuit breakers.


A in MTEP11 West ITCM/MEC 3213 5991 12/31/2015 Blackhawk Hazleton 1 345 1800 MVA Construct 345-161kV double circuit IA 12 Planned $23,866,416 Y Y Y B>AA in MTEP11 West ITCM/MEC 3213 6548 12/31/2015 Emery Blackhawk 1 345 Construct 345-161kV double circuit IA 29 Planned $57,677,172 Y Y Y B>AA in MTEP11 West ITCM/MEC 3213 6550 12/31/2015 Emery Blackhawk 1 161 Retire existing 161kV H frame circuit IA Planned $1,457,424 Y Y Y B>AA in MTEP11 West ITCM/MEC 3213 6549 12/31/2015 Emery Blackhawk 1 161 Construct 345-161kV double circuit and

transfer existing 161kV conductorIA Planned $0 Y Y Y B>A

A in MTEP11 West ITCM/MEC 3213 6551 12/31/2015 Blackhawk Hazleton 1 161 335 MVA Construct 345-161kV double circuit IA 12 Planned $0 Y Y Y B>AA in MTEP11 West ITCM/MEC 3213 6557 12/31/2015 Blackhawk Emery 1 345 345/161 kV double circuit line via Franklin IA 63 Planned $124,122,070 Y Y Y B>AA in MTEP11 West MDU 3199 5657 3/21/2011 Ellendale Transformer 1 230 115 150 new transformer, replace existing ND Under

Construction$2,000,000 Y B>A

A in MTEP11 West MDU 3199 5656 12/1/2011 Ellendale G359 POI 1 230 380 new line ND 24 Planned $12,400,000 Y B>A






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A in MTEP11 West MDU 3199 5658 12/1/2011 Ellendale Wavetrap on line to Oaks

230 new wave trap ND Planned $75,000 Y B>A

A in MTEP11 West MDU 3199 6407 12/1/2011 Merricourt New Generator Interconnection Substation

230 New Generator Interconnection Substation ND Planned $4,655,000 Y B>A

A in MTEP11 West MEC 2248 6565 6/1/2017 Ottumwa Iowa boarder 1 345 161 345/161 double circuit line IA 16.6 Planned $32,163,860 Y Y Y B>AA in MTEP11 West MEC 3022 6586 12/1/2014 Oak Grove 1 345 New 345 kV terminal at Oak Grove for Oak

Grove - Galesburg-Fargo 345 kV lineIL Planned $2,337,000 Y Y Y B>A

A in MTEP11 West MEC 3022 6564 12/1/2016 Sub 56 Sub 85 161 410 Reconductor Sub 56-Sub 85 161 kV line with T2- 556.5 ACSR conductor

IA 7.5 Planned $2,200,000 Y Y Y B>A

A in MTEP11 West MEC 3022 6562 6/1/2018 Oak Grove 345 kV terminal 345 add 345 kV terminal for Galesburg line IA Planned $2,336,952 Y Y Y B>AA in MTEP11 West MEC 3022 5989 6/1/2019 Oak Grove Galesburg 1 345 new 345/161 kV double circuit line IA 32 Planned $64,846,017 Y Y Y B>AA in MTEP11 West MEC 3205 5990 12/1/2016 Sheldon 345 New Sheldon three-way 345 kV Switching

StationIA Planned $10,450,000 Y Y Y B>A

A in MTEP11 West MEC 3205 5951 12/1/2016 Sheldon Webster 345 1739 Sheldon to Webster 345/161 kV double ckt line - Candidate MVP Portfolio #1. Includes rebuild of non-MISO 161 kV circuit from Wisdom to Webster.

IA 122 Planned $231,261,000 Y Y Y B>A

A in MTEP11 West MEC 3205 6561 12/1/2016 Burt 345 New three-way 345 kV Switching Station near Burt Substation


A in MTEP11 West MEC 3205 6560 12/1/2016 Webster 345 New terminal at Webster for Sheldon - Webster 345 kV line


A in MTEP11 West MEC 3213 5992 12/1/2015 Black Hawk Black Hawk 345 161 560 Black Hawk 345-161 kV substation with line terminals to Emery and Hazleton

IA Planned $15,019,000 Y Y Y

A in MTEP11 West MEC 3213 6424 12/1/2015 Franklin Butler 1 161 410 Rebuild Franklin-Butler 161 kV line. IA 26.24 Planned Y Y Y B>AA in MTEP11 West MEC 3213 6587 12/1/2015 Black Hawk Emery 345 1739 Blackhawk - Emery 345/161 kV double circuit

line via Franklin. Includes rebuild of non-MISO 161 kV circuit from Franklin to Emery.

IA 88 Planned $124,122,000 Y Y Y B>A

A in MTEP11 West MEC 3213 6427 12/1/2015 Black Hawk Hazleton 1 161 410 Rebuild Black Hawk-Hazleton 161 kV line. IA 24 Planned Y Y Y B>AA in MTEP11 West MEC 3213 6426 12/1/2015 Union Tap Black Hawk 1 161 410 Rebuild Union Tap-Black Hawk 161 kV line. IA 7.9 Planned Y Y Y B>AA in MTEP11 West MEC 3213 6425 12/1/2015 Butler Union Tap 1 161 410 Rebuild Butler-Union Tap 161 kV line. IA 15.93 Planned Y Y Y B>AA in MTEP11 West MEC 3213 6556 12/31/2015 Blackhawk 345-161 kV transformer 345 161 add 345-161 kV transformer & 2 line

terminalsIA Planned $15,019,305 Y Y Y B>A

A in MTEP11 West MEC 3268 6091 11/1/2012 Lehigh Reactor 345 50 Lehigh: 345 kV 50 MVAr Reactor IA Planned $2,750,000 Y C>B>AA in MTEP11 West MEC 3270 6093 6/1/2011 Council Bluffs River Bend 161 410 CBEC-River Bend 161 kV Rebuild IA 0.5 Planned $675,000 Y C>B>AA in MTEP11 West MEC 3271 6094 6/1/2011 River Bend Bunge 161 410 River Bend-Bunge 161 kV Rebuild IA 1.88 Planned $700,000 Y C>B>AA in MTEP11 West MEC 3272 6090 6/1/2011 Raun 345 1195 Replace 345 kV circuit breaker IA Planned $500,000 Y C>B>AA in MTEP11 West MEC, ITCM 2248 6566 6/1/2017 Ottumwa 345 kV terminal 345 add 345 kV terminal for Adair line IA Planned $3,294,904 Y Y Y B>AA in MTEP11 West MP 2549 4561 6/1/2014 15th AVE West Fond du Lac H.E. 1 115 182 MP Line #15 Upgarde MN 11.33 Planned $3,179,000 y y C>B>AA in MTEP11 West MP 2634 6369 12/1/2012 Savanna 1 115 Savanna 115 kV breaker Station MN Planned $2,600,000 Y Y B>AA in MTEP11 West MP 2634 6370 12/1/2014 Savanna Floodwood Tap 1 115 Thermal upgrade of Savanna-9 Line tap MN Planned $1,500,000 Y Y B>AA in MTEP11 West MP 3373 6244 12/30/2012 Blackberry Floodwood Tap 1 115 Thermal Upgrade MN 16 0 Planned $8,000,000 Y Y C>B>AA in MTEP11 West MP 3374 6245 11/1/2012 Diamond Lake (old

Greenway)115 23 15 re-energize existing substation MN Planned $700,000 Y C>B>A

A in MTEP11 West MP 3374 6246 11/1/2012 Diamond Lake (old Greenway)

Diamond Lake (old Greenway) 28L tap

1 115 re-energize existing 28L to Greenway MN Planned Y C>B>A

A in MTEP11 West MP 3374 6247 11/1/2012 Diamond Lake (old Greenway)

Diamond Lake (old Greenway) 45L tap

1 115 re-energize existing 45L to Greenway MN Planned Y C>B>A

A in MTEP11 West OTP 2856 5009 6/30/2011 Victor 41.6 kV New Effington 41.6 kV 41.6 24 MVA Rebuild Existing 4-Mile 41.6 kV Line SD In Service $200,000 Y C>B>AA in MTEP11 West OTP 3466 6392 8/1/2012 Doran Tap Doran 41.6 kV 1 41.6 Add 3 Way Switch on 41.6 kV line between

Doran 41.6 kV substation to Doran Jct.MN Planned $140,000 Y B>A

A in MTEP11 West OTP 3481 6432 7/1/2013 Buffalo 115 kV Casselton Ethanol 115 kV

1 115 337 MVA Construct new 16-mile 115 kV line from Buffalo - Casselton

ND 16 Planned $7,000,000 Y Y C>B>A

A in MTEP11 West OTP 3481 6434 12/31/2014 Buffalo 345 kV Buffalo 115/41.6 kV 1 345 115 187 MVA Replace existing 112 MVA 345/115/41.6 kV transformer with a new 187 MVA 345/115/41.6 kV transformer

ND Planned $3,000,000 Y Y C>B>A






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A in MTEP11 West OTP, MDU 2220 4092 12/31/2019 Big Stone South Ellendale 345 Line SD/ND 145 Planned $300,000,000 Y Y Y B>AA in MTEP11 West OTP, MDU 2220 6382 12/31/2019 Ellendale 345/230 Transformer 345 230 Transformer 345/230 ND Planned $26,164,000 Y Y Y B>AA in MTEP11 West OTP, XEL 2221 4116 12/31/2017 Big Stone South 345/230 Transformer 1 345 230 672 MVA Transformer #1 345/230/13.8 kV SD Planned $4,000,000 Y Y Y B>A

A in MTEP11 West OTP, XEL 2221 4117 12/31/2017 Big Stone South Brookings 345 kV double circuit

1,2 345 Line #1 and #2 SD 65 Planned $165,000,000 Y Y Y B>A

A in MTEP11 West OTP, XEL 2221 6572 12/31/2017 Brookings County Substation 345 Termination for Big Stone - Brookings Co 345 kV line and conversion of the existing ring bus to a breaker-and-a-half

SD Planned $9,720,000 Y Y Y B>A

A in MTEP11 West OTP, XEL 2221 6588 12/31/2017 Big Stone South Sub Equipment 345 230 Substation Equipment SD Planned $30,000,000 Y Y Y B>AA in MTEP11 West OTP, XEL 2221 6387 12/31/2017 Big Stone South 345/230 Transformer 2 345 230 672 MVA Transformer #2 345/230/13.8 kV SD Planned $4,000,000 Y Y Y B>A

A in MTEP11 West OTP, XEL 2221 6589 12/31/2017 Big Stone 230 Big Stone 230 230 230 Substation Equipment SD Planned $10,000,000 Y Y Y B>AA in MTEP11 West OTP, XEL 2221 6383 12/31/2017 Big Stone Big Stone South 1 230 Line #1 SD 2 Planned $2,000,000 Y Y Y B>AA in MTEP11 West OTP, XEL 2221 6384 12/31/2017 Big Stone Big Stone South 2 230 Line #2 SD 2 Planned $2,000,000 Y Y Y B>AA in MTEP11 West OTP/XEL 3481 6433 12/31/2014 Mapleton 115 kV Sheyenne 115 kV 1 115 147 MVA Rebuild 8 mile portion of the existing

Sheyenne - Mapleton 115 kV line from 266 ACSR conductor to 795 ACSS conductor

ND 8 Planned $4,000,000 Y Y C>B>A

A in MTEP11 West XEL 1203 4224 1/22/2014 Franklin Transformer 2 115 69 70 Upgrade 47 MVA to 70 MVA (Time line is dependant on SW MN - Twinc Cities 345 kV line

MN Planned $4,000,000 Y Y NT B>A

A in MTEP11 West XEL 1203 1897 1/22/2014 Franklin Transformer 1 115 69 70 Upgrade 47 MVA to 70 MVA (Time line is dependant on SW MN - Twinc Cities 345 kV line

MN Planned $2,400,000 Y Y NT B>A

A in MTEP11 West XEL 3309 6145 8/1/2011 Pipestone 1 115 Retap the breaker CTs going to Buffalo Ridge to 2000:5.

MN Planned Y C>B>A

A in MTEP11 West XEL 3309 6144 8/1/2011 Buffalo Ridge 1 115 Upgrade the wave traps and line switches at Buffalo Ridge going to Lake Yankton and Pipestone substations from 1200 A to 2000 A.

MN Planned $286,000 Y C>B>A

A in MTEP11 West XEL 3310 6150 6/1/2012 Victoria tap West Creek 1 115 361 New 115 kV line MN 1 1 Planned $19,450,000 Y C>B>AA in MTEP11 West XEL 3310 6154 6/1/2012 Chaska Scott County 1 115 upgrade 69 kV line to 115 kV MN 1.9 Planned Y C>B>AA in MTEP11 West XEL 3310 6148 6/1/2012 Augusta Victoria tap 1 115 361 Upgrade 69 kV line to 115 kV MN 1.5 Planned Y C>B>AA in MTEP11 West XEL 3310 6149 6/1/2012 Victoria 115 Upgrade substation to 115 kV MN Planned Y C>B>AA in MTEP11 West XEL 3310 6156 6/1/2012 Chaska 115 Add new line termination MN Planned Y C>B>AA in MTEP11 West XEL 3310 6155 6/1/2012 West Waconia 115 Add new line termination MN Planned Y C>B>AA in MTEP11 West XEL 3310 6146 6/1/2012 West Waconia Augusta 1 115 361 upgrade 69 kV line to 115 kV MN 1 2.5 Planned Y C>B>AA in MTEP11 West XEL 3310 6152 6/1/2012 West Creek Chaska 1 115 361 Upgrade 69 kV line to 115 kV MN 1.9 1 Planned Y C>B>AA in MTEP11 West XEL 3310 6151 6/1/2012 West Creek 115 New 115 kV disttribution substation MN Planned Y C>B>AA in MTEP11 West XEL 3310 6147 6/1/2012 Augusta 115 Upgrade substation to 115 kV MN Planned Y C>B>AA in MTEP11 West XEL 3310 6153 6/1/2012 Chaska 115 Upgrade 69 kV substation to 115 kV MN Planned Y C>B>AA in MTEP11 West XEL 3312 6158 6/1/2014 Minnesota Valley Maynard 1 115 361 upgrade existing 115 kV line to higher

capacityMN 10.89 Planned $5,790,000 Y Y C>B>A

A in MTEP11 West XEL 3312 6159 6/1/2014 Maynard Kerkhoven tap 1 115 361 upgrade existing 115 kV line to higher capacity

MN 14.8 Planned $7,870,000 Y Y C>B>A

A in MTEP11 West XEL 3313 6160 6/1/2012 SMMPA New Prague tap 69 Install 1 way switch MN Planned $180,000 Y C>B>A

A in MTEP11 West XEL 3314 6161 6/1/2014 Kohlman Lake Long Lake 2 115 361 Convert the bifurcated 115 kV line to double circuit

MN 0.08 Planned $3,000,000 Y C>B>A

A in MTEP11 West XEL 3314 6163 6/1/2014 Long Lake 115 Add new line termination MN Planned Y C>B>AA in MTEP11 West XEL 3314 6162 6/1/2014 Kohlman Lake 115 Add new line termination MN Planned Y C>B>AA in MTEP11 West XEL 3315 6165 6/1/2014 Chisago County 345 Install breakers to accommodate the new TR MN Planned Y C>B>AA in MTEP11 West XEL 3315 6164 6/1/2014 Chisago County 5 345 115 448 Install 2nd 345/115 kV transformer MN Planned $7,000,000 Y C>B>AA in MTEP11 West XEL 3315 6166 6/1/2014 Chisago County 115 Install breakers to accommodate the new TR MN Planned Y C>B>AA in MTEP11 West XEL 3316 6167 6/1/2014 Riverside Apache 1 115 361 Upgrade line to higher capacity MN 3.5 Planned $3,000,000 Y C>B>AA in MTEP11 West XEL 3316 6168 6/1/2014 Apache 115 Upgrade Apache switch MN Planned Y C>B>A






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A in MTEP11 West XEL 3317 6169 6/1/2014 Goose Lake Kohlman Lake 2 115 361 Build 2nd Goose Lake - Kohlman Lake circuit by rebuilding the existing line to double circuit.

MN 3.2 Planned $6,000,000 Y Y C>B>A

A in MTEP11 West XEL 3317 6171 6/1/2014 Kohlman Lake 115 361 Install breakers to accommodate 2nd line to Goose Lake

MN Planned Y Y C>B>A

A in MTEP11 West XEL 3317 6170 6/1/2014 Goose Lake 115 361 Install breakers to accommodate 2nd line to Kohlman Lake

MN Planned Y Y C>B>A

A in MTEP11 West XEL 3318 6172 10/1/2011 Parkers Lake 115 Replace the Parkers Lake breakers 5M48, 5M49, 5M50, 5M51, 5M52, 5M53, 5M57, 5M58, and 5M62

MN Planned $1,900,000 Y C>B>A

A in MTEP11 West XEL 3319 6173 12/1/2011 Split Rock 115 Replace the Split Rock breakers 5X28, 5X29, 5X32, 5X34, 5X35, 5X36, 5X75, 5X76, 5X77, 5X81, and 5X83

SD Planned $1,344,000 Y C>B>A

A in MTEP11 West XEL 3320 6174 12/1/2011 Split Rock 115 Replace the broken 50 MVAR reactor and failed associated breaker at the Split Rock substation

SD Planned $100,000 Y C>B>A

A in MTEP11 West XEL 3321 6175 1/14/2011 Chemolite 115 Two breakers will be added to complete Breaker and 1/2 configuration

MN In Service $580,000 Y C>B>A

A in MTEP11 West XEL 3322 6178 6/1/2013 Colfax Wheeler 1 69 Rebuild line ot 477 ACSR WI 3.7 Planned Y C>B>AA in MTEP11 West XEL 3322 6177 6/1/2013 Hay River Colfax 1 69 Rebuild line ot 477 ACSR WI 0.8 Planned Y C>B>AA in MTEP11 West XEL 3322 6176 6/1/2013 Cedar Falls Hay River 1 69 Rebuild line ot 477 ACSR WI 7.6 Planned Y C>B>AA in MTEP11 West XEL 3322 6179 6/1/2013 Wheeler Ridgeland 1 69 Rebuild line ot 477 ACSR WI 10.2 Planned Y C>B>AA in MTEP11 West XEL 3322 6180 6/1/2013 Ridgeland Clear Lake 69 Rebuild line ot 477 ACSR WI 20.4 Planned $14,000,000 Y C>B>AA in MTEP11 West XEL 3323 6182 12/1/2012 Park Falls 115 Install new termination on straight bus at

Park Falls for radial lineWI Planned Y C>B>A

A in MTEP11 West XEL 3323 6181 12/1/2012 Flambeau Bio 115 13.8 Install new Customer supply sub WI Planned Y C>B>AA in MTEP11 West XEL 3323 6465 12/1/2012 Park Falls Osprey 1 115 120 Rebuild 27 miles from 2/0 ACSR to 477

ACSRWI 27 Planned $18,000,000 Y C>B>A

A in MTEP11 West XEL 3323 6183 6/1/2013 Park Falls Flambeau Bio 1 115 Install ~1.5 miles of 336 ACSR 115 kV line WI Planned $5,769,000 Y C>B>AA in MTEP11 West XEL 3324 6184 12/1/2011 Eau Claire 69 Replace overstressed Eau Claire 69 kV

breakers. 4E185, 4E186, 4E187, 4E188, 4E189, 4E190, 4E191, 4E192, 4E193, 4E195.


A in MTEP11 West XEL 3325 6187 12/1/2012 Orono Crow River 1 115 Run an in and out to Orono from the Medina - Crow River line

MN 0.5 Planned Y C>B>A

A in MTEP11 West XEL 3325 6186 12/1/2012 Orono Medina 1 115 Run an in and out to Orono from the Medina - Crow River line

MN 0.5 Planned Y C>B>A

A in MTEP11 West XEL 3325 6185 12/1/2012 Orono 115 Convert sub to 115 kV MN Planned $5,340,000 Y C>B>AA in MTEP11 West XEL 3326 6188 6/1/2012 Black Dog Savage 1 115 239 Rebuild line to 795 ACSS MN Planned $4,564,000 Y C>B>AA in MTEP11 West XEL 3327 6190 12/1/2011 Sterling Madison Street 1 69 117 Replace .4 miles of 4/0 conductor with 795

ACSRWI 0.4 Planned Y C>B>A

A in MTEP11 West XEL 3327 6189 12/1/2011 Eau Claire Sterling 1 69 68 Replace .5 miles of 4/0 conductor with 795 ACSR

WI 0.5 Planned $1,600,000 Y C>B>A

A in MTEP11 West XEL 3454 6366 6/1/2013 Hollydale 1 115 13.8 Rebuild substation for 115 kV line MN Planned $4,340,000 N Y C>B>AA in MTEP11 West XEL 3454 6365 6/1/2013 Hollydale Pomerleau Lake 1 115 361 Rebuild 69 kV line from Hollydale to new

Plymouth area substationMN 3.4 Planned $3,690,000 N Y C>B>A

A in MTEP11 West XEL 3454 6367 6/1/2013 Pomerleau Lake switching station 1 115 New 115 kV switching station to tie 115 kV line to Medina into the GRE Parkers Lake - Elm Creek line.

MN Planned $7,880,000 N Y C>B>A

A in MTEP11 West XEL 3473 6403 6/1/2014 Sioux Falls (New) 115 13.8 New 115/13.8 kV substation located near the existing Sioux Falls substation

SD Planned Y C>B>A

A in MTEP11 West XEL 3473 6404 6/1/2014 Lawrence 115 34.5 Rebuild 115 kV yard to breaker and a half to accommodate new 115 kV line

SD Planned Y C>B>A

A in MTEP11 West XEL 3473 6402 6/1/2014 West Sioux Falls 115 13.8 Add new line termination and breaker SD Planned Y C>B>AA in MTEP11 West XEL 3473 6401 6/1/2014 Sioux Falls (New) West Sioux Falls 1 115 361 Rebuild line to 115 kV SD 4.3 Planned Y C>B>AA in MTEP11 West XEL 3473 6400 6/1/2014 Lawrence Sioux Falls (New) 1 115 361 Rebuilding line to 115/69 kV double circuit SD 5.4 Planned $35,000,000 Y C>B>A






Max kV


Miles Upg.


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Postage Stamp


A in MTEP11 West XEL 3474 6405 6/1/2012 Adams 345 Install a 50 MVAR reactor on the Pleasant Valley line, along with breaker and disconect switch

MN Planned $2,260,000 Y C>B>A

A in MTEP11 West XEL 3475 6406 6/1/2014 MPC Prairie NSP Prairie 7 230 115 230/115 kV 336 MVA transformer and 230 kV line from MPC Prairie to NSP Prairie

ND Planned $12,000,000 Y C>B>A

A in MTEP11 West XEL 3476 6408 6/1/2014 Cass Coutny 1 345 115 448 New 345/115 kV transformer and 3 row 115 kV breaker and Half


A in MTEP11 West XEL 3476 6409 6/1/2014 Maple River Cass County 1 345 2390 New 4.5 mile 345kV line from Maple River to Cass Coutny substation

ND 4.5 Planned $4,436,000 Y C>B>A

A in MTEP11 West XEL 3476 6410 6/1/2014 Maple River 345 New 345 kV breakers at Maple River substation to accommodate the proposed 345 kV line


A in MTEP11 West XEL 3509 6480 1/1/2013 Iron River Ownership change near Lakeside

1 115 230 Rebuild 5 miles of 115 kV from 336 ACSR to 795 ACSR


A in MTEP11 West XEL 3509 6479 1/1/2013 Ino Pump Iron River 1 115 230 Rebuild 9 miles of 115 kV from 336 ACSR to 795 ACSR


A in MTEP11 West XEL 3509 6478 1/1/2013 Bayfront Ino Pump 1 115 230 Rebuild 19 miles of 115 kV from 336 ACSR to 795 ACSR


A in MTEP11 West XEL, GRE 3454 6364 6/1/2013 Medina Hollydale 1 115 361 Rebuild 4.6 Miles of 69 kV line to 795 ACSS 115 kV

MN 4.6 Planned $7,380,000 N Y C>B>A

A in MTEP11 AmerenIL 3022 6554 6/1/2019 Galesburg 345/138 kV transformer 1 345 138 560 MVA new Planned Y Y Y B>AA in MTEP03 Central SIPC 81 60 9/1/2012 Power Plant Carrier Mills 161kV 161 25-mile 161kV transmission line from

Southern Illinois Power Cooperative's power plant to a new 161/69kV substation

IL 25 Planned $9,200,000 Y A

A in MTEP09 Central Ameren 1240 1940 6/1/2012 Sioux Huster 3 138 370 Reconductor 13 miles MO 13 Planned $5,550,000 Y Y AA in MTEP09 Central Ameren 1240 1939 6/1/2012 Sioux Huster 1 138 370 Reconductor 15 miles MO 15 Planned $5,550,000 Y Y AA in MTEP08 Central Ameren 1235 1934 6/1/2016 Fredericktown AECI Fredericktown Tap 1 161 250 Increase ground clearance MO 12 Planned $1,200,000 Y A

A in MTEP08 Central Ameren 1238 1937 11/17/2011 GM 161 kV Sub. AECI Enon Substation 1 161 280 Extend 1 mile of line to AECI Enon Substation

MO 1 Planned $1,896,500 Y A

A in MTEP07 Central Ameren 152 399 11/30/2011 Big River Rockwood 1 138 339 new line MO 10 Planned $13,381,100 Y Y AA in MTEP10 Central AmerenIL 1528 2604 6/1/2012 Rising Transformer 1 345 138 560 Replace existing transformer with a 560 MVA IL Planned $5,000,000 Y AA in MTEP10 Central AmerenIL 1535 2612 6/1/2012 Wood River Stallings 1 138 259 Replace terminal equipment at Stallings,

reconductor section of line (Line # 1456)IL 6 Planned $2,036,000 Y A

A in MTEP10 Central AmerenIL 2064 3973 6/1/2012 South Bloomington Diamond Star Tap 1 138 382 Reconductor 3.33 miles of 336 ACSR in S Bloomington - Danvers line to 1600 Amps

IL 3.33 Planned $2,113,000 Y A

A in MTEP10 Central AmerenIL 2288 4204 6/1/2012 Line 1364 (new tap) Washington Street Substation

2 138 Tap 138 kV Line 1364 for 'in-out' arrangement, replace Line 1326 w/ 'in-out'

IL 0.17 Planned $4,155,000 Y A

A in MTEP10 Central AmerenIL 2957 5155 12/31/2012 Edwards Plant Tazewell 2 138 322 Edwards-Tazewell 138 kV Line 1373 - Reconductor 1.57 miles of 795 kcmil ACSR conductor and 7.5 miles of 927 kcmil ACAR conductor with conductor capable of carrying 1600 A under summer emergency conditions. Replace a 1200 A wavetrap and CT's at Edwards.

IL 9.07 Planned $121,000 Y A

A in MTEP10 Central AmerenIL 2986 5190 6/1/2014 Wood River-Stallings-1456

Tap to Supply North Alton 138-34.5 kV Sub

1 138 240 North Alton 138-34.5 kV Substation Supply - Supply new 138-34.5 kV Substation from an in-out connection to the Wood River-Stallings-1456 138 kV line. Approximately 4 miles of double-circuit 138 kV line needed.

IL 4 Planned $6,445,500 Y A

A in MTEP10 Central AmerenIL 2986 5189 12/1/2015 Wood River-North Staunton-1436

Tap to Supply North Alton 138-34.5 kV Sub

1 138 240 North Alton 138-34.5 kV Substation Supply - Supply new 138-34.5 kV Substation from an in-out connection to the Wood River-Stallings-1456 138 kV line. Approximately 4 miles of double-circuit 138 kV line needed.







Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP10 Central AmerenIL 2992 5197 6/1/2014 Bondville S.W. Campus 1 138 411 Bondville-S.W. Campus 138 kV - Construct 8 miles of new 138 kV line. Construct 138 kV Ring Bus at Bondville (2 new PCB's) and a 138 kV Ring Bus at Champaign S.W. Campus (4 new PCB's).

IL 8 Planned $10,000,000 Y A

A in MTEP09 Central AmerenIL 2273 4187 6/1/2013 LaFarge 161 kV Supply to Customer Substation

161 Provide 161 kV supply to customer substation

IL Planned $570,000 Y A

A in MTEP09 Central AmerenIL 2279 4195 10/5/2011 Campbell Steelville 1 138 220 Reconductor 477 kcmil ACSR to carry 1200 A summer emergency

IL 6.19 Planned $1,866,000 Y A

A in MTEP09 Central AmerenIL 2472 4446 12/1/2016 Maple Ridge 345 kV Switching Station

New Substation 345 Install switching station in Duck Creek-Tazewell 345 kV line

IL Planned $6,523,000 Y Y Y A

A in MTEP09 Central AmerenIL 2472 4444 12/1/2016 Fargo 345/138 kV New Substation 345 138 560 Install 560 MVA, 345/138 kV Transformer IL Planned $9,370,000 Y Y AA in MTEP09 Central AmerenIL 2472 4445 12/1/2016 Fargo Maple Ridge 1 345 1793 Install approximately 20 miles of new line to

supply Fargo SubstationIL 20 Planned $62,275,000 Y Y Y A

A in MTEP08 Central AmerenIL 1529 2605 12/22/2011 Brokaw State Farm Line 1596 1 138 337 Reconductor to 2000 A Summer Emergency IL 3.2 Planned $2,566,900 Y AA in MTEP08 Central AmerenIL 2060 3958 6/1/2012 East Peoria Flint 1 138 233 Reconductor to 1200 A capability IL 4.54 Planned $2,113,000 Y AA in MTEP08 Central AmerenIL 2068 3964 12/1/2014 Latham Oreana 1 345 1195 Build 8.5 miles of 345 kV line and remove the

Latham - Maroa W connectionIL 8.5 Planned $35,077,000 Y Y Y A

A in MTEP08 Central AmerenIL 2069 3962 12/1/2014 Brokaw South Bloomington 1 345 1793 Build approximately 5 miles of 345 kV line from Brokaw - South Bloomington substation

IL 5 Planned $13,429,000 Y Y Y A

A in MTEP08 Central AmerenIL 2069 3963 12/1/2014 South Bloomington South Bloomington XFMR

1 345 138 560 Install 560 MVA 345/138 kV transformer at South Bloomington substation

IL Planned $6,600,000 Y Y A

A in MTEP06 Central AmerenIL 739 1432 11/1/2012 Line 4561 Tap Franklin County Power Plant

1 345 345 kV connection (new ring bus) to new generation

IL Planned $6,410,900 Y A

A in MTEP05 Central AmerenIL 725 1418 4/26/2012 N. LaSalle Wedron Fox River 1 138 266 2 CB at N LaSalle, 1 CB at Wedron Fox River Substation

IL 25 Planned $21,357,530 Y A

A in MTEP05 Central AmerenIL 726 1419 7/30/2013 Ottawa Wedron Fox River 1 138 266 1 CB at Ottawa, new 138 kV line to Wedron Fox River Substation


A in MTEP10 Central AmerenMO 2972 5172 6/1/2012 Bailey Joachim 1 138 411 Sandy Creek-Joachim-1 138 kV Line - Reconductor 6.2 miles of 795 kcmil ACSR with conductor having 1600 A summer emergency capability between Sandy Creek and Bailey Substations

MO 0.5 Planned $246,700 Y A

A in MTEP10 Central AmerenMO 2972 5173 6/1/2012 Bailey Sandy Creek 1 138 322 Sandy Creek-Joachim-1 138 kV Line - Reconductor 6.2 miles of 795 kcmil ACSR with conductor having 1600 A summer emergency capability between Sandy Creek and Bailey Substations

MO 6.2 Planned $3,059,000 Y A

A in MTEP10 Central AmerenMO 2976 5177 12/1/2012 Cahokia-Central-1 Relocate Central 138-34.5 kV Substation

1 138 370 Central 138-34.5 kV Substation - Relocate Substation - Reterminate Cahokia-Central-1 138 kV line to the new Central Substation. New substation will be located roughly one-half mile from existing substation.

MO Planned $1,544,300 Y A

A in MTEP10 Central AmerenMO 2976 5178 12/1/2012 Cahokia-Central-2 Relocate Central 138-34.5 kV Substation

2 138 370 Central 138-34.5 kV Substation - Relocate Substation - Reterminate Cahokia-Central-2 to the new Central Substation. New substation will be located roughly one-half mile from existing substation.


A in MTEP10 Central AmerenMO 2976 5179 12/1/2012 Central-Watson-1 Relocate Central 138-34.5 kV Substation

1 138 367 Central 138-34.5 kV Substation - Relocate Substation - Reterminate Central-Watson-1 138 kV line to the new Central Substation. New substation will be located roughly one-half mile from existing substation.


A in MTEP10 Central AmerenMO 3107 5444 6/17/2011 Arnold Tyson 3 138 241 Install 4-138 kV Breakers at Arnold Substation and rearrange 138 kV bus configuration at Arnold Substation.

MO Planned $570,800 Y A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP10 Central AmerenMO 3107 5447 6/17/2011 Arnold Meramec 4 138 241 Install 4-138 kV Breakers at Arnold Substation and rearrange 138 kV bus configuration at Arnold Substation.


A in MTEP10 Central AmerenMO 3107 5446 6/17/2011 Arnold Tyson 4 138 241 Install 4-138 kV Breakers at Arnold Substation and rearrange 138 kV bus configuration at Arnold Substation.


A in MTEP10 Central AmerenMO 3107 5445 6/17/2011 Arnold Meramec 3 138 240 Install 4-138 kV Breakers at Arnold Substation and rearrange 138 kV bus configuration at Arnold Substation.


A in MTEP10 Central DEM 1520 2596 6/1/2017 Durbin 230/69 substation 1 230 69 Build a new 230 69kv 150mva sub with 2 69kv line terminals

IN Planned $7,000,000 Y A

A in MTEP10 Central DEM 1903 3800 6/1/2014 Fishers North Fishers 69 1 69 245 Reconductor 1.05 miles 69kV line from Fishers No to Fishers with 954ACSR@100C conductor

IN 1.05 Planned $455,229 NT A

A in MTEP10 Central DEM 2050 5033 12/31/2011 Dresser Trans Sub 345 138 Reconfigure Dresser substation bus and breakers, etc. for final Bank 3 configuration.

IN Under Construction

$2,980,000 Y Y A

A in MTEP10 Central DEM 2123 2908 6/1/2012 Bloomington 230 Martinsville SE Jct 1 69 153 Bloomington to Martinsville 69kV - 6903 ckt. - Rebuild 9.2 miles of 336ACSR with 954ACSR@100C

IN 9.2 Planned $2,020,000 NT A

A in MTEP10 Central DEM 2134 2919 6/30/2013 Bloomington 230 Needmore Jct. 1 69 143 Bloomington 230kV Sub to Needmore Jct (Pole #825-3379) reconductor 6949 line with 954ACSR 100C conductor and replace (2) Needmore Jct. 69kV - 600 amp switches with 1200 amp switches. Old PIN 804J3052

IN 10.85 Planned $2,712,500 NT A

A in MTEP10 Central DEM 2136 2921 6/30/2012 Greenwood HE Honey Creek Jct

Frances Creek Jct 1 69 100 Greenwood HE Honey Creek Jct to Frances Creek Jct uprate 69kV - 69102 line 1.12 mile for 100C


A in MTEP10 Central DEM 2137 2922 6/30/2012 Greenwood Averitt Rd Jct

HE Honey Creek Jct 1 69 100 Greenwood Averitt Rd Jct to HE Honey Creek Jct 69 kV - 69102 Uprate 1.05 mile line section of 477acsr for 100C conductor temperature operation


A in MTEP10 Central DEM 2143 2929 6/1/2014 Frances Creek bank 2 2 345 69 200 Add Frances Creek 345/69kV Bank 2 - 200MVA with LTC

IN Planned $6,887,000 NT A

A in MTEP10 Central DEM 2858 5011 6/1/2017 Geist Fortville 1 69 153 Reconductor 69kV 3.62 mile line from Geist sub to Fortville sub with 954ACSR conductor.

IN 3.62 Planned $1,820,000 NT A

A in MTEP10 Central DEM 2859 5012 6/1/2012 Peru Muni Jct Wabash Jct 1 69 100 Peru Muni J to Wabash J 6986 Reconductor approx., 10.3 miles of 4/0 ACSR with 477 ACSR

IN 10.3 Planned $3,810,000 NT A

A in MTEP10 Central DEM 2860 5013 6/1/2012 Brazil East Reelsville Jct 1 69 100 Reconductor 6938 line from Brazil East to Reelsville Jct. with 477ACSR 100C conductor. Replace Reelsville Jct switches with 1200 amp switches.

IN 6.58 Planned $2,550,000 NT A

A in MTEP10 Central DEM 2861 5014 6/1/2012 Greencastle Madison J Greencastle Ind Pk 1 69 143 Reconductor 6996 line from Greencastle Madison Jct. to Greencastle East Jct. to Greencastle Ind. Pk. with 954ACSR 100C conductor. Replace or upgrade 2-600 amp Greencastle East Jct switches to 1200amp.

IN 5.83 Planned $1,482,000 NT A

A in MTEP10 Central DEM 2863 5016 6/2/2012 Carmel SE new Jct in 69145 ckt. 1 69 143 Build new 69kV-954ACSR circuit from Carmel SE to new Jct in the 69145 line on Cumberland Rd, completing a loop from Carmel 146th St to Geist. also, (AMIN0057) Carmel SE Bank 2 69kV 22.4MVA; retire the 138-12kV existing bank fed from IPL (NERC tie)







Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP10 Central DEM 2865 5018 6/1/2012 Frankfort Burlington St Middlefork 1 69 53 Frankfort Brlngtn St to Midfrk - 69133 ckt - uprate 11.5 miles of 4/0ACSR to 100C and reconductor 1.0 mile of 2/0CUB7 to 954ACSR@100C


A in MTEP10 Central DEM 2869 5022 6/1/2012 Zimmer 345kV sub Trans Sub 345 Replace 345kV gas insulated sub with an air insulated sub

OH Under Construction

$4,032,000 Y A

A in MTEP10 Central DEM 2871 5024 12/31/2011 EKPC Hebron 138/69 substation 1 138 69 Add new EKPC Hebron 138/69kV transformer (outside DEM area 208). Includes 3 position – 138kV CB ring bus and associated Duke owned facilities (inside DEM area 208). 138kv Tie from DEM to EKPC is being revised slightly. 100% to be paid for by EKPC.

KY Planned $3,345,000 Y A

A in MTEP10 Central DEM 2872 5025 12/31/2011 Manhattan new dist sub 1 138 12 Install 1200A - 138kv line switching on both sides of proposed tap line to new joint use DEM/WVPA Manhattan distribution sub in the 13802 ckt.

IN Planned $525,723 Y A

A in MTEP10 Central DEM 2874 5027 12/1/2011 Noblesville Gen. Station Geist 1 230 319 Relocate section of 23007 between Noblseville and Giest to new RoW around expanding mine operation - approx. 0.6 mile of added line length

IN 0.6 Planned $1,766,218 Y A

A in MTEP10 Central DEM 2875 5028 12/31/2011 Edwardsville new dist sub 1 138 12 Construct new Edwardsville 138/12kV distribution substation - single 22.4 MVA transformer

IN Planned $467,387 NT A

A in MTEP10 Central DEM 2876 5029 6/1/2013 Red Bank Trans Sub 345 Replace 345kV gas insulated bus with an air insulated bus

OH Planned $3,467,832 Y A

A in MTEP10 Central DEM 2877 5030 12/31/2015 West End Trans Sub 138 13.2 Modifications to West End Substation facilities, 138 kV transmission lines and distribution lines to accommodate Brent Spence Bridge project


A in MTEP10 Central DEM 2878 5031 6/1/2014 Miami Fort Trans Sub 345 Replace 345kV gas insulated bus with an air insulated bus and Miami Fort-Tanner Cir 4504 Relocate


A in MTEP10 Central DEM 2879 5032 12/31/2012 Brazil West new dist sub 1 69 12 Construct Brazil West 10.5MVA 69/12kV sub in the 6902 Line to be located on 900N east of 425W


A in MTEP10 Central DEM 2882 5035 12/31/2012 Lateral 138kV Bus 7 to Bus 8 tie 138 478 Replace bus tie breaker #840 and associated disconnect sw's - new limits will be CB - 3000A and D/S's - 2000A.

OH Planned $445,302 Y A

A in MTEP09 Central DEM 1647 3378 6/1/2012 Carmel SE 69/12 substation 69 12 245 Construct Carmel SE Bank 1 22.4MVA bank with 2 exits - extend a new radial 69kv - 954ACSS@200C from Carmel 146th St (no new bkr - share dist bk terminal)

IN 4 Planned $2,000,000 NT A

A in MTEP09 Central DEM 1880 3774 12/31/2012 Columbia distribution sub 138 12 Columbia 138kV-22.4MVA Sub - New site or purchase and rebuild existing Siemens Sub #537- in F5484 between Warren and Maineville


A in MTEP09 Central DEM 2127 2912 6/1/2019 Martinsville 69 69163-1 switch 69 143 69163-1 switch replacement near tap to HE Cope with 1200A switch


A in MTEP09 Central DEM 2132 2917 6/30/2012 Frances Creek capacitor 69 36 MVAR Frances Creek Install 36MVAR 69kV capacitor bank


A in MTEP09 Central DEM 2133 2918 6/1/2012 Franklin 230 Franklin Forsythe 2 69 143 Franklin 230 sub to Forsythe 69 sub - Build new 3.5 mile 69kV - 69159 line; new line terminal at Forsythe; use existing terminal at Franklin 230







Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP09 Central DEM 2148 2935 5/1/2012 Cadiz Milner's Corner Jct 1 69 143 Cadiz-Markleville-Milner's Corner J - Reconductor 69kv - 69131 ckt - 9.24 mile section with 477ACSR@100C; Replace 69kv three way switch at Milner's Corner Jct with three one way 1200A switches; Upgrade the Markleville 600A switches #1 and #2 to 1200A

IN 9.24 Planned $3,208,251 NT A

A in MTEP09 Central DEM 2149 2936 12/31/2011 West End bus tie bkr & line bkr 1 138 478 West End substation - Install a 138kV circuit breaker to tie the east and west 138 kV busses together and a line breaker in the 1389 ckt

OH Under Construction

$1,040,000 Y A

A in MTEP09 Central DEM 2153 2941 6/1/2017 Mohawk Lee Hanna 1 69 71.7 Mohawk to Lee Hanna 69kV reconductor 69130 ckt (5.27 mi) with 954acsr@100C

IN 5.27 Planned $2,317,000 NT A

A in MTEP09 Central DEM 2154 2942 12/31/2013 Carmel Rohrer Rd. distribution sub 69 12 Carmel Rohrer Rd 69/12-22.4MVA sub to looped through the 6989 ckt. at or near the existing Carmel Shell Oil tap

IN 0.4 0.4 Planned $591,143 NT A

A in MTEP09 Central DEM 2327 4259 6/1/2013 Speed HE Bethany 1 69 53 Speed to HE Bethany 69kV - 6955 Reconductor Ph1 - Replace 5.2 miles of 3/0 ACSR with 477 ACSR (new limiter 4/0acsr @ 80C)


A in MTEP09 Central DEM 2331 4263 6/1/2012 Shelbyville NE Knauf 1 69 153 Shelbyville NE to Knauf Reconductor 1.75 miles of 397ACSR on 6946 ckt. with 954acsr@100C


A in MTEP09 Central DEM 2332 4264 6/1/2012 Zionsville Turkeyfoot Zionsville 96th St Jct 1 69 153 Zionsville Turkeyfoot to Zionsville 96th St Jct Reconductor 1.59 mile 69kV - 69155 ckt with 954ACSR@100C


A in MTEP09 Central DEM 2334 4266 6/1/2012 Fishers 106th St distribution sub 69 12 New Fishers 106th St 69/12 kv sub: Construct 69kV line in and out of sub and 69kv bus; located in the proposed loop between Carmel SE 69 sub and Fishers 69145


A in MTEP08 Central DEM 834 3071 6/1/2014 Kingman Capacitor 69 7.2 MVAR Add capacitor IN Planned $500,000 NT AA in MTEP08 Central DEM 835 3072 6/1/2013 Pittsboro Capacitor 69 14.4 MVAR Add capacitor IN Planned $422,362 NT AA in MTEP08 Central DEM 841 820 6/1/2015 Westwood Bk1 transformer 1 345 138 369.4 Replace 1600A 138kV breaker with 3000A to

allow full xfr rating.IN Planned $141,623 Y A

A in MTEP08 Central DEM 1245 1959 6/1/2014 Potato Creek Switching Station

69 Construct 69kV switching station IN Planned $1,007,000 NT A

A in MTEP08 Central DEM 1245 1958 6/1/2014 Frankfort Jefferson Potato Creek 69 153 69178 Build 2.7 miles of 954 ACSR 69kV IN 2.7 Planned $1,087,115 NT AA in MTEP08 Central DEM 1501 2574 6/1/2014 Carmel 146th St Capacitor 2 69 36 MVAR Install a 2nd 69kV 36MVAR cap bank IN Planned $624,145 NT AA in MTEP08 Central DEM 1512 4270 6/1/2012 Ridgeway Ashland 1 138 282 Install underground 138 kV circuit from

Ridgeway to Ashland - expand Ashland sub to complete 138kv ring bus. Build new Ridgeway sub - 138kv-13.1kv

OH 1.31 Planned $1,000,000 Y A

A in MTEP08 Central DEM 1512 2588 12/31/2012 Rochelle Ridgeway 1 138 13.1 282 Install underground 138 kV circuit from Rochelle - Ridgeway - expand Rochelle sub to complete 138kv ring bus.

OH 1.04 Planned $7,802,000 Y A

A in MTEP08 Central DEM 1512 2939 12/31/2012 Red Bank Ashland 1 138 Install 3.8 ohm-1410Amp-138kV reactors in Feeder 7484 at Oakley sub (line runs through Oakley with no connections to other ckts - transitions to UG here)


A in MTEP08 Central DEM 1513 2589 7/15/2011 Metea Capacitor 69 14.4 MVAR Install 14.4MVAR 69kV unit IN Under Construction

$865,946 NT A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP08 Central DEM 1514 3776 12/31/2011 Wabash River Station Burnett Jct 1 138 Reconductor the 6-wire 13847 477ACSR underbuild from 976-1005 to 976-1035 (34,000 ft), with 3-wire 954ACSSTW conductor to allow uprating of 23002 line overbuild. Wab Riv to Spelterville to Burnett Jct.

IN 6.44 Under Construction

$1,286,147 Y A

A in MTEP08 Central DEM 1514 2590 12/31/2011 Wabash River Station Staunton 230 478 Uprate Wabash River to Staunton 23002 to 100C summer operating temperature and 80C winter (559MVA). 478mva/1200A equipment limited - also, have to modify the 13847 underbuild from 6-wired to 954 3-wire


$0 Y A

A in MTEP08 Central DEM 1519 2595 12/31/2012 Noblesville NE Geist 69 Build a new 69kV line from Noblesville NE sub to tap the Fishers North - Geist 69kV line


A in MTEP08 Central DEM 1560 3111 7/15/2011 Edwardsport capacitor 138 57.6 MVAR Install a 138kV 57.6MVAR capacitor at Edwardsport.

IN Under Construction

$709,293 Y A

A in MTEP08 Central DEM 1561 3112 6/1/2012 Kokomo Webster St (terminal equipment)

New London 1 230 797 Retire existing 1600A circuit switcher and complete the Webster St ring in order to utilize the full capacity of the bundled 477 ACSS wire on the 23016 line.


A in MTEP08 Central DEM 1564 3116 12/31/2011 Roseburg Switching Station

Capacitor 69 21.6 MVAR Install 69kV 21.6MVAR std capacitor IN Planned $518,503 NT A

A in MTEP08 Central DEM 1568 3120 6/1/2013 Qualitech transformer 1 345 138 300 Qualitech Sub- Install one 345/138kv, 300Mva Xtr and 2-345kv Bkrs and 1-138kv Bkr to provide second 138kv source to proposed Hendricks Co 138kv system


A in MTEP08 Central DEM 1569 3121 6/2/2013 Qualitech Pittsboro Jct 1 138 306 Construct new 138kv line, Qualitech to Pittsboro Jct, and connect to the Pittsboro-Brownsbg line to provide new 954ACSR outlet line from Qualitech 345/138kV Bank

IN 3.3 Planned $1,507,856 Y A

A in MTEP08 Central DEM 1570 3122 6/3/2013 Plainfield South Pittsboro Jct 1 138 306 Convert the existing 69KV (69144) line from Plainfield S. to Pittsboro Jct(and 4 distribution subs) over to 138KV operation and connect to the new Qualitech to Pittsboro 138KV line

IN 17.6 Planned $4,139,000 Y A

A in MTEP08 Central DEM 1650 3381 6/30/2014 Fairview HE Fairview 1 138 306 Fairview to HE Fairview 13854 Reconductor with 954ACSR @ 100C

IN 3.3 Planned $1,236,384 Y A

A in MTEP08 Central DEM 1881 3775 12/31/2011 Bloomington Rogers St Whitehall Pike 1 138 201 Bloomington Rogers St - replace 13836 breaker and WT; replace 13871 breaker, WT, and disc sw's - All 2000Amp rated; Replace relays for 13836, 13837, 13871


A in MTEP08 Central DEM 1889 3785 6/23/2011 Danville Danville Jct 1 69 153 Danville to Preswick Jct to Danville Jct - recond. 5.2 mi of the 6945 ckt. with 954acsr OVAL @100C and replace the 600 amp, two way switches at Danville Jct with two 1200 amp one way switches and replace the 600 amp switch at Prestwick Jct with a 1200 amp


$1,622,359 NT A

A in MTEP08 Central DEM 1890 3786 8/16/2011 Geist 69181 Fishers N. Jct (new)

1 69 153 Build new 69kV line - 69181 - 4 miles with 954ACSR along 126th St. (completes approx 5.9 mile line section)

IN 4 Under Construction

$1,977,421 NT A

A in MTEP08 Central DEM 1893 3789 6/1/2013 Mitchell Lehigh Portland Bedford 25th St 1 69 100 Reconductor 10.3 miles of 69kV - 6995 line with 477 ACSR

IN 10.3 Planned $3,016,000 NT A

A in MTEP08 Central DEM 1895 3791 6/4/2013 Brownsburg Avon East 1 138 306 Brownsburg to Avon East 138kV Reconductor 2.9 miles of 138kV line with 954 ACSR - AFTER 138KV CONVERSION

IN 2.9 Planned $1,433,227 Y A

A in MTEP08 Central DEM 1896 3792 6/1/2012 Connersville 138 sub Connersville 30th St 1 69 53 Uprate to 100C 4/0 acsr sections – 1.2 miles - 6981 ckt







Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP08 Central DEM 1897 3793 6/1/2012 Deedsville Macy 1 69 100 Reconductor Deedsville to Macy section of 6957 circuit with 477ACSR approx 2.5 miles; and replace Macy #1 and #2 - 600A line switches (1955 vintage) with 1200A


A in MTEP08 Central DEM 1899 3795 12/31/2013 Macy Rochester Metals Jct 1 69 100 Reconductor Macy to Rochester Metals Jct section of 6957 circuit with 477ACSR - approx 9.1 miles


A in MTEP08 Central DEM 1901 3797 6/1/2013 Noblesville Gen Sta Noblesville Jct 1 69 245 Reconductor 69kV - 6984 & 6916 ckt. Noblesville Plant to Noblesville 8th St. to Noblesville Jct with 954ACSS @ 200C (5.47 miles)

IN 5.47 Planned $1,510,946 NT A

A in MTEP08 Central DEM 1902 3799 6/1/2012 Zionsville Zionsville 96th St 1 69 153 Reconductor .32 miles of the 69kV - 69155 line from Zionsville 69 sub to Zionsville 96th Jct with 954ACSR conductor; replace/upgrade 69kV switches, jumpers and bus at Zionsvile 69 sub for a min. capacity of 152MVA (502G6709)


A in MTEP07 Central DEM 852 2995 6/1/2013 Linden Ethanol Jct Tipmont Concord Jct 138 306 13819 reconductor with 954ACSR 100C IN 7.15 Planned $3,567,892 Y Y AA in MTEP07 Central DEM 852 1979 6/1/2013 Crawfordsville Linden Ethanol Jct 138 306 13819 reconductor with 954ACSR 100C IN 10.28 Planned $5,351,838 Y Y AA in MTEP06 Central DEM 851 826 6/1/2013 Lafayette Cumberland

AveLaf AE Staley 1 138 306 13806 reconductor with 954ACSR 100C

604F6347IN 1.3 Planned $349,357 Y A

A in MTEP06 Central DEM 853 828 6/1/2015 West Lafayette Cumberland Ave 1 138 306 13806 reconductor with 954ACSR 100C 604F6352

IN 2 Planned $706,921 Y A

A in MTEP06 Central DEM 1244 1946 6/1/2013 Frankfort 23013 Wave Trap

Cayuga 230 797 Replace 1600A wave trap with a 2000A wave trap. Increase line rating of the Cayuga to Frankfort 23013 line.


A in MTEP06 Central DEM 1244 1945 6/1/2013 Cayuga 23013 Wave Trap

Frankfort 230 797 Replace 1600A wave trap with a 2000A wave trap. Increase line rating of the Cayuga to Frankfort 23013 line.


A in MTEP10 Central HE 3080 5360 6/1/2011 HE Rocklane DEI 1 69 72MVA New Construction IN 3 Planned $3,000,000 Y AA in MTEP08 Central HE 1927 3806 9/1/2010 Hubbell Primary 1 138 2000 AMP Rebuild IN Planned $3,000,000 Y AA in MTEP08 Central HE 1928 3807 9/1/2011 Fairview Primary 1 138 2000 AMP Rebuild IN Planned $1,500,000 Y AA in MTEP08 Central HE 1929 3808 9/1/2012 Georgetown Primary 1 138 2000 AMP Rebuild IN Planned $1,250,000 Y AA in MTEP08 Central HE 2082 3978 9/1/2009 Shelbyville Intel Park

TaplineShelbyville Intel Park 1 138 New Construction IN 1 Planned $250,000 Y A

A in MTEP08 Central HE 2082 3979 9/1/2009 Shelbyville Intel Park 1 138 12.5 2000 AMP New Construction IN Planned $750,000 Y AA in MTEP08 Central HE 2083 3981 9/1/2009 Wayne County Indust

Park1 69 12.5 2000 AMP New Construction IN Planned $500,000 NT A

A in MTEP08 Central HE 2083 3980 9/1/2009 Wayne County Indust Park Tap

Wayne County Indust Park

1 69 New Construction IN 1 Planned $250,000 NT A

A in MTEP10 Central IPL 2900 5073 6/1/2011 Northwest Southwest 1 138 382 Increase line rating from 242 to 382 MVA IN 4.75 Planned $1,500,000 Y AA in MTEP09 Central IPL 2053 5341 6/1/2012 Petersburg 138 kV breakers 138 6 138 kV Breakers and disconnect switches IN Planned $2,000,000 N Y AA in MTEP09 Central IPL 2053 3940 6/1/2012 Petersburg West Autotransformer W 345 138 Replace autotransformer and 345 kV breaker IN Planned $6,700,000 Y Y A

A in MTEP09 Central IPL 2053 3939 6/1/2012 Petersburg East Autotransformer E 345 138 Replace autotransformer and 345 kV breaker IN Planned $6,700,000 Y Y A

A in MTEP08 Central IPL 1639 3301 6/1/2013 Various Locations capacitors Add capacitors to IPL General Distribution System


A in MTEP08 Central SIPC 1778 2871 7/1/2008 Hamilton (SIPC) Norris (Ameren) 138 Construct a 138KV line connecting SIPC Hamilton Substation to Ameren Norris City Substation. This project includes the construction of 18 miles of 138KV line.


A in MTEP03 Central SIPC 81 5339 9/1/2012 Carrier Mills 161/69 kV transformer 161 69 New 161/69kV substation located north of Carrier Mills, IL


A in MTEP09 Central Vectren 2461 4425 6/1/2014 Dubois Sub Z84 terminals

84 138 Add 1 new 138kV terminal to existing sub to avoid 3 term line







Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP09 Central Vectren 2465 4429 10/1/2011 Leibert Rd 138/12kV Substation

1 138 12.5 16/20 New 138/12kV Substation for load growth IN Planned $2,622,781 NT A

A in MTEP09 Central Vectren 2466 4430 6/1/2013 Roesner Rd 138/12kV Substation

1 138 12.5 16/20 New 138/12kV Substation for load growth IN Planned $3,000,000 NT A

A in MTEP08 Central Vectren 1002 1566 6/1/2012 Northeast Oak Grove 77 138 287/287 new line IN 5 Under Construction

$4,368,926 Y A

A in MTEP08 Central Vectren 1782 3572 12/31/2014 Northeast Sub Bus reconfig

Substation 1 138 Rebuild existing straight bus with more reliable breaker and half scheme


A in MTEP08 Central Vectren 1784 3574 6/1/2016 Jasper#3 Sub Exp-Victory Line

Victory 1 69 Extend existing Victory line to new term at existing sub


A in MTEP08 Central Vectren 1785 3575 12/31/2012 Z83 Upgrade NE Z83 Upgrade NW 83 138 Upgrade terminal equipment at NE and NW. IN Planned $100,000 Y AA in MTEP08 Central Vectren 1787 3577 6/1/2014 Dale Sub Santa Clause Sub 75 69 New 69kV line from Dale Sub to Santa

Clause SubIN Planned $5,000,000 NT A

A in MTEP08 Central Vectren 1788 3578 6/1/2014 St. Wendel Sub Mohr Rd Sub 34 69 New 69kV line from St. Wendel Sub to Mohr Rd Sub


A in MTEP08 Central Vectren 1789 3579 6/1/2014 Boonville Sub Boonville Pioneer Sub 56 69 New 69kV line from Boonville Sub to Boonville Pioneer Sub


A in MTEP08 Central Vectren 1790 3580 6/1/2014 NE Sub Elliott Sub 52 69 Rebuild/Reconductor existing Y52 and loop into Sunbeam


A in MTEP08 Central Vectren 1791 3581 6/1/2012 Angel Mound Sub East Side Sub 66 69 Uprate term equipment to increase capacity for Y66-2


A in MTEP06 Central Vectren 1257 1973 6/1/2012 AB Brown Reid (BREC) 17 345 1430/1430 new line IN/KY 25.7 Under Construction

$46,284,114 Y Y Y A

A in MTEP10 East ITC 2918 5087 12/31/2012 Breaker Replacement Program 2012

Throughout System 345 120 MI Planned $6,000,000 Y A

A in MTEP10 East ITC 2919 5088 12/31/2012 NERC Relay Loadability Compliance 2012

Throughout system 345 120 Upgrade relay throught system MI Planned $2,400,000 Y A

A in MTEP10 East ITC 2920 5089 12/31/2012 Potential Device Replacement 2012

Throughout System 345 120 Replace aging potential devices MI Planned $300,000 Y A

A in MTEP10 East ITC 2921 5090 12/31/2012 Relay Betterment Program 2012

Throughout System 345 120 MI Planned $1,200,000 Y A

A in MTEP10 East ITC 2922 5091 12/31/2012 Wood Pole Replacement 2012

Throughout System 120 Replace deteriorating wood pole MI Planned $4,800,000 Y A

A in MTEP10 East ITC 2923 5092 12/31/2012 Capacitor Replacement 2012

Throughout System 120 Replace capacitor banks MI Planned $600,000 Y A

A in MTEP10 East ITC 2925 5094 12/31/2011 Blanket for Customer Interconnections 2011

Throughout system 120 Connect interconnecting entities as requested











A in MTEP10 East ITC 2929 5099 12/30/2012 Ariel (formerly Holland) Wheeler 1 120 Distribution Interconnection to add two new 120/13.2kV transformers at Ariel (formerly Holland). Connects to the Wheeler to Troy 120kV circuit.

MI 0.1 Planned Y A

A in MTEP10 East ITC 2929 5100 12/30/2012 Ariel (formerly Holland) Troy 1 120 Distribution Interconnection to add two new 120/13.2kV transformers at Ariel (formerly Holland). Connects to the Wheeler to Troy 120kV circuit.

MI 0.73 0.1 Planned Y A

A in MTEP10 East ITC 2929 5098 12/30/2012 Ariel (formerly Holland) Holland 1 120 Distribution Interconnection to add two new 120/13.2kV transformers at Ariel (formerly Holland). Connects to the Wheeler to Troy 120kV circuit.







Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP10 East ITC 2930 5101 12/30/2015 Evergreen Warren 1 120 Upper Rouge to Tap Evergreen Warren 120 kV circuit. Rebuild 0.65 mile of six-wired 477 ACSR Warren-Evergreen 120 kV circuit.

MI 0.65 Planned $1,900,000 Y A

A in MTEP10 East ITC 3168 5581 12/31/2013 Baker (formerly Reese) Hampton 1 345 Tap the Pontiac to Hampton 345 kV circuit at new Baker site

MI Planned Y Y Y A

A in MTEP10 East ITC 3168 5984 12/31/2013 Baker (formerly Reese) Hampton 2 345 Tap the Hampton to Thetford 345 kV circuit at new Baker site

MI Planned Y Y Y A

A in MTEP10 East ITC 3168 5582 12/31/2013 Baker (formerly Reese) Pontiac 1 345 Tap the Pontiac to Hampton 345 kV circuit at new Baker site

MI Planned Y Y Y A

A in MTEP10 East ITC 3168 5577 12/31/2013 Baker (formerly Reese) switching station 345 New Switching Station MI Planned Y Y Y AA in MTEP10 East ITC 3168 5584 12/31/2013 Baker (formerly Reese) Thetford 1 345 Tap the Tittabawassee to Thetford (via

Manning) 345 kV circuit at new Baker siteMI Planned Y Y Y A

A in MTEP10 East ITC 3168 5983 12/31/2013 Baker (formerly Reese) Thetford 2 345 Tap the Hampton to Thetford 345 kV circuit at new Baker site

MI Planned Y Y Y A

A in MTEP10 East ITC 3168 5583 12/31/2013 Baker (formerly Reese) Tittabawassee (via Manning)

1 345 Tap the Tittabawassee to Thetford (via Manning) 345 kV circuit at new Baker site

MI Planned Y Y Y A

A in MTEP10 East ITC 3168 5596 12/31/2015 Fitz (formerly Saratoga) Belle River 1 345 Tap the three ended Belle River to Greenwood to Pontiac 345 kV circuit at new Fitz site

MI Planned Y Y Y A

A in MTEP10 East ITC 3168 5597 12/31/2015 Fitz (formerly Saratoga) Belle River 2 345 Tap the Belle River to Blackfoot 345 kV circuit at new Fitz site

MI Planned Y Y Y A

A in MTEP10 East ITC 3168 5598 12/31/2015 Fitz (formerly Saratoga) Blackfoot 1 345 Tap the Belle River to Blackfoot 345 kV circuit at new Fitz site

MI Planned Y Y Y A

A in MTEP10 East ITC 3168 5595 12/31/2015 Fitz (formerly Saratoga) Pontiac 1 345 Tap the three ended Belle River to Greenwood to Pontiac 345 kV circuit at new Fitz site

MI Planned Y Y Y A

A in MTEP10 East ITC 3168 5587 12/31/2015 Fitz (formerly Saratoga) switching station 345 New Switching Station MI Planned Y Y Y AA in MTEP10 East ITC 3168 5592 12/31/2015 Greenwood Fitz (formerly Saratoga) 1 345 Tap the three ended Belle River to

Greenwood to Pontiac 345 kV circuit at new Fitz site

MI Planned Y Y Y A

A in MTEP10 East ITC 3168 5593 12/31/2015 Greenwood Fitz (formerly Saratoga) 2 345 New 345 kV circuit MI 19 Planned Y Y Y AA in MTEP10 East ITC 3168 5594 12/31/2015 Greenwood Fitz (formerly Saratoga) 3 345 New 345 kV circuit MI 19 Planned Y Y Y AA in MTEP10 East ITC 3168 5588 12/31/2015 Greenwood sub expansion 345 Add two new rows to existing Greenwood

345 kV substationMI Planned Y Y Y A

A in MTEP10 East ITC 3168 5585 12/31/2013 Rapson (formerly Wyatt) Baker (formerly Reese) 1 345 New 345 kV circuit MI 56 Planned Y Y Y AA in MTEP10 East ITC 3168 5586 12/31/2013 Rapson (formerly Wyatt) Baker (formerly Reese) 2 345 New 345 kV circuit MI 56 Planned Y Y Y AA in MTEP10 East ITC 3168 5589 12/31/2015 Rapson (formerly Wyatt) Greenwood 1 345 New 345 kV circuit MI 65 Planned Y Y Y AA in MTEP10 East ITC 3168 5590 12/31/2015 Rapson (formerly Wyatt) Greenwood 2 345 New 345 kV circuit MI 65 Planned Y Y Y AA in MTEP10 East ITC 3168 5986 12/31/2013 Rapson (formerly Wyatt) Harbor Beach 1 120 Tap the Wyatt to Harbor Beach 120 kV circuit

at new Rapson siteMI Planned Y Y Y A

A in MTEP10 East ITC 3168 6104 12/31/2013 Rapson (formerly Wyatt) Seaside 1 120 Tap the Wyatt to Seaside 120 kV circuit at new Rapson site

MI Planned Y Y Y A

A in MTEP10 East ITC 3168 5988 12/31/2013 Rapson (formerly Wyatt) Seaside 1 120 Tap the Wyatt to Seaside 120 kV circuit at new Rapson site

MI Planned Y Y Y A

A in MTEP10 East ITC 3168 5578 12/31/2013 Rapson (formerly Wyatt) switching station 345 120 New Switching Station MI Planned Y Y Y AA in MTEP10 East ITC 3168 6101 12/31/2013 Rapson (formerly Wyatt) Wyatt 1 120 Tap the Wyatt to Harbor Beach 120 kV circuit

at new Rapson siteMI Planned Y Y Y A

A in MTEP10 East ITC 3168 5985 12/31/2013 Rapson (formerly Wyatt) Wyatt 1 120 Tap the Wyatt to Harbor Beach 120 kV circuit at new Rapson site

MI Planned Y Y Y A

A in MTEP10 East ITC 3168 5987 12/31/2013 Rapson (formerly Wyatt) Wyatt 2 120 Tap the Wyatt to Seaside 120 kV circuit at new Rapson site

MI Planned Y Y Y A

A in MTEP10 East ITC 3168 5579 12/31/2013 Rapson (formerly Wyatt) 345 kV

Rapson (formerly Wyatt) 120 kV

1 345 120 New 345/120 kV transformer MI Planned Y Y Y A

A in MTEP10 East ITC 3168 5580 12/31/2013 Rapson (formerly Wyatt) 345 kV

Rapson (formerly Wyatt) 120 kV

2 345 120 New 345/120 kV transformer MI Planned Y Y Y A

A in MTEP10 East ITC 3168 5591 12/31/2015 Sandusky 345 kV Sandusky 120 kV 1 345 120 New 345/120 kV transformer MI Planned Y Y Y A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP10 East ITC 3168 5599 12/31/2015 Total project cost estimate

Costs from ITC report to Michigan Wind Zones Board and the Michigan Public Service Commission dated November 30, 2009

MI Planned $510,000,000 Y Y Y A

A in MTEP09 East ITC 1872 3763 6/1/2013 ScioTP Spruce 1 120 313 MVA Scio Taps the Lark-Spruce 120kV circuit MI Planned Y AA in MTEP09 East ITC 1872 3764 6/1/2013 ScioTP Scio 1 120 343 MVA Scio Taps the Lark-Spruce 120kV circuit MI Planned $3,000,000 Y AA in MTEP09 East ITC 1872 3762 6/1/2013 ScioTP Lark 1 120 249 MVA Scio Taps the Lark-Spruce 120kV circuit MI Planned Y AA in MTEP09 East ITC 2519 4526 12/31/2011 Breaker Replacement

Program 2011Throughout System MI Planned $5,650,000 Y A

A in MTEP09 East ITC 2520 4527 12/31/2011 Cable Termination Replacement 2011

Throughout System MI Planned $3,000,000 Y A

A in MTEP09 East ITC 2521 4528 12/31/2011 Relay Betterment Program 2011

Throughout System MI Planned $1,200,000 Y A

A in MTEP09 East ITC 2525 4531 12/31/2011 Capacitor Replacement 2011

Throughout System Replace capacitor banks MI Planned $565,000 Y A

A in MTEP09 East ITC 2528 4534 12/31/2011 Potential Device Replacement 2011

Throughout System Replace aging potential devices MI Planned $300,000 Y A

A in MTEP09 East ITC 2531 4537 12/31/2011 Power Plant Control Relocation 2011

Throughout System Relocate substation controls currently located in power plants control rooms


A in MTEP09 East ITC 2534 4540 12/31/2011 Wood Pole Replacement 2011

Throughout System Replace deteriorating wood pole MI Planned $9,000,000 Y A

A in MTEP09 East ITC 2537 4543 12/31/2011 Synchronizing Sites 2011

Throughout System New 120kV synchronizing sites MI Planned $565,000 Y A

A in MTEP09 East ITC 2539 4545 12/31/2011 NERC Relay Loadability Compliance 2011

Throughout system 120 Upgrade relay throught system MI Planned $2,250,000 Y A

A in MTEP09 East ITC 2541 4547 7/22/2011 Hunters Creek - Robin - Wabash

120 Install double shield wire MI Under Construction

$2,400,000 Y A

A in MTEP09 East ITC 2545 4552 9/1/2011 Navarre 120 Relay modifications MI Planned $640,000 Y AA in MTEP08 East ITC 1870 3757 6/1/2013 ClydeTP Placid 1 120 343 MVA Clyde taps the Placid-Durant 120kV circuit MI 11.5 Planned Y AA in MTEP08 East ITC 1870 3758 6/1/2013 ClydeTP Durant 1 120 343 MVA Clyde taps the Placid-Durant 120kV circuit MI 6.6 Planned Y AA in MTEP08 East ITC 1870 3759 6/1/2013 ClydeTP Clyde 1 120 343 MVA Clyde taps the Placid-Durant 120kV circuit MI 3.3 Planned $2,750,000 Y AA in MTEP08 East ITC 1873 3765 5/31/2013 Tahoe Wixom 1 120 351 MVA Creates at new Tahoe-Wixom

120kV;constructs 2.6 miles of 120 kV line circuit

MI 2.6 Planned $2,800,000 Y A

A in MTEP06 East ITC 1308 2141 9/30/2011 Bunce Creek PAR 1 220 MI Planned $25,000,000 Y AA in MTEP06 East ITC 1310 2159 9/30/2011 St. Clair 120 kV pos. HS circuit breaker 120 CB replacement MI Planned $150,000 Y AA in MTEP10 East METC 2502 4502 12/31/2011 McGulpin 138 Install 15 MVAR shunt reactor at McGulpin MI Planned $3,000,000 Y AA in MTEP10 East METC 2903 5380 12/31/2012 Various Replace batteries and chargers MI Planned $300,000 Y AA in MTEP10 East METC 2904 5381 12/31/2012 Various Breaker replacement MI Planned $6,000,000 Y AA in MTEP10 East METC 2905 5382 12/31/2012 Various Relay loadability MI Planned $2,400,000 Y AA in MTEP10 East METC 2906 5383 12/31/2012 Various Potential device replacement MI Planned $300,000 Y AA in MTEP10 East METC 2907 5384 12/31/2012 Various Plant control relocation MI Planned $1,200,000 Y AA in MTEP10 East METC 2908 5385 12/31/2012 Various Relay replacement MI Planned $1,200,000 Y AA in MTEP10 East METC 2909 5078 12/31/2012 Sag clearance 2012 Throughout system 345 138 Review and correct NESC code violations MI Planned $3,600,000 Y AA in MTEP10 East METC 2910 5079 12/31/2012 Wood Pole Replacement

2012Throughout system 138 Replace deteriorating wood pole MI Planned $4,800,000 Y A

A in MTEP10 East METC 2912 5081 12/31/2011 Blanket for Customer Interconnections 2011












A in MTEP10 East METC 2916 5085 6/1/2012 Livingston Vanderbilt 138 Rebuild 9.7 miles of 138 kV 266 ACSR to 954 ACSR FDC 230 kV construction.

MI 9.7 Planned $12,734,400 Y Y A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP10 East METC 2917 5086 11/30/2011 David Jct Bingham 138 Improve sag clearance by replacing 16 wood poles with 138 kV FDC steel poles.


A in MTEP10 East METC 3073 5437 12/31/2011 TC East Substation TC East Substation 138 New 3 breaker switching station and 0.25 mile 954 ACSR line

MI Planned $4,913,791 N Y A

A in MTEP09 East METC 646 1329 12/1/2011 Edenville J. Warren 1 138 Replace poles on half of the Edenville Jct.-Warren 138kV line, prebuilt to 230kV

MI 7.8 Planned $6,000,000 Y A

A in MTEP09 East METC 646 4967 12/1/2012 Edenville J. Warren 1 138 Replace poles on half of the Edenville Jct.-Warren 138kV line, prebuilt to 230kV


A in MTEP09 East METC 662 3596 6/1/2013 Weeds Lake N_AVE 138 line extention on MILHAM to N_AVE circuit N_AVE side


A in MTEP09 East METC 662 3593 6/1/2013 Weeds Lake BRONCO 138 line extention on BRONCO 12th ST circuit BRONCO side


A in MTEP09 East METC 662 3592 6/1/2013 Weeds lake 345/138 kV Transformer 345 138 transformer MI Planned $23,365,447 Y Y AA in MTEP09 East METC 662 3595 6/1/2013 Weeds Lake 12th ST 138 line extention on BRONCO to 12th ST circuit

12TST sideMI Planned $5,010,000 Y Y A

A in MTEP09 East METC 662 3594 6/1/2013 Weeds Lake MILHAM 138 line extention on MILHAM to N_AVE circuit MILHAM side


A in MTEP09 East METC 662 1350 6/1/2013 Weeds Lake 138 kV BRONCO to 12th ST 138 tapping BRONCO to 12TST circuit into Weeds Lake

MI Planned $810,505 Y Y A

A in MTEP09 East METC 662 3597 6/1/2013 Weeds Lake Jct MILHAM to N_AVE 345 tapping MILHAM to N_AVE circuit into weeds lake

MI Planned $810,505 Y Y A

A in MTEP09 East METC 1810 3634 12/31/2011 East Tawas Iosco 1 138 Rebuild 12 miles of 138kV to 954 ACSR. MI 80 Planned $9,818,854 Y AA in MTEP09 East METC 1833 2880 12/31/2011 Sag clearance 2011 Throughout system MI Planned $3,400,000 Y AA in MTEP09 East METC 2475 4461 6/1/2015 Doans Beals 1 138 New 138kV switching station at Titus Lake

junction.MI Planned $2,100,000 Y A

A in MTEP09 East METC 2475 4462 6/1/2015 Doans Hazelwood 1 138 New 138kV switching station at Titus Lake junction.


A in MTEP09 East METC 2478 4466 5/31/2012 Capital Ave Battle Creek 1 138 Capital Ave taps the Battle Creek-Verona 138kV circuit #2.


A in MTEP09 East METC 2478 4467 5/31/2012 Capital Ave Battle Creek 1 138 Capital Ave taps the Battle Creek-Verona 138kV circuit #2.


A in MTEP09 East METC 2481 4470 6/1/2012 Forest Grove Campbell 1 138 Forest Grove taps the Campbell-Hudsonville (toward Ransom) 138kV circuit


A in MTEP09 East METC 2481 4471 6/1/2012 Forest Grove Hudsonville 1 138 Forest Grove taps the Campbell-Hudsonville (toward Ransom) 138kV circuit


A in MTEP09 East METC 2482 4472 5/31/2013 Hawthorne Four Mile 1 138 Hawthorne taps the Four Mile-Pingree (toward Blendon) 138kV circuit


A in MTEP09 East METC 2482 4473 5/31/2013 Hawthorne Pingree 1 138 Hawthorne taps the Four Mile-Pingree (toward Blendon) 138kV circuit


A in MTEP09 East METC 2483 4474 5/31/2012 Maines Road Marshall 1 138 Maines Road taps the Marshall-Blackstone 138kV circuit


A in MTEP09 East METC 2483 4475 5/31/2012 Maines Road Blackstone 1 138 Maines Road taps the Marshall-Blackstone 138kV circuit


A in MTEP09 East METC 2484 4476 5/31/2012 Scenic Lake Cornell 1 138 Scenic Lake taps the Cornell-Tihart 138kV circuit


A in MTEP09 East METC 2484 4477 5/31/2012 Scenic Lake Tihart 1 138 Scenic Lake taps the Cornell-Tihart 138kV circuit


A in MTEP09 East METC 2485 4478 6/1/2013 Ransom Buck Creek 1 138 Relay modifications MI Planned $12,000 Y AA in MTEP09 East METC 2486 4479 5/31/2014 Haakwood Rondo 1 138 Haakwood taps the Rondo-Vanderbilt section

of the Riggsville-Livingston 138kV line.MI Planned $85,000 Y A

A in MTEP09 East METC 2486 4480 5/31/2014 Haakwood Vanderbilt 1 138 Haakwood taps the Rondo-Vanderbilt section of the Riggsville-Livingston 138kV line.


A in MTEP09 East METC 2487 4482 6/30/2012 Birchwood Kraft 1 138 Birchwood taps the Spaulding-Kraft section of the Spaulding-Plaster Creek 138kV circuit







Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP09 East METC 2487 4481 6/30/2012 Birchwood Spaulding 1 138 Birchwood taps the Spaulding-Kraft section of the Spaulding-Plaster Creek 138kV circuit


A in MTEP09 East METC 2489 4485 9/30/2011 Tippy terminal equipment 138 Terminal equipment upgrade at Tippy on the Tippy-Keystone 138kV line.


A in MTEP09 East METC 2492 4490 6/1/2013 Battle Creek 138 Terminal equipment upgrade MI Planned $100,000 Y AA in MTEP09 East METC 2492 4491 6/1/2013 Verona 138 Terminal equipment upgrade MI Planned $100,000 Y AA in MTEP09 East METC 2496 4943 6/1/2013 Bullock Tittabawassee 138 Terminal equipment upgrade at Bullock MI Planned $220,000 Y AA in MTEP09 East METC 2496 4496 6/1/2013 Tittabawassee 138 Terminal equipment upgrade MI Planned $140,000 Y AA in MTEP09 East METC 2498 4800 12/31/2011 Breaker replacement

program2011 MI Planned $5,650,000 Y A

A in MTEP09 East METC 2499 4827 12/31/2011 Relay Betterment Program 2011

Throughout system MI Planned $1,200,000 Y A

A in MTEP09 East METC 2501 4500 6/1/2012 Keystone Install 50.4 MVAR capacitor MI Planned $740,323 Y AA in MTEP09 East METC 2501 4501 6/1/2012 Plum Install 25.2 MVAR capacitor MI Planned $435,484 Y AA in MTEP09 East METC 2501 4499 6/1/2012 New site (Wexford

prime)Install 25.2 MVAR capacitor MI Planned $1,524,194 Y A

A in MTEP09 East METC 2507 4510 6/1/2013 Alcona Mio 1 138 Rebuild the Twining-Mio 138kV line to 954 ACSR future-double-circuit (pre-built to 230kV)

MI 20 Planned $24,500,000 Y A

A in MTEP09 East METC 2510 4513 12/31/2011 Wood Pole Replacement 2011

Throughout system 138 Replace deteriorating wood pole MI Planned $6,000,000 Y A

A in MTEP09 East METC 2515 4518 8/1/2011 Oakland Dean 1 138 Replace wood structures MI Planned $3,774,325 Y AA in MTEP09 East METC 2515 4521 8/1/2011 Latson Tihart 1 138 Replace wood structures MI Planned $11,804,805 Y AA in MTEP09 East METC 2515 4522 8/1/2011 Genoa Latson (METC side) 1 138 Replace wood structures MI Planned $1,124,267 Y AA in MTEP09 East METC 2515 4520 8/1/2011 Dean Latson 1 138 Replace wood structures MI Planned $2,168,230 Y AA in MTEP09 East METC 2517 4524 12/31/2011 NERC Relay Loadability

Compliance 2011Throughout system 138 Upgrade relay throught system MI Planned $2,250,000 Y A

A in MTEP09 East METC 2522 4801 12/31/2011 Power Plant Control Relocation 2011

Throughout System Relocate substation controls currently located in power plants control rooms

Planned $1,200,000 Y A

A in MTEP08 East METC 1448 2452 6/1/2016 Simpson 138kV 138 12.5 Install a second distribution transformer at Simpson (Simpson)


A in MTEP08 East METC 1655 3406 12/31/2011 Weadock 138kV Breaker 500 138 MI Planned $160,000 Y AA in MTEP08 East METC 1655 3404 12/31/2011 Weadock 138kV Breaker 388 138 MI Planned $160,000 Y AA in MTEP08 East METC 1655 3403 12/31/2011 Weadock 138kV Breaker 288 138 MI Planned $160,000 Y AA in MTEP08 East METC 1796 3605 12/31/2011 Twining Almeda 1 138 Reconductor MI 22 Planned $22,819,200 Y Y AA in MTEP08 East METC 1814 3648 12/31/2012 Tippy Chase 1 138 Reconductor MI 30 Planned $26,970,000 Y Y AA in MTEP08 East METC 1820 2872 12/31/2011 METC Communication

and Relaying UpgradeThroughout system MI Planned $10,000,000 Y A

A in MTEP08 East METC 1834 3695 12/15/2011 Tirrell Road Battle Creek 1 138 Tirrel Rd. taps the Battle Creek-Cochran 138kV circuit


A in MTEP08 East METC 1834 3696 12/15/2011 Tirrell Road Cochran Jct. 1 138 Tirrel Rd. taps the Battle Creek-Cochran 138kV circuit


A in MTEP08 East METC 1841 3709 5/31/2012 Eagles Landing East Tawas 1 138 Eagles Landing Taps the Cottage Grove - East Tawas 138kV circuit


A in MTEP08 East METC 1841 3708 5/31/2012 Eagles Landing Cottage Grove 1 138 Eagles Landing Taps the Cottage Grove - East Tawas 138kV circuit


A in MTEP06 East METC 988 1551 12/31/2011 Simpson Batavia 1 138 MI 30 Planned $37,100,000 Y Y AA in MTEP06 East METC 1408 2411 6/30/2013 RTU/SCADA upgrades Throughtout System 345 138 Install and/or upgrade numerous

RTU/SCADA pointsMI Under

Construction$801,000 Y A

A in MTEP06 East METC 1434 2438 6/1/2014 Spaulding 138kV 138 Install bulk substation served from the Spaulding 138kV ring bus (Five Mile)


A in MTEP06 East METC 1445 2449 12/31/2016 Emmet 138kV distribution 138 Install a second distribution transformer at Emmet (Emmet)


A in MTEP06 East METC 1447 2451 6/1/2012 Eureka 138kV Vestaburg 138kV 1 138 Install bulk substation served from the Eureka-Deja-Vestaburg 138kV Line (Horseshoe Creek/Deja)


A in MTEP10 East MPPA 3073 5377 12/31/2012 TC East Substation TC East Substation 138 69 90/150 MVA New 138/69kV substation interconnection MI Planned $3,500,000 N Y A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP10 East MPPA 3074 5378 12/31/2012 TC East Substation Parsons Sub 69 108/140 MVA New 69kV line construction MI 4.1 Planned $1,600,000 Y AA in MTEP10 East NIPS 2322 4248 6/1/2011 Green Acres Transformer 345 138 560 Install a 560 MVA 345/138 kV transformer,

(1) 345 kV and (1) 138 kV circuit breaker and associated equipment at Green Acres Substation.

IN Planned $7,417,000 Y Y A

A in MTEP08 East NIPS 1996 2786 12/1/2012 Angola Switch #644 1 69 81 Circuit 6980 - Reconductor 2/0 CU to 336.4kcm ACSR

IN 12 Under Construction

$2,465,948 Y A

A in MTEP08 East NIPS 1997 2787 12/1/2015 Goshen Junction Model Tap 1 69 81 Circuit 6977 - Reconductor 4/0 CU to 336.4kcm ACSR

IN 1.5 Planned $357,000 Y A

A in MTEP10 EAST WPSC 3060 5335 12/31/2020 Morley Capacitor Bank 69 Install a Capacitor Bank MI Planned $260,000 Y AA in MTEP10 EAST WPSC 3061 5337 6/1/2012 Tremaine Lowell Junction 1 69 Tremaine taps the Portland to Burnips Circuit

near Lowell Junction - Install a tap pole and disconnect switches


A in MTEP10 EAST WPSC 3061 5336 6/1/2012 Portland Tremaine 1 69 Tremaine taps the Portland to Burnips Circuit near Lowell Junction - Install a tap pole and disconnect switches


A in MTEP10 EAST WPSC 3062 5326 12/31/2013 Blendon 138kV Blendon 69kV 1 138 69 150MVA Replace with a 90MVA Transformer MI Planned $3,750,000 Y AA in MTEP10 EAST WPSC 3063 5327 12/31/2011 Redwood Baseline 1 69 143.4MVA Rebuild to 795ACSS MI 6.12 Under

Construction$2,500,000 Y A

A in MTEP10 EAST WPSC 3068 5332 12/31/2014 South Boardman Capacitor Bank 69 Install a Capacitor Bank MI Planned $260,000 Y AA in MTEP10 EAST WPSC 3069 5333 12/31/2020 Weidman Capacitor Bank 69 Install a Capacitor Bank MI Planned $260,000 Y AA in MTEP09 East WPSC 2735 4756 12/31/2013 Alba Mancelona 1 69 143.4MVA Rebuild Overloaded Line MI 4.51 Planned $1,900,000 Y AA in MTEP09 East WPSC 2735 4757 12/31/2013 Mancelona Westwood 1 69 143.4MVA Rebuild Overloaded Line MI 6.7 Planned $2,900,000 Y AA in MTEP09 East WPSC 2736 4758 12/31/2014 East Bay South Boardman

Distribution1 69 143.4MVA Rebuild Overloaded Line MI 15.93 Planned $6,500,000 Y A

A in MTEP09 East WPSC 2770 4832 6/1/2012 Hersey Gilmore 1 69 Gilmore Taps the Hersey to Vestaburg 69kV circuit


A in MTEP09 East WPSC 2770 4833 6/1/2012 Gilmore Vestaburg 1 69 Gilmore Taps the Hersey to Vestaburg 69kV circuit


A in MTEP08 East WPSC 1222 1917 12/31/2011 Lake County Bus Upgrade 69 Convert Single Bus to Ring Bus MI Under Construction

$2,550,000 Y A

A in MTEP08 East WPSC 1222 2129 12/31/2011 Lake County 138 Lake County 69 138 69 150MVA Add 168MV transformer MI Under Construction

$3,500,000 Y A

A in MTEP08 East WPSC 1274 1996 12/31/2012 Allendale Blendon 69 143.4MVA Rebuild Overloaded line MI 2.11 Planned $900,000 Y AA in MTEP08 East WPSC 1274 3257 12/31/2014 Allendale Osipoff 1 69 143.4MVA Rebuild Overloaded line MI 14.53 Planned $6,500,000 Y AA in MTEP08 East WPSC 1311 2167 12/31/2012 Grawn Karlin 69 143.4MVA Rebuild Overloaded line MI 6.61 Planned $3,000,000 Y AA in MTEP08 East WPSC 1311 2166 12/31/2014 Copemish Karlin 69 143.4MVA Rebuild Overloaded line MI 13.59 Planned $6,100,000 Y AA in MTEP08 East WPSC 1313 2168 12/31/2012 Baldwin Plains X 69 143.4MVA Rebuild Overloaded line (Off peak case) MI 6.94 Planned $2,900,000 Y AA in MTEP08 East WPSC 1313 3850 12/31/2015 Hersey Lincoln X 1 69 143.4MVA Rebuild Overloaded Line (Off peak case) MI 3.05 Planned $1,400,000 Y AA in MTEP08 East WPSC 1313 3851 12/31/2015 Lincoln X Baldwin 1 69 143.4MVA Rebuild Overloaded Line (Off peak case) MI 16.47 Planned $7,150,000 Y AA in MTEP08 East WPSC 1581 3233 12/31/2011 East Jordan X Graves X 1 69 143.4MVA Rebuild Overloaded line MI 7.14 Planned $2,900,000 Y AA in MTEP08 East WPSC 1581 3134 12/31/2011 Alba Graves X 1 69 143.4MVA Rebuild Overloaded line MI 4.72 Planned $1,900,000 Y AA in MTEP08 East WPSC 1581 3852 12/31/2012 Advance Advance Dist. 1 69 143.4MVA Rebuild Overloaded Line MI 0.91 Planned $500,000 Y AA in MTEP08 East WPSC 1581 3853 12/31/2012 Advance Dist. East Jordan X 1 69 143.4MVA Rebuild Overloaded Line MI 4.66 Planned $2,000,000 Y AA in MTEP08 East WPSC 1586 3143 12/31/2015 Elmira Advance 1 69 143.4MVA Rebuild Overloaded line MI 16.26 Planned $7,200,000 Y AA in MTEP08 East WPSC 1967 3862 12/31/2020 Sebewa Portland 1 69 143.4MVA Rebuild Line (Poles have reached the end of

their useful life)MI 6.85 Planned $2,400,000 Y A

A in MTEP08 East WPSC 1967 3858 12/31/2020 Wayland Middleville X 1 69 143.4MVA Rebuild Line (Poles have reached the end of their useful life)

MI 10.69 Planned $3,800,000 Y A

A in MTEP08 East WPSC 1967 3860 12/31/2020 Superior Odessa 1 69 143.4MVA Rebuild Line (Poles have reached the end of their useful life)

MI 0.06 Planned $50,000 Y A

A in MTEP08 East WPSC 1967 3859 12/31/2020 Middleville X Superior 1 69 143.4MVA Rebuild Line (Poles have reached the end of their useful life)

MI 19.73 Planned $7,092,000 Y A

A in MTEP08 East WPSC 1967 3861 12/31/2020 Odesa Sebewa 1 69 143.4MVA Rebuild Line (Poles have reached the end of their useful life)

MI 3.37 Planned $1,200,000 Y A

A in MTEP06 East WPSC 1272 1994 12/31/2012 Redwood 138 Redwood 69 138 69 65MVA Add 75MV transformer MI Planned $3,000,000 Y A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP10 West ATC LLC 2451 4396 3/1/2012 Brodhead Spring Grove 1 69 80 MVA Rebuild Brodhead- S Monroe 69kV line with T2 477 kcmil ACSR

WI 3.1 Planned $11,800,000 Y A

A in MTEP10 West ATC LLC 2819 4957 12/27/2011 Bluemound transformer 3 230 138 400 MVA Replace Bluemound 230/138kV transformer T3 with a 400 MVA unit

WI Planned $8,000,000 Y A

A in MTEP10 West ATC LLC 3122 5473 6/19/2012 Dam Heights Okee Tap 1 69 73 MVA Reconductor 1.94 mi of 3-0 and 336 ACSR line conductor with T-2 4-0 ACSR keeping the T-2 3-0 ACSR for the DHT-Okee Tap section of line Y-8, replace 26 1919 vintage lattice towers and 4 wood poles

WI 8.88 Planned $2,177,421 Y A

A in MTEP09 West ATC LLC 2452 4394 12/31/2011 Glacier Hills Wind 2 generator W 0.69 150 MW H012 Glacier Hills 2 Wind Farm WI Planned Y AA in MTEP09 West ATC LLC 2452 4416 12/31/2011 Glacier Hills Wind 1 generator W 0.69 99 MW G706 Glacier Hills 1 Wind Farm WI Planned Y AA in MTEP08 West ATC LLC 356 897 6/1/2013 Rockdale/Albion 345 kV bus modification

at Rockdale/new 345 kV switching station at Albion

345 345 kV bus modification at Rockdale/new 345 kV switching station at Albion

WI Planned $15,020,590 Y Y Y A

A in MTEP08 West ATC LLC 356 488 6/1/2013 Cardinal (formerly West Middleton) 345/138

transformer 1 345 138 500 WI Planned $4,986,995 Y Y A

A in MTEP08 West ATC LLC 356 486 6/1/2013 Cardinal (formerly West Middleton)

Rockdale/Albion 1 345 1195 MVA SE WI 35 Planned $174,094,863 Y Y Y A

A in MTEP08 West ATC LLC 356 3383 6/1/2013 Cardinal (formerly West Middleton) 345/138

transformer, backup 2 345 138 500 WI Planned $4,986,995 Y Y A

A in MTEP08 West ATC LLC 356 3384 6/1/2013 Cardinal (formerly West Middleton)

substation 345 new 345 substation WI Planned $20,035,429 Y Y Y A

A in MTEP08 West ATC LLC 574 1370 6/1/2014 Council Creek 161-138 kV

transformer 1 161 138 210 New Council Creek Transformer WI Planned $5,404,000 Y A

A in MTEP08 West ATC LLC 574 1269 6/1/2014 Monroe County (XEL) Council Creek (ATC) 1 161 445 Install new T2-556 ACSR, OH-ATC-161-DC, 17.3 mi

WI 17.3 Planned $25,296,000 Y A

A in MTEP08 West ATC LLC 574 858 6/1/2014 Council Creek Petenwell 1 138 191 Uprated Petenwell substation to 191 MW CT limit

WI 30.3 Planned Y A

A in MTEP08 West ATC LLC 574 6329 6/1/2014 Council Creek Transformer 1 138 69 100 Replace relaying to uprate transformer as part of Project ID: 574 (Monroe County-Council Ck 161 kV line)


A in MTEP08 West ATC LLC 1683 3458 3/1/2012 Sunset Point Pearl Ave 1 69 57 MVA Rebuild 2.37 miles of 69 kV from Sunset Point-Pearl Ave with 477 ACSR

WI 2.37 Planned $4,128,701 Y A

A in MTEP08 West DPC 1957 3841 6/1/2012 new sub Burnswick 1 69 84 MVA Construct 69 kV line from new substation to DPC Brunswick Substation

WI Planned $0 NT A

A in MTEP08 West DPC 1957 3840 6/1/2012 new sub Union (DPC) 1 69 84 MVA Construct 69 kV line from new substation to DPC Union Substation

WI Planned $0 NT A

A in MTEP10 West GRE 1018 640 11/30/2012 Little Falls CWP Little Falls 1 115 196 115 kv line operated at 34.5 MN 4 Planned $1,705,514 Y AA in MTEP10 West GRE 2564 4566 10/28/2012 Sartell Le Sauk 1 115 Sartell Disribution Sub, 795 ACSS 115 kV

radial line and switchMN 3 Planned $1,385,861 Y A

A in MTEP10 West GRE 2565 4567 11/5/2012 Tower Frazer Bay 1 69 New Distribution MN 15 Under Construction

$8,783,373 NT A

A in MTEP10 West GRE 2565 4584 11/5/2012 Tower Transformer 1 115 69 70 New Substation MN 0 Planned $2,005,882 Y AA in MTEP10 West GRE 2565 4585 11/5/2012 Cook Frazer Bay 1 69 477 ACSR, 69 kV MN 12 Planned $8,485,844 NT AA in MTEP10 West GRE 2566 4569 10/14/2011 Potato Lake Potato Lake Tap 1 115 New distribution built 115 (op 34.5) MN 7 Under


A in MTEP10 West GRE 2567 4572 10/31/2012 Northport Northport Tap 1 115 New Distribution MN 1 Planned $1,149,664 Y AA in MTEP10 West GRE 2570 4581 6/2/2014 Ravenna Ravenna Tap 1 161 New Distribution MN 0 Planned $821,206 Y AA in MTEP10 West GRE 2574 4586 5/1/2017 St. Lawrence St. Lawrence Tap 1 115 St. Lawrence 69 kV 3-way switch MN 0.5 Planned $374,182 Y AA in MTEP10 West GRE 2576 4587 11/1/2011 Pokegama Pokegama Tap 1 115 New Distribution MN 8 Under


A in MTEP10 West GRE 2577 4588 6/1/2012 Elmcrest Elmcrest Tap 1 69 New Distribution MN 0 Planned $140,000 NT AA in MTEP10 West GRE 2579 4590 5/29/2015 Foster Lake Foster Lake Tap 1 69 New Distribution MN 0 Planned $140,000 NT AA in MTEP10 West GRE 2589 4600 3/25/2014 Rich Valley Rich Valley Tap 1 69 New Distribution MN 2 Planned $115,001 NT AA in MTEP10 West GRE 2605 4616 4/30/2012 Bunker Lake Bulk Substation 1 69 New Distribution MN 0 Planned $208,450 NT A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP10 West GRE 2621 4628 11/1/2013 Effie Big Fork 1 69 108 Effie-Big Fork 69 kV line, Wirt Tap 3-way switch, Jessie Lake 3-way switch, Big Fork 3-way switch

MN 19 Planned $8,107,919 NT A

A in MTEP10 West GRE 2621 4627 11/1/2013 Effie transformer 1 230 69 60 MN Planned $2,420,000 Y AA in MTEP10 West GRE 2624 4631 2/29/2012 Hudson Hudson Tap 1 115 141.6 MN 0.5 Under


A in MTEP10 West GRE 2630 4640 4/24/2013 Big Fork Wirt Tap 1 69 35 Resag MN 7.16 Planned $572,622 NT AA in MTEP10 West GRE 2630 4641 4/24/2013 Wirt Tap Jessie Lake 1 69 35 Resag MN 8.97 Planned $717,377 NT AA in MTEP10 West GRE 2631 4642 4/24/2013 Deer River Jessie Lake 1 69 58.8 Resag MN 16.52 Planned $1,339,996 NT AA in MTEP10 West GRE 2667 4684 9/30/2011 Rush City Adrian Robinson 1 69 58.8 Rush City distribution retemp MN 3.15 Planned $299,001 NT AA in MTEP10 West GRE 2670 4687 4/14/2020 Schuster Lake transformer 1 115 41.6 70 North Perham land acquisition and 115/41.6

kV sourceMN Planned $4,480,714 Y A

A in MTEP10 West GRE 2671 4634 12/30/2011 Ham Lake Soderville 1 69 75.8 Retemp MN 0.38 Planned $125,000 NT AA in MTEP10 West GRE 2671 4633 12/30/2011 Ham Lake Johnsville 1 69 75.8 Retemp MN 5.8 Planned $157,809 NT AA in MTEP10 West GRE 2672 4688 11/1/2011 Rush City transformer 1 230 69 112 Bunker Lake transformer moved to Rush City MN Planned $300,000 Y A

A in MTEP10 West GRE 2672 4689 6/1/2012 Bear Creek transformer 1 230 69 84 Rush City move to Bear Creek MN Planned $200,000 Y AA in MTEP10 West GRE 2731 4750 9/3/2012 Blomkest Lake Lillian Tap 1 69 New Distribution MN 2 Planned $1,140,342 NT AA in MTEP10 West GRE 2833 4979 10/21/2013 South Haven Lake Caroline 1 69 68 New Line MN 1 Planned $675,000 Y AA in MTEP10 West GRE 2834 4980 9/10/2013 Paynesville Hawick 1 69 85 New Line MN 5 Planned $5,138,000 Y AA in MTEP10 West GRE 3106 5441 9/3/2012 Tamarac Substation 1 115 Breaker for G619 plant wind farm connection MN Planned $728,000 Y Y AA in MTEP09 West GRE 2562 6513 3/30/2012 Pleasant Valley 161 161 kV bus work. 161 kV Breaker and half

scheme.MN Planned $1,006,365 Y A

A in MTEP09 West GRE 2563 4579 11/30/2012 Martin Lake Athens 1 69 135.9 System upgrades and permitting MN 10 Planned $6,234,719 NT AA in MTEP05 West GRE 599 753 6/1/2013 Crooked Lake Enterprise Park 1 115 316 New 115 kV line MN 4 Planned $8,616,069 Y AA in MTEP05 West GRE 600 1078 6/1/2012 Scearcyville Southdale 1 115 196 New line MN 9 Under


A in MTEP08 West GRE, OTP 1033 587 10/28/2011 Silver Lake 230/41.6 kV transformer 1 230 41.6 50 MN Under Construction

$3,230,626 Y A

A in MTEP08 West GRE, XEL, OTP, M 286 2976 12/15/2011 Quarry (St. Cloud) 345/115 transformer 1 345 115 448 new transformer and terminal works MN Planned $7,367,000 Y Y AA in MTEP08 West GRE, XEL, OTP, M 286 2640 12/15/2011 Waite Park (Quarry) Monticello 1 345 2085 Add a new 345 kV line from Waite Park to

Monticello substation and terminal worksMN 35 Planned $84,972,000 Y Y Y A

A in MTEP08 West GRE, XEL, OTP, M 286 6328 12/15/2011 Monticello substation 1 345 115 Improvements to the existing Monticello substation to accommodate new CAPX Fargo 345 kV line

MN Planned $9,755,500 Y A

A in MTEP08 West GRE, XEL, OTP, M 286 1104 5/7/2013 Alexandria SS Waite Park (Quarry) 1 345 2085 Add a new 345 kV line from Alexandria Switching Station to Waite Park and terminal works

MN 55 Planned $133,666,500 Y Y Y A

A in MTEP08 West GRE, XEL, OTP, M 286 2641 5/7/2013 Alexandria SS Transformer 1 345 115 448 new transformer and terminal works MN Planned $6,500,000 Y Y AA in MTEP08 West GRE, XEL, OTP, M 286 1105 3/31/2015 Bison Alexandria SS 1 345 2085 Add a new 345 kV line from Maple River to

Alexandria Switching Station substation and terminal works

MN/ND 135 Planned $288,050,000 Y Y Y A

A in MTEP08 West GRE, XEL, OTP, M 286 6514 3/31/2015 Bison substation 1 345 230 448 New substation ND Planned $34,436,000 Y AA in MTEP10 West ITCM 3046 5262 12/31/2012 Beverly 161kV Main and Line Breakers 69 143 MVA Add main breaker and 2 line breakers IA 0 0 Planned $1,500,000 Y AA in MTEP10 West ITCM 3046 5263 12/31/2012 26th Jct Beverly T4 1 69 140 MVA Open 26th Jct to Viola's Corner line and

extend 26th Jct to open point into the Beverly substation

IA 0 0.1 Planned $150,000 Y A

A in MTEP10 West ITCM 3046 5264 12/31/2012 Viola's Corner Beverly T4 1 69 140 MVA Open 26th Jct to Viola's Corner line and extend Viola's Corner to open point into the Beverly substation

IA 0 0.1 Planned $150,000 Y A

A in MTEP10 West ITCM 3047 5265 8/30/2011 Iowa Falls Industrial transformer 1 161 69 112 MVA Upgrade the IA Falls Ind 115/69kV TRF with a dual high side (161-115kV)/69kV TRF.

IA 0 0 Planned $1,980,000 Y A

A in MTEP10 West ITCM 3048 5266 12/31/2013 Jefferson Co Perlee 1 69 69 57 MVA Rebuild Jefferson Co-Perlee line IA 7.378 0 Planned $2,700,000 Y AA in MTEP10 West ITCM 3049 5300 12/31/2012 Huxley Industrial Park Breaker 1 161 161 335 MVA Add a 161kV line terminal to tie to the

rerouted Boone Jct-Huxley Park Ind 161kV line (CIPCO project).

IA 0 0 Planned $750,000 Y A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP10 West ITCM 3050 5272 12/31/2011 CBPC Alden new Alden-Buckeye 1 69 69 Build a 3 mile 69kV tap to the new Alden-Buckeye sub.

IA 0 3 Planned $1,080,000 Y A

A in MTEP10 West ITCM 3052 5271 12/31/2011 Washington Substation 1 69 69 Upgrade Washington 69kV sub & add bus tie breaker.

IA 0 0 Planned $2,400,000 Y A

A in MTEP10 West ITCM 3053 5297 12/31/2013 Commercial Carbide 1 69 69 100 MVA Rebild to doulbe ckt 69kV IA Planned $540,000 Y AA in MTEP10 West ITCM 3053 5295 12/31/2013 Keokuk Hydro Messenger 1 69 69 100 MVA Rebild to doulbe ckt 69kV IA Planned $540,000 Y AA in MTEP10 West ITCM 3053 5296 12/31/2013 Messenger Commercial 1 69 69 100 MVA Rebild to doulbe ckt 69kV IA Planned $540,000 Y AA in MTEP10 West ITCM 3053 5294 12/31/2013 Keokuk Hydro Carbide 1 69 69 100 MVA Build a new Keokuk Hydro-Carbide 69 kV

line.IA Planned $1,620,000 Y A

A in MTEP10 West ITCM 3054 5270 12/31/2011 Amana Amana T 1 69 69 Close N.O. Amana-Amana T line. IA 0 0 Planned $0 Y AA in MTEP10 West ITCM 3054 5268 12/31/2011 Swisher Swisher REC 1 69 69 Close N.O. Swisher-Swisher REC line. IA 0 0 Planned $352,000 Y AA in MTEP10 West ITCM 3054 5267 12/31/2011 Tharp (Swisher) Breaker Station 1 69 69 Build a new 3 terminal breaker station. IA 0 0 Planned $1,800,000 Y AA in MTEP10 West ITCM 3054 5269 12/31/2011 North Liberty North Liberty REC 1 69 69 Close N.O. North Liberty-North Liberty REC

line.IA 0 0 Planned $0 Y A

A in MTEP10 West ITCM 3055 5280 12/31/2011 Marion Collins 1 69 69 Rebuild 34kV to 69kV(operate at 34kV until 69kV/dist subs are ready)

IA 2.5 Planned $700,000 Y A

A in MTEP10 West ITCM 3055 5281 12/31/2011 Collins Hiawatha 1 69 69 Rebuild 34kV to 69kV(operate at 34kV until 69kV/dist subs are ready)

IA 1 Planned $700,000 Y A

A in MTEP10 West ITCM 3055 5288 12/31/2012 Downtown Network Substation 1 161 161 New 115kV/dist sub IA Planned $2,160,000 Y AA in MTEP10 West ITCM 3055 5286 12/31/2012 Downtown Network PCI 1 161 161 Rebuild 34kV to 161kV IA 5 Planned $2,100,000 Y AA in MTEP10 West ITCM 3055 5285 12/31/2012 Downtown Industrial Downtown Network 1 161 161 Rebuild 34kV to 161kV IA 2 Planned $2,100,000 Y AA in MTEP10 West ITCM 3055 5283 12/31/2013 Oak Hill Marion 1 69 69 Rebuild 34kV to 69kV(operate at 34kV until

69kV/dist subs are ready)IA 8 Planned $1,010,000 Y A

A in MTEP10 West ITCM 3055 5278 12/31/2013 Emerald Isle Cargil West 1 69 69 Rebuild 34kV to 69kV(operate at 34kV until 69kV/dist subs are ready)


A in MTEP10 West ITCM 3055 5282 12/31/2013 PCI Oak Hill 1 69 69 Rebuild 34kV to 69kV(operate at 34kV until 69kV/dist subs are ready)

IA 5 Planned $1,010,000 Y A

A in MTEP10 West ITCM 3055 5277 12/31/2013 Emerald Isle Louisa 1 69 69 Rebuild 34kV to 69kV(operate at 34kV until 69kV/dist subs are ready)


A in MTEP10 West ITCM 3055 5276 12/31/2013 Marion Emerald Isle 1 69 69 Rebuild 34kV to 69kV(operate at 34kV until 69kV/dist subs are ready)


A in MTEP10 West ITCM 3055 5279 12/31/2013 Cargil West PCI 1 69 69 Rebuild 34kV to 69kV(operate at 34kV until 69kV/dist subs are ready)


A in MTEP10 West ITCM 3055 5289 12/31/2013 Marion transformer 1 161 69 100 MVA Add a 161/69kV TRF at Marion IA Planned $3,240,000 Y AA in MTEP10 West ITCM 3055 5293 12/31/2013 Oak Hill Substation 1 69 New 69kV/dist sub IA Planned $2,160,000 Y AA in MTEP10 West ITCM 3055 5291 12/31/2014 Cargil West Substation 1 69 69 New 69kV/dist sub IA Planned $2,160,000 Y AA in MTEP10 West ITCM 3055 5290 12/31/2014 Collins Substation 1 69 69 New 69kV/dist sub IA Planned $2,160,000 Y AA in MTEP10 West ITCM 3055 5292 12/31/2014 Emerald Isle Substation 1 69 69 New 69kV/dist sub IA Planned $2,160,000 Y AA in MTEP10 West ITCM 3056 5298 12/31/2012 Grundy Center Reinbeck 1 69 69 Rebuild 34kV to 69kV IA 12 0 Planned $4,320,000 Y AA in MTEP10 West ITCM 3056 5299 12/31/2012 Reinbeck Hicks tap 1 69 69 Rebuild 34kV to 69kV IA 4 0 Planned $1,440,000 Y AA in MTEP10 West ITCM 3057 5303 12/31/2013 Moscow Tap Magmet T 1 69 69 Tap the Muscatine Switch Station to Magmet

T69kV line for new tap to Moscow.IA 0 0 Planned $0 Y A

A in MTEP10 West ITCM 3057 5304 12/31/2013 New Liberty New Liberty Tap 1 69 69 77 MVA Build a new 2 mile 69kV tap to New Liberty & retire 9.4 mile 34kV tap.

IA 0 2 Planned $700,000 Y A

A in MTEP10 West ITCM 3057 5302 12/31/2013 Muscatine Switch Station

Moscow Tap 1 69 69 Tap the Muscatine Switch Station to Magmet T69kV line for new tap to Moscow.

IA 0 0 Planned $0 Y A

A in MTEP10 West ITCM 3057 5301 12/31/2013 Moscow Moscow Tap 1 69 69 77 MVA Build a new 3.75 mile 69kV tap to Moscow & retire 7 mile 34kV tap.

IA 0 3.75 Planned $1,313,000 Y A

A in MTEP10 West ITCM 3057 6419 12/31/2013 New Liberty New Liberty Tap 1 34 34 Retire the New Liberty 34kV 9.4 mile tap IA Planned $282,000 Y AA in MTEP10 West ITCM 3057 6418 12/31/2013 Moscow Tap Moscow 1 34 34 Retire the Moscow 34kV 7 mile tap IA Planned $210,000 Y AA in MTEP10 West ITCM 3058 5319 12/31/2011 Shady Grove REC Substation 1 69 69 New 69kV/dist sub IA Planned $0 Y AA in MTEP10 West ITCM 3058 5310 12/31/2011 Quasqueton Tap Quasqueton REC 1 69 69 Rebuild 34kV to 69kV IA 4 0 Planned $1,440,000 Y AA in MTEP10 West ITCM 3058 5309 12/31/2011 Brandon Shady Grove REC 1 69 69 Rebuild 34kV to 69kV IA 4.5 0 Planned $1,980,000 Y AA in MTEP10 West ITCM 3058 5320 12/31/2011 Quasqueton REC Substation 1 69 69 New 69kV/dist sub IA Planned $0 Y AA in MTEP10 West ITCM 3058 5318 12/31/2011 Brandon Substation 1 69 69 New 69kV/dist sub IA Planned $0 Y AA in MTEP10 West ITCM 3058 5307 12/31/2012 Shellsburg Palo 1 69 69 Rebuild 34kV to 69kV IA 4 0 Planned $1,620,000 Y AA in MTEP10 West ITCM 3058 5311 12/31/2012 Troy Mills Walker REC 1 69 69 Rebuild 34kV to 69kV IA 6.55 Planned $2,358,000 Y A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP10 West ITCM 3058 5322 12/31/2012 Lafayette Substation 1 69 69 New 69kV/dist sub IA Planned $0 Y AA in MTEP10 West ITCM 3058 5315 12/31/2012 Vinton transformer 1 161 69 100 MVA Add a 161/69kV TRF at Vinton IA Planned $3,250,000 Y AA in MTEP10 West ITCM 3058 5316 12/31/2012 Palo Substation 1 69 69 New 69kV/dist sub IA Planned $0 Y AA in MTEP10 West ITCM 3058 5317 12/31/2012 Shellsburg Substation 1 69 69 New 69kV/dist sub IA Planned $0 Y AA in MTEP10 West ITCM 3058 5314 12/31/2012 Lafayette Hiawatha 1 69 69 Rebuild 34kV to 69kV IA 6 Planned $2,160,000 Y AA in MTEP10 West ITCM 3058 5323 12/31/2013 Urbana Substation 1 69 69 New 69kV/dist sub IA Planned $0 Y AA in MTEP10 West ITCM 3058 5308 12/31/2013 Palo Todville REC 1 69 69 New 69kV IA 0 4.5 Planned $1,260,000 Y AA in MTEP10 West ITCM 3058 5312 12/31/2013 Vinton Shellsburg 1 69 69 Rebuild 34kV to 69kV IA 11 Planned $4,320,000 Y AA in MTEP10 West ITCM 3058 5313 12/31/2013 Walker REC Urbana 1 69 69 Rebuild 34kV to 69kV IA 10 Planned $3,600,000 Y AA in MTEP10 West ITCM 3058 5321 12/31/2013 Walker REC Substation 1 69 69 New 69kV/dist sub IA Planned $0 Y AA in MTEP10 West ITCM 3059 5325 12/31/2011 West Liberty Breaker Station 1 69 69 140 MVA Build a new 3 terminal breaker station. IA 0 0 Planned $1,560,000 Y AA in MTEP10 West ITCM 3059 5324 12/31/2011 West Branch Breaker Station 1 69 69 140 MVA Build a new 3 terminal breaker station. IA 0 0 Planned $1,560,000 Y AA in MTEP09 West ITCM 2339 4286 9/30/2011 Ames Fernald 1 161 446 MVA Rebuild 115kV to 161kV line IA 6 Under

Construction$4,200,000 Y Y A

A in MTEP09 West ITCM 2339 4285 11/30/2011 Boone Junction Ames 1 161 446 MVA Rebuild 115kV to 161kV line IA 8.4 Under Construction

$5,880,000 Y Y A

A in MTEP09 West ITCM 2339 4284 5/30/2012 Boone Boone Junction 1 161 446 MVA Rebuild 115kV to 161kV line IA 5.2 Planned $3,640,000 Y Y AA in MTEP09 West ITCM 2340 4296 12/31/2011 Grand Junction Grand Junction City 1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 2.75 Planned $639,200 NT AA in MTEP09 West ITCM 2340 4297 12/31/2011 Grand Junction City Grand Junction North 1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 2 Planned $464,327 NT AA in MTEP09 West ITCM 2341 4331 9/1/2011 Amber Monticello Industrial 1 69 77/77 MVA Rebuild 34kV to 69kV IA 8.51 Under

Construction$2,291,032 NT A

A in MTEP09 West ITCM 2341 4332 9/1/2011 Amber breakers 69 Add two 69kV breakers at the Amber Creamery sub.

IA Under Construction

$185,000 NT A

A in MTEP09 West ITCM 2341 4333 9/1/2011 Sand Springs breaker 69 Add a Sand Springs 69kV breaker and operate the Sand Springs-Monticello Industrial-Amber line at 69kV.


$340,000 NT A

A in MTEP09 West ITCM 2341 4334 9/1/2011 Monticello Industrial breaker 69 Add a Monticello Industrial 69kV bus tie breaker and 69kV line breakers on the Sand Springs and Amber Creamery 69kV lines.


$364,000 NT A

A in MTEP09 West ITCM 2341 4335 10/30/2011 Lovell REC Tap Lovell REC Junction 1 34 39/39 MVA Rebuild the remaning 2.21 miles of the 4.14 mile Lovell REC Tap-Lovell Junction 34kV line to 69kV standards. This line section will continue operation at 34kV. Monticello Industrial-Lovell REC 34kV line N.O.

IA 2.21 Under Construction

$594,968 NT A

A in MTEP09 West ITCM 2342 4303 12/31/2011 Ridgeport REC Boone Junction 1 34 39/39 MVA Rebuild 6 miles of 34kV to 69kV (operated 34kV) from the Ridgeport REC sub south towards Boone Jct.

IA 6 Under Construction

$1,588,515 NT A

A in MTEP09 West ITCM 2342 4301 12/31/2011 Stanhope Stratford REC Tap 1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 5 Under Construction

$1,323,762 NT A

A in MTEP09 West ITCM 2342 4302 12/31/2011 Stratford REC Tap Ridgeport REC 1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 5 Under Construction

$1,323,762 NT A

A in MTEP09 West ITCM 2342 4300 12/31/2011 Jewell Stanhope 1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 9.25 Under Construction

$2,448,961 NT A

A in MTEP09 West ITCM 2343 4307 12/31/2011 Mid-America Pump Tap IA Valley Milling Tap 1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 0.5 Planned $302,891 NT AA in MTEP09 West ITCM 2343 4304 12/31/2011 West Branch Mid-America Storage 1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 2 Planned $550,710 NT AA in MTEP09 West ITCM 2343 4308 12/31/2011 IA Valley Milling Tap IA Valley Milling Sub 1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 1.1 Planned $137,678 NT AA in MTEP09 West ITCM 2343 4305 12/31/2011 Mid-America Storage Mid-America Pump Tap 1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 2 Planned $550,710 NT AA in MTEP09 West ITCM 2343 4309 12/31/2011 IA Valley Milling Tap West Liberty 1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 8.21 Planned $2,260,667 NT AA in MTEP09 West ITCM 2343 4306 12/31/2011 Mid-America Pump Tap Mid-America Pump

Station1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 1.25 Planned $344,194 NT A

A in MTEP09 West ITCM 2344 4311 12/31/2012 Dome Pipeline Oxford Mills 1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 5 Planned $1,675,000 NT AA in MTEP09 West ITCM 2344 4310 12/31/2012 Wyoming Dome Pipeline 1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 2.3 Planned $770,500 NT AA in MTEP09 West ITCM 2344 4312 12/31/2012 Oxford Mills Massilon 1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 4.7 Planned $1,574,500 NT AA in MTEP09 West ITCM 2345 4326 12/31/2012 Union Whitten 1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 5.25 Under

Construction$1,521,822 NT A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP09 West ITCM 2345 4313 12/31/2012 Otter Creek (Eldora North)

new switching station 69 Construct a new 4-terminal 69kV switching station along the Corn Belt 69kV line. Switch station will be named Otter Creek.


$1,658,000 NT A

A in MTEP09 West ITCM 2345 4330 12/31/2012 Beaman Gladbrook T 1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 3.5 Under Construction

$1,014,550 NT A

A in MTEP09 West ITCM 2345 4329 12/31/2012 Conrad distribution Beaman 1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 2.25 Under Construction

$652,210 NT A

A in MTEP09 West ITCM 2345 4328 12/31/2012 Conrad 69/34kV Conrad distribution 1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 5.05 Under Construction

$1,463,848 NT A

A in MTEP09 West ITCM 2345 4327 12/31/2012 Whitten Conrad 69/34kV 1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 4.8 Under Construction

$1,391,380 NT A

A in MTEP09 West ITCM 2345 4325 12/31/2012 CBPC Union Union 1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 1.5 Under Construction

$434,806 NT A

A in MTEP09 West ITCM 2345 4324 12/31/2012 Airport East Tap CBPC Union 1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 4.29 Under Construction

$1,243,546 NT A

A in MTEP09 West ITCM 2345 4323 12/31/2012 New Eldora North Switching

Airport East Tap 1 34 39/39 MVA Rebuild 34kV to 69kV (operated 34kV) IA 4.5 Under Construction

$1,304,419 NT A

A in MTEP09 West ITCM 2345 4322 12/31/2012 IPL Radcliffe Sub substation 34 Retire IPL Garden City Sub IA Under Construction

$0 NT A

A in MTEP09 West ITCM 2345 4314 12/31/2012 CBPC Radcliffe Switch Station

Hubbard Rural 1 69 77/77 MVA Operate at 69kV (already built to 69kV standards)


$0 NT A

A in MTEP09 West ITCM 2345 4320 12/31/2012 IPL Radcliffe 34kV/dist Sub

substation 34 Retire IPL Radcliffe Sub IA Under Construction

$0 NT A

A in MTEP09 West ITCM 2345 4319 12/31/2012 CBPC Enron substation 34 CBPC Enron Sub 34 to 69kV converion IA Under Construction

$0 NT A

A in MTEP09 West ITCM 2345 4318 12/31/2012 IPL Hubard Rural 69kV/dist Sub

substation 34 IPL Hubbard Rural Sub 34 to 69kV converion IA Under Construction

$0 NT A

A in MTEP09 West ITCM 2345 4317 12/31/2012 Eldora City Sub New Eldora North Switching

1 69 77/77 MVA Rebuild 34kV to 69kV IA 2 Under Construction

$579,755 NT A

A in MTEP09 West ITCM 2345 4316 12/31/2012 Enron Tap Eldora City Sub 1 69 77/77 MVA Rebuild 34kV to 69kV IA 14.5 Under Construction

$4,203,129 NT A

A in MTEP09 West ITCM 2345 4315 12/31/2012 Hubbard Rural Enron Tap 1 69 77/77 MVA Rebuild 34kV to 69kV IA 3.6 Under Construction

$1,043,535 NT A

A in MTEP09 West ITCM 2345 4321 12/31/2012 IPL Hubbard 34kV/dist. Sub

substation 34 Retire IPL Hubbard Sub IA Under Construction

$0 NT A

A in MTEP09 West ITCM 2348 4341 12/31/2011 Beaver Rock new switching station 1 69 Construct a new 3-terminal 69kV switching station along the Beaver Channel-Rock Creek 69kV line.


$1,553,178 NT A

A in MTEP09 West ITCM 2348 4340 12/31/2011 Beaver Rock Beaver Channel 1 69 103/103 MVA Tap Beaver Channel-Rock Creek 69kV for new switching station.


$20,000 NT A

A in MTEP09 West ITCM 2348 4338 12/31/2011 Beaver Rock Comanche Tap 1 69 77/77 MVA Tie new CIPCO 69kV line from Comanche REC to Beaver Rock.

IA 0.75 Under Construction

$0 NT A

A in MTEP09 West ITCM 2348 4339 12/31/2011 Beaver Rock Rock Creek 1 69 130/130 MVA Tap Beaver Channel-Rock Creek 69kV for new switching station. The Rock Creek-Beaver Rock 69kV line will be N.O.


$20,000 NT A

A in MTEP09 West ITCM 2353 4344 12/31/2011 Big River Breaker(Hunt Woods) Station

new switching station 69 Construct a new 3-terminal 69kV switching station where the Big River REC line taps the Agency-Sawyer 69kV line.

IA Planned $1,666,427 NT A

A in MTEP09 West ITCM 2357 4389 12/31/2013 Fairbank new switching station 1 69 Construct a new 3-terminal 69kV switching station, at the existing Fairbank substation.


A in MTEP09 West ITCM 2357 4390 12/31/2013 Fairbank Tap Fairbank Switching station

1 69 77/77 MVA Rebuild the 2.9 mile tap from the new Fairbank SS-Fairbank Tap to double circuit..

IA 2.9 Planned $1,370,000 NT A

A in MTEP09 West ITCM 2357 4391 12/31/2013 Fairbank Switching Station

Hazleton 1 69 77/77 MVA Build new 69kV line from the Fairbank sub to the existing Hazleton-Oelwein 69kV line.

IA 5 Planned $2,262,198 NT A

A in MTEP09 West ITCM 2357 6417 12/31/2013 Tripoli substation 69 Reset the existing 69kV relays at Tripoli IA Planned $10,000 Y AA in MTEP09 West ITCM 2357 6416 12/31/2013 Hazleton substation 69 Upgrade the Hazleton 69kV terminal IA Planned $500,000 Y A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP09 West ITCM 2357 6415 12/31/2013 Hazleton Oelwein 69 Retire portion of the Hazleton-Oelwein 69kV line not needed after theFairbankk 69kV loop is created.

IA Planned $67,000 Y A

A in MTEP09 West ITCM 2358 4352 12/31/2013 Hazleton Blackhawk 1 161 326/326 MVA Rebuild existing line IA 12 Planned $5,400,000 Y Y AA in MTEP09 West ITCM 2363 4385 8/30/2011 Glenworth 161/69kV new substation 1 161 69 Construct a new Glenville 161/69kV 100

MVA substation near the junction of the Hayward-Worth County 161kV line and the DPC Hayward-Twin Lakes 69kV line.


$7,240,605 Y A

A in MTEP09 West ITCM 2364 4386 12/31/2011 Bricelyn Thompson 1 69 77/77 MVA Rebuild 2 miles of the N.O. 69kV Bricelyn tap-Thompson tap to double circuit 69kV line to allow for 2 separate circuits.

IA 2 Planned $230,000 NT A

A in MTEP09 West ITCM 2364 4904 12/31/2011 Lincoln REC Tap (DPC) Golden Oval (DPC) 1 69 18 MVA Rebuild 2 miles of the N.O. 69kV Bricelyn tap-Thompson tap to double circuit 69kV line to allow for 2 separate circuits.


A in MTEP09 West ITCM 2367 4366 12/31/2013 Stuart Muni Tap Dexter 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).

IA 4.75 Planned $1,187,500 NT A

A in MTEP09 West ITCM 2367 4365 12/31/2013 Stuart REC Tap Stuart Muni Tap 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).

IA 1.6 Planned $400,000 NT A

A in MTEP09 West ITCM 2367 4368 12/31/2013 Diamondhead REC Redfield 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).


A in MTEP09 West ITCM 2367 4364 12/31/2013 Menlo Stuart REC Tap 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).

IA 4.28 Planned $1,070,000 NT A

A in MTEP09 West ITCM 2367 4363 12/31/2013 Thompson Menlo 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).


A in MTEP09 West ITCM 2367 4362 12/31/2013 Anita-Wiota Adair 1 34 39/39 MVA Rebuild 1.2 miles of the Anita-Wiota-Adair line.


A in MTEP09 West ITCM 2367 4367 12/31/2013 Dexter Diamondhead REC 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).


A in MTEP09 West ITCM 2367 4360 12/31/2013 Anita 161kV Exira REC 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).


A in MTEP09 West ITCM 2367 4361 12/31/2013 Anita 161kV Anita-Wiota 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).


A in MTEP09 West ITCM 2369 4372 12/31/2013 Walford Norway Tap 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).


A in MTEP09 West ITCM 2369 4379 12/31/2013 Conroy Junction Williamsburg 115kV 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).


A in MTEP09 West ITCM 2369 4378 12/31/2013 Marengo REC Conroy Junction 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).


A in MTEP09 West ITCM 2369 4376 12/31/2013 Pioneer Tap Marengo South 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).


A in MTEP09 West ITCM 2369 4373 12/31/2013 Walford Marengo North Tap 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).

IA 8.22 Planned $2,129,980 NT A

A in MTEP09 West ITCM 2369 4374 12/31/2013 Marengo North Tap Marengo East 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).


A in MTEP09 West ITCM 2369 4371 12/31/2013 Fairfax REC Walford 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).


A in MTEP09 West ITCM 2369 4370 12/31/2013 Fairfax dist. Fairfax REC 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).


A in MTEP09 West ITCM 2369 4369 12/31/2013 Fairfax 161kV Fairfax dist. 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).


A in MTEP09 West ITCM 2369 4375 12/31/2013 Marengo East Pioneer Tap 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).


A in MTEP09 West ITCM 2369 4377 12/31/2013 Marengo South Marengo REC 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).


A in MTEP09 West ITCM 2370 4381 12/31/2011 Monmouth Tap Monmouth dist 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).







Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP09 West ITCM 2370 4382 12/31/2011 Monmouth Tap Monmouth REC 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).


A in MTEP09 West ITCM 2370 4380 12/31/2011 Andrew Tap Andrew dist 1 34 39/39 MVA Rebuild the 34kV line to 69kV (operate at 34kV).

IA 5.75 Planned $1,386,865 NT A

A in MTEP09 West ITCM 2371 4383 12/31/2013 Marengo new switching station 1 69 Construct a new 3-terminal 69kV switching station at the existing Marengo 34kV sub. This work needs to be completed for 69kV operation.


A in MTEP08 West ITCM 1340 2973 12/31/2012 Hazelton 345 termination 345 1195 Expand ring bus to a five breaker ring bus (min 2000 amp). Add one 345kV CB.

Extend existing single dead-end tower to double dead-end tower.

Four existing 345kV switches rated 1600 amps replaced with 2000 amp switches.

IA Planned $1,080,000 Y A

A in MTEP08 West ITCM 1340 2974 12/31/2012 Salem 345 termination 345 1195 Expand ring bus to a five breaker ring bus (min 2000 amp). Add one 345kV CB. Extend

existing single dead-end tower to double dead-end tower. Four existing 345kV switches rated 1600 amps replaced with 2000 amp switches.


A in MTEP08 West ITCM 1340 4906 12/31/2012 Salem Transformer 2 345 161 448 Upgrade Salem 345 sub & add 2nd 345/161kV transformer


A in MTEP08 West ITCM 1340 5390 12/31/2012 Liberty Lore 1 161 Rebuild a portion of the 161kV line to 326 MVA capacity and install OPWG shield wire the entire distance.

IA 10.8 Planned Y A

A in MTEP08 West ITCM 1340 5389 12/31/2012 Dundee Liberty 1 161 326 MVA Rebuild the 161kV line to 326 MVA capacity. IA 1.94 Planned Y AA in MTEP08 West ITCM 1340 5388 12/31/2012 Hazleton Dundee 1 161 326 MVA Rebuild the 161kV line to 326 MVA capacity. IA 18.05 Planned Y AA in MTEP08 West ITCM 1340 4905 12/31/2012 Salem Hazleton 1 345 1195 Construct a new 345-161kV dbl ckt line(54

miles) and all new ROW for 27 miles of new single ckt 345kV.

IA 81 Planned $110,000,000 Y A

A in MTEP08 West ITCM 1618 2720 6/1/2013 Heron Lake Lakefield Jct 1 161 446/446 MVA Rebuild MN 17 Planned $14,000,000 Y Y AA in MTEP08 West ITCM 1619 2725 12/31/2011 East Calamus T Maquoketa 1 161 remove model branch IA Planned Y AA in MTEP08 West ITCM 1619 2723 12/31/2011 East Calamus Grand Mound 1 161 200/200 MVA New 161kV line IA Planned Y AA in MTEP08 West ITCM 1640 2751 8/30/2011 Iowa Falls Industrial transformer 1 115 69 35 MVA REMOVE transformer branch IA Planned $0 Y AA in MTEP08 West ITCM 1640 2737 12/31/2011 Iowa Falls Nuthatch 1 161 446 MVA Rebuild 115kV to 161kV line IA 2.65 0 Planned $1,000,000 Y AA in MTEP08 West ITCM 1640 2753 12/31/2011 Iowa Falls transformer 2 115 34 20 MVA REMOVE transformer branch IA Planned $0 Y AA in MTEP08 West ITCM 1640 2735 12/31/2011 Iowa Falls Industrial Iowa Falls 1 161 446 MVA Rebuild old IA Falls-IA Falls Industrial Tap

115kV to 161kV line. (operate at 115 kV until 2013 conversion completion) (1.54 miles IA Falls Ind Tap-IA Falls Ind already built to 161kV.

IA 2.75 0 Planned $580,000 Y A

A in MTEP08 West ITCM 1640 2752 12/31/2011 Iowa Falls transformer 1 115 34 20 MVA REMOVE transformer branch IA Planned $0 Y AA in MTEP08 West ITCM 1640 2734 12/31/2012 Eldora Iowa Falls Industrial 1 161 326/326 MVA Rebuild Eldora-IA Falls Ind Tap 115kV to

161kV line.(operate at 115 kV until 2013 conversion completion) Build a new completely separate ROW 2 mile 161kV line section from the approximate IA Falls Ind Tap location to the IA Falls Industrial sub.

IA 10.7 2 Planned $6,000,000 Y A

A in MTEP08 West ITCM 1640 2745 12/31/2013 Eldora transformer 1 161 34 20 MVA Retire Eldora Sub IA Planned $100,000 Y AA in MTEP08 West ITCM 1640 2742 12/31/2013 Iowa Falls Industrial Tap Iowa Falls Industrial 1 115 REMOVE model branch IA 1.54 0 Planned $0 Y AA in MTEP08 West ITCM 1640 2739 12/31/2013 Wellsburg Eldora 1 115 REMOVE model branch IA 11.5 0 Planned $0 Y AA in MTEP08 West ITCM 1640 2741 12/31/2013 Iowa Falls Industrial Tap Iowa Falls 1 115 REMOVE model branch IA 11.59 0 Planned $0 Y AA in MTEP08 West ITCM 1640 2754 12/31/2013 Wellsburg transformer 1 115 69 50 MVA REMOVE transformer branch IA Planned $0 Y AA in MTEP08 West ITCM 1640 2736 12/31/2013 Iowa Falls Industrial Tap 3-terminal line 1 161 262/262 MVA Iowa Falls Industrial Tap bus (3-terminal line)

will be eliminated.IA 0 0 Planned $0 Y A

A in MTEP08 West ITCM 1640 2740 12/31/2013 Eldora Iowa Falls Industrial Tap 1 115 REMOVE model branch IA 1.21 0 Planned $0 Y AA in MTEP08 West ITCM 1640 2749 12/31/2013 Wellsburg transformer 1 161 69 100 MVA Upgrade 115kV xfmr to 161kV IA Planned $1,500,000 Y A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP08 West ITCM 1640 2750 12/31/2013 Eldora transformer 1 115 34 20 MVA REMOVE transformer branch IA Planned $0 Y AA in MTEP08 West ITCM 1640 2733 12/31/2013 Wellsburg Eldora 1 161 326/326 MVA Rebuild Wellsburg-Eldora 115kV to 161kV

line.(operate at 115 kV until 2013 conversion completion)

IA 11 0 Planned $5,500,000 Y A

A in MTEP08 West ITCM 1640 2732 12/31/2013 Marshalltown Wellsburg 1 161 326/326 MVA Rebuild 115kV to 161kV line (operate at 115 kV until 2013 conversion completion)

IA 23.8 0 Planned $6,900,000 Y A

A in MTEP08 West ITCM 1640 2738 12/31/2013 Marshalltown Wellsburg 1 115 REMOVE model branch IA 27 0 Planned $0 Y AA in MTEP08 West ITCM 1645 2759 12/31/2011 Leon Cap Bank 1 69 7.2 MVAR new 69kV Cap Bank IA Planned $2,511,808 NT AA in MTEP08 West ITCM 1744 3546 12/31/2016 Maquoketa Grand Mound 1 161 326/326 MVA Reconductor IA 14.5 Planned $10,150,000 Y AA in MTEP08 West ITCM 1747 3554 5/31/2011 Elk transformer 1 161 69 100 MVA Upgrade transformer MN Under


A in MTEP08 West ITCM 1747 5534 12/31/2011 Elk substation 161 69 Add a 161kV Elk bus tie breaker and 161kV breaker on the line to Brewster and add new control building.


$900,000 Y A

A in MTEP08 West ITCM 1747 3555 12/31/2011 Elk transformer 2 161 69 100 MVA Upgrade transformer MN Under Construction

$3,049,198 Y A

A in MTEP08 West ITCM 2108 2821 10/31/2011 G358 GSU Substation new switching station 1 161 34.5 Facilities, excluding the Transmission Owner Interconnection Facilities, required for a 4 terminal, 3 breaker switching station

MN Planned $3,600,000 Y Y A

A in MTEP08 West ITCM 2108 2822 10/31/2011 Winnebago WinnCo 1 161 Transmission line taps to new 161 kV switching station.

MN Planned $250,000 Y Y A

A in MTEP08 West ITCM 2108 4030 10/31/2011 Microwave communication network

Upgrade Transmission Owner's microwave communication network


A in MTEP08 West ITCM 2108 2824 10/31/2011 WinnCo substation 1 161 Upgrade Winnebago Junction substation relays and carrier to accommodate the new switching station


A in MTEP08 West ITCM 2108 2823 10/31/2011 Winnebago Junction substation 1 161 Upgrade Winnebago Junction substation relays and carrier to accommodate the new switching station


A in MTEP06 West ITCM 1289 2120 3/30/2012 Belle Plaine Stoney Point 1 115 233/233 Rebuild IA 27 Under Construction

$8,208,000 Y A

A in MTEP06 West ITCM 1289 6411 12/31/2013 Belle Plaine terminal equipment 161 Replace BKRs 1420 & 1430 IA Planned $580,000 Y AA in MTEP06 West ITCM 1289 6412 12/31/2013 Stoney Point terminal equipment 161 Replace BKRs 1410, 3250, & 3630 IA Planned $2,200,000 Y AA in MTEP06 West ITCM 1289 6413 12/31/2013 Marshalltown terminal equipment 161 Replace BKR postion 1450 IA Planned $365,000 Y AA in MTEP06 West ITCM 1289 6414 12/31/2013 Toledo terminal equipment 161 Add BKRs IA Planned $2,300,000 Y AA in MTEP06 West ITCM 1342 5632 12/31/2014 Lewis Fields new 161-115 kV

Substation1 161 558 MVA Add breakers & associated equipment(bus,

control building, relays, etc.) for the new 161-115 kV Lewis Fields substation.


A in MTEP06 West ITCM 1342 2209 12/31/2014 Lewis Fields transformer 1 161 115 250/250 MVA new transformer IA Planned $6,200,000 Y AA in MTEP06 West ITCM 1342 4902 12/31/2014 Hiawatha new 161 kV line terminal 1 161 558 MVA Add 161 kV breaker & associated equipment

for the new 161 kV line terminal to Lewis Fields.


A in MTEP06 West ITCM 1342 2208 12/31/2014 Lewis Fields Hiawatha 1 161 326/326 MVA new line IA 8.5 Planned $8,151,600 Y AA in MTEP06 West ITCM 1342 5633 12/31/2014 Lewis Fields Transformer 1 161 115 250 MVA Install new 161-115 kV transformer IA Planned $1,900,000 Y AA in MTEP06 West ITCM 1344 5391 12/31/2014 Arnold Morgan Valley 1 161 326 MVA Tap the Arnold-Fairfax 161kV line for in and

out at Morgan ValleyIA Planned $150,000 Y A

A in MTEP06 West ITCM 1344 5392 12/31/2014 Morgan Valley Fairfax 1 161 326 MVA Tap the Arnold-Fairfax 161kV line for in and out at Morgan Valley


A in MTEP06 West ITCM 1344 2212 12/31/2014 Morgan Valley transformer 1 345 161 335 new substation IA Planned $8,750,000 Y AA in MTEP06 West ITCM 1344 2211 12/31/2014 Morgan Valley Beverly 1 161 335 new line IA 7.9 Planned $5,530,000 Y AA in MTEP09 West MDU 1355 2242 9/30/2011 Heskett Additional 230/115 kV

Switchyard230 115 200 MVA Switchyard in parallel w/ existing Heskett

switchyardND Planned $9,500,000 Y Y A

A in MTEP09 West MDU 1355 2241 12/31/2014 Heskett Capacitor 115 30 MVAr ND Planned $1,500,000 Y Y AA in MTEP10 West MP 2547 4558 6/30/2012 Essar steel plant sub

(McCarthy Lake)Substation Equipment 230 14 166 Essar Substation high side equipment MN Under


A in MTEP10 West MP 2547 4559 6/30/2012 Essar Mine Sub (Calumet)

Substation Equipment 230 14 166 Essar Substation high side Equipment MN Under Construction

$4,000,000 Y A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP10 West MP 2547 4560 6/30/2012 Essar Mine Sub (Calumet)

Essar steel plant sub (McCarthy Lake)

1 230 465 Essar new Line MN 2.5 Planned $2,200,000 Y A

A in MTEP10 West MP 2547 4556 6/30/2012 Essar Steel Sub (McCarthy Lake)

Shannon 1 230 423 Essar 94L Line reroute MN 8 Planned $4,100,000 Y A

A in MTEP10 West MP 2547 4555 6/30/2012 Boswell Essar Mine Sub (Calumet)

1 230 423 Essar Line 94L Line reroute MN 16 Planned $6,100,000 Y A

A in MTEP10 West MP 2547 4557 7/30/2014 Blackberry Essar Steel Sub (McCarthy Lake)

1 230 465 Essar new Line and new bay at McCarthy Lake (facility #4558)

MN 16 Planned $12,900,000 Y A

A in MTEP10 West MP 2547 5438 7/30/2014 Blackberry Substation Equipment 230 14 465 line entrance & breaker MN Planned $1,100,000 Y AA in MTEP10 West MP 2761 4780 12/30/2012 Dunka Road Substation Equipment 115 14 15 Substation Equipment & Transformer MN Planned $3,000,000 Y AA in MTEP10 West MP 2762 4776 12/16/2012 Airpark Substation Equipment 115 34.5 39 Substation Equipment & Transformer MN Under


A in MTEP10 West MP 2762 4778 6/30/2013 Airpark Substation Equipment 115 14 39 Substation Equipment & Transformer MN Under Construction

$2,005,000 Y A

A in MTEP10 west MP 3091 5409 5/30/2012 Boswell Nashwaulk 1 115 144 reroute existing MP Line #28 MN 7.5 planned $3,190,000 Y AA in MTEP09 West MP 2552 4554 12/1/2012 Skibo Hoyt Lakes 1 138 202 new line MN 3 Planned $2,540,000 Y AA in MTEP09 West MP 2759 4782 6/1/2012 Laskin Substation Equipment 115 46 28 Substation Transformer MN Planned $500,000 Y AA in MTEP09 West MP 2763 4779 8/30/2011 LSPI Substation Equipment 115 34.5 30 Substation Equipment & Transformer MN Under


A in MTEP07 West MP 1025 2663 7/1/2012 Swatara 230/115 kV transformer 230 115 New 230/115 kV Swatara Substation MN Planned $8,817,640 Y Y AA in MTEP07 West MP 1025 2659 7/1/2012 Blackberry 230 230 Blackberry Sub: 3 each-230 kV circuit

breakers, 9 each-230 kV air break switches, structural steel, bus work and control equipment


A in MTEP07 West MP 1025 2661 7/1/2012 Swatara 230 Riverton 230 230 Swatara to Riverton 33.2 Miles MN Planned $24,878,937 Y Y AA in MTEP07 West MP 1025 2662 7/1/2012 Blackberry 230 kV sub 230 230 kV Bus Position for Boswell-Riverton

Line at BoswellMN Planned $3,017,108 Y Y A

A in MTEP07 West MP 1025 2664 7/1/2012 Riverton 230 kV sub 230 230 kV Bus Position for Boswell-Riverton Line at Riverton


A in MTEP07 West MP 1025 2660 7/1/2012 Boswell 230 Swatara 230 230 Boswell to Swatara 34.6 Miles MN Planned $34,069,591 Y Y AA in MTEP05 West MP 600 2943 2/28/2012 Scearcyville switching station 115 new switching station MN Under


A in MTEP10 West XEL, OTP, MP, non-MISO

3156 5540 12/31/2013 Helga 115 kV Bemidji 115 kV 1 115 115 144 Structural Improvements MN 7.67 Planned $66,000 Y Y A


3156 5537 12/31/2013 Cass Lake 115 kV Nary 115 kV 1 115 115 200 Reconductor 115 kV transmission line MN 11.05 Planned $3,900,000 Y Y A


3156 5539 12/31/2013 Nary 115 kV Helga 115 Kv 1 115 115 144 Structural Improvements MN 4.96 Planned $33,000 Y Y A


279 1098 12/31/2012 Boswell Wilton 1 230 495 Add a new 230 kV line between Boswell and Wilton

MN 72 Planned $98,530,747 Y Y A


3156 3584 12/31/2012 Cass Lake 230 kV Cass Lake 115 kV 1 230 115 187 MVA Add a 230/115 kV Transformer at Cass Lake MN Planned $6,400,000 Y A

A in MTEP10 West MPW 2934 5106 6/1/2014 South 161/69 kV transformer 1 161 69 134 Replace 75 MVA transformer IA Planned $5,400,000 Y AA in MTEP10 West NWE 3092 5410 6/1/2011 Lake 26 Webb Lake 69 15 Rebuild 34.5KV line to Webb Lake at 69KV

with horizontal post construction and #4/0 ACSR

WI 2.6 0 Planned $425,000 Y A

A in MTEP08 West NWE 2011 3992 6/1/2011 Frederic Lewis 69 31 Rebuild the 34.5Kv system between Frederic and Lewis sub at 69KV with 477ASCR and horizontal post construction.

WI 2.8 0 Planned $350,000 Y A

A in MTEP08 West NWE 2012 3993 9/1/2011 Falun Penta 69 47 Rebuild the 34.5Kv system between Falun and Penta sub at 69KV with 477ASCR and horizontal post construction.

WI 4.3 0 Under Construction

$538,000 Y A

A in MTEP08 West NWE 2013 3994 6/1/2011 Penta Siren Tap 69 15 Rebuild the 34.5Kv system between Penta sub and Siren Tap at 69KV with 477ASCR and horizontal post construction.

WI 1.4 0 Planned $175,000 Y A

A in MTEP08 West NWE 2016 3997 1/1/2012 Frederic Coffee Cup 69 84 Reconductor 69KV line with 477ACSR WI 2 0 Planned $100,000 Y A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP08 West NWE 2018 3999 6/1/2011 Eureka Tap Centuria 69 12.5 Build new 69KV line to Centuria and build Distribution Sub

WI 0 4 Planned $1,200,000 Y A

A in MTEP09 West OTP 2751 4774 12/31/2013 New Perham distribution sub 115 12.5 14 MVA Build New 115/12.5 kV Substation at Perham to Serve as a Back-up Source for Outage of Primary Source

MN Planned $400,000 Y A

A in MTEP10 West OTP, MPC 2826 4966 12/31/2015 Thief River Falls 115 kV 15 MVAR capacitor bank 115 15 MVAR Install Capacitor Bank on 115 kV at Thief River Falls. One 15 MVAR. Add second bank to existing bank.

ND Planned $950,000 Y A

A in MTEP10 West OTP,MPC 2826 4965 12/31/2012 Karlstad 115 kV 14 MVAR capacitor bank 115 14 MVAR Install Capacitor Bank on 115 kV at Karlstad. One 14 MVAR.

ND Planned $950,000 Y A

A in MTEP10 West SMP 2166 4005 12/1/2011 Tap Existing Area Line New Load Serving Sub at St Peter

1 69 69 72 MVA Add 7.0 Miles 69kV line and construct new load serving substation at St Peter

MN 7 Under Construction

$6,000,000 NT A

A in MTEP10 West SMP 2167 4006 12/1/2011 Tap Existing Area Line New Load Serving Sub at Redwood Falls

1 115 115 142 MVA Add 5.2 Miles 115kV line and construct load serving substation at Redwood Falls

MN 4 Planned $4,000,000 NT A

A in MTEP10 West SMP 2171 2992 8/1/2011 Mora generator 12.47 3 MW additional 3 MW of landfill gas MN Under Construction

$3,700,000 Y A

A in MTEP09 West SMP 2178 4970 12/1/2011 Byron Line termination 161 161kV Byron - Pleasant Valley161 kV Line Terminal Improvements


$715,181 Y Y A

A in MTEP10 West XEL 2767 4795 1/1/2012 Fenton Transformer 1 115 69 47 new transformer MN Planned $2,143,430 Y AA in MTEP10 West XEL 2767 4794 1/1/2012 Fenton in and out between

Chandler tap and Lake Wilson

1 69 new line MN 3 Planned $1,566,570 Y A

A in MTEP10 West XEL 3097 5424 6/1/2012 Monroe County Transformer 2 161 69 70 Install 2nd 70 MVA transformer at Monroe County substation

WI Planned $3,680,000 N Y A

A in MTEP10 West XEL 3100 5431 6/1/2012 Westgate Transformer 2 115 69 70 upgrade to70 MVA MN Planned $2,070,000 N Y AA in MTEP09 West XEL 1952 3833 12/1/2011 Plato Cap Bank Cap Bank 69 10 MVAR New 10 MVAR cap bank at Lester Prairie MN Planned $700,000 NT AA in MTEP09 West XEL 2157 2966 11/1/2011 Douglas Co Transformer 2 115 69 70 2nd 115/69 kV transformer at MN Planned $4,435,000 NT AA in MTEP09 West XEL 2158 2968 9/30/2011 West Union Osakis 1 69 84 upgrade using lower impedance line MN 5.8 Planned $1,740,000 NT AA in MTEP09 West XEL 2158 2967 9/30/2011 Sauk Center West Union 1 69 84 upgrade using lower impedance line MN 9 Planned $2,774,000 NT AA in MTEP09 West XEL 2160 2970 6/1/2012 Park Falls Transformer 1 115 34.5 47 Upgrade the transformer to higher rating WI Planned $1,677,900 NT AA in MTEP09 West XEL 2160 2971 6/1/2012 Park Falls Transformer 2 115 34.5 47 Upgrade the transformer to higher rating WI Planned $1,677,900 NT AA in MTEP09 West XEL 2178 4021 6/1/2012 Pleasant Valley Byron 1 161 447 MVA new 161 kV line from PV to Byron MN 25 Planned $9,292,000 Y Y AA in MTEP09 West XEL 2307 4225 6/1/2012 Benton Co Mayhew Lake 1 115 361 MVA Convert double circuit 115 kV line from

Benton Co to St. Cloud tap to bifurcated single circuit, build additional 4 miles of 115 kV line from St. Cloud tap to Mayhew Lake substation.

MN 4 Planned $3,000,000 Y Y A

A in MTEP09 West XEL 2307 4226 6/1/2012 St. Cloud Granite City 1 115 194 MVA Convert 1 mile of double circuit from St. Cloud tap to Granite City to bifurcated single circuit.


A in MTEP09 West XEL 2307 4227 6/1/2012 Sauk River W St. Cloud 1 115 361 MVA Upgrade line to 361 MVA MN 1.4 Planned $1,000,000 Y Y AA in MTEP09 West XEL 2307 4228 6/1/2012 Mayhew Lake substation Breakers 115 Upgrade to 115 kV ring bus MN Planned $2,000,000 Y Y AA in MTEP09 West XEL 2308 4236 9/1/2011 Lowry tap Glenwood (XCEL) 1 69 100 MVA Upgrade to 477 ACSR MN 0.04 Planned $17,058 NT AA in MTEP09 West XEL 2308 4235 9/1/2011 Glenwood (GRE) Lowry tap 1 69 100 MVA Upgrade to 477 ACSR MN 2.8 Planned $11,941,126 NT AA in MTEP09 West XEL 2308 4234 9/1/2011 Sedan Glenwood (GRE) 1 69 100 MVA Upgrade to 477 ACSR MN 5 Planned $2,132,344 NT AA in MTEP09 West XEL 2308 4233 9/1/2011 Grove Lake Sedan 1 69 100 MVA Upgrade to 477 ACSR MN 5.3 Planned $2,260,284 NT AA in MTEP09 West XEL 2309 4229 6/1/2012 Maple Lake Annandale 1 69 100 MVA Upgrade to 477 ACSR MN 6 Planned $2,487,000 NT AA in MTEP09 West XEL 2772 4838 6/1/2012 Midtown Sidtribution Substation 115 13.8 New distribution substation MN Planned $11,120,000 Y AA in MTEP09 West XEL 2772 4836 6/1/2012 Hiawatha Distribution Substation 115 13.8 New distribution substation Between Elliot

Park and SouthtownMN Planned $14,270,000 Y A

A in MTEP09 West XEL 2772 4837 6/1/2012 Hiawatha Midtown 1,2 115 ~360 Double Circuit 1.25 mile line MN 1.25 Planned $1,500,000 Y AA in MTEP08 West XEL 675 1364 6/1/2014 Westgate Scott County 1 115 194 MVA upgrade line MN 20.1 Planned $14,000,000 Y AA in MTEP08 West XEL 1487 2306 12/31/2011 Somerset Stanton 1 69 84 New 69 kV line WI Planned $9,247,500 NT AA in MTEP08 West XEL 1549 2638 9/1/2011 Wheaton Eau Claire 161 434 Reconductor 4.3 Miles of 161 kV line with

795 ACSS conductorWI 4.3 Planned $645,000 Y A

A in MTEP08 West XEL 1549 2633 12/1/2011 Eau Claire Hallie 161 434 Rebuild 69 kV corridor to 161 kV, convert Hallie Substation to 161 kV

WI 1.5 Planned $2,425,000 Y A






Max kV


Miles Upg.


Cost Shared

Postage Stamp


A in MTEP08 West XEL 1957 3839 6/1/2012 new sub London - Madison tap 1 69 84 MVA Rebuild 69 kV line from London/Madison Tap to new substation

WI Planned $0 NT A

A in MTEP08 West XEL 1957 3838 6/1/2012 Southwest of Eau Claire (new sub)

new sub 1 161 69 New 161/69 kV Substation southwest of Eau Claire where Alma – Elk Mound 161 kV line intersects with Shawtown – Naples 69 kV line


A in MTEP08 West XEL 1958 3843 12/1/2012 Edge Water substation upgrade to 161 kV 161 Convert the Edgewater 69 kV load to the new 161 kV line. Construct 161 kV facilities at Edgewater Substation

WI Planned $0 Y A

A in MTEP08 West XEL 1958 3842 12/1/2012 Stone Lake Edge Water 1 161 434 MVA New 161 kV line from Stone Lake to Edgewater


A in MTEP06 West XEL 1458 2496 11/30/2011 Yankee feeders 34.5 four new 50 MW underground feeder lines and all associated equipment

MN Planned $2,202,000 NT A

A in MTEP09 West XEL, GRE 2156 2964 6/1/2011 St. Thomas substation 1 115 69 112 New 115/69 kV substation MN Planned $5,000,000 NT AA in MTEP09 West XEL, GRE 2156 2963 6/1/2011 Helena St. Thomas 1 115 115 318 New 6 mile 115 kV line MN 6 Planned $2,750,000 Y AA in MTEP09 West XEL, GRE 2156 2962 6/1/2011 Helena Transformer 1 345 115 448 New 345/115 kV transformer at Helena

substationMN Planned $7,250,000 Y A

A in MTEP09 West XEL, GRE 2156 2965 6/1/2011 Lesueur Tap substation 69 69 kV switching station at LeSueur MN Planned $2,450,000 NT AA in MTEP08 West XEL, SMPA, DPC 1024 1677 12/15/2012 North Rochester Northern Hills 1 161 400 new line and termial works MN 12.6 Planned $23,068,992 Y Y A

A in MTEP08 West XEL, SMPA, DPC 1024 1675 12/15/2012 North Rochester Transformer 1 345 161 448 new transformer and terminal works MN Planned $19,346,751 Y Y A

A in MTEP08 West XEL, SMPA, DPC 1024 2984 12/15/2012 North Rochester substation 1 345 new substation MN Planned $6,164,382 Y A

A in MTEP08 West XEL, SMPA, DPC 1024 2983 3/31/2013 Hampton Corner and North Rochester

substation 1 345 new substation MN Planned $9,395,227 Y A

A in MTEP08 West XEL, SMPA, DPC 1024 1676 3/31/2014 North La Crosse Transformer 1 345 161 448 new transformer and terminal works WI Planned $11,744,034 Y Y A

A in MTEP08 West XEL, SMPA, DPC 1024 2647 3/31/2014 North Rochester North La Crosse 1 345 2050 new line and termial works MN 82 Planned $292,987,075 Y Y Y A

A in MTEP08 West XEL, SMPA, DPC 1024 1678 3/30/2015 North Rochester Chester 1 161 400 new line MN 14 Planned $11,137,053 Y A

A in MTEP08 West XEL, SMPA, DPC 1024 1673 9/30/2015 Hampton Corner North Rochester 1 345 2050 new line MN 36 Planned $71,156,485 Y A


Appendix A-1: Preliminary MTEP11 Appendix A Baseline Reliability and Generation Interconnection Project Cost Allocations by Pricing Zones Subject to Approval for Appendix A

AMIL AMMO ATC BREC CWLD CWLP DEM DPC GRE HE IPL ITC ITCM MDU MEC METC MICH13A MP MPW NIPS NSP OTP SIPC SMMPA VECT Total

2306 BRP Central Jun-16 AMMO 30,751,000 1,051,903 26,723,064 454,291 63,516 12,115 13,507 453,570 44,337 43,626 26,053 114,164 378,475 132,889 28,721 174,720 299,986 28,278 75,274 5,671 130,011 368,724 54,212 17,913 11,144 44,838 30,751,000 30,751,000

Central Total 30,751,000 1,051,903 26,723,064 454,291 63,516 12,115 13,507 453,570 44,337 43,626 26,053 114,164 378,475 132,889 28,721 174,720 299,986 28,278 75,274 5,671 130,011 368,724 54,212 17,913 11,144 44,838 30,751,000 30,751,000

1809 BRP East Dec-13 METC 32,600,000 32,600,000 32,600,000 32,600,000

2812 BRP East May-12 METC 43,300,000 43,300,000 43,300,000 43,300,000

3303 BRP East Jun-15 METC 11,400,000 42,530 11,357,470 11,400,000 11,400,000

3304 BRP East Dec-13 METC 26,600,000 26,600,000 26,600,000 26,600,000

3516 GIP East Sep-11 ITC 242,500 242,500 242,500 485,000

3517 GIP East Dec-12 METC 5,829,500 5,829,500 5,829,500 11,659,000

3518 GIP East Jun-12 METC 32,000 32,000 32,000 64,000

East Total 120,004,000 - - - - - - - - - - - 285,030 - - - 119,718,970 - - - - - - - - - 120,004,000 126,108,000

1950 BRP West Jun-11 ATC 17,697,000 17,697,000 17,697,000 17,697,000

2634 BRP West Dec-14 GRE/MP 25,233,333 220,023 22,746,133 2,085,492 181,686 25,233,333 25,233,333

3191 GIP West Feb-11 ITCM 4,074,000 74,771 73,159 101,798 14,233 2,715 3,027 101,636 9,935 9,776 5,838 25,582 84,809 3,288,978 6,436 39,151 67,221 6,336 16,867 1,271 29,133 82,624 12,148 4,014 2,497 10,047 4,074,000 8,148,000

3192 GIP West Dec-11 ITCM 29,400 29,400 29,400 58,800

3193 GIP West Dec-11 ITCM 111,942 111,942 111,942 223,884

3194 GIP West Jul-10 ITCM 211,332 211,332 211,332 422,664

3195 GIP West Oct-10 ITCM 1,758,082 1,758,082 1,758,082 3,516,163

3196 GIP West Jul-11 ITCM 831,141 831,141 831,141 1,662,281

3206 GIP West Jun-18 ATC 86,539,748 1,277,327$ 1,249,795$ 71,415,397$ 243,141$ 46,375$ 51,705$ 1,736,269$ 209,442$ 167,001$ 99,731$ 437,020$ 1,448,806$ 1,449,164$ 109,944$ 1,007,504$ 1,148,348$ 108,247$ 391,837$ 21,707$ 497,683$ 2,932,912$ 207,525$ 68,570$ 42,661$ 171,639$ 86,539,748 173,079,497

3312 BRP West Jun-14 NSP 13,660,000 1,545,669 9,026,660 3,087,671 13,660,000 13,660,000

3317 BRP West Jun-14 NSP 6,000,000 6,000,000 6,000,000 6,000,000

3373 BRP West Dec-12 MP 8,000,000 653,494 85,801 91,225 6,276,961 843,029 49,489 8,000,000 8,000,000

3397 BRP West Jun-14 DPC 18,000,000 885,926 8,491,279 87,065 2,150,057 6,385,673 18,000,000 18,000,000

3481 BRP West Dec-14 OTP 14,000,000 101,251 8,455 134,575 252,515 13,503,204 14,000,000 14,000,000

West Total 196,145,978 1,352,097 1,322,955 90,753,615 257,374 49,089 54,732 1,837,905 8,796,457 2,222,010 105,568 462,601 1,533,614 9,830,095 124,835 1,046,656 1,215,569 114,584 29,566,373 22,978 526,816 27,608,905 17,041,723 72,584 45,158 181,686 196,145,978 289,701,622

MISO Total 346,900,978 2,404,000 28,046,018 91,207,905 320,890 61,204 68,239 2,291,475 8,840,794 2,265,636 131,621 576,765 2,197,119 9,962,983 153,556 1,221,376 121,234,525 142,861 29,641,647 28,649 656,827 27,977,629 17,095,935 90,496 56,303 226,524 346,900,978 446,560,622

Total Project Cost

with 100% GIP3

Pricing Zone

Values shown below are subject to change depending on actual project costs 1

Project ID ISD Zone

Total Shared

Cost2Region

Project

Type

Notes:Notes:

(1) The allocations shown above are estimates which are based on current estimates of project costs and projected in-service dates.The actual allocation amounts will vary depending on the actual project costs and actual in-service dates.

(2) Total Shared Cost reflects the Project cost subject to sharing and allocated to pricing zones in MISO. This does not include 50% or 90% of the Network Upgrade cost of the Generator Interconnection Projects (GIP) assgined to the Generators .

(3) Total Project Cost with 100% GIP includes the total network upgrade costs for GIPs including the 50% or 90% assigned to the generators. This does not take into account those GIPs with agreements for Transmission Owners to reimburse the generators for 100% of their Network Upgrade costs.

Appendix A-2.1. Indicative Schedule 26 Annual Charges by MISO Pricing Zone for new MTEP 11 Approved Baseline Reliability Projects and Generation Interconnection Projects

2012 2013 2014 2015 2016 2017 2018 2019 2020 2021

AMIL 18,468 18,173 28,123 48,320 99,253 333,744 381,871 431,193 424,328 417,462

AMMO 18,070 17,781 27,517 47,278 97,114 4,810,148 4,788,672 4,768,367 4,693,085 4,617,802

ATC 3,306,603 3,402,261 3,920,281 5,146,542 7,954,466 10,841,665 13,648,377 16,521,956 16,254,068 15,986,180

BREC 3,515 3,459 5,353 9,198 18,893 39,672 49,198 58,951 58,009 57,067

CWLD 671 660 1,021 1,754 3,603 7,567 9,384 11,244 11,064 10,884

CWLP 748 736 1,138 1,956 4,018 8,436 10,462 12,536 12,336 12,136

DPC 2,454 21,872 23,214 1,324,018 1,318,159 1,320,037 1,314,060 1,308,279 1,293,285 1,278,291

DUK 25,104 24,702 38,228 65,681 134,915 283,297 351,320 420,969 414,242 407,515

GRE 2,415 23,064 24,047 379,268 379,861 388,066 388,543 389,175 382,462 375,748

HE 1,442 1,419 2,196 3,773 7,749 16,272 20,180 24,180 23,794 23,407

IPL 6,319 6,218 9,622 16,532 33,958 71,306 88,427 105,958 104,265 102,572

ITC 88,192 86,745 96,919 118,714 187,077 309,608 365,084 421,917 415,019 408,122

ITCM 1,531,233 1,506,629 1,493,650 1,820,903 1,850,895 1,904,076 1,933,713 1,964,708 1,931,955 1,899,203

MDU 1,590 1,564 2,421 6,040 10,396 19,764 24,043 28,425 27,971 27,517

MEC 9,670 9,516 17,442 33,451 73,703 144,445 184,231 224,960 221,371 217,782

METC 16,603 13,544,878 29,645,680 29,224,907 31,957,180 31,570,383 31,130,437 30,691,567 30,202,183 29,712,799

MICH13A 1,565 1,540 2,383 4,095 8,411 17,662 21,903 26,245 25,826 25,406

MP 4,166 1,427,585 1,408,769 6,581,382 6,495,360 6,422,472 6,336,249 6,250,392 6,147,299 6,044,206

MPW 314 309 478 821 1,687 3,542 4,392 5,263 5,179 5,095

NIPS 7,196 7,081 10,958 18,827 38,672 81,204 100,702 120,666 118,738 116,810

NSP 20,408 211,263 231,522 4,377,802 4,429,811 4,546,162 4,597,187 4,650,958 4,575,714 4,500,470

OTP 3,000 14,176 15,620 3,597,185 3,550,890 3,514,054 3,467,613 3,421,367 3,365,992 3,310,618

SIPC 991 976 1,510 2,594 5,328 11,188 13,875 16,625 16,360 16,094

Pricing Zone

Year

Values shown below (in 2011$) are subject to change depending on actual project costs including Construction Work in Progress, actual In-service Dates, and actual Annual Charge Rates for Transmission Owners

SIPC 991 976 1,510 2,594 5,328 11,188 13,875 16,625 16,360 16,094

SMMPA 617 607 939 1,614 3,315 6,961 8,632 10,343 10,178 10,013

VECT 2,482 2,442 3,779 6,493 13,337 28,005 34,730 41,615 40,950 40,285

MISO Total 5,073,835 20,335,655 37,012,811 52,839,146 58,678,049 66,699,735 69,273,285 71,927,862 70,775,673 69,623,483

Notes:

1) Indicative Schedule 26 annual charges not intended to be used for rate making purposes.

2) The indicative annual charges shown only reflect new MTEP 11 projects and would be additive to the indicative annual Schedule 26 charges shown in the posted spreadsheet at the following link on the MISO website under the MTEP Status Report and Cost Allocation section: https://www.misoenergy.org/PLANNING/TRANSMISSIONEXPANSIONPLANNING/Pages/TransmissionExpansionPlanning.aspx

3) Annual Revenue Requirement calculated using an estimated Annual Charge Rate for each constructing Transmission Owner based on the methodology described in Attachment GG. Annual Charge Rate estimated using Transmission Owner's Attachment O data as of January 2011 and assumes 40-year straight-line depreciation.

4) For approved projects with recovery for Construction Work in Progress, charges are phased-in based on an assumed schedule. For example a project with an in-service date five-years out, CWIP charges are phased in as follows: 1 Year from In-Service Date (ISD) = 75% of estimated project cost; 2 Years from ISD = 45%; 3 Years from ISD = 20%; 4 Years from ISD = 7.5%.

5) For approved projects without approval for Construction Work in Progress recovery, charges start based on the estimated in-service date and whether the constructing Transmission Owner uses forward-looking or historic recovery mechanisms. For example, if a project is expected to go in-service in June 2012 and the constructing Transmission Owner uses forward-looking then the charges are assumed to start in 2012, and if the Transmision Owner uses historic the charges for this project would start in 2013.

6) Please contact Jeremiah Doner at [email protected] with any questions.

Appendix A-2.2. Indicative MTEP 06 through MTEP 11 Cost Allocation Summary for Baseline Reliability, Generation Interconnection, and Market Effficiency Projects

Pricing Zone

Total Approved Cost

Shared Transmision

Investment

Costs Allocated for

Projects Located

Outside Pricing Zone

Costs Allocated for

Projects Located

within the Pricing

Zone

Total Project Cost

Allocated to Pricing

Zone

[1] [2] [3] [4] [5] = [3] + [4]

AMIL $150,901,748 32,189,497 124,225,956 $156,415,453

AMMO $74,232,100 25,534,161 68,799,775 $94,333,936

ATC $684,196,645 71,197,425 550,149,646 $621,347,071

BREC $0 320,890 - $320,890

CWLD $0 813,458 - $813,458

CWLP $0 1,398,167 - $1,398,167

DPC $18,000,000 607,901 8,491,279 $9,099,180

DUK $42,719,762 78,533,640 39,799,859 $118,333,499

GRE $179,205,420 27,691,765 9,322,330 $37,014,094

HE $0 10,432,502 - $10,432,502

IPL $15,400,000 13,749,996 3,875,701 $17,625,697

ITC $85,332,101 33,318,503 78,567,534 $111,886,037

ITCM $82,691,614 64,011,172 74,649,280 $138,660,452

MDU $11,000,000 8,619,445 10,756,475 $19,375,921

MEC $0 1,431,658 - $1,431,658

METC $379,483,053 69,949,782 367,324,160 $437,273,943

MICH13A $0 5,184,234 - $5,184,234

MP $161,718,208 83,050,043 59,029,213 $142,079,256

MPW $0 29,202 - $29,202

NIPS $20,645,686 14,495,479 19,319,177 $33,814,656

NSP $604,210,564 242,668,673 327,149,322 $569,817,995

OTP $182,095,007 114,131,638 52,849,946 $166,981,584

SIPC $0 1,453,606 - $1,453,606

SMMPA $0 20,987,479 - $20,987,479

VECT $114,757,364 4,864,381 50,434,703 $55,299,084

MISO Total $2,806,589,271 $926,664,697 $1,844,744,355 $2,771,409,052

Note: The difference in the MISO Total of columns 2 and 5 represents the portion of project cost allocated to FirstEnergy who is no longer part of the MISO footprint.

Appendix A-3. Indicative Multi-Value Project (MVP) Schedule 26-A Annual Charges by MISO Local Balancing Authority (LBA) for Approved and Pending Approval MVPs

Figure A-3.1 Approved and Pending Approval MVPs

Project ID Project Name

Geographic Location

by TO Member System

Estimated In-

Service Date

Estimated Project

Cost (2011$) Approval Status

[1] [2] [3] [4] [5] [6]1203

Brookings, SD - SE Twin Cities 345 kVXEL/GRE/OTP/MRES/C

MMPA 5/1/2015 $695,000,000Conditionally Approved

June 20112202 New Reynolds to Greentown 765 kV line DUK 8/1/2018 $245,300,000 Pending Dec 20112220 Ellendale to Big Stone South OTP, MDU 12/31/2019 $260,700,000 Pending Dec 20112221 Big Stone South to Brookings OTP, XEL 12/31/2017 $190,800,000 Pending Dec 20112237 Pana - Mt. Zion - Kansas - Sugar Creek 345 kV line AMIL 6/1/2020 $284,100,000 Pending Dec 20112239 Sidney to Rising 345 kV line AMIL 6/1/2017 $90,100,000 Pending Dec 20112248 Adair - Ottumwa 345 AMMO, ITCM, MEC 6/1/2017 $152,037,000 Pending Dec 20112844 Pleasant Prairie-Zion Energy Center 345 kV line ATC 12/31/2014 $26,400,000 Pending Dec 20113017 Palmyra -Quincy-Meredosia - Ipava & Meredosia-Pawnee 345 kV Line AMIL 6/1/2018 $392,400,000 Pending Dec 20113022 Fargo-Oak Grove 345 kV Line AMIL, MEC 6/1/2018 $193,200,000 Pending Dec 20113127 N LaCrosse-N Madison-Cardinal -Spring Green - Dubuque area 345-kV ATC, XEL, ITCM 12/31/2020 $714,430,000 Pending Dec 20113168 Michigan Thumb Wind Zone ITC 12/31/2015 $510,000,000 Approved MTEP 103169 New Pawnee to Pana - 345 kV Line AMIL 6/1/2018 $88,100,000 Pending Dec 20113170 West Adair-Palmyra Tap 345 kV Line AMMO 6/1/2018 $97,600,000 Pending Dec 20113203 New Reynolds to E. Winnamac to Burr Oak to Hiple 345 kV NIPS 12/31/2013 $271,200,000 Pending Dec 20113205 Lakefield-Burt & Sheldon-Webseter 345 kV line MEC, ITCM 12/31/2015 $505,650,000 Pending Dec 20113213 Winco-Lime Creek-Emery-Blackhawk-Hazelton 345 kV line MEC, ITCM 12/31/2015 $480,050,000 Pending Dec 2011

Total $5,197,067,000

Figure A-3.2 Indicative MVP Usage Rates for Approved and Pending Approval MVPs (2011 dollars)

Year (2012-2021) 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021

Indicative MVP Usage Rate ($/MWh) $0.02 $0.14 $0.35 $0.50 $0.88 $0.94 $1.13 $1.30 $1.41 $1.44

Year (2022-2031) 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031


Year (2032-2041) 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041


Year (2042-2051) 2042 2043 2044 2045 2046 2047 2048 2049 2050 2051


Values shown below (in 2011 Dollars) are subject to change depending on actual withdrawals (MWh), actual project costs including Construction Work in

Progress, actual In-service Dates, and actual Annual Charge Rates for Transmission Owners

Notes:

1) Indicative Schedule 26-A MVP Usage Rate not intended to be used for rate making purposes.

Notes:

1) Indicative Schedule 26-A MVP Usage Rate not intended to be used for rate making purposes.

2) Indicative MVP Usage Rate based on the approved and pending approval MVPs listed in Figure A-3.1.

3) Annual MISO Withdrawals based on 2010 values with years 2012-2051 escalated assuming an annual energy growth rate of 1.42% consistent with the assumed energy growth rate used in the MTEP 11 Business as Usual Future with historical energy growth rates.

4) Annual Revenue Requirement calculated using an estimated Annual Charge Rate for each Transmission. Annual Charge Rate estimated using Transmission Owner's Attachment O data as of January 2011 and assumes 40-year straight-line depreciation.

5) Construction Work in Progress (CWIP) charges are assumed only for projects that have FERC approval for CWIP recovery. Estimated annual CWIP charges are based on an assumed phase-in schedule depending on the in-service date. For example, if a project has an in-service date in 2016 then CWIP charges occur as follows: 2012 = 7.5% of estimated project cost; 2013 = 20%; 2014 = 45%; 2015 = 75%; 2016=100%. The annual charge rate is reduced by 2.5% during the years of CWIP recovery to reflect that depreciation expense reletated charges are not incurred.

6) For the Michigan Thumb MVP the project is assumed to be phased in-service equally over the 2013-2015 period.

7) The Indicative MVP Usage Rate for the Michigan Thumb project reflects First Energy's obligation for a portion of the Michigan Thumb project.

8) Please contact Jeremiah Doner at [email protected] with any questions.

Figure A-3.3 Indicative Annual MVP Charges for Approved and Pending Approval MVPs by Local Balancing Authority for 2012-2021 (in Millions of 2011 Dollars)

LBA 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021

ALTE $0.21 $1.72 $4.46 $6.57 $11.63 $12.58 $15.39 $17.94 $19.79 $20.55

ALTW $0.34 $2.79 $7.23 $10.66 $18.85 $20.40 $24.95 $29.09 $32.10 $33.33

AMIL $0.80 $6.48 $16.82 $24.80 $43.85 $47.45 $58.04 $67.65 $74.65 $77.51

AMMO $0.74 $6.04 $15.68 $23.11 $40.87 $44.23 $54.10 $63.06 $69.58 $72.25

BREC $0.06 $0.67 $2.33 $3.43 $6.07 $6.56 $8.03 $9.36 $10.33 $10.72

CIN $1.15 $9.33 $24.20 $35.68 $63.10 $68.28 $83.52 $97.35 $107.43 $111.55

CONS $0.75 $6.09 $15.80 $23.30 $41.20 $44.58 $54.53 $63.56 $70.14 $72.83

CWLD $0.02 $0.20 $0.52 $0.77 $1.37 $1.48 $1.81 $2.11 $2.33 $2.42

CWLP $0.03 $0.28 $0.72 $1.06 $1.88 $2.03 $2.49 $2.90 $3.20 $3.32

DECO $0.90 $7.31 $18.95 $27.94 $49.41 $53.47 $65.40 $76.23 $84.12 $87.35

DPC $0.10 $0.78 $2.03 $3.00 $5.30 $5.74 $7.02 $8.18 $9.02 $9.37

GRE $0.21 $1.72 $4.47 $6.59 $11.65 $12.60 $15.41 $17.97 $19.83 $20.59

HE $0.01 $0.06 $0.14 $0.21 $0.38 $0.41 $0.50 $0.58 $0.64 $0.67

IPL $0.26 $2.14 $5.55 $8.18 $14.46 $15.65 $19.14 $22.31 $24.62 $25.56

MDU $0.05 $0.37 $0.96 $1.42 $2.50 $2.71 $3.31 $3.86 $4.26 $4.43

MEC $0.41 $3.35 $8.70 $12.82 $22.68 $24.54 $30.02 $34.99 $38.61 $40.09

MGE $0.06 $0.48 $1.24 $1.83 $3.24 $3.51 $4.29 $5.00 $5.52 $5.73

MP $0.18 $1.47 $3.81 $5.61 $9.93 $10.74 $13.14 $15.31 $16.90 $17.55

MPW $0.02 $0.12 $0.32 $0.47 $0.83 $0.90 $1.10 $1.29 $1.42 $1.47

NIPS $0.32 $2.64 $6.85 $10.10 $17.85 $19.32 $23.63 $27.54 $30.39 $31.56

NSP $0.80 $6.53 $16.94 $24.97 $44.16 $47.79 $58.45 $68.13 $75.18 $78.06

OTP $0.13 $1.09 $2.83 $4.18 $7.39 $7.99 $9.78 $11.39 $12.57 $13.06

SIGE $0.13 $1.10 $2.84 $4.19 $7.41 $8.02 $9.81 $11.44 $12.62 $13.11

SIPC $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00

SMP $0.03 $0.23 $0.61 $0.89 $1.58 $1.71 $2.09 $2.44 $2.69 $2.80

UPPC $0.02 $0.16 $0.41 $0.61 $1.07 $1.16 $1.42 $1.66 $1.83 $1.90

WEC $0.58 $4.70 $12.20 $17.99 $31.82 $34.43 $42.11 $49.09 $54.17 $56.25

WPS $0.24 $1.97 $5.12 $7.55 $13.35 $14.45 $17.67 $20.59 $22.73 $23.60

Exports and Wheel-Throughs excluding those sinking in PJM $0.19 $1.58 $4.10 $6.04 $10.69 $11.57 $14.15 $16.49 $18.20 $18.89

Total $8.74 $71.41 $185.85 $273.99 $484.52 $524.31 $641.30 $747.48 $824.87 $856.50

Appendix A.4: MTEP11 New Appendix A Projects

Planning Region

Geographic Location by TO Member

System PrjID Project Name Project Description States

Allocation Type per

FFShare Status

Other Type

Estimated Cost

Expected ISD (Max)

Central AmerenIL 2239 Candidate MVP Portfolio 1 - Sidney to Rising 345 kV line

Sidney to Rising 345 kV line, plus 345 kV ring bus at Rising and breaker-and-a-half arrangement at Sidney.

IL MVP Shared $83,230,000 11/15/2016

Central AmerenIL 3017 Candidate MVP Portfolio 1 - Palmyra -Quincy-Meredosia - Ipava & Meredosia-Pawnee 345 kV Line

Palmyra Tap to Quincy to Meredosia to Ipava 345 line and Meredosia to Pawnee 345 kV line. Install additional transformers at Quincy, Meredosia and Pawnee. 345 kV ring bus at Quincy, Meredosia, and Ipava, with breaker-and-a-half arrangement at Pawnee and Palmyra Tap Substations.

IL MVP Shared $432,160,000 11/15/2017

Central AmerenIL 3169 Candidate MVP Portfolio 1 - New Pawnee to Pana - 345 kV Line

Pawnee to Pana 345 kV, 31 mile line including additional transformer at Pana

IL MVP Shared $99,360,000 11/15/2018

Central AmerenIL, DEM 2237 Candidate MVP Portfolio 1 - Pana - Mt. Zion - Kansas - Sugar Creek 345 kV line

Pana to Mt. Zion to Kansas to Sugar Creek 345 kV line. Install transformers at Mt. Zion and Kansas, with 345 kV ring bus at Mt. Zion and breaker-and-a-half arrangement at Kansas and Pana.

IL MVP Shared $318,410,000 11/15/2019

Central AmerenIL, MEC 3022 Candidate MVP Portfolio 1 - Fargo-Oak Grove 345 kV Line

Fargo-Galesburg-Oak Grove (MEC) 345 kV Line - New 70 mile, 3000 A summer emergency capability line. 345 kV ring bus at Fargo.

IA, IL MVP Shared $272,249,969 11/15/2019

Central AmerenMO 3170 Candidate MVP Portfolio 1 - West Adair-Palmyra Tap 345 kV Line

West Adair - Palmyra 345 kV, 58 miles of line; Establish Palmyra Tap Substation

MO MVP Shared $112,790,000 11/15/2020

Central AmerenMO, ITCM

2248 Candidate MVP Portfolio 1 - Adair - Ottumwa 345

West Adair Substation - New 560 MVA, 345/161 kV Transformer. New 71 mile 345 kV line from Adair to Ottumwa with 3000 A summer emergency capability. 345 kV ring bus at West Adair

IA, MO MVP Shared $244,627,764 11/15/2020

Central DEM, NIPS 2202 Candidate MVP Portfolio 1 - Reynolds to Greentown 765 kV line

Reynolds to Greentown 765 kV line IN MVP Shared $186,875,000 8/1/2018

East NIPS 3203 Candidate MVP Portfolio 1 - Reynolds to E. Winnamac to Burr Oak to Hiple 345 kV

Reynolds to E. Winnamac to Burr Oak to Hiple 345 kV line and tie in second AEP 345 kV circuits at Reynolds and Hiple

IN MVP Shared $271,000,000 12/31/2019

Planning Region



Allocation Type per

FFShare Status

Other Type

Estimated Cost

Expected ISD (Max)

West ATC LLC 2844 Candidate MVP Portfolio 1 - Pleasant Prairie-Zion Energy Center 345 kV line

Construct a new Pleasant Prairie-Zion Energy Center 345-kV line

WI/IL MVP Shared $28,856,000 3/16/2014

West ATC LLC, XEL, ITCM

3127 Candidate MVP Portfolio 1 - N LaCrosse-N Madison-Cardinal -Spring Green - Dubuque area 345-kV

N LaCrosse- N Madison - Cardinal 345-kV & Dubuque County - Spring Green - Cardinal 345 kV line. Spring Green and Briggs Road transformers

WI, IA MVP Shared $679,260,000 12/31/2020

West MEC, ITCM 3205 Candidate MVP Portfolio 1: Lakefield Jct. - Winnebago - Winco - Burt area & Sheldon - Burt Area - Webster 345 kV line

New 345 kV line from Lakefield Junction to Burt via Winnebago and Winco and a new 345 kV line from Sheldon to Webster via Burt. Includes 161 kV rebuild as underbuild along portions of the route.

MN, IA MVP Shared $514,069,787 12/1/2016

West MEC, ITCM 3213 Candidate MVP Portfolio 1 - Winco to Hazelton 345 kV line

Winco to Lime Creek to Floyd to Blackhawk to Hazelton 345 kV line and Lime Creek, Floyd and Black Hawk transformers

IA MVP Shared $591,551,532 12/31/2015

West OTP, MDU 2220 Candidate MVP Portfolio 1 - Ellendale to Big Stone South

Big Stone to Ellendale 345 kV double circuit line ND, SD MVP Shared $326,164,000 12/31/2019

West OTP, XEL 2221 Candidate MVP Portfolio 1 - Big Stone South to Brookings

Brookings to Big Stone 345 kV double circuit SD MVP Shared $226,720,000 12/31/2017

West XEL, GRE 1203 Candidate MVP Portfolio 1 - Brookings, SD - SE Twin Cities 345 kV

Brookings Cty-Lyon Cty (Single Ckt 345 kV); Lyon Cty-Cedar Mountain-Helena (Double Ckt 345 kV); Helena-Lake Marion-Hampton Corner (Single Ckt 345 kV); Lyon Cty-Hazel (Single Ckt 345 kV); Hazel-Minnesota Valley (Single Ckt 345 kV, initially operate at 230 kV); Cedar Mountain-Franklin (Single Ckt 115 kV)

MN, SD MVP Shared $738,400,000 2/16/2015

Central AmerenIL 2065 Stallings 345/138 kV Sub - Replace 560 MVA 345/138 kV transformer

Stallings 345/138 kV Substation-Replace 560 MVA, 345/138 kV Transformer with 700 MVA unit. Install a 345kV ring bus

IL BaseRel Shared $10,075,000 6/1/2012

Planning Region



Allocation Type per

FFShare Status

Other Type

Estimated Cost

Expected ISD (Max)

Central AmerenIL 2980 Tazewell-San Jose Rail - Reconductoring

Tazewell-San Jose Rail Substation section of East Springfield-Tazewell-1384 138 kV Line - Reconductor 3.67 miles of 927 kcmil ACAR conductor at the Tazewell end of the line with conductor capable of carrying at least 1278 A under summer emergency conditions

IL BaseRel Not Shared

$3,251,000 6/1/2013

Central AmerenIL 2981 McLean-Oglesby 138 kV Reconductor

Replace 9.72 miles of 138 kV line on L1382, from McLean County Substation to El Paso Tap to a minimum 1200A SE capability

IL BaseRel Not Shared

$5,100,000 9/1/2013

Central AmerenMO 2306 Nortwest Cape Area 345/161 kV Substation

Install 560 MVA, 345/161 kV Transformer. Provide 345 kV supply from 11 mile 345 kV line extension from Lutesville Substation

MO BaseRel Shared $30,751,000 6/1/2016

East ITC 2931 Adams-Spokane/Burns1-Jewel 120 kV Rebuild

Rebuild 2.4 miles of DC 3/0 Cu 120 kV lin to 1431 ACSR 230 kV construction.

MI BaseRel Not Shared

$3,200,000 6/30/2012

East ITC 3285 Fermi & Shoal 120kV Capacitors

33.3 Mvar Capacitors at Fermi and Shoal 120kV Mi BaseRel Not Shared

$3,800,000 6/1/2014

East METC 1809 Keystone-Hodenpyl 138 kV Rebuild

Rebuild the 27 mile Keystone to Hodenpyl 138 kV line to 954 ACSR (Pre-build to 230 kV construction).

Mi BaseRel Shared $32,600,000 12/31/2013

East METC 2812 Twining - Alcona 138kV Rebuild

Rebuild the Twining-Mio 138kV 38 mile line to 954 ACSR future-double-circuit (pre-built to 230kV)

MI BaseRel Shared $43,300,000 5/31/2012

East METC 3303 Cottage Grove-East Tawas 138 kV Rebuild

Rebuild 12.3 miles of 138 kV line MI BaseRel Shared $11,400,000 6/1/2015

East METC 3304 Croton-Nineteen Mile 138 kV Rebuild

Rebuild 21.5 miles of 138 kV 110 CU to 954 ACSR (Pre-build to 230 kV construction).

Mi BaseRel Shared $26,600,000 12/31/2013

East METC 3520 NERC Alert Facility Ratings for 2011: Eureka - Vestaburg 138 kV line upgrade

Eureka - Vestaburg 138 kV line upgrade: Remediate sag limits to conductor rating of circuit

Mi BaseRel Not Shared

$1,100,000 6/1/2012

East METC 3521 NERC Alert Facility Ratings for 2011: Bullock - Summerton 138 kV line upgrade

Bullock - Summerton 138 kV line upgrade: Remediate sag limits to conductor rating of circuit

Mi BaseRel Not Shared

$3,600,000 6/1/2012

West ATC LLC 1729 Uprate Straits-McGulpin 138 kV

Uprate overhead portions of Straits-McGulpin 138-kV circuits #1 & #3 to 200 F degree summer emergency ratings


$300,000 4/20/2011

Planning Region



Allocation Type per

FFShare Status

Other Type

Estimated Cost

Expected ISD (Max)

West ATC LLC 1950 2nd Kewaunee 345-138 kV Transformer

Reconfigure Kewaunee 345/138 kV switchyard and install a 2nd Kewaunee 345-138 kV transformer of 500 MVA.

WI BaseRel Shared $17,697,000 3/17/2011

West ATC LLC 2800 Uprate Arpin-Hume 115-kV

Marshfield Electric & Water Department project to increase ground clearance to operate the line at 200 Deg F

WI BaseRel Not Shared

$191,000 9/10/2010

West ATC LLC 2846 Straits power flow control

Install AC-DC-AC Back to Back Voltage Source Converterpower (VSC) flow controller at the Straits 138-kV substation

MI BaseRel Shared $90,000,000 5/1/2014

West ATC LLC 3427 Nordic-Perch Lk Uprate (AM)

Increase ground clearance for the Nordic-Perch Lk 138 kV line


$1,543,040 3/7/2011

West ATC LLC 3459 A-157 Hume-Wildwood 115kV Uprate

Increase ground clearance on the Hume-Wildwood 115kV line


$50,000 4/12/2011

West ATC LLC 3461 N-144 McMillan-Wildwood 115kV Uprate

Increase ground clearance on the McMillan-Wildwood 115kV line


$50,000 2/28/2011

West DPC 3397 Genoa to La Crosse Tap 161 Rebuild

Rebuild of the 161 kV line from Genoa to the La Crosse tap. WI BaseRel Shared $18,000,000 6/1/2014

West GRE/MP 2634 Savanna-Cromwell Savanna-Cromwell MN BaseRel Shared $30,000,225 12/1/2014West ITCM 3410 Bridgeport Terminal

UpgradesUpgrade the Bridgeport-Ottumwa 161kV terminal equipment IA BaseRel Not

Shared$200,000 12/31/2011

West ITCM 3415 Marion Termianl Upgrades

Uprate 115 kV breaker 3710 terminal equipment at Marion. IA BaseRel Not Shared

$10,000 12/31/2011

West ITCM 3499 NERC Alert Facility Ratings for 2011

Verify and remediate facilities as required due to the industry-wide NERC alert

IA BaseRel Not Shared

12/31/2011

West MEC 3268 Lehigh: 345 kV 50 MVAr Reactor

Add a 345 kV, 50 MVAr reactor IA BaseRel Not Shared

$2,750,000 11/1/2012

West MP 3373 9 Line Thermal Upgrade MN BaseRel Shared $8,000,000 12/30/2012West OTP 3481 Buffalo - Casselton 115

kV LineConstruct 16 mile 115 kV line from Buffalo - Casselton (ND); Replace Buffalo 345/115 kV Transformer; Rebuild portion of Sheyenne - Mapleton 115 kV Line

ND BaseRel Shared $14,000,000 12/31/2014

West XEL 3309 Buffalo Ridge Substation Equipment Upgrade

Upgrade the wave traps and line switches at Buffalo Ridge to 2000 A going to Lake Yankton and Pipestone. Retap the Pipestone CTs to 2000 A going to Buffalo Ridge.

MN BaseRel Not Shared

$286,000 8/1/2011

West XEL 3312 Minn Valley - Maynard - Kerkhoven tap upgrade

This project is to upgrade the Minn Valley - Maynard - Kerkhoven tap 115 kV line to 795 ACSS conductor

MN BaseRel Shared $13,660,000 6/1/2014

Planning Region



Allocation Type per

FFShare Status

Other Type

Estimated Cost

Expected ISD (Max)

West XEL 3314 Kohlman Lake - Long Lake 2nd circuit

This project is to convert the Kohlman Lake - Long Lake 115 kV bifurcated line to double circuit with separate line terminations at Kohlman Lake and Long Lake


$3,000,000 6/1/2014

West XEL 3315 Chisago County 2nd 345/115 kV transformer

This project is to install a 2nd 345/115 kV transformer at Chisago County


$7,000,000 6/1/2014

West XEL 3316 Riverside - Apache lie upgrade

This project is to upgrade Riverside - Apache line to 360 MVA and upgrade Apache switch to 2000A


$3,000,000 6/1/2014

West XEL 3317 Goose Lake - Kohlman Lake 2nd circuit

This project is to convert the single circuit line between Goose Lake and Kohlman Lake to double circuit.

MN BaseRel Shared $6,000,000 6/1/2014

West XEL 3318 Parkers Lake Overstressed Breakers

This project replaces some of the 115 kV breakers at Parkers Lake with 63 kA rated breakers


$1,900,000 10/1/2011

West XEL 3319 Split Rock Overstressed Breakers

This project replaces some of the 115 kV breakers at Split Rock with 63 kA rated breakers

SD BaseRel Not Shared

$1,344,000 12/1/2011

West XEL 3320 Split Rock Reactor Replacement

This project is needed to replace the failed 50 MVAR reactor and associated breaker.

SD BaseRel Not Shared

$100,000 12/1/2011

West XEL 3321 Chemolite Breaker Addition

This project adds two breakers at Chemolite to insure only one line at a time will be removed from service during a breaker failure.


$580,000 1/14/2011

West XEL 3326 Black Dog Outlet This line will rebuild the 115 kV line from Black Dog to Savage to 795 ACSS conductor.


$4,564,000 6/1/2012

West XEL 3475 Prairie 3rd transformer This project is to install a 3rd 230/115 kV transformer at Prairie substation

ND BaseRel Not Shared

$12,000,000 6/1/2014

West XEL 3476 Maple River - Cass County 345 kV line

This project is to build a new 4.5 mile 345 kV line from Maple River to Cass County substation along with the 345/115 kV transformer at Cass County substation.

ND BaseRel Not Shared

$13,226,000 6/1/2014

Central AmerenIL 3337 G931 Paxton-Gilman Reconductoring

Reconductor to 1200 A summer emergency capability IL GIP Not Shared

$7,390,000 12/1/2013

Central AmerenIL 3357 Hennepin-E. Kewanee L1552 - Increase Ground Clearance

G545 and G569 Increase ground clearance on 477 kcmil ACSR conductor to permit operation at 120 degrees C. Upgrade E. Kewanee breaker and terminal equipment to 1200 A capability

IL GIP Not Shared

$3,180,000 12/31/2012

Central AmerenIL 3358 G545 Generator connection and bus rearrangement - E. Kewanee

Rearrange 138 kV bus at E. Kewanee and install terminal equipment (including 1200 A breaker) to connect wind farm (G545)

IL GIP Not Shared

$1,501,000 10/15/2012

Planning Region



Allocation Type per

FFShare Status

Other Type

Estimated Cost

Expected ISD (Max)

Central AmerenIL 3359 G569 Generator connection and bus upgrade - E. Galesburg

Upgrade 138 kV bus at E. Galesburg and install terminal equipment, including 1200 A breaker, to facilitate connection of wind farm (G569).

IL GIP Not Shared

$834,000 10/1/2012

Central AmerenIL 3360 G931 Generator connection and Establishment of Sheldon Soth Switching Station

Construct a new 138 kV switching station to connect a new wind farm (G931) to the Watseka-Morrison Ditch-1 138 kV line. Upgrade relaying at Watseka terminal.

IL GIP Not Shared

$4,425,000 5/6/2011

Central AmerenIL 3361 G996 Generator connection and bus upgrade - Paxton, South

Install terminal equipment, including 2000 A breaker, to facilitate connection of wind farm (G996). Install 2000 A bus-tie breaker

IL GIP Not Shared

$1,512,200 7/26/2011

Central DEM 3387 Tri-County Wind Energy 230kV Station - DPP J028

J028 - 230kV - Gen. interconnect sub - install three brkr ring bus for 200MW wind farm between Attica and Lafayette in the 23027 ckt.

IN GIP Not Shared

$3,778,246 6/1/2013

East ITC 3516 J025-Macomb County LF Gas Gen. Facility

12.8 MW LF Gas Gen. tapping the Carbon Tap on the 120kV Jewell - St. Clair 120kV line.

MI GIP Shared $485,000 9/1/2011

East METC 3517 G905-Gratiot County Wind Generation

200 MW wind farm connecting at the new METC owned Redstone substation

MI GIP Shared $21,630,500 12/31/2012

East METC 3518 G809-MCV 190 MW increase of the existing MCV Co-generation plant MI GIP Shared $64,000 6/1/2012West ATC LLC 1143 G282, 37628-02 Net: rating of HILLMAN 138/69 kV TRANSFORMER 1 is

upgraded to 100 MVA. Int: The Generator is required to provide a 138/34.5kV transformer, a circuit breaker and a disconnect switch on the high side of the 138/34.5kV transformer and 34.5kV facilities to c

WI GIP Not Shared

$4,200,000 12/31/2012

West ATC LLC 3160 G706-H012 Line X-6 Portage-Hamilton-Staff-Friesland-North Randolph 138 kV Uprate

G706-H012 Line X-6 Portage-Hamilton-Staff-Friesland-North Randolph 138 kV Uprate

WI GIP Not Shared

$1,447,679 12/31/2011

West ATC LLC 3161 G749 EcoMont Wind Farm

New EcoMont substation tapped into Belmont Tap-Rewey Tap 69 kV Line for G749

WI GIP Not Shared

$4,569,183 11/30/2012

Planning Region



Allocation Type per

FFShare Status

Other Type

Estimated Cost

Expected ISD (Max)

West ATC LLC 3206 G833-4_J022-3 Long Term Solution

1) Construct a new Barnhart 345 & 138 kV substation2) Install a new 345/138 kV transformer at Barnhart3) Loop Edgewater-South Fond du Lac, Edgewater-Cedarsauk, Sheboygan Energy Center-Granville 345 kV lines into Barnhart4) Loop the South Sheboygan Falls-Mullet River 138 kV line into Barnhart 138 kV5) Construct a new 138 kV line from Barnhart to Plymouth #46) Construct a new 138 kV line from Plymouth #4 to Howards Grove7) Construct a new 138 kV line from Howards Grove to Erdman8) Convert the existing Forest Junction-Howards Grove-Plymouth #4 138 kV line and the northern portion of the existing Plymouth #4-Holland 138 kV line to 345 kV9) Terminate the not-converted Holland 138 kV line at Barnhart 138 kV10) Terminate the southern end of the converted 345 kV line at Barnhart 11) Construct a new Branch River 345 kV substation12) Loop the converted 345 kV line into Branch River 345 kV substation13) Loop the Point Beach-Forest Juction, Point Beach-Sheboygan Energy Center 345 kV lines into Branch River14) Uprate Barnhart-Cedarsauk 345 kV line to 960 MVA for

WI GIP Shared $173,309,000 6/1/2018

West ATC LLC 3457 GIC J060 Garden City Wind Phase I

Interconnect GIC J060 Garden City Wind MI GIP Not Shared

$4,779,758 12/30/2011

West GRE 3467 MISO G604 Connect Oak Glen Wind Farm to 69 kV system MN GIP Not Shared

$1,722,464 7/1/2011

West GRE 3468 MISO H062 Connect H062 Wind Generation MN GIP Not Shared

$1,312,741 9/1/2011

West GRE 3469 MISO H061 Connect H061 Wind generation MN GIP Not Shared

$192,530 10/1/2011

West ITCM 3191 G164-Lakefield Jct 345 kV Breaker & Half

Convert the Lakefield 345kV ring bus to breaker and a half. MN GIP Shared $8,148,000 4/29/2011

Planning Region



Allocation Type per

FFShare Status

Other Type

Estimated Cost

Expected ISD (Max)

West ITCM 3192 G604-Ellendale 69 kV Switch Station

Construct a new Ellendale 69kV four terminal breaker station. The Hayward-West Owatanna 69kV line will be rerouted into the Ellendale breaker station. Then change the N.O. point on the line to closed.

MN GIP Shared $1,913,706 12/31/2011

West ITCM 3193 G741-Martin Co Waste Heat

Construct a new 69kV tap to the G741 customer. Tap the Trimont (IPL)-Sherburn(SCREC) 69kV line.

MN GIP Shared $223,884 10/1/2010

West ITCM 3194 G798-Story County Upgrades

Expand the ring bus at Story County. IA GIP Shared $422,664 7/31/2010

West ITCM 3195 G870-Freeborn Tap the Hayward-Winnebago Jct 161kV and construct a new Freeborn 161kV three terminal breaker station. Approximately 4 mile tap will connect Freeborn to the new G870 customer substation.

MN GIP Shared $3,516,163 10/1/2010

West ITCM 3196 H007-Bond Breaker Station

Tap the Hayward-Winnebago Jct 161kV and construct a new Bond 69kV three terminal breaker station.

IA GIP Shared $3,560,163 7/1/2011

West MDU 3199 G359, 38073-01 230 kV line from project interconnection to Ellendale Jct substation and new 230/115 kV transformer at Ellendale

ND GIP Not Shared

$19,130,000 12/1/2011

West OTP 3466 Project J-035 5 MW Wind Farm on OTP Doran 41.6 kV line.

Add 3 Way Switch on 41.6 kV line between Doran 41.6 kV substation to Doran Jct.

MN GIP Not Shared

$140,000 8/1/2012

Central AmerenIL 3370 Oreana Substation - Add 138-69 kV Transformer

To accommodate the installation of a new 138-69 kV transformer at Oreana, install 1-2000 A breaker and 2-2000 A disconnect switches to expand ring bus. Install 138 kV, 600 A motor operated disconnect switch at high-side of new 138-69 kV transformer.

IL Other Not Shared

Condition $750,000 6/1/2012

Central AmerenMO 3355 Labadie Breaker Replacements

Replace Breakers on Bland and Montgomery line positions with 3000 A, 50 kA breakers

MO Other Not Shared

Reliability $2,610,000 12/31/2011

Central AmerenMO 3368 Bailey Substation Install 2-2000 A bus-tie breakers and 2-138 kV circuit switchers

MO Other Not Shared

Reliability $4,000,000 6/1/2012

Central DEM 3377 Scottsburg 69kV - 28.8MVAR Capacitor

Replace Scottsburg 69kV - 7.2Mvar capacitor with a 28.8 Mvar capacitor and upgrade 69kV capacitor switching equipment

IN Other Not Shared

Reliability $500,000 12/31/2015

Central DEM 3378 Canal 69kV Dist Sub Canal Sub - Purchase land and build 22.4MVA, 69/12kV sub near Canal Road and Allison Street in the 5762 ckt.

OH Other Not Shared

Reliability $756,196 6/1/2012

Central DEM 3379 Shelbyville McKay Rd. 69kV Dist Sub

Shelbyville McKay Rd. - add new 69/12kV distribution sub in the 6976 ckt. Loop through with 954acsr and a set of 1200A line switches.

IN Other Not Shared

Reliability $303,710 6/1/2014

Planning Region



Allocation Type per

FFShare Status

Other Type

Estimated Cost

Expected ISD (Max)

Central DEM 3380 Noblesville Sta. 138kV Brkrs and 345kV Ckt Sws

Noblesville Gen. Sta. - Replace 138KV OB OCB: 138TR, 13869-9, 138230-7, 13886 and Circuit Switchers: 345230-11, 34519.

IN Other Not Shared

Condition $2,909,606 12/31/2011

Central DEM 3383 H.E. Rocklane Alternate 69kV Feed

Ckt. 6999 new Sherman Rd. Jct. to H.E. Rocklane line section. Replace DEM 69kV poles to accommodate new H.E. tap line. This will be an alternate feed to Rocklane - operated N.O. - built and owned by HE, inside DEM area.

IN Other Not Shared

Reliability $64,568 2/6/2011

Central DEM 3384 Hortonville to Marathon Jct. 69kV Reconductor

Hortonville to Marathon Jct. section of ckt. 6917 - Replace 336ACSR and 477ACSR with 954ACSS@200C. Upgrade Marathon Jct 600A switches to 1200A.

IN Other Not Shared

Reliability $1,409,099 12/1/2012

Central DEM 3385 Carmel Homeplace to Springmill Jct 69kV Reconductor

Carmel Homeplace to Springmill Jct. section of ckt. 69155 - Reconductor with 954ACSS@200C

IN Other Not Shared

Reliability $1,691,315 12/31/2012

Central DEM 3386 Carmel Springmill Rd. to Hortonville 69kV Line and Brkrs

Carmel Springmill Rd. Sub - Add 3-69kV breakers in straight bus config and build new .23 mile 69kV 954ACSS@200C line from Springmill Sub to old Springmill Jct. to complete circuit to Hortonville. Change operating mode at Homeplace to close loop from 146th to Springmill.

IN Other Not Shared

Reliability $3,000,000 6/1/2016

Central DEM 3388 Walton to Logansport S. 69kV Reconductor

Walton to Logansport S. - Reconductor 69kV - 69110 line with 477acsr at 100C

IN Other Not Shared

Reliability $1,900,000 6/1/2015

Central DEM 3389 WVPA Center Valley 138kV Dist Sub

DEM to install new line switching in the 138kV - 13867 ckt. at intersection with SR39 for tap line to radially feed new WVPA Center Valley dist sub

IN Other Not Shared

Reliability $236,677 12/1/2011

Central DEM 3390 Inland Container to Hillsdale 69kV Line Rebuild

Rebuild 69kV - 6906 line from Inland Container to WROW Jct. to Hillsdale - 477acsr26x7 at 100C

IN Other Not Shared

Condition $3,663,434 12/31/2011

Central DEM 3391 Elnora to Newberry 69kV Line Rebuild

Rebuild 69kV - 6959 line section from Elnora to Newberry - 477acsr26x7 at 100C

IN Other Not Shared

Condition $1,716,818 12/31/2011

Central DEM 3392 DEM Speed to LGEE Paddys West 345kV tie

New DEM Speed to LGEE Paddys West 345kV tie line IN Other Not Shared

Reliability $15,000,000 12/31/2012

Central IPL 3273 Southwest - Stout CT Line Rating Upgrade

Increase line rating above 322 MVA to mitigate the potential overload

IN Other Not Shared

Reliability $300,000 6/1/2011

Central IPL 3274 South - Stout S Line Rating Upgrade

Increase line rating above 272 MVA to mitigate the potential overload

IN Other Not Shared

Reliability $350,000 6/1/2011

Central Vectren (SIGE) 2460 Leonard Rd 69kV Substation

Add new 69kV switching substation near Leonard Rd IN Other Not Shared

Reliability $2,150,000 6/1/2013

Central Vectren (SIGE) 2462 Y53 Stringtown to Folz Reconductor

Reconductor existing 69kV line for more capacity IN Other Not Shared

Condition $2,500,000 6/1/2013

Planning Region



Allocation Type per

FFShare Status

Other Type

Estimated Cost

Expected ISD (Max)

Central Vectren (SIGE) 2463 Y31 Mt Vernon to Givens 69kV recond.


Condition $5,700,000 6/1/2013

Central Vectren (SIGE) 2464 Y33 Mt Vernon to New Harmony 69kV recond.


Condition $10,600,000 6/1/2014

East ITC 1868 Cato GIS replacement Replace GIS Equipment MI Other Not Shared

Condition $5,400,000 12/1/2012

East ITC 3276 ITCT Annual Breaker Replacement Program for 2013

Annual Breaker Replacement Program Mi Other Not Shared

Condition $9,000,000 12/31/2013

East ITC 3277 ITCT Annual NERC Relay Loadability Compliance Program for 2013

Annual NERC Relay Loadability Program Mi Other Not Shared

Reliability $2,400,000 12/31/2013

East ITC 3278 ITCT Annual Potential Device Replacement Program for 2013

Annual Potential Device Replacement Program Mi Other Not Shared

Condition $300,000 12/31/2013

East ITC 3279 ITCT Annual Relay Betterment Program for 2013

Annual Relay Betterment Program Mi Other Not Shared

Condition $1,800,000 12/31/2013

East ITC 3280 ITCT Annual Wood Pole Replacement Program for 2013

Annual Wood Pole Replacement Program Mi Other Not Shared

Condition $3,000,000 12/31/2013

East ITC 3281 Lima Substation Distribution Interconnection Request Mi Other Not Shared

Distribution $8,400,000 12/31/2012

East ITC 3283 Dexter Township Substation

Distribution Interconnection Request Mi Other Not Shared

Distribution $2,676,000 11/1/2012

East ITC 3284 ITCT Customer Interconnections - Year 2015


Distribution $2,000,000 12/31/2015

East ITC 3286 Fermi 345kV Disconnect Replacement Project - 3rd Row

Replace 345kV Disconnects, add 3rd 345kV Row Mi Other Not Shared

Condition $5,050,000 12/31/2013

East ITC 3495 NERC Alert Facility Ratings for 2011


MI Other Not Shared

Reliability $1,700,000 12/31/2011

Planning Region



Allocation Type per

FFShare Status

Other Type

Estimated Cost

Expected ISD (Max)

East ITC 3503 Air Flow Spoilers Installation

Install air flow spoilers on approximately 15 miles of the targeted areas of the Belle River-Greenwood-Pontiac and Belle River-Blackfoot 345 kV double circuit tower lines.

MI Other Not Shared

Reliability $1,620,000 12/31/2012

East METC 3139 Tippy-Wexford 138 kV Circuit Uprgrade

Terminal Equipment upgrade at Tippy MI Other Not Shared

Reliability $20,000 6/1/2012

East METC 3287 Riggsville Rebuild Rebuild 138 kV bus and switches Mi Other Not Shared

Condition $4,600,000 9/30/2011

East METC 3288 METC Annual Breaker Replacement Program for 2013

Annual Breaker Replacement Program Mi Other Not Shared

Condition $6,000,000 12/31/2013

East METC 3289 METC Annual NERC Relay Loadability Compliance Program for 2013

Annual NERC Relay Loadability Program Mi Other Not Shared

Reliability $2,400,000 12/31/2013

East METC 3290 METC Annual Potential Device Replacement Program for 2013

Annual Potential Device Replacement Program Mi Other Not Shared

Condition $300,000 12/31/2013

East METC 3291 METC Annual Relay Betterment Program for 2013

Annual Relay Betterment Program Mi Other Not Shared

Condition $1,200,000 12/31/2013

East METC 3292 METC Annual Wood Pole Replacement Program for 2013

Annual Wood Pole Replacement Program Mi Other Not Shared

Condition $4,800,000 12/31/2013

East METC 3293 METC Annual Battery Replacement Program for 2013

Annual Battery Replacement Program Mi Other Not Shared

Condition $100,000 12/31/2013

East METC 3294 METC Annual Power Plant Control Relocation Program for 2013

Annual Power Plant Control Relocation Program Mi Other Not Shared

Operation $3,120,000 12/31/2013

East METC 3295 METC Sag Clearance Program for 2013

Sag Clearance Program Mi Other Not Shared

Clearance $3,600,000 12/31/2013

East METC 3296 METC Spill Prevention Control and Countermeasure Program for 2011

Annual SPCC Program Mi Other Not Shared

Condition $3,100,000 12/31/2011

Planning Region



Allocation Type per

FFShare Status

Other Type

Estimated Cost

Expected ISD (Max)



Condition $3,100,000 12/31/2012



Condition $3,100,000 12/31/2013

East METC 3299 METC Customer Interconnections - Year 2015


Distribution $2,500,000 12/31/2015

East METC 3306 Karn-Cottage Grove 138 (Karn Position 488) Relay Replacement Project

Mi Other Not Shared

Reliability $200,000 6/1/2012

East METC 3308 Livingston to Gaylord 138 kV Dual Pilot Relay Protection Scheme Installation

Install new dual pilot relay scheme on 138kV circuit Mi Other Not Shared

Reliability $315,000 12/31/2012

East METC 3491 NERC Alert Facility Ratings for 2011


MI Other Not Shared

Reliability $2,100,000 12/31/2011

East METC 3505 Eaton Rapids Load Interconnection

Serve new load in Eaton Rapids with 2 new 138kV circuits from Clinton Jct. and the Delhi-Tompkins circuit

MI Other Not Shared

Distribution $28,500,000 1/1/2013

East WPSC 3328 Barryton New Distribution Interconnection from the Hersey to Weidman circuit

MI Other Not Shared

Distribution $100,000 12/31/2011

East WPSC 3329 Burnips to Wayland Rebuild the Burnips to Wayland line section with a larger conductor

MI Other Not Shared

Reliability $7,250,000 12/31/2013

East WPSC 3330 Cansovia Capacitor Bank

Install a Capacitor Bank tap at the Casnovia substation MI Other Not Shared

Reliability $260,000 12/31/2011

East WPSC 3331 Redwood to Hart Rebuild the Redwood to Hart line section with a larger conductor

MI Other Not Shared

Reliability $750,000 12/31/2015

East WPSC 3332 Bass Lake Transmission Upgrade

Install Relaying MI Other Not Shared

Reliability $250,000 2/28/2011

East WPSC 3333 Lemon Junction Transmission Station

Construct a single breaker station MI Other Not Shared

Reliability $350,000 12/31/2011

East WPSC 3334 Casnovia to Sternberg Rebuild a portion of the line for Distibution Underbuild MI Other Not Shared

Reliability $400,000 6/30/2011

Planning Region



Allocation Type per

FFShare Status

Other Type

Estimated Cost

Expected ISD (Max)

East WPSC 3335 Burnip Transmission Station Upgrade

Upgrade to replace outdated equipment. Bus, breakers, relays, and other equipment as necessary.

MI Other Not Shared

Condition $900,000 12/31/2013

West ATC LLC 174 Canal-Dunn Road 138 kV

Construct a 7.7 mile Canal - Dunn Road 138 ckt , Sum rate 400; install a new 138/69 kV transformer at Dunn Road substation.

WI Other Not Shared

Reliability $24,763,300 3/1/2012

West ATC LLC 333 Hiawatha-Indian Lake conversion to 138 kV

Hiawatha-Indian Lake conversion to 138 kV MI Other Excluded Condition $4,900,000 6/1/2013

West ATC LLC 1699 Mckenna & Chaffee Ck Capacitor Banks Upgrades

Upgrade Mckenna 6.3 MVAR capacitor bank to 15.3 MVAR and upgrade Chaffee Ck 10.8 MVAR to 14.4 MVAR capacitor bank

WI Other Not Shared

Reliability $686,750 7/31/2011

West ATC LLC 1705 Bass Creek area upgrades

Install a 138/69 kV transformer at Bass Creek substation, Uprate Townline Road-Bass Creek 138 kV line

WI Other Not Shared

Reliability $6,975,946 4/1/2011

West ATC LLC 2036 Uprate Y-40 Gran Grae-Boscobel 69 kV

Increase line clearance to 200/300 deg F SN/SE WI Other Not Shared

Condition $5,291,028 12/15/2011

West ATC LLC 2037 Rebuild Dane-Okee 69 kV

Rebuild Dane-Okee 69 kV WI Other Not Shared

Reliability $6,798,033 6/19/2012

West ATC LLC 2055 Clear Lake-Woodmin 115 kV

Construct a 7.5 mile 115 kv line from Clear Lake to a new Woodmin distribution substation

WI Other Not Shared

Reliability $21,331,000 6/1/2012

West ATC LLC 2820 Replace Bluemound 230/138kV transformerT1


WI Other Not Shared

Condition $8,200,000 5/31/2012

West ATC LLC 2842 Uprate Spring Green-Stage Coach 69-kV

Uprate Spring Green-Stage Coach 69-kV WI Other Not Shared

Reliability $6,957,394 4/8/2011

West ATC LLC 3095 Uprate 9Mile-Roberts 69 kV line 6952

Increase ground clearance for the 9Mile-Roberts 69 kV line 6952 to 176 deg f clearance for all seasons & Install Arresters, Replace Select Components

MI Other Not Shared

Reliability $19,743,032 4/1/2012

West ATC LLC 3108 Rebuild Pine River-Straits 69kV dbl ckt line

Rebuild Pine River-Straits 69kV dbl ckt line with t2-477 ACSR

MI Other Not Shared

Reliability $40,804,513 6/1/2014

West ATC LLC 3126 Install a 2nd Chandler Transformer

Install a 2nd Chandler Transformer & reconfigure bus to 138 kV Ring bus

MI Other Not Shared

Reliability $9,700,000 12/9/2012

West ATC LLC 3157 Line Y-95 Fount Valley-Fountain Valley Tap-Red Granite Tap-ACEC Spring Lake Tap-Silver Lake-Wautoma Uprate

Line Y-95 Fount Valley-Fountain Valley Tap-Red Granite Tap-ACEC Spring Lake Tap-Silver Lake-Wautoma Uprate

WI Other Not Shared

Reliability $362,468 6/17/2011

West ATC LLC 3188 Pleasant Prairie-Zion 345-kV uprate

Replace 345kV Wave traps at the ComEd Zion SS and Jumpers

WI/IL Other Not Shared

Economic $1,544,571 3/25/2011

Planning Region



Allocation Type per

FFShare Status

Other Type

Estimated Cost

Expected ISD (Max)

West ATC LLC 3395 Milwaukee Co T-D Install a new Milwaukee Co T-D substation by looping in line 5042 (Bluemound-Everett 138kV)

WI Other Not Shared

Distribution $33,500,000 4/1/2015

West ATC LLC 3396 Uprate Blue River Tap-Muscoda 69 kV

Uprate Blue River Tap-Muscoda 69 kV line by increasing clearance at a distribution crossing to 564 Amps

WI Other Not Shared

Condition $580,000 11/15/2010

West ATC LLC 3428 Stage Coach-Timberlane 69kV uprate

Increase ground clearance for the Stage Coach-Timberlane 69kV line

WI Other Not Shared

Reliability $35,000 4/8/2011

West ATC LLC 3432 Uprate Stoughton-Oregon 69kV line

Uprate Stoughton-Oregon 69kV line WI Other Not Shared

Reliability $570,000 4/21/2011

West ATC LLC 3433 Uprate Stagecoach-Mt Horeb NE-Mt Horeb 69 kV line Y-128

Uprate Stagecoach-Mt Horeb NE-Mt Horeb 69 kV line Y-128

WI Other Not Shared

Reliability $36,505 12/31/2011

West ATC LLC 3447 Ontonagon 138/69kV Tr uprate

Retap CT related to Ontonagon 138/69 kV Tr to obtain a higher rating

MI Other Not Shared

Reliability $12,410 12/7/2010

West ATC LLC 3448 Ontonagon 138/69kV Tr Replacement

Replace the Ontonagon 138/69 kv Tr with a larger unit MI Other Not Shared

Reliability $935,786 12/1/2011

West ATC LLC 3449 Rebuild the Atlantic-M38 69kV line

Rebuild the Atlantic-M38 69kV line with a larger conductor MI Other Not Shared

Reliability $18,878,963 12/31/2013

West ATC LLC 3451 Y-136 Mt Horeb-Verona 69kV Rerate

Increase ground clearance on the Mt Horeb-Verona 69kV line

WI Other Not Shared

Reliability $710,000 11/1/2011

West ATC LLC 3452 Y-158 Bass Ck-Sheepskin 69kV Rerate

Increase ground clearance on the Bass Ck-Sheepskin 69kV line

WI Other Not Shared

Reliability $920,000 11/1/2011

West ATC LLC 3453 Y-25 Waupun-S Fond du Lac 69kV Rerate

Increase ground clearance on the Waupun-S Fond du Lac 69kV line

WI Other Not Shared

Reliability $2,186,630 2/28/2012

West ATC LLC 3458 Aurora 115-69kV T3 Replacement

Aurora 115-69kV T3 Replacement WI Other Not Shared

Condition $2,958,914 6/3/2011

West ATC LLC 3460 Y-93 Berlin-Ripon 69kV Uprate

Increase ground clearance on the Berlin-Ripon 69kV line WI Other Not Shared

Reliability $1,389,745 2/28/2011

West ATC LLC 3472 Pleasant Prairie Bus Reconfiguration

Construct a new 6-rung breaker-and-a-half 345 kV bus at the P4 site adjacent to the existing P4 yard.

WI Other Not Shared

Reliability $39,400,000 3/22/2013

West ATC LLC 3479 Progress-Aviation 138 kV Uprate

Increase ground clearance for the Progress-Aviation line to 187 degrees F

WI Other Not Shared

Condition $492,563 3/1/2012

West ATC LLC 3480 Engadine Load Move Construct a new radial 69-kV tap from the existing Indian Lake-Hiawatha 69-kV line 6913 to the Engadine Substation

WI Other Not Shared

Reliability $810,804 10/1/2012

West ATC LLC 3488 Uprate Brick Church to Walworth 69 kV line

Asset management project to uprate Y-159 from Brick Church to Walworth 69 kv Line

WI Other Not Shared

Condition $532,000 3/1/2012

Planning Region



Allocation Type per

FFShare Status

Other Type

Estimated Cost

Expected ISD (Max)

West ATC LLC 3489 UprateY-34 Jennings Road to Darlington 69 kV line

Asset management project to uprate Y-34 from Jennings Road to Darlington 69 kv Line

WI Other Not Shared

Condition $314,000 3/1/2012

West ATC LLC 3504 Y-80 Omro to Winneconne Rerate

Rerate Line Y-80 conductor from Omro sub to Winneconne sub to a rating of 580 amps

WI Other Not Shared

Condition $205,000 12/1/2012

West DPC 3434 Lufkin 161 kV substation

Build a new 161 kV substation on the Alma to Elk Mound 161 line in the Eau Claire area.

WI Other Not Shared

Reliability $2,164,000 9/1/2012

West GRE 2571 MN Pipeline-Menahga 8.0 mile line

MN Pipeline-Menahga 8.0 mile line. Built 115 kV but will be operated at 34.5.

MN Other Not Shared

Distribution $4,199,990 11/15/2014

West GRE 2599 Shell Lake (IM) 5.0 mile, 115 kV line

Shell Lake (IM) 5.0 mile, 115 kV line MN Other Not Shared

Distribution $4,201,000 10/31/2014

West GRE 2643 Parkers Prairie 115 kV conversion

Parkers Prairie 115 kV conversion, New Distribution tap MN Other Not Shared

Distribution $1,220,998 5/1/2013

West GRE 2679 Ramsey-Grand Forks (81.02 mi.) 230 kV Rebuild

Ramsey-Grand Forks (81.02 mi.) 230 kV Rebuild MN Other Not Shared

Condition $40,500,000 11/1/2019

West ITCM 3406 Adams-Rochester Terminal Upgrades

Upgrade the Adams terminal equipment to winter conductor limit

MN Other Not Shared

Reliability $360,000 4/29/2011

West ITCM 3407 Bluff Substation Additions

Add 69kV breakers to the Bluff Substation 69kV and install associated relay equipment.

IA Other Not Shared

Distribution $1,920,000 12/31/2011

West ITCM 3408 BooneQuartz Sustation This project performs the conversion of the Boone Quartz substation from 34.5kV to 69kV as part of the overall rebuild and conversion of the 34.5kV system. The Boone Quartz substation was constructed with a dual high side transformer and the high side was laid out for 69kV operation in preparation for the conversion. Two 69kV line breakers will be installed at the Boone Quartz substation. Existing 69kV lines and 34.5kV lines already constructed for 69kV operation will be re-configured along with installation of 69kV taps into the Boone Quartz substation to make the change to 69kV. No new load is being added during the conversion to 69kV.

IA Other Not Shared

Reliability $1,700,000 12/31/2011

West ITCM 3409 Bricelyn-Walters Rebuild

The recommended project is to completely rebuild a 5 mile section of the Bricelyn - Walters 69 kV line with standard T2-477 construction and shield wire.

IA Other Not Shared

Condition $2,625,000 12/31/2013

Planning Region



Allocation Type per

FFShare Status

Other Type

Estimated Cost

Expected ISD (Max)

West ITCM 3411 Bridgeport T8 Add a 69kV breaker to the Bridgeport North 69kV ring and install associated relay equipment.

IA Other Not Shared

Distribution $360,000 12/31/2011

West ITCM 3412 Fort Madison Interconnection

Install tap capable of double circuit 69kV to Fort Madison substation and install associated relay equipment.

IA Other Not Shared

Distribution $360,000 12/31/2012

West ITCM 3413 Gladbrook 161kV tap Install a 161kV tap pole in the Marshalltown to Traer line with two line switches. Construct a 161kV tap line to the new Gladbrook substation.

IA Other Not Shared

Distribution $300,000 12/31/2013

West ITCM 3414 Magnolia 7.1 MVAR 69kV Cap

ITCM will move the existing Lewisville 69kV 7.1 MVAR capacitor to the 69kV bus at Magnolia. Recent system changes have opened up a 69kV bay at Magnolia and this will be used for the capacitor bank and 69kV breaker.

IA Other Not Shared

Reliability $480,000 12/31/2012

West ITCM 3416 Marion Circuit 0410 Rebild to 69kV

This project rebuilds the sections (approximately 25 miles) of Marion circuit 0410 that will be utilized in the overall 34.5kV to 69kV conversion plan but have not yet been constructed for 69kV operation.

IA Other Not Shared

Distribution $10,500,000 12/31/2012

West ITCM 3417 Marshalltown East Nevada

Construct a 1-2 span 34.5kV tap, install new relays for Marshalltown circuits 1810 and 2620, and upgrade terminal limit to address overload during contingency. Remove two normally open switches to limit system configuration to address system protection coordination issues which can occur when rural and city circuits are tied together.

IA Other Not Shared

Reliability $280,000 12/31/2011

West ITCM 3418 Mount Vernon Circuit 6420 Rebild to 69kV

This project rebuilds the sections (approximately 17 miles) of Mount Vernon circuit 6420 that will be utilized in the overall 34.5kV to 69kV conversion plan but have not yet been constructed for 69kV operation.

IA Other Not Shared

Distribution $7,150,000 12/31/2013

West ITCM 3419 Bertram161kV tap The new transformer high side voltage is 69/34.5kv; it will need a 0.5 mile tap line built to the substation from the existing 34.5kV system with the future plans of 69kV rebuild. Adding the double-circuit tap to the substation will allow connection to the new transformers. The double circuit tap will provide additional reliability, with switching, to have the ability to separate the parallel transformers in the situation a transformer fails, no load will be lost.

IA Other Not Shared

Distribution $270,000 12/31/2012

Planning Region



Allocation Type per

FFShare Status

Other Type

Estimated Cost

Expected ISD (Max)

West ITCM 3420 OGS Breaker Install new 345kV breaker in the Ottumwa Generating Station substation to replace the failed 345kV circuit switcher. Replace the transformer lockout/breaker control panel. Replace the existing 345kV relay panel with two new panels and one lockout panel, which will allow for the retirement of an existing transfer trip scheme. The new line panels will implement a new redundant transfer trip scheme. Install second set of battery back up.

IA Other Not Shared

Condition $1,350,000 12/31/2011

West ITCM 3421 Centervile 7.1 MVAR 69kV Cap

nstall a 7 MVAR 69 kV capacitor, breaker with synchronous closing control, switch, and 0.5 mH reactor. 69 kV breakers 0-6961-1 and 0-6921-2 will be replaced due to condition. A 69 kV bus tie breaker and switch will be added for reliability between transformers 2 and 3.

IA Other Not Shared

Reliability $1,350,000 12/31/2011

West ITCM 3422 South Broadway TEQ Install Sub IA Other Not Shared

Distribution $150,000 12/31/2012

West ITCM 3423 Truro Line Rebuild Rebuild the line between the Truro substation and the White Oak tap and operate the line at 69 kV.

IA Other Not Shared

Reliability $3,360,000 12/31/2011

West ITCM 3425 VMEU Interconnect Install line switches at the interconnection point. IA Other Not Shared

Reliability $110,000 12/31/2011

West ITCM 3426 DPC/ITC Interconnect move

The recommended project is to move the existing interconnection point approximately 0.6 miles south. ITC will install a laminate structure and associated equipment to accommodate DPC’s project.

IA Other Not Shared

Distribution $0 12/31/2013

West MEC 3270 CBEC-River Bend 161 kV Rebuild

Increase 161 kV line rating. IA Other Not Shared

Reliability $675,000 6/1/2011

West MEC 3271 River Bend-Bunge 161 kV Rebuild

Increase 161 kV line rating. IA Other Not Shared

Reliability $700,000 6/1/2011

West MEC 3272 Raun 345 kV Breaker Replacement

Replace existing SFA 345 kV breaker 0170 with a new unit. IA Other Not Shared

Condition $500,000 6/1/2011

West MP 2549 15L Upgrade Thermal Upgrade of MP Line #15 MN Other Not Shared

Reliability $3,179,000 6/1/2014

West MP 3374 Greenway Re-energize existing 115/23 kV substation MN Other Not Shared

Distribution $700,000 11/1/2012

West OTP 2856 Victor-New Effington 41.6 kV Line Upgrade

Rebuild Existing 4-Mile 41.6 kV Line SD Other Not Shared

Reliability $200,000 6/30/2011

Planning Region



Allocation Type per

FFShare Status

Other Type

Estimated Cost

Expected ISD (Max)

West XEL 3310 Highway 212 Corridor upgrade

This project is to complete the conversion of 69 kV line between Scott County and West Waconia substation to 115 kV. The scope also involves building new West Creek distribution substation and converting the Chaska, Victoria and Augusta substations to 115 kV.

MN Other Not Shared

Distribution $19,450,000 6/1/2012

West XEL 3313 New Prague switch This project is to install a 69 kV 1 way switch to provide SMMPA's New Prague substation a new interconnection point. The existing interconnection would require cutting the line jumpers phisically when the New Prague - Veslie line is out of service.

MN Other Not Shared

Reliability $180,000 6/1/2012

West XEL 3322 Cedar Falls - Clear Lake Rebuild

Rebuild 43 Miles of 69 kV line to 477 ACSR WI Other Not Shared

Reliability $14,000,000 6/1/2013

West XEL 3323 Park Falls Bio-Refinery Build radial 115 kV line from Park Falls sub to a new customer and install a new distribution sub for the customer

WI Other Not shared

Distribution $23,769,000 6/1/2013

West XEL 3324 Eau Claire Overstressed Breakers

Replace overstressed Eau Claire 69 kV breakers. 4E185, 4E186, 4E187, 4E188, 4E189, 4E190, 4E191, 4E192, 4E193, 4E195.

WI Other Not Shared

Reliability $1,683,000 12/1/2011

West XEL 3325 Orono 115 kV conversion

This project will move the supply for Orono from its current 69 kV supply to the 115 kV line from Medina to Crow River

MN Other Not Shared

Reliability $5,340,000 12/1/2012

West XEL 3327 Eau Claire - Madison Street Rebuild

This project will replace 1 mile of 4/0 Cu conductor with 795 ACSS on the 69 kV line between Eau Claire - Sterling - Madison St.

WI Other Not Shared

Reliability $1,600,000 12/1/2011

West XEL 3473 Sioux Falls 115 kV Phase 1

This project re-constructs 10 miles of existing 69 kV line in Sioux Falls, SD to 115 kV; 6 miles of the new line will be double circuit with existing 69 kV.

SD Other Not Shared

Reliability $35,000,000 6/1/2014

West XEL 3474 Adams 345 kV Reactor Installation

Installing a 50 MVAR reactor at Adams substation on the Pleasant Valley line, along with a breaker and disconect switch

MN Other Not Shared

Reliability $2,260,000 6/1/2012

West XEL 3509 Stinson to Bayfront 115 kV line rebuild

Rebuild approximately 33 miles of 115 kV line from 336 ACSR to 795 ACSR

WI Other Not Shared

Condition $15,400,000 1/1/2013

West XEL, GRE 3454 Hollydale 115 kV upgrade

This project will upgrade the 69 kV line from GRE's Medina to Plymouth substations. A new switching station will be added on GRE's 115 kV line between Parkers Lake and Elm Creek north or south of the Plymouth Substation depending on the permitted location. Joint project with GRE P3394 at Medina

MN Other Not Shared

Reliability $24,676,164 6/1/2013

















Agreements

MTEP11 MISO Transmission Expansion Plan 2011 Appendix BAppendix B: Project Table 9/7/2011 Project Summary Information from Facility table

Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

B Central AmerenIL 1234 Havana, South-Mason City, West 138 kV Increase ground clearance on 18.4 miles IL BaseRel $642,300 6/1/2014 6/1/2014 Proposed 138 B YB Central AmerenIL 1533 Washington Street-S. Bloomington -

Upgrade Terminal EquipmentReplace terminal equipment at S. Bloomington IL BaseRel $137,000 12/1/2013 12/1/2013 Proposed 138 B Y

B Central AmerenIL 1537 Mt. Vernon, West-S. Centralia - Upgrade Terminal Equipment

Replace terminal equipment at S. Centralia IL BaseRel $200,000 6/1/2013 6/1/2013 Proposed 138 B Y

B Central AmerenIL 2114 IP03 Network upgrades for tariff service request IL GIP In Suspension $2,082,000 9/30/2009 12/1/2013 Planned 138 B YB Central AmerenIL 2117 IP08 Network upgrades for tariff service request IL GIP In Suspension $1,891,464 6/1/2014 6/1/2014 Planned 138 B YB Central AmerenIL 2118 IP04, IP08 Network upgrades: Line #1382 & #1384: Project of

replacing approximately 47.1 circuit miles of existing three phase, single conductor, 477 MCM 30/7 ASCR with three phase 556.5 MCM 26/7 ACSS conductor. Approximately 121 existing wood H-frame type structures will be replaced with new wood H-frame type structures to gain additional ground clearance.

IL GIP In Suspension 6/1/2014 6/1/2014 Planned 138 B Y

B Central AmerenIL 2280 LaSalle-Oglesby Main 138 kV Line 1496 Reconductor 2.16 miles of 477 kcmil ACSR and 336 kcmil ACSR to 1200 A summer emergency capability

IL BaseRel Not Shared $900,000 6/1/2013 6/1/2013 Planned 138 B Y

B Central AmerenMO 2774 Adair Wind Farm Connect Wind Farm at Adair Substation MO GIP In Suspension 11/1/2020 11/1/2020 Proposed 161 B YB Central DEM 1521 Bloomington 13836 Switches Replace the Bloomington 13836 600A breaker

disconnect switches with 2000A switches. New limit 800A Wave Trap.

IN BaseRel Not Shared $233,455 6/1/2016 6/1/2016 Planned 138 B Y

B Central DEM 3381 Meldahl Dam Generator 345kV Interconnect Install interconnection substation for Meldahl Dam generator. Install 3-breaker 345kV ring bus, 345-138kV - 120 MVA transformer, loop Feeder 4545 through new substation. Connect independent generator per MISO requirements.

OH GIP Not Shared $8,949,798 12/31/2013 12/31/2013 Planned 345 138 B Y

B Central DEM, IPL 1558 Close Wheatland Breaker Close the breaker at IPL's Wheatland - make upgrade to Petersburg - Francisco and the Petersburg - Thompson 345 kV to address 1st contingency limitations

IN Other $11,435,000 5/1/2013 5/1/2013 Proposed 345 B Y

B Central IPL, DEM 1557 Bloomington to Pritchard to Franklin to Hanna 345 kV line

Tap the Hanna - Stout 345 and Hanna - Francs 345 kV circuits into one new 345 kV Switching Station at the Franklin twp site and build station at Pritchard. Also adds 345 kV single circuit from Bloomington - Pritchard - Frankin Twp station.

IN RegBen $41,750,000 1/1/2014 1/1/2014 Proposed 345 B Y

B East ITC 1850 Hancock 230/120kV Transformer Cut the Wixom-Quaker 230kV circuit into Hancock Station, install a 230/120kV transformer.

MI BaseRel Shared $9,000,000 12/31/2013 12/31/2013 Proposed 230 120 B Y

B East METC 2809 Garfield-Hemphill 138kV Replace 9.1 miles of 336 ACSR with 1431 ACSR MI Other Excluded $11,740,000 6/1/2014 6/1/2014 Proposed 138 B YB East METC 2822 Edenville Jct. - Warren 138kV Reconductor the Edenville-Warren 138kV line to 954

ACSRMI Other Not Shared $7,000,000 12/1/2016 12/1/2016 Proposed 138 B Y

B East NIPS 3154 Sheffield Substation - 13877 Reactors Add 0.795 Ohm reactor on BP Whiting to Sheffield IN Other Not Shared $807,141 12/1/2012 12/1/2012 Proposed 138 B YB West ATC LLC 544 Bluemound 3x75 Cap Banks Add 3x75 Cap Banks to 2 Bluemound buses WI Other Not Shared $3,463,000 6/1/2015 6/1/2015 Conceptual 138 B YB West ATC LLC 1269 Arcadian transformer replacement Replace Arcadian 345/138kV transformer #3 with a

500MVA transformer.WI Not Shared $3,500,000 6/1/2020 6/1/2020 Conceptual 345 138 B Y

B West ATC LLC 1270 Rebuild Arcadian - Waukesha 138kV lines Rebuild the two Arcadian - Waukesha 138kV lines WI Other Not Shared $14,586,895 6/1/2016 6/1/2016 Proposed 138 B YB West ATC LLC 1284 Tie the 138kV radial line Racine - Somers -

Albers to the 138kV substation at Albers. Also upgrade the 138kV radial line to 345/477 summer normal/emergency ratings.

Tie the 138kV radial line Racine - Somers - Albers to the 138kV substation at Albers. Also upgrade the 138kV radial line to 345/477 summer normal/emergency ratings.

WI BaseRel 6/1/2050 6/1/2050 Conceptual 138 B Y

B West ATC LLC 1624 Uprate X-67 Portage-Trienda 138 kv line Increase clearance and uprate SS equipment WI Not Shared 6/1/2022 6/1/2022 Conceptual 138 B YB West ATC LLC 1687 Metomen 138-69 kV Transformer

ReplacementReplace the Metomen 138-69 kV transformer to achieve a higher emergency rating

WI Other Not Shared $4,700,000 6/1/2017 6/1/2017 Planned 138 69 B Y

B West ATC LLC 1946 2nd Spring Green 138-69 kV Transformer Install a 2nd Spring Green 138-69 kV Transformer with a 100 MVA summer normal rating

WI Other Not Shared $1,400,000 6/1/2018 6/1/2018 Conceptual 138 69 B Y

B West ATC LLC 2044 Uprate Castle Rock-McKenna 69kV Increase line clearance to 200 deg F SN/SE WI Other Not Shared $1,093,828 6/1/2017 6/1/2017 Conceptual 69 B YB West ATC LLC 2454 G590 Stony Brook G590 G-T Interconnection From Techumseh Rd 138 kV

bus. Upgrade Kaukauna Central tap - Tayco 138 kV line.WI GIP In Suspension $1,610,720 5/1/2012 5/1/2012 Planned 138 B Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

B West ATC LLC 3089 Nine Springs Pflaum Area Project Uprate Fitchburg-Nine Springs and Royster-Pflaum lines to 275 deg F SE clearance and move AGA load onto Femrite-Royster line and install 2-16.33Mvar cap banks at Nine Springs

WI $4,400,000 1/31/2013 1/31/2013 Proposed 69 B Y

B West ATC LLC 3118 North Lake Geneva-South Lake Geneva 138kV

North Lake Geneva-South Lake Geneva 138kV line WI $16,401,632 6/1/2016 6/1/2016 Proposed 138 69 B Y

B West GRE 2098 G390, A252, A253 Network upgrades for tariff service request for G390, A252, A253

MN GIP In Suspension $6,272,080 4/1/2013 4/1/2013 Proposed 230 B Y

B West ITCM 1147 G298, 37061-02 Net: The Transmission Owner shall install a new 161kV line breaker on the Triboji- Wisdom Line and a new 161kV transformer breaker located on the existing #1 Triboji 161/69kV transformer and are shown in Exhibit A2.. Int: Generator shall construct a 161/34kV substation consisting of 161kV breaker, 161/34kV transformer, 34kV breakers and a 161kV line from (Bob what is name of Customer sub?) to the dead-end tower at the IPL Triboji substation.

IA GIP In Suspension $2,300,000 12/31/2011 12/31/2011 Planned 161 B Y

B West ITCM 1741 G517: Dotson - Storden - Heron Lake 161kV

Network upgrades for G517. Build a new Heron Lake - Cottonwood Co 161 kV line and a new Cottonwood Co 161 kV switch station. Build Cottonwood Co to Dotson 161kV line.

MN GIP Shared $36,719,820 12/31/2012 12/31/2012 Planned 161 B Y

B West MDU 1148 G297, 37664-01 Net: At the Glenham Jct Substation, two 115 kV line potential sources and sync-check relaying on breakers 7047 and 7050. · At the Bowdle Jct Substation, five 41.6 kV line potential sources and sync-check relaying on breakers 500, 510, 5049, 5050 and 6470. Int:

SD GIP In Suspension 12/31/2012 12/31/2012 Planned 115 1 B Y

B West MDU 1153 G311, 37699-01 Net: The Transmission Owner shall install a larger 115/34.5kV substation transformer, and relaying associated with the new transformer. Add 34.5kV PTs, 34.5kV station service transformer, SCADA RTU, 115kV CVTs and 115kV line relaying at Gascoyne. Add sync-check relaying on breaker 2132 at the Hettinger Jct Substation. Int: Generator shall cause to be constructed the following interconnection facilities at Transmission Owner's Gascoyne Jct Substation: 2-circuit breaker disconnect switches, 1- “intertie circuit breaker” and associated 34.5kV line and intertie protective relaying, meters, 34.5kV potential and current transformers, arresters, the associated high voltage bus work, grounding, foundations, conduit and control wiring.

ND GIP In Suspension 9/1/2012 9/1/2012 Planned 115 1 B Y

B West MDU 3083 Dickinson 115 kV Loop Complete 115 kV loop & new 115/41.6 subsation in Dickinson area

ND TBD $11,150,000 10/1/2014 10/1/2014 Planned 115 41.6 B Y

B West MEC 2937 Sub 39 Add 2nd 345-161 kV Xfmr Add a second 345-161 kV xfmr. Expand 345 kV and 161 kV buses.

IL BaseRel Shared $14,500,000 6/1/2014 6/1/2014 Proposed 345 161 B Y

B West MEC 2938 Uprate Sub 39 - Cordova 345 kV Line Change out structures to increase rating. IL BaseRel Shared $400,000 6/1/2014 6/1/2014 Proposed 345 B YB West MEC 2939 Raun-Sioux City 345 kV Line Construct a 23 mile 345 kV line between the Raun and

Sioux City SubstationsIA BaseRel Shared $28,400,000 6/1/2016 6/1/2016 Proposed 345 B Y

B West MP 1292 Raise tower height on ETCO-Forbes 115 kV line

Raise tower height on ETCO-Forbes 115 kV line so the 336 ACSR conductor rating can reach 122/134 MVA

MN BaseRel Not Shared $400,000 12/1/2012 12/1/2012 Planned 115 B Y

B West OTP 549 Jamestown Reactor Addition Jamestown 115 kV 25 MVAR reactor ND BaseRel Not Shared $250,000 12/1/2015 12/1/2015 Proposed 115 B YB West OTP 585 Pelican Rapids 115 kV Line Uprate Pelican Rapids - Pelican Rapids Turkey Plant 115 kV

lineMN Other Not Shared Reliability $858,869 12/31/2013 12/31/2013 Planned 115 B Y

B West OTP 2824 Hensel Capacitor Bank Install Capacitor Bank on 115 kV at Hensel, ND. Two 15 MVAR.

ND Other Not Shared Reliability $750,000 12/31/2014 12/31/2014 Proposed 115 41.6 B Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

B West XEL 2107 G520 Network upgrades: Install new 3-position 115 kV substations (tapping Lake Yankton - Lyon County 115 kV line) with breakers, switches, buswork, steel, foundations, control house and associated equipment. Install new loop in-and-out tap, 3.5 miles of double circuit, 115 kV transmission line.

MN GIP In Suspension $5,930,926 4/2/2009 4/2/2009 Planned 115 34.5 B Y

B West XEL 2115 G491 G491: One new 120 MVA, 118-36.2 kV transformer, three new 115 kV breakers and associated disconnect switches, one new 34.5 kV transformer low side main breaker and associated disconnect switches, control house expansion, structural steel and foundations associated with this new equipment, control and protection equipment associated with these new installations

MN GIP In Suspension $4,363,152 9/1/2010 9/1/2010 Planned 115 B Y

B West XEL 3099 Franklin TR upgrade Upgrade Franklin 115/69 kV Xfrmr 1 and 2 to 70 MVA as part of the CapX underlying system upgrade

MN Other Not Shared Reliability $4,800,000 6/1/2013 6/1/2013 Planned 115 69 B Y

B in MTEP10 Central AmerenIL 2964 Secure Energy Connection Secure Energy - Provide connection to Secure Energy coal gasification plant with 5 PCB 138 kV ring bus substation. Plant would connect in the Decatur area to ADM North-North 27th Street 138 kV Line 1604 between ADM North and Caterpillar Substations.

IL Other Not Shared $5,966,000 6/1/2011 6/1/2011 Proposed 138 1 B Y

B in MTEP10 Central AmerenIL 2978 ESK Capacitor Bank ESK Customer Substation - Install 32 Mvar, 138 kV capacitor bank to improve customer load power factor.

IL BaseRel Not Shared $1,521,000 6/1/2013 6/1/2013 Proposed 138 B Y

B in MTEP10 Central AmerenMO 2970 Apache Flats - Scruggs Delivery Point Apache Flats 161 kV Substation - Install 1-161 kV, 2000 A PCB and necessary metering and relaying to provide a delivery point for Associated Electric's Scruggs 161-69 kV Substation.

MO Other Not Shared $1,035,000 6/1/2012 6/1/2012 Planned 161 B Y

B in MTEP10 Central IPL 3212 Wheatland - Breed 345kV rating upgrade and close Wheatland 345 kV tie breaker

Increase rating to 1386MVA on line Wheatland - Breed 345kV. Close Wheatland 345 kV Tie breaker

IN $12,000,000 1/1/2015 1/1/2015 Proposed 345 B Y

B in MTEP10 East ITC 1856 Belle River - Greenwood - Pontiac 345kV cut into Jewell

Cut the Pontiac section of the Belle River-Greenwood-Pontiac 345kV circuit into and out of Jewell station. Utilize an existing unused side of 345kV tower for one of the circuits into Jewell, and relocate the Jewell-Spokane 230kV circuit

MI BaseRel Shared $5,200,000 12/31/2015 12/31/2015 Proposed 345 B Y

B in MTEP10 East ITC 2932 St Antoine-Essex #2 120 kV Construct 2nd underground cable from St Antoine to Essex (5.1 miles).

MI BaseRel Shared $54,800,000 6/1/2015 6/1/2015 Proposed 120 B Y

B in MTEP10 East METC 3210 Vanderbilt - Riggsville 138 kV Rebuild Rebuild 30.3 miles of 138 kV 266 ACSR to 954 ACSR FDC 230 kV construction.

MI $33,254,000 6/1/2014 6/1/2014 Proposed 138 B Y

B in MTEP10 West MPW 2935 Reconductor 69 kV lines South - Wiggins - Power Plant (Lines 81 & 82)

The 2008 updated schedule changed the schedule for the 69 kV transmission line upgrades. MPW is looking at upgrading the 69 kV transmission lines from 633501 South Sub to 633511 Wiggins Road (Line 82) and from 633511 Wiggins Road to our 633408 Power Plant (Line 81) from 58 MW to at least 89 MW (636 ACSR) by 2014.

IA Other Not Shared Reliability $300,000 6/1/2017 6/1/2017 Proposed 69 B Y

B in MTEP10 West XEL 3121 Lake Marion - Burnsville upgrade Upgrade 13 miles of 115 kV line between Lake Marion and Burnesville to 2-795 ACSR conductor

MN BaseRel Shared $6,200,000 6/1/2016 6/1/2016 Planned 115 B Y

B in MTEP10 West, Central, East

Midwest ISO 3200 RGOS 765 kV Strategy. In AMIL,AMMO,MEC,XEL,OTP,ALTE,GRE,WEC,MDU,MGE,ALTW,DPC,DEM,IPL,ITCT,SIGE,FE,WPS,Non-MISO

Build transmission throughout the Midwest ISO system that helps the facilitation of the collection and delivery of renewable energy to meet the current mandate needs. This strategy focuses on the introduction of 765 kV transmission throughout the Midwest ISO footprint. Further development and identification of timing needs will be dependent on further regional analysis and candidate MVP evaluation.

IA WI MVP $12,581,351,094 1/1/2025 1/1/2025 Conceptual 765 115 B Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility


Midwest ISO 3202 RGOS Native Voltage Strategy. In AMIL,AMMO,MEC,XEL,OTP,ALTE,GRE,WEC,MDU,MGE,ALTW,DPC,DEM,IPL,ITCT,SIGE,FE,WPS

Build transmission throughout the Midwest ISO system that helps the facilitation of the collection and delivery of renewable energy to meet the current mandate needs. This strategy focuses on the development of transmission voltages that are already native to the areas. Further development and identification of timing needs will be dependent on further regional analysis and candidate MVP evaluation.

IA WI MVP $10,423,998,000 1/1/2025 1/1/2025 Conceptual 765 115 B Y

B in MTEP11 Central AmerenIL 2967 Grand Tower Capacitor Bank Grand Tower Plant - Install 2-stage 80 Mvar (2 x 40 Mvar) 138 kV capacitor bank. 2-138 kV PCB's needed.

IL BaseRel Not Shared $2,715,000 6/1/2013 6/1/2013 Proposed 138 B Y

B in MTEP11 Central AmerenIL 2977 LaSalle Substation Relocation LaSalle 138-34.5 kV Substation - Relocate Substation to avoid flooding and to permit remediation of manufactured gas plant site.

IL Other Not Shared $1,347,000 6/1/2013 6/1/2013 Proposed 138 B Y

B in MTEP11 Central AmerenIL 2982 Washington Street-S. Bloomington Line 1326 - Upgrade Terminal Equipment

Washington Street-S. Bloomington 138 kV Line 1326 - Replace terminal equipment (wavetrap, 3-CT's and bus conductor) at S. Bloomington with equipment capable of carrying minimum 2000 A under summer emergency conditions.

IL BaseRel Not Shared $137,000 12/1/2013 12/1/2013 Proposed 138 B Y

B in MTEP11 Central AmerenIL 3009 Newton-Hutsonville-Merom 345 kV Line Newton-Hutsonville 345 kV line – New 40 mi. 3000 A summer emergency capability line. Hutsonville-Merom 345 kV line - New 12 mi. 3000 A summer emergency capability line. 345/138 kV 560 MVA transformer @ Hutsonville

IL $110,000,000 6/1/2018 6/1/2018 Proposed 345 138 B Y

B in MTEP11 Central AmerenIL 3010 Baldwin-Grand Tower-N.W. Cape 345 kV Line

New 69 mile, single-circuit line (possible double circuit), 3000 A SE capability (Baldwin-Grand Tower - 45 miles; Grand Tower-N.W. Cape - 24 miles). Grand Tower 345/138 kV Substation - 1-560 MVA transformer, 345 kV Ring bus

IL $151,000,000 12/1/2025 12/1/2025 Proposed 345 138 B Y

B in MTEP11 Central AmerenMO 2971 Rolla Alftermann Substation Rolla Alfermann Substation - Tap Clark-Osage-2 and Rivermines-Maries-1 138 kV lines to establish 138 kVsupplies to new 138-34.5 kV Alfermann Substation, owned by City of Rolla. Ameren to construct tapping structures. 2-138 kV, 1200 A disconnect switches

MO Other Not Shared $963,000 6/1/2012 6/1/2012 Planned 138 B Y

B in MTEP11 Central AmerenMO 2973 Howard Bend Substation Connection Howard Bend 138-12 kV Substation - Provide 138 kV ring bus connection from Mason-Carrollton-8 138 kV line to new Howard Bend Substation. Install 1-138 kV, 2000 A PCB at Carrollton Substation as a bus-tie.

MO Other Not Shared $1,371,000 12/1/2016 12/1/2016 Proposed 138 B Y

B in MTEP11 Central AmerenMO 2979 Enon 345 kV Breaker Addition Enon 345/161 kV Substation - Install 2-345 kV PCB's on incoming 345 kV lines.

MO BaseRel Not Shared $1,876,000 6/1/2013 6/1/2013 Proposed 345 B Y

B in MTEP11 Central AmerenMO 2988 Warrenton-Lincoln Bulk 161 kV Line Warrenton-Lincoln Bulk Substation 161 kV - Establish a second 161 kV supply to Lincoln Bulk Substation from Warrenton Substation. 10 miles of new 161 kV line, 2-161 kV, 2000 A PCBs at Warrenton Substation.

MO BaseRel Shared $12,000,000 6/1/2016 6/1/2016 Proposed 161 B Y

B in MTEP11 East ITC 3282 Southfield - Sunset 120 kV Rebuild Rebuild 6.4 mile 120 kV Line Mi BaseRel Shared $7,100,000 12/31/2013 12/31/2013 Planned 120 C>B YB in MTEP11 East METC 1803 Plum-Stover 138 kV Rebuild Rebuild the 8.8 mile 138 kV line to 954 ACSR (Pre-build

to 230 kV construction).MI BaseRel Shared $10,900,000 12/31/2013 12/31/2013 Planned 138 C>B Y

B in MTEP11 East METC 1815 Chase - Mecosta 138kV Rebuild Rebuild 7.2 miles of 138kV 110 and 115 CU to 954 ACSR. Prebuild to 230kV construction.

MI BaseRel Shared $8,900,000 12/31/2014 12/31/2014 Planned 138 C>B Y

B in MTEP11 West ATC LLC 2799 Kinross Load Interconnection Construct a 3 mile line to connect the Kinross load MI $3,882,248 7/1/2013 7/1/2013 Conceptual 69 C>B YB in MTEP11 West ATC LLC 3119 Uprate 6923 Pine River-9mile 69kV Increase ground clearance for 6923 Pine River-9Mile

69kV line to 167 deg f clearanceMI $2,000,000 6/1/2016 6/1/2016 Proposed 69 C>B Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

B in MTEP11 West ATC LLC 3209 Replace Edgewater 138/69kV Trs Replace the Edgewater 138-69 kV Trs with 60 MVA unitsReplace the 4/0 Cu strain bus sections 1 & 2 with conductor capable of 75 MVA SERemove 69 kV by-pass switches 1666A, 359A, 460A, and 368A Replace the following 69 kV disconnect switches with new GOAB switches 359L, 359B, 368L and 368BAdd line side surge arresters to 69 kV lines Y-31, Y-55, and Y-142Upgrade and/or replace relaying and protection systemsInstall new GCBs to the low side (69KV) positions of T31 and T32. Replace T31 and T32 transformer 69 kV disconnect switches 315A and 337A.

WI $5,409,471 10/25/2013 10/25/2013 Proposed 138 69 C>B Y

B in MTEP11 West ATC LLC 3490 Rebuild Y-20 Doylestown-Rio Pumping Station

Asset Management project to Rebuild Y-20 Doylestown to Rio Pumping Station

WI $7,400,000 4/15/2013 4/15/2013 Planned 69 C>B Y

B in MTEP11 West ATC LLC 3514 96th St Breaker and a half bus reconfiguration

Create 96ST 6-rung breaker and a half for zoo interchange relocation project

WI $28,000,000 9/1/2013 9/1/2013 Proposed 138 C>B Y

B in MTEP11 West ATC LLC 3519 RiverBend T-D Load interconnection Construct a 138 kV loop through River Bend distribution Substation on line 731.

WI Other Not Shared Distribution $3,016,359 12/31/2012 12/31/2012 Proposed 138 24.9 C>B Y

B in MTEP11 West MEC 3214 Sub 17 and Sub 39 Replace Relays 161-17-39-1

Replace relaying and remove wave trap IL Other Not Shared Condition $225,000 12/1/2015 12/1/2015 Proposed 161 C>B Y

B in MTEP11 West MEC 3215 Sub 49 161 kV Capacitor Add 50 MVAr 161 kV capacitor IL BaseRel Not Shared $840,000 6/1/2014 6/1/2014 Proposed 161 C>B YB in MTEP11 West MEC 3216 Plymouth-Sioux City 161 kV Line Construct a 2 mile 161 kV line between the Plymouth

and Sioux City Substations and associated substation equipment additions.

IA BaseRel Not Shared $2,400,000 6/1/2014 6/1/2014 Planned 161 C>B Y

B in MTEP11 West MEC 3266 Sub 56-89 161 Line Uprate Increase 161 kV line rating. IA BaseRel TBD $680,000 6/1/2016 6/1/2016 Proposed 161 C>B YB in MTEP11 West OTP 3431 Hankinson 230/41.6 kV Transformer

AdditionAdd a second 230/41.6 kV transformer at Hankinson Substation which will include the addition of 2 new 230 kV breakers.

ND $835,000 10/1/2012 10/1/2012 Planned 230 41.6 C>B Y

B in MTEP11 West OTP 3462 Project G-968 100 MW Wind Farm near Viking MN

Add 3 breaker 115 kV ring bus MN $2,800,000 10/30/2012 10/30/2012 Proposed 115 115 C>B Y

B in MTEP11 West OTP 3464 Project G-873 20 MW Wind Farm on Donaldson 41.6 kV Line

Add 3 Way Switch on 41.6 kV line between Donaldson 115 kV substation to Donaldson distribution sub.

MN GIP Not Shared $160,000 12/1/2012 12/1/2012 Proposed 41.6 B Y

B in MTEP11 West OTP 3465 Project G-875 80 MW Wind Farm at Donaldson 115/41.6 kV Substation

Add 3 new 115 kV Breakers & expand substation to accommodate wind farm.

MN GIP Not Shared $1,500,000 12/31/2012 12/31/2012 Proposed 115 41.6 B Y


AmerenMO, AMIL, MEC, XEL

3201 RGOS Identified DC transmission Build transmission throughout the Midwest ISO system that helps the facilitation of the collection and delivery of renewable energy to meet the current mandate needs. This strategy focuses on the introduction of HVDC transmission throughout the Midwest ISO footprint. Further development and identification of timing needs will be dependent on further regional analysis and candidate MVP evaluation.

IA SD MVP $5,401,519,474 1/1/2025 1/1/2025 Conceptual 800 B Y












MTEP11 MISO Transmission Expansion Plan 2011 Appendix BAppendix B: Project Facility Table 9/7/2011




Max kV


Miles Upg.


Cost Shared

Postage Stamp


B Central AmerenIL 1234 1933 6/1/2014 Havana, South Mason City, West 1 138 160 Increase ground clearance on 18.4 miles IL 18.4 Proposed $642,300 Y BB Central AmerenIL 1533 2610 12/1/2013 Washington Street S. Bloomington 1 138 255 Replace terminal equipment at S.

BloomingtonIL Proposed $137,000 Y B

B Central AmerenIL 1537 2614 6/1/2013 Mt. Vernon, West S. Centralia 1 138 146 Replace terminal equipment at S. Centralia IL Proposed $200,000 Y BB Central AmerenIL 2114 2839 9/30/2009 Mahomet Substation Brokaw Substation 1 138 Tapping structures installed inline with line

#1376: 138 XX Line Extension 477 MCM 30/7 ACSR, 138 YY Line Extension 477 MCM 30/7 ACSR

IL Planned $237,000 Y Y B

B Central AmerenIL 2114 2838 12/1/2013 Project IP03 Substation substation 1 138 New (IP03) 138 kV Straight Bus Interconnection Substation, tap existing line #1376 Mahomet Substation to Brokaw Station.

IL Planned $1,845,000 Y Y B

B Central AmerenIL 2117 2846 6/1/2014 El Paso CE Minok 1 138 Tapping structures installed inline with line #1382: 138 kV XX Line Extension 556.5 MCM 26/7 ACSS conductor and 7#8 Alumoweld shield wire, 138 kV YY Line Extension 556.5 MCM 26/7 ACSS conductor and 7#8 Alumoweld shield wire

IL Planned $230,000 Y Y B

B Central AmerenIL 2117 2845 6/1/2014 Project IP08 Substation substation 1 138 New 138 kV Straight Bus Interconnection Substation, located north of the tap point to the Transmission Owner’s El Paso substation and south of the tap point to the Transmission Owner’s CE Minok substation on line #1382.

IL Planned $1,661,464 Y Y B

B Central AmerenIL 2118 2848 6/1/2014 Oglesby Substation IP08 Substation 1 138 Line #1382 & #1384: Reconductor 477 MCM 30/7 ASCR with three phase 556.5 MCM 26/7 ACSS conductor.

IL 33.3 Planned Y Y B

B Central AmerenIL 2280 4196 6/1/2013 LaSalle Oglesby Main 1 138 256 Reconductor 477 kcmil ACSR and 336 kcmil ACSR to 1200 A summer emerg.

IL 2.16 Planned $900,000 Y B

B Central AmerenMO 2774 4868 11/1/2020 Adair Wind Farm 1 161 Connect Wind Farm to Adair Sub MO Proposed Y Y BB Central DEM 1521 2597 6/1/2016 Bloomington 230

(terminal equipment)Bloomington NW 138 191 Replace the 600A 13836 bkr disconnect

switches with 2000A switches. New limit 800A Wave Trap.

IN Planned $233,455 Y B

B Central DEM 3381 6254 12/31/2013 Meldahl Dam Gen. Meldahl Dam Gen. 345kV I-connect Sub

1 345 138 Install interconnection substation for Meldahl Dam generator. Install 3-breaker 345kV ring bus, 345-138kV - 120 MVA transformer, loop Feeder 4545 through new substation. Connect independent generator per MISO requirements.

OH Planned $8,949,798 Y B

B Central DEM, IPL 1558 3109 5/1/2013 Petersburg Francisco 1 345 1195 MVA Upgrade to fix 1st contingency for the Wheatland breaker close

IN Proposed $6,420,000 Y B

B Central DEM, IPL 1558 3110 5/1/2013 Petersburg Thompson 1 345 1195 MVA Upgrade to fix 1st contingency for the Wheatland breaker close

IN Proposed $5,015,000 Y B

B Central IPL 1557 3107 1/1/2014 Pritchard Franklin Twp 1 345 956 New IN 24 Proposed $24,000,000 Y BB Central IPL 1557 3108 1/1/2014 Franklin Twp Hanna 1 345 1386 New IN 2.75 Proposed $2,750,000 Y BB Central IPL 1557 3106 1/1/2014 Bloomington Pritchard 1 345 1386 New IN 15 Proposed $15,000,000 Y BB East ITC 1850 3732 12/31/2013 Hancock Wixom 1 230 New Line resulting from Quaker-Wixom cut

into HancockMI Proposed Y B

B East ITC 1850 3733 12/31/2013 Hancock Quaker 1 230 New Line resulting from Quaker-Wixom cut into Hancock

MI Proposed Y B

B East ITC 1850 3734 12/31/2013 Hancock 230/120 kV Transformer 1 230 120 New Transformer MI Proposed $9,000,000 Y BB East METC 2809 336 6/1/2014 Garfiled Hemphill 1 138 Reconductor MI 9.1 Proposed $11,360,000 Y BB East METC 2809 4453 6/1/2014 Hemphill 138 Relay replacement MI Proposed $380,000 Y BB East METC 2822 5408 12/1/2016 Edenville J. Warren 1 138 Reconductor the Edenville-Warren 138kV

line to 954 ACSRMI 14.8 Proposed $7,000,000 Y B

B East NIPS 3154 5535 12/1/2012 Sheffield Reactor 138 Add 0.795 Ohm reactor on BP Whiting to Sheffield circuit

IN Proposed $807,141 Y B






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B West ATC LLC 544 898 6/1/2015 Bluemound Capacitor bank 138 225 Mvar Add 3x75 Cap Banks to 2 Bluemound buses WI Conceptual $3,463,000 Y BB West ATC LLC 1269 1988 6/1/2020 Arcadian 345-138kV transformer 1 345 138 500 replace Arcadian 345/138kV transformer #2

& #3WI Conceptual $3,500,000 Y B

B West ATC LLC 1270 1990 6/1/2016 Arcadian Waukesha 1 138 504 Rebuild Ck 1 of Arcadian to Waukesha 138 kV Line

WI 4.06 Proposed $7,293,448 Y B

B West ATC LLC 1270 1989 6/1/2016 Arcadian Waukesha 2 138 504 Rebuild Ck 2 of Arcadian to Waukesha 138 kV Line

WI 3.88 Proposed $7,293,448 Y B

B West ATC LLC 1284 2110 6/1/2050 Albers Tie 1 138 tie 138kv buses at Albers WI Conceptual Y BB West ATC LLC 1284 2113 6/1/2050 Albers Somers 1 138 347 MVA albers-somers w/477-t2 WI 3.3 Conceptual Y BB West ATC LLC 1284 2112 6/1/2050 Racine Somers 1 138 347 MVA somers-racine w/477-t2 WI 4.3 Conceptual Y BB West ATC LLC 1624 3241 6/1/2022 Portage Trienda 2 138 277 uprate X-67 WI 3.4 Conceptual Y BB West ATC LLC 1687 3463 6/1/2017 Metomen Transformer 1 138 69 100 MVA Replace the 138/69 kV transformer at

Metomen substation to increase ratingWI Planned $4,700,000 Y B

B West ATC LLC 1946 3825 6/1/2018 Spring Green transformer 2 138 69 100 MVA Install a 2nd Spring Green 138-69 kV Transformer

WI Conceptual $1,400,000 Y B

B West ATC LLC 2044 3926 6/1/2017 A13(Quincy) McKenna 1 69 49 MVA Increase line clearance to 200 deg F SN/SE WI 7.6 Conceptual $978,011 Y BB West ATC LLC 2044 3925 6/1/2017 Castle Rock A13(Quincy) 1 69 49 MVA Increase line clearance to 200 deg F SN/SE WI 0.9 Conceptual $115,817 Y BB West ATC LLC 2454 4412 5/1/2012 Melissa Tayco 1 138 160 MVA Uprate terminal equip to achieve a 199 MVA

SE ratingWI 0.3 Planned $12,260 Y B

B West ATC LLC 2454 4411 5/1/2012 Meadows Melissa 1 138 169 MVA Increase line clearance to achieve a 198 MVA SE rating

WI 1.1 Planned $44,960 Y B

B West ATC LLC 2454 4410 5/1/2012 Kaukauna Central Tap Meadows 1 138 169 MVA Increase line clearance to achieve a 198 MVA SE rating

WI 7.8 Planned $318,800 Y B

B West ATC LLC 2454 4406 5/1/2012 STNYBRK Wind generator W 0.6 98.7 MW G590 Stony Brook Wind Farm WI Planned Y BB West ATC LLC 2454 4405 5/1/2012 STNYBRK Wind substation 1 138 G-T Interconnection From Techumseh Rd

138 kV busWI Planned $1,234,700 Y B

B West ATC LLC 3089 5398 1/31/2013 Fitchburg Syene 1 69 83 MVA Uprate Fitchburg-Syene-Nine Springs 69kV line to 275 deg F SE clearance

WI 3.7 Proposed $4,400,000 Y B

B West ATC LLC 3089 5404 1/31/2013 Nine Springs substation 1 69 32.66 MVAR Install 2-16.33Mvar cap banks at Nine Springs 69kV

WI Proposed Y B

B West ATC LLC 3089 5403 1/31/2013 Royster AGA TP 1 69 95 MVA Move AGA load onto Femrite-Royster line creating Femrite-AGA TP-Royster 69kV

WI 2 Proposed Y B

B West ATC LLC 3089 5402 1/31/2013 Femrite AGA TP 1 69 95 MVA Move AGA load onto Femrite-Royster line creating Femrite-AGA TP-Royster 69kV

WI 1.8 Proposed Y B

B West ATC LLC 3089 5401 1/31/2013 AGA TP Pflaum 1 69 82 MVA Uprate Royster-AGA TP-Pflaum 69kV line to 275 deg F SE clearance

WI 0.1 Proposed Y B

B West ATC LLC 3089 5400 1/31/2013 Royster AGA Tap 1 69 83 MVA Uprate Royster-AGA TP-Pflaum 69kV line to 275 deg F SE clearance

WI 1.9 Proposed Y B

B West ATC LLC 3089 5399 1/31/2013 Syene Nine Springs 1 69 82 MVA Uprate Fitchburg-Syene-Nine Springs 69kV line to 275 deg F SE clearance

WI 2.9 Proposed Y B

B West ATC LLC 3118 5468 6/1/2016 South Lake Geneva North Lake Geneva 1 138 293 MVA construct a new 138kV line from North Lake Geneva to South Lake Geneva

WI 5 Proposed $14,428,632 Y B

B West ATC LLC 3118 1251 6/1/2016 South Lake Geneva 138-69 kV

transformer 1 138 69 100 MVA Install new South Lake Geneva 138-69kV Transformer

WI Proposed $1,973,000 Y B

B West GRE 2098 2993 4/1/2013 RDF Daytonport 1 69 78 MVA Upgrade of RDF - Daytonport to at least 78 MVA

MN 3.7 Proposed $1,377,324 Y B

B West GRE 2098 2804 4/1/2013 Elk River #14 substation Bunker Lake Distribution 1 230 271 Upgrade of Elk River #14 substation - Bunker Lake Distribution 230 kV to at least 271 MVA.

MN 14.3 Proposed $4,894,756 Y B

B West ITCM 1147 5386 12/31/2011 Triboji Upgrades 161 Upgrade Triboji to 4 breaker ring bus IA Planned $2,300,000 Y BB West ITCM 1147 5387 12/31/2011 Cayler Switch Station 161 New switch station (paid for by customer)

tapping the Dickinson Co-Wisdom 161kV lineIA Planned $0 Y B

B West ITCM 1741 4027 12/31/2012 Communication System Upgrades

161 MN Planned $400,000 Y Y B

B West ITCM 1741 4026 12/31/2012 Heron Lake Substation 161 MN Planned $4,195,530 Y Y BB West ITCM 1741 4025 12/31/2012 Cottonwood County

substation161 MN Planned $4,833,216 Y Y B






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B West ITCM 1741 4028 12/31/2012 South Storden Cottonwood County 1 161 MN Planned $4,092,575 Y Y BB West ITCM 1741 3292 12/31/2012 Heron Lake South Storden 1 161 440 Rebuild line to higher capacity MN Planned $6,818,660 Y Y BB West ITCM 1741 2235 12/31/2012 Storden (Cottonwood

County)Dotson 1 161 446 New line MN 26 Planned $16,379,839 Y Y B

B West MDU 1148 1798 12/31/2012 Java (Glenham) generator 115 1 39 new generator SD Planned Y BB West MDU 1153 1803 9/1/2012 Crownbutte Wind

(Gascoyne)generator and associated network upgrades

115 1 19 new generator ND Planned Y B

B West MDU 3083 5365 10/1/2014 North Dickinson 2 PCB 115 Complete North Dickinson bus ND Planned $1,200,000 Y BB West MDU 3083 5366 10/1/2014 West Dickinson 115/41.6 kV transformer 1 115 41.6 60 New transformer & substation ND Planned $7,400,000 Y BB West MDU 3083 5367 10/1/2014 Dickinson Basin 1 PCB 115 Add terminal for new loop line ND Planned $550,000 Y BB West MDU 3083 5364 10/1/2014 North Dickinson Dickinson West 1 115 120 New line Segment ND 3 Planned $750,000 Y BB West MDU 3083 5363 10/1/2014 Dickinson Basin Dickinson West 1 115 120 New line Segment ND 5 Planned $1,250,000 Y BB West MEC 2937 5112 6/1/2014 Sub 39 Transformer 2 345 161 560 Add 2nd 345-161 kV xfmr IL Proposed $14,500,000 Y BB West MEC 2938 5113 6/1/2014 Sub 39 Cordova 1 345 1471 Uprate 345 kV line structures IL 15.5 Proposed $400,000 Y BB West MEC 2939 5115 6/1/2016 Raun 345 Terminal at the MEC Raun Substation IA Proposed $1,300,000 Y BB West MEC 2939 5116 6/1/2016 WAPA Sioux City 345 Terminal at the WAPA Sioux City Substation IA Proposed $1,300,000 Y BB West MEC 2939 5114 6/1/2016 Raun WAPA Sioux City 1 345 New 345 kV line between Raun and WAPA

Sioux CityIA 23 Proposed $25,800,000 Y B

B West MP 1292 2123 12/1/2012 ETCO Forbes 1 115 122/134 Increase ground clearance MN Planned $400,000 Y BB West OTP 549 1530 12/1/2015 Jamestown Reactor 115 25 Mvar Add a 1 x 25 MVAr reactor at OTP

Jamestown substationND Proposed $250,000 Y B

B West OTP 585 589 12/31/2013 Pelican Rapids Pelican Rapids Turkey Plant

1 115 85 Convert an existing 41.6 kV line to 115 kV MN 2.5 Planned $858,869 Y B

B West OTP 2824 4962 12/31/2014 Hensel 115 kV Hensel 69/41.6 kV 115 41.6 2 x 15 MVAR Install New Capacitor Bank on Hensel 115 kV line for Voltage Support During Contingencies

ND Proposed $750,000 Y B

B West XEL 2107 2820 4/2/2009 G520 Substation new substation 1 115 34.5 Install new 3-position 115 kV substation with breakers, switches, buswork, steel, foundations, control house and associated equipment. Install new loop in-and-out tap, 3.5 miles of double circuit, 115 kV transmission line.

MN 3.5 Planned $5,930,926 Y Y B

B West XEL 2115 2841 9/1/2010 Chanarambie Lake Yankton 1 115 Three spans of the existing 115 kV transmission line between Chanarambie and Lake Yankton will be relocated immediately outside of the Chanarambie substation to accommodate the expansion of the substation for G491.

MN Planned $58,152 Y Y B

B West XEL 2115 2840 9/1/2010 Chanarambie Substation substation upgrades 1 115 G491: three new 115 kV breakers and disconnect switches, control house expansion, structural steel and foundations associated with this new equipment, control and protection equipment associated with these new installations

MN Planned $4,305,000 Y Y B

B West XEL 3099 5429 6/1/2013 Franklin Transformer 1 115 69 70 upgrade to70 MVA MN Planned $2,400,000 N Y BB West XEL 3099 5430 6/1/2013 Franklin Transformer 2 115 69 70 upgrade to70 MVA MN Planned $2,400,000 N Y BB in MTEP10 Central AmerenIL 2964 5163 6/1/2011 ADM North-North 27th

StreetConnection to Secure Energy

1 138 1 478 Secure Energy - Provide connection to Secure Energy coal gasification plant with 5 PCB 138 kV ring bus substation. Plant would connect in the Decatur area to ADM North-North 27th Street 138 kV Line 1604 between ADM North and Caterpillar Substations.

IL Proposed $5,966,000 Y B

B in MTEP10 Central AmerenIL 2978 5181 6/1/2013 ESK Customer Sub 32 Mvar, 138 kV Capacitor Bank

1 138 32 ESK Customer Substation - Install 32 Mvar, 138 kV capacitor bank to improve customer load power factor.







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B in MTEP10 Central AmerenIL 3200 5760 1/1/2025 Rising upgrade existing substation

345 138 Add 1 new 345 bay(s) at Existing station. Add 1 new 138 bay(s) at Existing station. Add 1 new 345/138 autotransformer(s).

IL Conceptual $16,100,000 Y B

B in MTEP10 Central AmerenIL 3200 5750 1/1/2025 MO-A Station new substation 345 Add 2 new 345 bay(s) at New station. MO Conceptual $11,800,000 Y BB in MTEP10 Central AmerenIL 3200 5711 1/1/2025 Goose Creek Rising 1 345 1195 Equipment upgrade to increase line rating IL 18 Conceptual $27,000,000 Y BB in MTEP10 Central AmerenIL 3202 5902 1/1/2025 IL-K Station new substation 1 345 Add 2 new 345 bay(s) at New station. IL Conceptual $11,800,000 Y BB in MTEP10 Central AmerenIL 3202 5935 1/1/2025 Rising upgrade existing

substation1 345 138 Add 1 new 345 bay(s) at Existing station.

Add 1 new 138 bay(s) at Existing station. Add 1 new 345/138 autotransformer(s).


B in MTEP10 Central AmerenIL 3202 5925 1/1/2025 Newton new substation 1 345 Add 2 new 345 bay(s) at New station. IL Conceptual $11,800,000 Y BB in MTEP10 Central AmerenIL 3202 5908 1/1/2025 Meredosia new substation 1 345 138 Add 4 new 345 bay(s) at New station. Add 2

new 138 bay(s) at New station. Add 2 new 345/138 autotransformer(s).


B in MTEP10 Central AmerenIL 3202 5882 1/1/2025 Fargo upgrade existing substation

1 345 Add 1 new 345 bay(s) at Existing station. IL Conceptual $5,900,000 Y B

B in MTEP10 Central AmerenIL 3202 5852 1/1/2025 Goose Creek Rising 1 345 1195 Equipment upgrade to increase line rating IL 18 Conceptual $27,000,000 Y BB in MTEP10 Central AmerenMO 2970 5169 6/1/2012 Apache Flats AECI Scruggs Delivery

Pt.1 161 558 Apache Flats 161 kV Substation - Install 1-

161 kV, 2000 A PCB and necessary metering and relaying to provide a delivery point for Associated Electric's Scruggs 161-69 kV Substation.

MO Planned $1,035,000 Y B

B in MTEP10 Central AmerenMO 3200 5726 1/1/2025 Fairport new substation 765 345 Add 3 new 765 bay(s) at New station. Add 3 new 345 bay(s) at new station. Add 1 new 765/345 autotransformer(s).

MO Conceptual $102,000,000 Y B

B in MTEP10 Central AmerenMO 3200 4040 1/1/2025 Montgomery St. Francois 1 765 3975 MO 103.9 Conceptual $332,462,592 Y BB in MTEP10 Central AmerenMO 3200 4062 1/1/2025 St. Francois upgrade existing

substation765 345 Add 3 new 765 bay(s) at New station. Add 1

new 345 bay(s) at Existing station. Add 1 new 765/345 autotransformer(s).


B in MTEP10 Central AmerenMO 3200 4063 1/1/2025 Montgomery upgrade existing substation

765 345 Add 3 new 765 bay(s) at New station. Add 1 new 345 bay(s) at Existing station. Add 1 new 765/345 autotransformer(s).


B in MTEP10 Central AmerenMO 3202 5945 1/1/2025 Thomas Hill upgrade existing substation

1 345 161 Add 1 new 345 bay(s) at Existing station. Add 1 new 161 bay(s) at Existing station. Add 1 new 345/161 autotransformer(s).


B in MTEP10 Central AmerenMO 3202 5933 1/1/2025 Palmyra new substation 1 345 161 Add 2 new 345 bay(s) at New station. Add 1 new 161 bay(s) at Existing station. Add 1 new 345/161 autotransformer(s).


B in MTEP10 Central AmerenMO 3202 5931 1/1/2025 Overton upgrade existing substation



B in MTEP10 Central AmerenMO 3202 5916 1/1/2025 MO-A Station new substation 1 345 Add 2 new 345 bay(s) at New station. MO Conceptual $11,800,000 Y BB in MTEP10 Central AmerenMO 3202 5881 1/1/2025 Fairport new substation 1 345 Add 3 new 345 bay(s) at New station. MO Conceptual $23,600,000 Y BB in MTEP10 Central AmerenMO 3202 5862 1/1/2025 Adair new substation 1 345 Add 1 new 345 bay(s) at New station. MO Conceptual $5,900,000 Y BB in MTEP10 Central ATC LLC 3200 5718 1/1/2025 Bain upgrade existing

substation345 Add 1 new 345 bay(s) at Existing station. WI Conceptual $5,900,000 Y B

B in MTEP10 Central ATC LLC 3200 5729 1/1/2025 Granville upgrade existing substation


IN Conceptual $16,100,000 Y B

B in MTEP10 Central DEM 3200 5707 1/1/2025 Kokomo Tipton 1 230 497 Equipment upgrade to increase line rating IN 16.8 Conceptual $12,600,000 Y BB in MTEP10 Central DEM 3200 5706 1/1/2025 Kokomo New London 1 230 497 Equipment upgrade to increase line rating IN 8.28 Conceptual $6,210,000 Y BB in MTEP10 Central DEM 3202 5782 1/1/2025 Noblesville Nucor 1 345 1510 IN 55.56 Conceptual $111,120,000 Y BB in MTEP10 Central DEM, IPL 3200 5708 1/1/2025 Whitestown Guion 1 345 1195 Equipment upgrade to increase line rating IN 13.44 Conceptual $26,880,000 Y BB in MTEP10 Central HE 3202 5909 1/1/2025 Merom new substation 1 345 Add 3 new 345 bay(s) at New station. IN Conceptual $23,600,000 Y BB in MTEP10 Central HE, AmerenIL 3202 5781 1/1/2025 Merom Newton 1 345 1510 IL/IN 50.28 Conceptual $77,460,000 Y BB in MTEP10 Central HE, DEM 3202 5780 1/1/2025 Merom Gwynn 2 345 1510 2nd circuit of double circuit IN 127.4 Conceptual $254,880,000 Y B






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B in MTEP10 Central IPL 3200 5763 1/1/2025 Stout upgrade existing substation



B in MTEP10 Central IPL 3200 5732 1/1/2025 Guion upgrade existing substation



B in MTEP10 Central IPL 3200 5709 1/1/2025 Petersburg Thompson 1 345 1195 Equipment upgrade to increase line rating IN 115.68 Conceptual $231,360,000 Y BB in MTEP10 Central IPL 3212 5980 1/1/2015 Wheatland Breed 1 345 1386 MVA rating upgrade and close Wheatland 345 tie

CBIN Proposed $12,000,000 Y B

B in MTEP10 Central LGEE 3202 5851 1/1/2025 Daviess 7HARDIN 345.00 1 345 945 Equipment upgrade to increase line rating IN 79.2 Conceptual $158,400,000 Y BB in MTEP10 Central MIPU, AmerenMO 3200 5660 1/1/2025 Fairport Montgomery 1 765 3975 MO 205.3 Conceptual $656,935,680 Y BB in MTEP10 Central SIGE 3200 5716 1/1/2025 AB Brown upgrade existing

substation345 138 Add 1 new 345 bay(s) at Existing station.



B in MTEP10 Central SIGE 3202 5861 1/1/2025 AB Brown upgrade existing substation



B in MTEP10 Central/NAmerenIL, Non-MI 3200 5662 1/1/2025 Fairport MO-A Station 2 345 1510 2nd circuit of double circuit MO 50.93 Conceptual $117,144,060 Y BB in MTEP10 Central/NAmerenIL, Non-MI 3200 5659 1/1/2025 Meadow Lake IN-E Station 1 345 1510 IN 25.31 Conceptual $50,621,760 Y BB in MTEP10 Central/NAmerenMo Non-M 3202 5783 1/1/2025 Fairport Adair 1 345 1510 MO 111.2 Conceptual $100,116,000 Y BB in MTEP10 Central/NCE, AmerenIL 3200 5685 1/1/2025 IL-F Station IN-E Station 1 345 1510 IL/IN 55.7 Conceptual $86,171,688 Y BB in MTEP10 Central/NNon-MISO 3202 5778 1/1/2025 Greentown Blue Creek 1 765 3975 IN/OH 72.36 Conceptual $202,608,000 Y BB in MTEP10 Central/NNon-MISO 3202 5784 1/1/2025 Fairport MO-A Station 2 345 1510 2nd circuit of double circuit MO 50.88 Conceptual $117,024,000 Y BB in MTEP10 DEM DEM 3202 5888 1/1/2025 Greentown upgrade existing

substation1 765 Add 1 new 765 bay(s) at Existing station. IN Conceptual $12,550,000 Y B

B in MTEP10 East ITC 1856 3744 12/31/2015 Jewell Belle River - Greenwood Jct

1 345 Cut Pontiac-Greenwood-Belle River into Jewell creating Pontiac-Jewell and Jewell-Belle River-Greenwwod

MI Proposed $2,600,000 Y B

B in MTEP10 East ITC 1856 3743 12/31/2015 Jewell Pontiac 1 345 Cut Pontiac-Greenwood-Belle River into Jewell creating Pontiac-Jewell and Jewell-Belle River-Greenwwod

MI Proposed $2,600,000 Y B

B in MTEP10 East ITC 2932 5104 6/1/2015 St Antoine Essex 1 120 Construct 2nd underground cable from St Antoine to Essex (5.1 miles).

MI 5.1 Proposed $54,800,000 Y B

B in MTEP10 East ITCT 3200 5745 1/1/2025 MI-D Station new substation 345 Add 2 new 345 bay(s) at New station. MI Conceptual $11,800,000 Y BB in MTEP10 East ITCT 3200 5752 1/1/2025 Murphy new substation 345 Add 4 new 345 bay(s) at New station. MI Conceptual $23,600,000 Y BB in MTEP10 East ITCT 3200 5746 1/1/2025 MI-E Station new substation 345 Add 2 new 345 bay(s) at New station. MI Conceptual $11,800,000 Y BB in MTEP10 East ITCT 3200 5744 1/1/2025 MI-C Station new substation 345 Add 2 new 345 bay(s) at New station. MI Conceptual $11,800,000 Y BB in MTEP10 East ITCT 3200 5740 1/1/2025 Keystone new substation 345 Add 2 new 345 bay(s) at New station. MI Conceptual $11,800,000 Y BB in MTEP10 East ITCT 3200 5730 1/1/2025 Greenwood new substation 345 Add 2 new 345 bay(s) at New station. MI Conceptual $11,800,000 Y BB in MTEP10 East ITCT 3200 5710 1/1/2025 19STOGA 345.00 19BFOOT 345.00 1 345 1756 Equipment upgrade to increase line rating MI 45.6 Conceptual $82,080,000 Y BB in MTEP10 East ITCT 3202 5920 1/1/2025 Murphy new substation 1 345 Add 4 new 345 bay(s) at New station. MI Conceptual $23,600,000 Y BB in MTEP10 East ITCT 3202 5910 1/1/2025 MI-C Station new substation 1 345 Add 2 new 345 bay(s) at New station. MI Conceptual $11,800,000 Y BB in MTEP10 East ITCT 3202 5911 1/1/2025 MI-D Station new substation 1 345 Add 2 new 345 bay(s) at New station. MI Conceptual $11,800,000 Y BB in MTEP10 East ITCT 3202 5912 1/1/2025 MI-E Station new substation 1 345 Add 2 new 345 bay(s) at New station. MI Conceptual $11,800,000 Y BB in MTEP10 East ITCT 3202 5903 1/1/2025 Keystone new substation 1 345 Add 2 new 345 bay(s) at New station. MI Conceptual $11,800,000 Y BB in MTEP10 East ITCT 3202 5850 1/1/2025 19STOGA 345.00 Blackfoot 1 345 1756 Equipment upgrade to increase line rating MI 45.6 Conceptual $82,080,000 Y BB in MTEP10 East ITCT 3202 5889 1/1/2025 Greenwood new substation 1 345 Add 2 new 345 bay(s) at New station. MI Conceptual $11,800,000 Y BB in MTEP10 East METC 3210 5953 6/1/2014 Vanderbilt Riggsville 138 Rebuild 30.3 miles of 138 kV 266 ACSR to

954 ACSR FDC 230 kV construction.MI 30.3 Proposed $33,254,000 Y B

B in MTEP10 East Non-MISO 3202 5834 1/1/2025 OH-B Station OH-C Station 1 765 3975 OH 49.32 Conceptual $138,096,000 Y BB in MTEP10 East/Non NIPS, CE 3202 5848 1/1/2025 Sheffield BURNH; B 345.00 1 345 1314 Equipment upgrade to increase line rating IL/IN 7.2 Conceptual $12,600,000 Y BB in MTEP10 East/Non NIPS, CE 3202 5849 1/1/2025 St. John Crete 1 345 1334 Equipment upgrade to increase line rating IL/IN 14.4 Conceptual $25,200,000 Y BB in MTEP10 East/Non Non-MISO 3202 5779 1/1/2025 South Canton OH-C Station 1 765 3975 OH 99.48 Conceptual $278,544,000 Y BB in MTEP10 MISO ATC LLC 3202 5887 1/1/2025 Granville upgrade existing




B in MTEP10 MISO DEM 3202 5893 1/1/2025 Gwynn new substation 1 345 Add 2 new 345 bay(s) at New station. IN Conceptual $11,800,000 Y B






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B in MTEP10 MISO DEM 3202 5926 1/1/2025 Noblesville upgrade existing substation

1 345 Add 1 new 345 bay(s) at Existing station. IN Conceptual $5,900,000 Y B

B in MTEP10 MISO DEM 3202 5928 1/1/2025 Nucor upgrade existing substation

1 345 Add 1 new 345 bay(s) at Existing station. IN Conceptual $5,900,000 Y B

B in MTEP10 MISO IPL 3202 5891 1/1/2025 Guion upgrade existing substation



B in MTEP10 MISO MEC 3202 5875 1/1/2025 Cordova (MEC) new substation 1 345 Add 2 new 345 bay(s) at New station. IL Conceptual $11,800,000 Y BB in MTEP10 MISO Non-MISO 3202 5874 1/1/2025 Collins upgrade existing

substation1 345 Add 1 new 345 bay(s) at Existing station. IL Conceptual $5,900,000 Y B

B in MTEP10 MISO XEL 3202 5895 1/1/2025 Hazel upgrade existing substation

1 345 Add 1 new 345 bay(s) at Existing station. MN Conceptual $5,900,000 Y B

B in MTEP10 MISO XEL 3202 5878 1/1/2025 Eden Prairie upgrade existing substation


MN Conceptual $16,100,000 Y B

B in MTEP10 West ALTW, DPC 3200 5694 1/1/2025 Mitchell Co North La Crosse 1 765 3975 MN/WI 89.28 Conceptual $313,570,092 Y BB in MTEP10 West ALTW, DPC 3202 5826 1/1/2025 Mitchell County Genoa 2 345 1510 2nd circuit of double circuit IA/MN/WI 82.8 Conceptual $202,464,000 Y BB in MTEP10 West ALTW, MEC 3200 5693 1/1/2025 Mitchell Co Hills 1 765 3975 IA/MN 178.9 Conceptual $574,060,800 Y BB in MTEP10 West ALTW, MEC 3202 5812 1/1/2025 Hazleton Hills 1 345 1510 IA 87.12 Conceptual $139,392,000 Y BB in MTEP10 West ALTW, MEC 3202 5811 1/1/2025 Hazleton Blackhawk 1 345 1510 IA 27.72 Conceptual $44,352,000 Y BB in MTEP10 West ALTW, MEC 3202 5835 1/1/2025 Ottumwa Montezuma 1 345 478 IA 42.96 Conceptual $68,736,000 Y BB in MTEP10 West ALTW, XEL 3200 4034 1/1/2025 Mitchell Co Hampton Corner 1 765 3975 MN 91.54 Conceptual $320,376,000 Y BB in MTEP10 West ALTW, XEL 3202 5818 1/1/2025 Lakefield Chanarambie 1 345 1510 MN 58.08 Conceptual $104,544,000 Y BB in MTEP10 West ATC LLC 3200 5754 1/1/2025 North Madison upgrade existing




B in MTEP10 West ATC LLC 3200 5758 1/1/2025 Paddock upgrade existing substation

345 Add 1 new 345 bay(s) at Existing station. WI Conceptual $5,900,000 Y B

B in MTEP10 West ATC LLC 3200 5762 1/1/2025 SEC upgrade existing substation

345 Add 1 new 345 bay(s) at Existing station. WI Conceptual $5,900,000 Y B

B in MTEP10 West ATC LLC 3200 5764 1/1/2025 Tamarac Tap new substation 345 Add 2 new 345 bay(s) at New station. WI Conceptual $11,800,000 Y BB in MTEP10 West ATC LLC 3200 5767 1/1/2025 WI-D Station new substation 345 Add 2 new 345 bay(s) at New station. WI Conceptual $11,800,000 Y BB in MTEP10 West ATC LLC 3200 5712 1/1/2025 Arcadian Mill Rd 1 345 1076 Equipment upgrade to increase line rating WI 36 Conceptual $75,600,000 Y BB in MTEP10 West ATC LLC 3200 5675 1/1/2025 Elm Road Tamarac Tap 1 345 1510 WI 30.43 Conceptual $63,908,208 Y BB in MTEP10 West ATC LLC 3200 5725 1/1/2025 Elm Road new substation 345 Add 2 new 345 bay(s) at New station. WI Conceptual $11,800,000 Y BB in MTEP10 West ATC LLC 3200 5723 1/1/2025 Darlington new substation 765 345 Add 3 new 765 bay(s) at New station. Add 2



B in MTEP10 West ATC LLC 3200 5703 1/1/2025 SEC Tamarac Tap 1 345 1510 WI 54.3 Conceptual $114,035,040 Y BB in MTEP10 West ATC LLC 3200 5714 1/1/2025 Edgewater Cedar Sauk 1 345 956 Equipment upgrade to increase line rating WI 56.4 Conceptual $118,440,000 Y BB in MTEP10 West ATC LLC 3200 5713 1/1/2025 Cypress Mill Rd 1 345 1076 Equipment upgrade to increase line rating WI 61.2 Conceptual $128,520,000 Y BB in MTEP10 West ATC LLC 3200 5672 1/1/2025 Darlington North Madison 1 765 3975 WI 64.51 Conceptual $258,028,320 Y BB in MTEP10 West ATC LLC 3200 5698 1/1/2025 Paddock Darlington 1 345 1510 WI 62.1 Conceptual $130,419,828 Y BB in MTEP10 West ATC LLC 3200 5747 1/1/2025 Mill Rd upgrade existing




B in MTEP10 West ATC LLC 3202 5799 1/1/2025 Cypress Mill Road 1 345 1510 WI 63.36 Conceptual $133,056,000 Y BB in MTEP10 West ATC LLC 3202 5798 1/1/2025 Cypress Forest Jct 1 345 1510 WI 28.92 Conceptual $60,732,000 Y BB in MTEP10 West ATC LLC 3202 5802 1/1/2025 Elm Road Tetonka 1 345 1510 WI 30.48 Conceptual $64,008,000 Y BB in MTEP10 West ATC LLC 3202 5788 1/1/2025 Arcadian Mill Road 1 345 1076 WI 9.96 Conceptual $20,916,000 Y BB in MTEP10 West ATC LLC 3202 5803 1/1/2025 Forest Jct Sheboygan Falls 1 345 1510 WI 41.76 Conceptual $87,696,000 Y BB in MTEP10 West ATC LLC 3202 5932 1/1/2025 Paddock new substation 1 345 Add 2 new 345 bay(s) at New station. WI Conceptual $11,800,000 Y BB in MTEP10 West ATC LLC 3202 5936 1/1/2025 Rocky Run upgrade existing

substation1 345 Add 1 new 345 bay(s) at Existing station. WI Conceptual $5,900,000 Y B

B in MTEP10 West ATC LLC 3202 5938 1/1/2025 SEC upgrade existing substation

1 345 Add 1 new 345 bay(s) at Existing station. WI Conceptual $5,900,000 Y B

B in MTEP10 West ATC LLC 3202 5940 1/1/2025 Sheboygan Falls new substation 1 345 Add 3 new 345 bay(s) at New station. WI Conceptual $23,600,000 Y B






Max kV


Miles Upg.


Cost Shared

Postage Stamp


B in MTEP10 West ATC LLC 3202 5924 1/1/2025 Nelson Dewey new substation 1 345 161 Add 6 new 345 bay(s) at New station. Add 2 new 161 bay(s) at New station. Add 2 new 345/161 autotransformer(s).


B in MTEP10 West ATC LLC 3202 5942 1/1/2025 Spring Green new substation 1 345 138 Add 3 new 345 bay(s) at New station. Add 1 new 138 bay(s) at Existing station. Add 1 new 345/138 autotransformer(s).


B in MTEP10 West ATC LLC 3202 5944 1/1/2025 Tamarack Tap new substation 1 345 Add 3 new 345 bay(s) at New station. WI Conceptual $23,600,000 Y BB in MTEP10 West ATC LLC 3202 5948 1/1/2025 Cardinal upgrade existing


B in MTEP10 West ATC LLC 3202 5939 1/1/2025 South Fon du Lac new substation 1 345 Add 2 new 345 bay(s) at New station. WI Conceptual $11,800,000 Y BB in MTEP10 West ATC LLC 3202 5927 1/1/2025 North Randolph new substation 1 345 Add 2 new 345 bay(s) at New station. WI Conceptual $11,800,000 Y BB in MTEP10 West ATC LLC 3202 5913 1/1/2025 Mill Road upgrade existing




B in MTEP10 West ATC LLC 3202 5877 1/1/2025 Darlington new substation 1 345 138 Add 5 new 345 bay(s) at New station. Add 1 new 138 bay(s) at Existing station. Add 1 new 345/138 autotransformer(s).


B in MTEP10 West ATC LLC 3202 5840 1/1/2025 SEC 345.00 Tamarack Tap 1 345 1510 WI 54.36 Conceptual $114,156,000 Y BB in MTEP10 West ATC LLC 3202 5838 1/1/2025 Rocky Run North Randolph 1 345 1510 WI 84.72 Conceptual $177,912,000 Y BB in MTEP10 West ATC LLC 3202 5842 1/1/2025 South Fon du Lac Sheboygan Falls 1 345 1510 WI 37.08 Conceptual $77,868,000 Y BB in MTEP10 West ATC LLC 3202 5876 1/1/2025 Cypress new substation 1 345 Add 2 new 345 bay(s) at New station. WI Conceptual $11,800,000 Y BB in MTEP10 West ATC LLC 3202 5841 1/1/2025 South Fon du Lac North Randolph 1 345 1510 WI 35.52 Conceptual $74,592,000 Y BB in MTEP10 West ATC LLC 3202 5836 1/1/2025 Paddock Darlington 2 345 1510 2nd circuit of double circuit WI 62.16 Conceptual $167,832,000 Y BB in MTEP10 West ATC LLC 3202 5865 1/1/2025 Arcadian upgrade existing


B in MTEP10 West ATC LLC 3202 5866 1/1/2025 Arpin upgrade existing substation



B in MTEP10 West ATC LLC 3202 5844 1/1/2025 Tamarack Tap Sheboygan Falls 1 345 1510 WI 54.36 Conceptual $114,156,000 Y BB in MTEP10 West ATC LLC 3202 5855 1/1/2025 Edgewater Cedar Sauk 1 345 956 Equipment upgrade to increase line rating WI 56.4 Conceptual $118,440,000 Y BB in MTEP10 West ATC LLC 3202 5830 1/1/2025 Nelson Dewey Darlington 2 345 1510 2nd circuit of double circuit WI 54.6 Conceptual $147,420,000 Y BB in MTEP10 West ATC LLC 3202 5883 1/1/2025 Forest Jct new substation 1 345 Add 2 new 345 bay(s) at New station. WI Conceptual $11,800,000 Y BB in MTEP10 West ATC LLC 3202 5880 1/1/2025 Elm Road new substation 1 345 Add 2 new 345 bay(s) at New station. WI Conceptual $11,800,000 Y BB in MTEP10 West CE, AmerenIL 3202 5817 1/1/2025 IL-F Station IN-E Station 1 345 1510 IL/IN 55.8 Conceptual $86,340,000 Y BB in MTEP10 West CE, MEC 3202 5858 1/1/2025 Quad Cities Cordova (MEC) 1 345 1173 Equipment upgrade to increase line rating IL 2.4 Conceptual $3,600,000 Y BB in MTEP10 West DPC 3200 5753 1/1/2025 North La Crosse upgrade existing




B in MTEP10 West DPC 3202 5921 1/1/2025 North LaCrosse new substation 1 345 Add 2 new 345 bay(s) at New station. WI Conceptual $11,800,000 Y BB in MTEP10 West DPC 3202 5886 1/1/2025 Genoa new substation 1 345 Add 4 new 345 bay(s) at New station. WI Conceptual $23,600,000 Y BB in MTEP10 West DPC 3202 5831 1/1/2025 North LaCrosse Genoa 1 345 1510 WI 22.08 Conceptual $46,368,000 Y BB in MTEP10 West DPC, ATC LLC 3200 5696 1/1/2025 North La Crosse North Madison 1 765 3975 WI 119.2 Conceptual $476,650,560 Y BB in MTEP10 West DPC, ATC LLC 3202 5805 1/1/2025 Genoa Nelson Dewey 1 345 1510 IA 70.8 Conceptual $113,280,000 Y BB in MTEP10 West GRE 3200 5755 1/1/2025 ND-New Station new substation 345 Add 3 new 345 bay(s) at New station. ND Conceptual $23,600,000 Y BB in MTEP10 West GRE 3200 5743 1/1/2025 McHenry upgrade existing



ND Conceptual $34,600,000 Y B

B in MTEP10 West GRE 3200 5692 1/1/2025 McHenry ND-New Station 1 345 1510 ND 145.6 Conceptual $203,903,280 Y BB in MTEP10 West GRE 3202 5794 1/1/2025 Center McHenry 1 345 1510 ND 80.28 Conceptual $112,392,000 Y BB in MTEP10 West GRE 3202 5934 1/1/2025 Prairie new substation 1 345 230 Add 5 new 345 bay(s) at New station. Add 2



B in MTEP10 West GRE 3202 5907 1/1/2025 McHenry new substation 1 345 230 Add 4 new 345 bay(s) at New station. Add 2 new 230 bay(s) at New station. Add 2 new 345/230 autotransformer(s).


B in MTEP10 West GRE 3202 5923 1/1/2025 ND New Station new substation 1 345 Add 3 new 345 bay(s) at New station. ND Conceptual $23,600,000 Y BB in MTEP10 West GRE 3202 5837 1/1/2025 Prairie ND New Station 2 345 1510 2nd circuit of double circuit ND 66.48 Conceptual $126,312,000 Y B






Max kV


Miles Upg.


Cost Shared

Postage Stamp


B in MTEP10 West GRE 3202 5872 1/1/2025 Center new substation 1 345 Add 3 new 345 bay(s) at New station. ND Conceptual $23,600,000 Y BB in MTEP10 West GRE 3202 5824 1/1/2025 McHenry ND New Station 1 345 1510 ND 145.7 Conceptual $203,952,000 Y BB in MTEP10 West ITCM 3200 5739 1/1/2025 IA-H Station new substation 345 Add 2 new 345 bay(s) at New station. IA Conceptual $11,800,000 Y BB in MTEP10 West ITCM 3200 5686 1/1/2025 Lakefield Junction IA-B Station 1 345 1510 IA/MN 61.09 Conceptual $101,138,208 Y BB in MTEP10 West ITCM 3200 5683 1/1/2025 IA-G Station IA-H Station 1 345 1510 IA 35.74 Conceptual $57,180,288 Y BB in MTEP10 West ITCM 3200 5738 1/1/2025 IA-G Station new substation 765 345 Add 3 new 765 bay(s) at New station. Add 4


IA Conceptual $102,000,000 Y B

B in MTEP10 West ITCM 3200 5737 1/1/2025 IA-F Station new substation 345 Add 2 new 345 bay(s) at New station. IA Conceptual $11,800,000 Y BB in MTEP10 West ITCM 3200 5736 1/1/2025 IA-B Station new substation 345 Add 2 new 345 bay(s) at New station. IA Conceptual $11,800,000 Y BB in MTEP10 West ITCM 3200 5733 1/1/2025 Guthrie Center new substation 345 Add 3 new 345 bay(s) at New station. IA Conceptual $23,600,000 Y BB in MTEP10 West ITCM 3200 5681 1/1/2025 IA-B Station IA-F Station 1 345 1510 IA 26.88 Conceptual $43,014,336 Y BB in MTEP10 West ITCM 3200 5682 1/1/2025 IA-F Station IA-G Station 1 345 1510 IA 38.92 Conceptual $62,278,656 Y BB in MTEP10 West ITCM 3200 5741 1/1/2025 Lakefield new substation 765 345 Add 4 new 765 bay(s) at New station. Add 1



B in MTEP10 West ITCM 3200 5679 1/1/2025 Guthrie Center IA-H Station 1 345 1510 IA 41.24 Conceptual $65,985,600 Y BB in MTEP10 West ITCM 3200 5748 1/1/2025 Mitchell Co new substation 765 345 Add 5 new 765 bay(s) at New station. Add 1

new 765/345 autotransformer(s).MN Conceptual $103,400,000 Y B

B in MTEP10 West ITCM 3202 5898 1/1/2025 IA-B Station new substation 1 345 Add 2 new 345 bay(s) at New station. IA Conceptual $11,800,000 Y BB in MTEP10 West ITCM 3202 5896 1/1/2025 Hazleton new substation 1 345 Add 3 new 345 bay(s) at New station. IA Conceptual $23,600,000 Y BB in MTEP10 West ITCM 3202 5809 1/1/2025 Guthrie Center IA-H Station 2 345 1510 2nd circuit of double circuit IA 41.28 Conceptual $94,944,000 Y BB in MTEP10 West ITCM 3202 5816 1/1/2025 IA-G Station IA-H Station 1 345 1510 IA 35.76 Conceptual $57,216,000 Y BB in MTEP10 West ITCM 3202 5815 1/1/2025 IA-F Station IA-G Station 1 345 1510 IA 38.88 Conceptual $62,208,000 Y BB in MTEP10 West ITCM 3202 5814 1/1/2025 IA-B Station IA-F Station 1 345 1510 IA 26.88 Conceptual $43,008,000 Y BB in MTEP10 West ITCM 3202 5813 1/1/2025 Hazleton Mitchell County 1 345 956 IA 85.32 Conceptual $136,512,000 Y BB in MTEP10 West ITCM 3202 5899 1/1/2025 IA-F Station new substation 1 345 Add 2 new 345 bay(s) at New station. IA Conceptual $11,800,000 Y BB in MTEP10 West ITCM 3202 5930 1/1/2025 Ottumwa new substation 1 345 Add 1 new 345 bay(s) at New station. IA Conceptual $5,900,000 Y BB in MTEP10 West ITCM 3202 5900 1/1/2025 IA-G Station new substation 1 345 Add 4 new 345 bay(s) at New station. IA Conceptual $23,600,000 Y BB in MTEP10 West ITCM 3202 5901 1/1/2025 IA-H Station new substation 1 345 Add 3 new 345 bay(s) at New station. IA Conceptual $23,600,000 Y BB in MTEP10 West ITCM 3202 5914 1/1/2025 Mitchell County new substation 1 345 Add 5 new 345 bay(s) at New station. IA Conceptual $29,400,000 Y BB in MTEP10 West ITCM 3202 5819 1/1/2025 Lakefield IA-B Station 1 345 1510 IA/MN 61.08 Conceptual $101,136,000 Y BB in MTEP10 West ITCM 3202 5892 1/1/2025 Guthrie Center new substation 1 345 Add 4 new 345 bay(s) at New station. IA Conceptual $23,600,000 Y BB in MTEP10 West MDU 3200 5724 1/1/2025 Ellendale upgrade existing




B in MTEP10 West MDU 3200 5751 1/1/2025 MT_Zone upgrade existing substation


MT Conceptual $41,100,000 Y B

B in MTEP10 West MDU 3200 5674 1/1/2025 Ellendale Tetonka 2 345 1510 2nd circuit of double circuit ND 25.27 Conceptual $48,022,044 Y BB in MTEP10 West MDU 3202 5796 1/1/2025 Center Tetonka 1 345 1510 ND 150.5 Conceptual $210,672,000 Y BB in MTEP10 West MDU 3202 5801 1/1/2025 Ellendale Tetonka 1 345 1510 ND 25.32 Conceptual $35,448,000 Y BB in MTEP10 West MDU 3202 5946 1/1/2025 Tetonka new substation 1 345 230 Add 7 new 345 bay(s) at New station. Add 2



B in MTEP10 West MDU 3202 5919 1/1/2025 MT_Zone new substation 1 345 230 Add 3 new 345 bay(s) at New station. Add 2 new 230 bay(s) at New station. Add 2 new 345/230 autotransformer(s).

MT Conceptual $45,600,000 Y B

B in MTEP10 West MDU 3202 5885 1/1/2025 Fort Thompson new substation 1 345 230 Add 2 new 345 bay(s) at New station. Add 1 new 230 bay(s) at Existing station. Add 1 new 345/230 autotransformer(s).

SD Conceptual $22,800,000 Y B

B in MTEP10 West MDU 3202 5879 1/1/2025 Ellendale new substation 1 345 230 Add 3 new 345 bay(s) at New station. Add 1 new 230 bay(s) at Existing station. Add 1 new 345/230 autotransformer(s).


B in MTEP10 West MDU, OTP 3200 5673 1/1/2025 Ellendale Oakes 2 345 1510 2nd circuit of double circuit ND 27.64 Conceptual $52,519,116 Y BB in MTEP10 West MDU, OTP 3202 5800 1/1/2025 Ellendale Oakes 1 345 1510 ND 27.6 Conceptual $38,640,000 Y BB in MTEP10 West MEC 3200 5678 1/1/2025 Grimes Hills 1 765 3975 IA 141.3 Conceptual $452,044,800 Y B






Max kV


Miles Upg.


Cost Shared

Postage Stamp


B in MTEP10 West MEC 3200 5735 1/1/2025 Hills upgrade existing substation



B in MTEP10 West MEC 3200 5731 1/1/2025 Grimes new substation 765 345 Add 4 new 765 bay(s) at New station. Add 3 new 345 bay(s) at New station. Add 1 new 765/345 autotransformer(s).


B in MTEP10 West MEC 3200 5684 1/1/2025 IA-G Station Grimes 1 765 3975 IA 105.3 Conceptual $336,932,352 Y BB in MTEP10 West MEC 3202 5808 1/1/2025 Grimes Montezuma 2 345 1510 2nd circuit of double circuit IA 77.52 Conceptual $178,296,000 Y BB in MTEP10 West MEC 3202 5807 1/1/2025 Grimes Lehigh 1 345 1510 IA 61.92 Conceptual $99,072,000 Y BB in MTEP10 West MEC 3202 5897 1/1/2025 Hills new substation 1 345 Add 4 new 345 bay(s) at New station. IA Conceptual $23,600,000 Y BB in MTEP10 West MEC 3202 5905 1/1/2025 Lehigh new substation 1 345 Add 2 new 345 bay(s) at New station. IA Conceptual $11,800,000 Y BB in MTEP10 West MEC 3202 5917 1/1/2025 Montezuma new substation 1 345 Add 6 new 345 bay(s) at New station. IA Conceptual $35,400,000 Y BB in MTEP10 West MEC 3202 5869 1/1/2025 Bondurant upgrade existing

substation1 345 Add 1 new 345 bay(s) at Existing station. IA Conceptual $5,900,000 Y B

B in MTEP10 West MEC 3202 5868 1/1/2025 Blackhawk new substation 1 345 161 Add 4 new 345 bay(s) at New station. Add 2 new 161 bay(s) at New station. Add 2 new 345/161 autotransformer(s).


B in MTEP10 West MEC 3202 5853 1/1/2025 Bondurant Montezuma 1 345 1510 Equipment upgrade to increase line rating IA 58.08 Conceptual $92,928,000 Y BB in MTEP10 West MEC 3202 5856 1/1/2025 Montezuma Hills 1 345 1510 Equipment upgrade to increase line rating IA 63.84 Conceptual $102,144,000 Y BB in MTEP10 West MEC 3202 5854 1/1/2025 Bondurant Sycamore 1 345 1510 Equipment upgrade to increase line rating IA 12 Conceptual $19,200,000 Y BB in MTEP10 West MEC 3202 5845 1/1/2025 Webster Blackhawk 1 345 1510 IA 106.1 Conceptual $169,728,000 Y BB in MTEP10 West MEC 3202 5829 1/1/2025 Montezuma Hills 2 345 1510 IA 63.84 Conceptual $102,144,000 Y BB in MTEP10 West MEC 3202 5890 1/1/2025 Grimes new substation 1 345 Add 5 new 345 bay(s) at New station. IA Conceptual $35,400,000 Y BB in MTEP10 West MEC, ALTW 3200 5677 1/1/2025 Grimes Guthrie Center 2 345 1510 2nd circuit of double circuit IA 42.02 Conceptual $96,656,580 Y BB in MTEP10 West MEC, ALTW 3200 5704 1/1/2025 Webster IA-G Station 1 345 1510 IA 72.99 Conceptual $116,776,704 Y BB in MTEP10 West MEC, ALTW 3202 5806 1/1/2025 Grimes Guthrie Center 2 345 1510 2nd circuit of double circuit IA 42 Conceptual $96,600,000 Y BB in MTEP10 West MEC, ALTW 3202 5846 1/1/2025 Webster IA-G Station 1 345 1510 IA 72.96 Conceptual $116,736,000 Y BB in MTEP10 West MEC, ALTW 3202 5820 1/1/2025 Lehigh IA-G Station 1 345 1510 IA 69.36 Conceptual $110,976,000 Y BB in MTEP10 West MPW 2935 5108 6/1/2017 Wiggins Power Plant 1 69 89 Reconductor Line from 336.4 to 636 ACSR IA 4.2 Proposed $252,000 Y BB in MTEP10 West MPW 2935 5107 6/1/2017 South Wiggins 1 69 89 Reconductor Line from 336.4 to 636 ACSR IA 0.8 Proposed $48,000 Y BB in MTEP10 West OTP 3200 5756 1/1/2025 Oakes upgrade existing




B in MTEP10 West OTP 3200 5759 1/1/2025 Prairie new substation 345 Add 4 new 345 bay(s) at New station. ND Conceptual $23,600,000 Y BB in MTEP10 West OTP 3200 5734 1/1/2025 Hankinson upgrade existing




B in MTEP10 West OTP 3200 5742 1/1/2025 Maple River new substation 345 Add 3 new 345 bay(s) at New station. ND Conceptual $23,600,000 Y BB in MTEP10 West OTP 3200 5721 1/1/2025 Center new substation 345 Add 3 new 345 bay(s) at New station. ND Conceptual $23,600,000 Y BB in MTEP10 West OTP 3200 5727 1/1/2025 Forman upgrade existing




B in MTEP10 West OTP 3200 5680 1/1/2025 Hankinson Forman 2 345 1510 2nd circuit of double circuit ND 42.93 Conceptual $81,574,068 Y BB in MTEP10 West OTP 3200 5690 1/1/2025 Maple River Hankinson 1 345 1510 ND 66.36 Conceptual $92,908,368 Y BB in MTEP10 West OTP 3200 5691 1/1/2025 Maple River Prairie 2 345 1510 2nd circuit of double circuit ND 83.08 Conceptual $157,852,380 Y BB in MTEP10 West OTP 3200 5697 1/1/2025 Oakes Forman 2 345 1510 2nd circuit of double circuit ND 26.57 Conceptual $50,473,728 Y BB in MTEP10 West OTP 3202 5810 1/1/2025 Hankinson Forman 1 345 1510 ND 42.96 Conceptual $60,144,000 Y BB in MTEP10 West OTP 3202 5906 1/1/2025 Maple River new substation 1 345 Add 3 new 345 bay(s) at New station. ND Conceptual $23,600,000 Y BB in MTEP10 West OTP 3202 5929 1/1/2025 Oakes new substation 1 345 230 Add 3 new 345 bay(s) at New station. Add 1



B in MTEP10 West OTP 3202 5857 1/1/2025 Prairie Winger 1 230 389 Equipment upgrade to increase line rating ND 69.6 Conceptual $52,200,000 Y BB in MTEP10 West OTP 3202 5867 1/1/2025 Big Stone new substation 1 345 Add 1 new 345 bay(s) at New station. SD Conceptual $5,900,000 Y BB in MTEP10 West OTP 3202 5833 1/1/2025 Oaks Forman 1 345 1510 ND 26.52 Conceptual $37,128,000 Y BB in MTEP10 West OTP 3202 5884 1/1/2025 Forman new substation 1 345 230 Add 3 new 345 bay(s) at New station. Add 1








Max kV


Miles Upg.


Cost Shared

Postage Stamp


B in MTEP10 West OTP 3202 5894 1/1/2025 Hankinson new substation 1 345 230 Add 5 new 345 bay(s) at New station. Add 2 new 230 bay(s) at New station. Add 2 new 345/230 autotransformer(s).


B in MTEP10 West OTP 3202 5823 1/1/2025 Maple River Prairie 2 345 1510 2nd circuit of double circuit ND 83.04 Conceptual $157,776,000 Y BB in MTEP10 West OTP 3202 5822 1/1/2025 Maple River Hankinson 1 345 1510 ND 66.36 Conceptual $92,904,000 Y BB in MTEP10 West OTP, GRE 3200 5669 1/1/2025 Center McHenry 1 345 1510 ND 80.33 Conceptual $112,464,576 Y BB in MTEP10 West OTP, GRE 3200 5699 1/1/2025 Prairie ND-New Station 2 345 1510 2nd circuit of double circuit ND 66.48 Conceptual $126,319,980 Y BB in MTEP10 West OTP, MDU 3200 5765 1/1/2025 Tetonka new substation 345 230 Add 7 new 345 bay(s) at New station. Add 2



B in MTEP10 West OTP, MDU 3200 5671 1/1/2025 Center Tetonka 1 345 1510 ND 150.5 Conceptual $210,690,480 Y BB in MTEP10 West OTP, WAPA 3202 5792 1/1/2025 Big Stone Granite Falls 1 345 1510 MN/SD 69.12 Conceptual $122,688,000 Y BB in MTEP10 West WAPA 3202 5795 1/1/2025 Center MT_Zone 1 345 1510 MT/ND 201.6 Conceptual $282,240,000 Y BB in MTEP10 West WAPA 3202 5791 1/1/2025 Brookings County White 1 115 160 SD 0.6 Conceptual $300,000 Y BB in MTEP10 West WAPA, MDU 3202 5804 1/1/2025 Fort Thompson Tetonka 1 345 1510 ND/SD 163.2 Conceptual $228,480,000 Y BB in MTEP10 West XEL 3121 5470 6/1/2016 Kenrick Ritter Park 1 115 Upgrade to 2-795 ACSR MN Planned Y BB in MTEP10 West XEL 3121 5471 6/1/2016 Ritter Park Dakota Heights 1 115 Upgrade to 2-795 ACSR MN Planned Y BB in MTEP10 West XEL 3121 5469 6/1/2016 Lake Marion Kenrick 1 115 Upgrade to 2-795 ACSR MN Planned $6,200,000 Y BB in MTEP10 West XEL 3121 5472 6/1/2016 Dakota Heights Burnsville 1 115 Upgrade to 2-795 ACSR MN Planned Y BB in MTEP10 West XEL 3200 5766 1/1/2025 White upgrade existing




B in MTEP10 West XEL 3200 5761 1/1/2025 SD-H Station new substation 345 Add 3 new 345 bay(s) at New station. SD Conceptual $23,600,000 Y BB in MTEP10 West XEL 3200 5666 1/1/2025 Brookings County Hampton Corner 1 765 3975 MN/SD 210.7 Conceptual $734,385,859 Y BB in MTEP10 West XEL 3200 5665 1/1/2025 Brookings County New 765 Sub 2 1 765 3975 MN/SD 20.19 Conceptual $66,696,773 Y BB in MTEP10 West XEL 3200 5664 1/1/2025 New 765 Sub 1 New 765 Sub 2 1 765 3975 MN 25.83 Conceptual $90,391,560 Y BB in MTEP10 West XEL 3200 5667 1/1/2025 Brookings County SD-H station 1 345 1510 SD 58.02 Conceptual $81,231,696 Y BB in MTEP10 West XEL 3200 4059 1/1/2025 Hampton Corner upgrade existing




B in MTEP10 West XEL 3200 5722 1/1/2025 New 765 Sub 2 new substation 765 115 Add 4 new 765 bay(s) at New station. Add 2 new 115 bay(s) at New station. Add 2 new 765/115 autotransformer(s).


B in MTEP10 West XEL 3200 5720 1/1/2025 New 765 Sub 1 new substation 765 115 Add 4 new 765 bay(s) at New station. Add 2 new 115 bay(s) at New station. Add 2 new 765/115 autotransformer(s).


B in MTEP10 West XEL 3200 5719 1/1/2025 Brookings County new substation 765 345 Add 4 new 765 bay(s) at New station. Add 2 new 345 bay(s) at New station. Add 2 new 765/345 autotransformer(s).


B in MTEP10 West XEL 3200 5717 1/1/2025 Alexandria upgrade existing substation

345 Add 1 new 345 bay(s) at Existing station. MN Conceptual $5,900,000 Y B

B in MTEP10 West XEL 3200 5695 1/1/2025 MN-K Station IA-J Station 1 345 1510 IA/MN 48.19 Conceptual $78,101,486 Y BB in MTEP10 West XEL 3200 5688 1/1/2025 Lakefield Junction New 765 Sub 1 1 765 3975 MN 58.08 Conceptual $203,279,160 Y BB in MTEP10 West XEL 3200 5749 1/1/2025 MN-K Station new substation 765 345 Add 3 new 765 bay(s) at New station. Add 1

new 765/345 autotransformer(s).MN Conceptual $78,200,000 Y B

B in MTEP10 West XEL 3200 5701 1/1/2025 SD-H Station SD-J Station 1 345 1510 SD 53.48 Conceptual $74,871,216 Y BB in MTEP10 West XEL 3202 5793 1/1/2025 Buffalo Ridge Chanarambie 1 345 1510 MN 25.8 Conceptual $46,440,000 Y BB in MTEP10 West XEL 3202 5789 1/1/2025 Brookings County Buffalo Ridge 1 345 1510 MN/SD 20.16 Conceptual $34,032,000 Y BB in MTEP10 West XEL 3202 5864 1/1/2025 Alexandria new substation 1 345 Add 2 new 345 bay(s) at New station. MN Conceptual $11,800,000 Y BB in MTEP10 West XEL 3202 5941 1/1/2025 Sioux City new substation 1 345 230 Add 2 new 345 bay(s) at New station. Add 1



B in MTEP10 West XEL 3202 5937 1/1/2025 SD-H Station new substation 1 345 Add 3 new 345 bay(s) at New station. SD Conceptual $23,600,000 Y BB in MTEP10 West XEL 3202 5943 1/1/2025 Split Rock upgrade existing

substation1 345 Add 1 new 345 bay(s) at Existing station. SD Conceptual $5,900,000 Y B






Max kV


Miles Upg.


Cost Shared

Postage Stamp


B in MTEP10 West XEL 3202 5947 1/1/2025 Watertown upgrade existing substation



B in MTEP10 West XEL 3202 5915 1/1/2025 MN-K Station new substation 1 345 Add 2 new 345 bay(s) at New station. MN Conceptual $11,800,000 Y BB in MTEP10 West XEL 3202 5904 1/1/2025 Lakefield new substation 1 345 161 Add 3 new 345 bay(s) at New station. Add 1



B in MTEP10 West XEL 3202 5918 1/1/2025 Monticello upgrade existing substation


B in MTEP10 West XEL 3202 5922 1/1/2025 North Rochester upgrade existing substation


B in MTEP10 West XEL 3202 5870 1/1/2025 Brookings County new substation 1 345 Add 4 new 345 bay(s) at New station. SD Conceptual $23,600,000 Y BB in MTEP10 West XEL 3202 5790 1/1/2025 Brookings County SD-H Station 1 345 1510 SD 58.08 Conceptual $81,312,000 Y BB in MTEP10 West XEL 3202 5871 1/1/2025 Buffalo Ridge new substation 1 345 115 Add 2 new 345 bay(s) at New station. Add 2



B in MTEP10 West XEL 3202 5873 1/1/2025 Chanarambie new substation 1 345 115 Add 2 new 345 bay(s) at New station. Add 2 new 115 bay(s) at New station. Add 2 new 345/115 autotransformer(s).


B in MTEP10 West XEL 3202 5863 1/1/2025 Adams upgrade existing substation


B in MTEP10 West XEL 3202 5828 1/1/2025 Monticello Alexandria 1 345 1510 MN 97.8 Conceptual $176,040,000 Y BB in MTEP10 West XEL 3202 5825 1/1/2025 Minnesota Valley Hazel 1 230 338 MN 7.44 Conceptual $5,580,000 Y BB in MTEP10 West XEL, ALTW 3202 5786 1/1/2025 Adams Mitchell County 1 345 956 IA/MN 8.04 Conceptual $14,016,000 Y BB in MTEP10 West XEL, DPC 3202 5832 1/1/2025 North Rochester North LaCrosse 1 345 1510 MN/WI 69.84 Conceptual $126,432,000 Y BB in MTEP10 West XEL, MDU 3200 5702 1/1/2025 SD-H Station Tetonka 1 345 1510 ND/SD 152 Conceptual $212,788,464 Y BB in MTEP10 West XEL, MDU 3202 5839 1/1/2025 SD-H Station Tetonka 2 345 1510 2nd circuit of double circuit ND/SD 151.9 Conceptual $288,648,000 Y BB in MTEP10 West XEL, MEC 3200 5689 1/1/2025 Lakefield Junction IA-G Station 1 765 3975 IA/MN 109.8 Conceptual $355,430,412 Y BB in MTEP10 West XEL, MEC 3202 5827 1/1/2025 MN-K Station IA-J Station 1 345 1510 IA/MN 48.24 Conceptual $78,192,000 Y BB in MTEP10 West XEL, OTP 3200 5663 1/1/2025 Alexandria Hankinson 1 345 1510 MN/ND 90.59 Conceptual $155,254,104 Y BB in MTEP10 West XEL, OTP 3202 5787 1/1/2025 Alexandria Hankinson 1 345 1510 MN/ND 90.6 Conceptual $155,256,000 Y BB in MTEP10 West XEL, WAPA 3202 5843 1/1/2025 Split Rock Sioux City 1 345 717 IA/SD 85.2 Conceptual $129,288,000 Y BB in MTEP10 West XEL, WAPA 3202 5859 1/1/2025 Split Rock White 1 345 1308 Equipment upgrade to increase line rating SD 70.8 Conceptual $99,120,000 Y BB in MTEP10 West/CenAmerenIL, MEC 3202 5785 1/1/2025 Fargo Oak Grove 1 345 1510 IL 73.92 Conceptual $110,880,000 Y BB in MTEP10 West/CenMIPU, MEC 3200 5661 1/1/2025 Fairport Grimes 1 765 3975 IA/MO 140.9 Conceptual $450,955,776 Y BB in MTEP10 West/NonCE, ATC LLC 3200 5668 1/1/2025 Byron Darlington 1 765 3975 IL/WI 70.68 Conceptual $221,095,152 Y BB in MTEP10 West/NonCE, ATC LLC 3200 5687 1/1/2025 Liberty Elm Road 1 345 1510 IL/WI 44.7 Conceptual $84,763,368 Y BB in MTEP10 West/NonCE, ATC LLC 3202 5821 1/1/2025 Liberty Elm Road 1 345 1510 IL/WI 44.64 Conceptual $84,672,000 Y BB in MTEP10 West/NonCE, MEC 3200 5700 1/1/2025 Quad Cities Hills 1 765 3975 IA/IL 77.26 Conceptual $246,977,135 Y BB in MTEP10 West/NonCE, MEC 3202 5797 1/1/2025 Cordova Hills 1 345 1510 IA/IL 78.84 Conceptual $125,928,000 Y BB in MTEP10 West/NonOTP, WAPA 3200 5670 1/1/2025 Center Mt. Zion 1 345 1510 MT/ND 201.5 Conceptual $282,119,208 Y BB in MTEP10 West/NonWAPA, MDU 3200 5676 1/1/2025 Fort Thompson Tetonka 1 345 1510 ND/SD 163.1 Conceptual $228,379,553 Y BB in MTEP10 West/NonXEL, WAPA 3200 5715 1/1/2025 Split Rock White 1 345 1308 Equipment upgrade to increase line rating SD 70.8 Conceptual $99,120,000 Y BB in MTEP11 Central AmerenIL 2967 5166 6/1/2013 Grand Tower Plant 2-Stage, 80 Mvar

Capacitor Bank1 138 80 Grand Tower Plant - Install 2-stage 80 Mvar

(2 x 40 Mvar) 138 kV capacitor bank. 2-138 kV PCB's needed.


B in MTEP11 Central AmerenIL 2977 5180 6/1/2013 LaSalle-Oglesby 138 kV Relocate LaSalle Substation

1 138 120 LaSalle 138-34.5 kV Substation - Relocate Substation to avoid flooding and to permit remediation of manufactured gas plant site. (Approx. 1 mile move.)


B in MTEP11 Central AmerenIL 2979 5182 6/1/2013 AECI Enon Substation Install 2-345 kV Breakers 345 Enon 345/161 kV Substation - Install 2-345 kV PCB's on incoming 345 kV lines. (Belleau-Enon and Enon-Montgomery

MO Proposed $1,876,000 Y B






Max kV


Miles Upg.


Cost Shared

Postage Stamp


B in MTEP11 Central AmerenIL 2982 5185 12/1/2013 Washington Street South Bloomington 1326 138 255 Washington Street-S. Bloomington 138 kV Line 1326 - Replace terminal equipment (wavetrap, 3-CT's and bus conductor) at S. Bloomington with equipment capable of carrying minimum 2000 A under summer emergency conditions.

IL Proposed $137,000 Y B

B in MTEP11 Central AmerenIL 3009 5217 6/1/2018 Hutsonville Plant Merom 1 345 1793 Newton-Hutsonville 345 kV line – New 40 mi. 3000 A summer emergency capability line. Hutsonville-Merom 345 kV line - New 12 mi. 3000 A summer emergency capability line. 345/138 kV 560 MVA transformer @ Hutsonville

IL 12 Proposed $100,000,000 Y B

B in MTEP11 Central AmerenIL 3009 5218 6/1/2018 Hutsonville Plant Install 345/138 kV Xfmr 1 345 138 560 Newton-Hutsonville 345 kV line – New 40 mi. 3000 A summer emergency capability line. Hutsonville-Merom 345 kV line - New 12 mi. 3000 A summer emergency capability line. 345/138 kV 560 MVA transformer @ Hutsonville


B in MTEP11 Central AmerenIL 3010 5219 12/1/2025 Baldwin N.W. Cape 1 345 1793 Baldwin-Grand Tower-N.W. Cape 345 kV - Construct 69 miles of 3000 A summer emergency capability. Install a 560 MVA, 345/138 kV transformer at Grand Tower

IL 69 Proposed $146,000,000 Y B

B in MTEP11 Central AmerenIL 3010 5220 12/1/2025 Grand Tower Plant Install 345/138 kV Xfmr 1 345 138 560 Install a 560 MVA, 345/138 kV transformer at Grand Tower


B in MTEP11 Central AmerenIL 3201 5775 1/1/2025 Grand Tower DC Station for 6400 MW 800 6400 IL Conceptual $274,500,000 Y BB in MTEP11 Central AmerenMO 2971 5171 6/1/2012 Rivermines-Maries-1 Tap for Rolla Alfermann

Substation1 138 478 Rolla Alfermann Substation - Tap Rivermines-

Maries-1 138 kV line to establish 138 kV supply to new 138-34.5 kV Alfermann Substation, owned by City of Rolla. Ameren to construct tapping structures. 1-138 kV, 1200 A disconnect switch

MO Planned $481,500 Y B

B in MTEP11 Central AmerenMO 2971 5170 6/1/2012 Clark-O-2 Tap for Rolla Alfermann Substation

1 138 478 Rolla Alfermann Substation - Tap Clark-Osage-2 138 kV line to establish 138 kV supply to new 138-34.5 kV Alfermann Substation, owned by City of Rolla. Ameren to construct tapping structures. 1-138 kV, 1200 A disconnect switch.

MO Planned $481,500 Y B

B in MTEP11 Central AmerenMO 2973 5174 12/1/2016 Mason-Carrollton-8 Connection to Howard Bend 138-12 kV Sub

1 138 478 Howard Bend 138-12 kV Substation - Provide 138 kV ring bus connection from Mason-Carrollton-8 138 kV line to new Howard Bend Substation. Install 1-138 kV, 2000 A PCB at Carrollton Substation as a bus-tie.

MO Proposed $1,371,000 Y B

B in MTEP11 Central AmerenMO 2988 5192 6/1/2016 Warrenton Lincoln 138-34.5 kV Bulk 1 161 280 Warrenton-Lincoln Bulk Substation 161 kV - Establish a second 161 kV supply to Lincoln Bulk Substation from Warrenton Substation. 10 miles of new 161 kV line, 2-161 kV, 2000 A PCBs at Warrenton Substation.

MO 10 Proposed $12,000,000 Y B

B in MTEP11 East ITC 3282 6114 12/31/2013 Southfield Sunset 1 120 220 Rebuild 6.4 mile 120 kV line Mi 6.4 Planned $7,100,000 Y C>BB in MTEP11 East METC 1803 3618 12/31/2013 Plum Stover 1 138 191 Rebuild 8.8 miles (230 kV construction,

operate at 138 kV)MI 8.8 Planned $10,900,000 Y C>B

B in MTEP11 East METC 1815 3649 12/31/2014 Chase Mecosta 1 138 108 Rebuild 7.2 miles (230 kV construction, operate at 138 kV)

MI 7.2 Planned $8,900,000 Y C>B

B in MTEP11 West ATC LLC 2799 4924 7/1/2013 Kinchelo Tap Kinross 1 69 84 MVA Construct a 3 mile line to connect the Kinross load

MI 3 Conceptual $3,882,248 Y C>B

B in MTEP11 West ATC LLC 3119 5464 6/1/2016 Tone Kincheloe 1 69 48 MVA Increase ground clearance for 6923 Pine River-9Mile 69kV line to 167 deg f clearance

MI 2.51 Proposed $299,043 Y C>B






Max kV


Miles Upg.


Cost Shared

Postage Stamp


B in MTEP11 West ATC LLC 3119 5465 6/1/2016 Kincheloe 9 Mile 1 69 48 MVA Increase ground clearance for 6923 Pine River-9Mile 69kV line to 167 deg f clearance


B in MTEP11 West ATC LLC 3119 5463 6/1/2016 Rudyard Tone 1 69 48 MVA Increase ground clearance for 6923 Pine River-9Mile 69kV line to 167 deg f clearance


B in MTEP11 West ATC LLC 3119 5462 6/1/2016 Pine River Rudyard 1 69 48 MVA Increase ground clearance for 6923 Pine River-9Mile 69kV line to 167 deg f clearance


B in MTEP11 West ATC LLC 3209 5976 10/25/2013 Edgewater Transformer 1 138 69 60 Replace Edgewater 138/69kV Tr T21 with a larger unit and uprate terminal equipment to a minimum of the transformer ratings

WI Proposed $2,704,736 Y C>B

B in MTEP11 West ATC LLC 3209 5977 10/25/2013 Edgewater Transformer 2 138 69 60 Replace Edgewater 138/69kV Tr T22 with a larger unit and uprate terminal equipment to a minimum of the transformer ratings

WI Proposed $2,704,735 Y C>B

B in MTEP11 West ATC LLC 3490 6450 4/15/2013 Doylestown Rio Pumping Station 1 69 72 Asset Management project to Rebuild Y-20 Doylestown to Rio Pumping Station

WI 11.46 Planned $7,400,000 Y C>B

B in MTEP11 West ATC LLC 3514 6493 9/1/2013 96th Street Sub 138 WI Proposed $28,000,000 Y C>BB in MTEP11 West ATC LLC 3514 6494 9/1/2013 Walker Load Move Relocate Walker Load from line 96S to line

5042 BMDWI Proposed Y C>B

B in MTEP11 West ATC LLC 3519 6515 12/31/2012 Riverbend 138 24.9 Loop the Ranegline-Port Washington 138 kV line 731 into a new breakered Riverbend SS

WI 0.078 Proposed $3,016,359 Y C>B

B in MTEP11 West MEC 3201 5774 1/1/2025 IA-G DC Station for 6400 MW 800 6400 IA Conceptual $274,500,000 Y BB in MTEP11 West MEC 3201 5772 1/1/2025 Lakefield Jct DC Station for 6400 MW 800 6400 MN Conceptual $274,500,000 Y BB in MTEP11 West MEC 3201 5773 1/1/2025 IA-B DC Station for 6400 MW 800 6400 IA Conceptual $274,500,000 Y BB in MTEP11 West MEC 3214 6098 12/1/2015 Sub 17 Sub 39 1 161 260 Sub 17 & Sub 39 Replace Relays 161-17-39-

1 and Remove Wave TrapIL Proposed $225,000 Y C>B

B in MTEP11 West MEC 3215 6089 6/1/2014 Sub 49 Capacitor 161 50 Sub 49 161 kV 50 MVAr Capacitor IL Proposed $840,000 Y C>BB in MTEP11 West MEC 3216 6096 6/1/2014 Plymouth 161 450 Plymouth Substation 161 kV Line Terminal IA Planned $500,000 Y C>BB in MTEP11 West MEC 3216 6097 6/1/2014 Sioux City 161 450 WAPA Sioux City 161kV Line Terminal IA Planned $500,000 Y C>BB in MTEP11 West MEC 3216 6095 6/1/2014 Plymouth Sioux City 2 161 450 Plymouth-Sioux City 161 kV Line IA 2 Planned $1,400,000 Y C>BB in MTEP11 West MEC 3266 6085 6/1/2016 Sub 56 Sub 89 1 161 314 Sub 56-89 161 kV line uprate IA 22 Proposed $680,000 Y C>BB in MTEP11 West OTP 3431 6327 10/1/2012 Hankinson 230 Hankinson 41.6 230 41.6 Add a second 230/41.6 kV transformer at

Hankinson Substation which will include the addition of 2 new 230 kV breakers.

ND Planned $835,000 Y C>B

B in MTEP11 West OTP 3462 6388 10/30/2012 Karlstad 115 kV Viking 115 kV 1 115 115 Add 3 breaker 115 kV ring bus MN Proposed $2,800,000 Y C>BB in MTEP11 West OTP 3464 6390 12/1/2012 Donaldson 41.6 Donaldson -town 41.6

kV1 41.6 Add 3 Way Switch on 41.6 kV line between

Donaldson 115 kV substation to Donaldson distribution sub.

MN Proposed $160,000 Y B

B in MTEP11 West OTP 3465 6391 12/31/2012 Donaldson 115 kV Donaldson 41.6 kV 115 41.6 Add 3 new 115 kV Breakers & expand substation to accommodate wind farm.

MN Proposed $1,500,000 Y B

B in MTEP11 West XEL 3201 5771 1/1/2025 Brookings DC Station for 6400 MW 800 6400 SD Conceptual $274,500,000 Y BB in MTEP11 West/CenMEC, AmerenMO 3201 5769 1/1/2025 IA-B Hang Rock 1 765 6400 IA/MO/IL/IN/OH 6401 Conceptual $2,297,669,299 Y BB in MTEP11 West/NonXEL, Non-MISO 3201 5770 1/1/2025 Brookings County Blue Creek 1 765 6400 MN/IA/IL/IN/OH 6401 Conceptual $1,731,350,174 Y B


















Agreements

MTEP11 MISO Transmission Expansion Plan 2011 Appendix CAppendix C: Project Table 9/7/2011 Project Summary Information from Facility table

Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

C West ATC LLC 3506 Vinburn T-D Interconnection Construct a 69 kV loop through Vinburn distribution Substation on line Y104. This project also includes rerouting the Hampden tap into Vinburn Substation.

WI $3,362,287 12/31/2012 12/31/2012 Proposed 69 C Y

C West ATC LLC 3507 Shoto-Manrap Uprate This project is a thermal uprate of C-55 (MANRAP - SHOTO 69KV)

WI $319,044 3/1/2012 3/1/2012 Proposed 69 C Y

C West ATC LLC 3508 Revere-Northeast Uprate This project is a thermal uprate of C-103 (Revere - Northeast 69KV)

WI $171,475 1/1/2012 1/1/2012 Proposed 69 C Y

C West ATC LLC 3515 Granville Economic Project Uprate 3443 Granville-Tosa 138kV & 3453 Granville-Butler 138kV

WI $1,136,322 12/31/2011 12/31/2011 Proposed 138 C Y

C West GRE 3470 MISO G667 MN $118,182 12/1/2011 12/1/2011 Planned C YC Central AmerenIL 2283 South Bloomington 138-34.5 kV Substation Install 2 new 2000 A, 138 kV Bus-Tie breakers IL Other $1,030,000 6/1/2014 6/1/2014 Proposed 138 C YC Central AmerenIL 2289 Benton-W. Frankfort 138 kV Line Reconductor 9.62 miles of 350 kcmil Cu to carry 1200 A

under summer emergency conditionsIL BaseRel $1,871,000 6/1/2014 6/1/2014 Proposed 138 C Y

C Central AmerenIL 2290 Joppa 345 kV Switching Station 2nd. Xfmr Add 2nd. 345/161 kV, 560 MVA Transformer IL BaseRel Not Shared $4,000,000 6/1/2015 6/1/2015 Proposed 345 161 C YC Central AmerenIL 2293 N. LaSalle-LaSalle Jct. 138 kV Line 1556A Reconductor 9.68 miles of 477 kcmil ACSR to 1600 A

summer emergency capabilityIL $2,515,000 41791 41791 Proposed 138 C Y

C Central AmerenIL 2294 Stallings 345/138 kV Sub - 138 kV Bus-Tie CT Replacement

Reconnect or replace 1200 A CT in the 138 kV Bus-Tie Position 1302 to 2000 A capability.

IL BaseRel 6/1/2013 6/1/2013 Proposed 138 C Y

C Central AmerenIL 2295 W. Mt. Vernon-E. W. Frankfort 345 kV Upgrade terminal equipment to 3000 A continuous capability

IL Other $1,366,000 6/1/2015 6/1/2015 Proposed 345 C Y

C Central AmerenIL 2299 Fargo 138-69 kV Substation Install 138 kV Capacitor Bank IL BaseRel $1,500,000 6/1/2015 6/1/2015 Proposed 138 C YC Central AmerenIL 2300 Hennepin Plant - 138 kV Bus-Tie Breakers Install 2-3000 A, 138 kV Breakers as Bus-Ties in the

Hennepin North and South Buses. Swap connection to Transformer TT2 with breaker position 1556 or 6101.

IL BaseRel Shared $9,124,000 6/1/2019 6/1/2019 Proposed 138 C Y

C Central AmerenIL 2301 Hennepin-Oglesby 138 kV Line 1556 Reconductor 8.37 miles of 477 kcmil ACSR to 1600 A summer emergency capability

IL BaseRel $4,215,000 6/1/2014 6/1/2014 Proposed 138 C Y

C Central AmerenIL 2302 Madison Industrial-Madison State Street 138 kV

Reconductor 2.35 miles of 795 kcmil SAC conductor to 1200 A summer emergency capability

IL BaseRel $710,000 6/1/2015 6/1/2015 Proposed 138 C Y

C Central AmerenIL 2305 Monmouth Substation 138 kV Capacitor Bank

Install 30 Mvar, 138 kV capacitor bank IL BaseRel $1,022,000 6/1/2013 6/1/2013 Proposed 138 C Y

C Central AmerenIL 3024 Bunsonville 2nd. 345/138 kV Transformer Bunsonville 345/138 kV Substation - Install 2nd. 560 MVA Transformer.

IL $5,000,000 6/1/2015 6/1/2015 Proposed 345 138 C Y

C Central AmerenIL 3336 Gilman-Watseka Reconductoring Reconductor to 1600 A summer emergency capability IL $4,763,000 6/1/2014 6/1/2014 Proposed 138 C YC Central AmerenIL 3338 Lanesville Transformer Replacement Replace existing transformer with 560 MVA unit IL $4,000,000 6/1/2013 6/1/2013 Proposed 345 138 C YC Central AmerenIL 3339 Pana, North-Taylorville, South

ReconductoringReconductor to 1600 A summer emergency capability. Upgrade terminal equipment to match.

IL $4,073,000 6/1/2014 6/1/2014 Proposed 138 C Y

C Central AmerenIL 3340 Pawnee, West-Taylorville, South Terminal Equipment

Replace bus conductor at both terminals to 1200 A summer emergency capability

IL $100,000 6/1/2016 6/1/2016 Proposed 138 C Y

C Central AmerenIL 3341 Diamond Star-West Washington Street Reconductoring

Reconductor 336 kcmil ACSR conductor to 1200 A summer emergency capability

IL $375,000 6/1/2015 6/1/2015 Proposed 138 C Y

C Central AmerenIL 3342 Diamond Star-McClean County Sw. Station -Increase Ground Clearance

Increase ground clearance on 2.4 miles of 477 kcmil ACSR conductor

IL $240,000 6/1/2015 6/1/2015 Proposed 138 C Y

C Central AmerenIL 3343 Increase Ground Clearance - Raab Rd.-White Oak Tap


IL $400,000 6/1/2015 6/1/2015 Proposed 138 C Y

C Central AmerenIL 3344 Increase Ground Clearance - El Paso Tap-Minonk


IL $1,300,000 6/1/2015 6/1/2015 Proposed 138 C Y

C Central AmerenIL 3345 Increase Ground Clearance - R.S. Wallace-E. Peoria

Increase ground clearance on 0.6 mile of 477 kcmil ACSR conductor.

IL $60,000 6/1/2016 6/1/2016 Proposed 138 C Y

C Central AmerenIL 3346 Reconductor Mason-Holland Reconductor 0.05 mile 795 kcmil ACSR to 1200 A summer emergency capability

IL $25,000 6/1/2016 6/1/2016 Proposed 138 C Y

C Central AmerenIL 3347 Reconductor Mason-San Jose Rail Reconductor 0.05 mile 795 kcmil ACSR to 1200 A summer emergency capability

IL $25,000 6/1/2016 6/1/2016 Proposed 138 C Y

C Central AmerenIL 3351 Wood River 138 kV Bus-Tie Breakers Install 2-2000 A, 138 kV bus-tie breakers IL $2,000,000 6/1/2015 6/1/2015 Proposed 138 C YC Central AmerenIL 3352 West Tilton 138 kV Capacitor Bank Install 40 Mvar, 138 kV capacitor bank. IL $1,500,000 6/1/2013 6/1/2013 Proposed 138 C YC Central AmerenIL 3353 Edwards-Keystone 138 kV - Breaker

Replacement at KeystoneReplace 138 kV, 1200 A breaker and terminal equipment at Keystone terminal to 2000 A capability

IL $1,100,000 6/1/2012 6/1/2012 Proposed 138 C Y

C Central AmerenIL 3354 Edwards-Caterpillar Sub 1 - Increase Ground Clearance

Increase ground clearand on 795 kcmil ACSR and 927 ACAR conductor

IL $950,000 6/1/2014 6/1/2014 Proposed 138 C Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

C Central AmerenIL 3362 H100 Generator connection - Sidney-Rantoul Jct.

Install a 3-position ring bus to facilitate connection of wind farm (H100) to the Sidney-Rantoul Jct. 138 kV line.

IL $3,240,000 9/30/2013 9/30/2013 Proposed 138 C Y

C Central AmerenIL 3369 Quincy, East Sub. - Replace Transformer #3

Replace 138-34.5 kV Transformer Bank #3 with a 112 MVA unit. Replace 600 A, 138 kV disconnect switch with minimum 800 A capability

IL $100,000 6/1/2012 6/1/2012 Planned 138 C Y

C Central AmerenMO 2296 Belleau 345/138 kV Substation - 2nd. Xfmr Install 2nd. 560 MVA, 345/138 kV Transformer MO BaseRel Not Shared $8,335,000 6/1/2013 6/1/2013 Proposed 345 138 C YC Central AmerenMO 2297 Belleau 345/138 kV Substation - Install 138

kV capacitor bankInstall 138 kV, 120 Mvar capacitor bank (as 2-60 Mvar stages) At Belleau Substation

MO Other $3,071,000 6/1/2013 6/1/2013 Proposed 138 C Y

C Central AmerenMO 2975 Dupo Ferry-Selma-1 - Connection to Wings Enterprises

Dupo Ferry-Selma-1 138 kV Line - Install 3 position 138 kV ring bus and extend 138 kV line to serve a customer substation (Wings Enterprises). 3-138 kV, 1200A PCB's

MO $1,141,000 12/1/2012 12/1/2012 Proposed 138 C Y

C Central AmerenMO 3356 Tegeler-Osage Disconnect Switch Replacement

Replace 138 kV disconnect switch at Freeburg with new 1200 A switch

MO $200,000 12/1/2012 12/1/2012 Planned 138 C Y

C Central AmerenMO 3364 Prairie Dell Substation Install 138 kV breakers, build 3.1 miles of new 138 kV double circuit line, reuse a total of 9.6 miles of 34.5 kV line at 138 kV to establish supplies to Prairie Dell Substation

MO $11,100,000 6/1/2015 6/1/2015 Proposed 138 C Y

C Central AmerenMO 3365 Delbridge Substation High-Side Transfer Install 2000 A breaker and 2-2000 A 138 kV motor operated disconnect switches

MO $2,221,000 12/1/2011 12/1/2011 Proposed 138 C Y

C Central AmerenMO 3366 Wallen Creek Substation High-Side Transfer

Install 2000 A breaker and 2-2000 A 138 kV motor operated disconnect switches

MO $2,221,000 12/1/2011 12/1/2011 Proposed 138 C Y

C Central AmerenMO 3367 Pershall Substation Install 4-2000 A breaker ring bus and connect to Berkeley-Sioux-1 138 kV to establish 138 kV connections for Pershall 138-12.47 kV Sub

MO $4,631,000 9/1/2013 9/1/2013 Proposed 138 C Y

C Central AMRN 3197 Oak Grove - Kewanee 161 kV Build new 161 kV circuit from Oak Grove to Kewanee IL MVP $61,000,000 5/1/2014 6/1/2017 Proposed 161 138 C YC Central AMRN 3198 Oak Grove - Kewanee 345 kV Build new 345 kV circuit from Oak Grove to Kewanee IL MVP $86,000,000 5/1/2014 6/1/2017 Proposed 345 138 C YC Central DEM 2795 Pioneer 765 New 765 kV line from Rockport (AEP) to Greentown

(DEM)IN $1,000,000,000 5/1/2015 5/1/2015 Proposed 765 C Y

C Central DEM 2862 Staunton to Lonestar Jct 138kV - 13802 ckt. Uprate

Uprate Staunton to Greencastle Jct to Lonestar Jct 13802 circuit 336ACSR for 100C cond temp operation (Lone Star Jct switches may also need upgraded to 1200A)

IN $350,000 6/1/2016 6/1/2016 Planned 138 C Y

C Central IPL, HE 2901 Hanna - Bloomington 345 kV Line Economic Project Portfolio

Add a new 345 kV line from IPL Hanna - IPL Franklin Township - HE Bloomington Substation, Close the Duke Wheatland Substation Tie Breakers and Upgrade the rating of the 345 kV line from IPL Petersburg - Duke Wheatland - AEP Breed to 1386 MVA. Closing the Duke Wheatland bus tie breakers connects the IPL Petersburg-Duke Wheatland-AEP Breed line into the Duke Wheatland 345 kV substation.

IN $70,900,000 Proposed 345 C Y

C West ATC LLC 1689 Ripon Capacitor Banks Upgrade 4.1 MVAR capacitor bank to 8.2 MVAR and install a new 8.2 MVAR capacitor bank at Ripon 69 kV substation

WI Not Shared $895,300 6/1/2015 6/1/2015 Conceptual 69 C Y

C West ATC LLC 1700 Ripon-Metomen 69 kV line Construct a 69 kV line from SW Ripon to the Ripon-Metomen 69 kV line

WI Not Shared 9/30/2015 9/30/2015 Conceptual 69 C Y

C West ATC LLC 2779 New Chandler-18th Road 138 kV line + 18th Road 138/69 kV SS and xfmr

Build a new 6-mile 138 kV line from Chandler to 18th Road, add a new 138/69 kV SS and 138/69 kV 150 MVA xfmr at 18th Road

MI WI TBD TBD $22,000,000 6/1/2014 6/1/2014 Proposed 138 69 C Y

C West ATC LLC 3096 Uprate Inland line Munising-Blaney Park 69kV

Increase ground clearance for the Inland line Munising-Blaney Park 69kV to 167 deg f (37 MVA) clearance

MI $21,003,000 6/1/2014 6/1/2014 Conceptual 69 C Y

C West ATC LLC 3125 Install a 345/138kV Tr at Arnold Tap the Plains-Dead River 345kV line into the Arnold 138kV substation and add a 345/138kV transformer

MI $16,000,000 6/1/2015 6/1/2015 Proposed 345 138 C Y

C West ATC LLC 3158 Petenwell 138/69kV Transformer Replacement

Petenwell 138/69kV Transformer Replacement WI $3,246,000 6/1/2015 6/1/2015 proposed 138 69 C Y

C West ATC LLC 3159 West Middleton-Timberlane-Stage Coach Uprate

West Middleton-Timberlane-Stage Coach 69kV line Uprate

WI $1,808,043 6/1/2015 6/1/2015 Conceptual 69 C Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

C West GRE 2569 Shoal Lake (Lawrence Lake) 115 kV line Shoal Lake (Lawrence Lake) 115 kV line MN Other Not Shared Distribution $6,450,515 12/2/2013 12/2/2013 Planned 115 C YC West GRE 2600 Big Sandy (LCP) 4.0 mile, 69 kV line Big Sandy (LCP) 4.0 mile, 69 kV line MN Other Not Shared Distribution $5,149,000 10/30/2015 10/30/2015 Planned 69 C YC West GRE 2632 Onigum 115 kV Conversion Onigum 115 kV Conversion MN $5,300,000 12/1/2013 12/1/2013 Proposed 115 C YC West GRE 3393 Peterson 115 kV Distribution Convert Peterson Substation from 24 kV to 115 kV

operationMN Other Not Shared Reliability $742,690 11/1/2013 11/1/2013 Planned 115 C Y

C West OTP, XEL, GRE, MP, MHEB

3085 Dorsey - Maple River - Helena 500kV Dorsey - Maple River 50% series compensated 500kV line with one 500/345kV 1,200 MVA transformer at Maple River. Maple River - Helena 50% series compensated 500kV line with two 1,200MVA transformers at Helena.

MN TDSP Direct Assigned $1,180,000,000 6/1/2017 6/1/2017 Proposed 500 345 C Y

C West ITCM 1746 Lakefield-Adams 161kV Rebuild Rebuild Lakefield-Fox Lake-Rutland-Winnebago-Hayward-Adams 161kV line to double ckt 345 & 161kV. Allow for a 345kV line position for future use.

MN BaseRel $97,580,000 12/31/2011 12/31/2015 Proposed 161 C Y

C West OTP, XEL 3204 Sheyenne - Audubon 230 kV line Sheyenne - Audubon 230 kV line MN ND $6,000,000 12/31/2015 12/31/2015 Planned 230 C YC West ATC LLC 3510 Mukwonago-St Martins 138 kV Rebuild Rebuild Mukwonago-Edgewood-St. Martins 138 kV Line,

includes replacing jumpers at Edgewood and Mukwonago

WI $19,200,000 6/1/2017 6/1/2017 Proposed 138 C Y

C West ATC LLC 3511 Edgewater-Saukville 345 kV Uprate AM project to uprate Edgewater to Saukville line clearance issues

WI $1,798,252 11/14/2011 11/14/2011 Proposed 345 C Y

C Central AmerenIL 1536 Latham-Mason City - Reconductor Reconductor from Latham Tap to Kickapoo Tap IL $4,670,000 6/1/2014 6/1/2014 Proposed 138 C YC Central AmerenIL 1538 Pana, North-Ramsey, East - Rebuild Line Reconductor 18.43 miles of line to 2000 A summer

emergency capability.IL $5,500,000 6/1/2015 6/1/2015 Proposed 138 C Y

C Central AmerenIL 1539 Roxford Substation - Install 345 kV PCB Install 345 kV PCB on Roxford-Stallings line position IL $1,000,000 6/1/2015 6/1/2015 Proposed 345 C YC Central AmerenIL 1540 Sidney-Windsor - Reconductor Reconductor 13.1 miles to 1600 A Summer Emergency

CapabilityIL $3,900,000 6/1/2014 6/1/2014 Proposed 138 C Y

C Central AmerenIL 2232 MTEP08 Reference Future EHV Overlay - East Moline to Kewanee

Build 345 kV circuit from East Moline to Kewanee in Illinois

IL $44,000,000 8/1/2018 8/1/2018 Conceptual 345 138 C Y

C Central AmerenIL 2233 MTEP08 Reference Future EHV Overlay - Kewanee to Tazewell

Build 345 kV circuit from Kewanee to Tazewell in Illinois IL $85,000,000 8/1/2018 8/1/2018 Conceptual 345 C Y

C Central AmerenIL 2242 MTEP08 Reference Future EHV Overlay - Norris City to Albion

Build 345 kV circuit from Norris City to Albion in Illinois IL $50,000,000 6/1/2020 6/1/2020 Conceptual 345 C Y

C Central AmerenIL 2983 Mt. Carmel Capacitor Banks Mt. Carmel - Install capacitor bank(s). IL $1,500,000 6/1/2014 6/1/2014 Proposed 138 C YC Central AmerenIL 2985 Monmouth Blvd. Capacitor Bank Monmouth Blvd 138/69 kV Substation - Install 138 kV 30

Mvar capacitor bank and circuit breaker.IL $1,500,000 6/1/2014 6/1/2014 Proposed 138 C Y

C Central AmerenIL 2994 Gillespie Macoupin Substaiton - 2nd. Transformer

Gillespie Macoupin 138-34.5 kV Substation - Tap Wood River-North Staunton 138 kV Line 1436 and make a 138 kV 'in-out' arrangement at the substation with installation of the 2nd. 138-34.5 kV transformer. 2-2000 A, 138 kV PCB's needed.

IL $2,000,000 6/1/2015 6/1/2015 Proposed 138 C Y

C Central AmerenIL 2995 Brokaw Substation Bus Conductor Replacment

Brokaw 345/138 kV Substation - Replace 477 kcmil ACSR Bus Conductor in Brokaw-Normal East 138 kV Line 1578 position with conductor capable of carrying 1200 A continuously.

IL $100,000 6/1/2015 6/1/2015 Proposed 138 C Y

C Central AmerenIL 2999 LaSalle-Oglesby Main Line 1496 Reconductoring

LaSalle-Oglesby Main 138 kV Line 1496 - Reconductor 2.16 miles of 477 kcmil ACSR and 336 kcmil ACSR with conductor capable of carrying 1200 A under summer emergency conditions.

IL $650,000 6/1/2015 6/1/2015 Proposed 138 C Y

C Central AmerenIL 3001 Mascoutah Area 345/138 kV Substation Mascoutah Area 345/138 kV Substation - Install a new 345/138 kV Substation. Supply from the Baldwin-Prairie State 345 kV line. 1-560 MVA 345/138 kV transformer, 3-345 kV PCB's, 1-138 kV PCB.

IL $9,000,000 6/1/2015 6/1/2015 Proposed 345 138 C Y

C Central AmerenIL 3002 N. Decatur-Clinton Rt. 54 Line 1313 Reconductoring

N. Decatur-Clinton Rt. 54 138 kV Line 1313 - Reconductor 5.41 miles of 336 kcmil ACSR conductor in the N. Decatur-County Hwy. 20 line section with conductor capable of carrying 1200 A under summer emergency conditions.

IL $1,650,000 6/1/2015 6/1/2015 Proposed 138 C Y

C Central AmerenIL 3004 Gilman Capacitor Bank Gilman 138-69 kV Substation - Install 138 kV capacitor bank and PCB

IL $1,500,000 6/1/2015 6/1/2015 Proposed 138 C Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

C Central AmerenIL 3005 S. Belleville-Tilden Terminal Equipment S. Belleville-Tilden 138 kV Line 1526 - Replace 1200 A terminal equipment (PCB, CT's, and bus conductor) at S. Belleville Substation with equipment capable of carrying 2000 A continuously.

IL $1,100,000 12/1/2015 12/1/2015 Proposed 138 C Y

C Central AmerenIL 3006 Vermilion-Champaign Reconductoring Vermilion-Champaign 138 kV Line 1396 - Reconductor 26.8 miles of 477 kcmil ACSR with minimum 1200 A SE capability.

IL $8,100,000 6/1/2016 6/1/2016 Conceptual 138 C Y

C Central AmerenIL 3011 Joppa-Mound City 161 kV Line Reconductoring

Joppa-Mound City 161 kV Line - Reconductor 23.4 mi. 556 ACSR with conductor capable of carrying 1200 A under summer emergency conditions.

IL $7,100,000 6/1/2017 6/1/2017 Conceptual 161 C Y

C Central AmerenIL 3012 Normal East Substation Terminal Upgrade Normal East 138/34 kV Substation - Upgrade 600 A terminal equipment to minimum 1200 A SE capability in the Brokaw-Normal East 138 kV line terminal.

IL $100,000 6/1/2017 6/1/2017 Proposed 138 C Y

C Central AmerenIL 3013 Turkey Hill-Cahokia Reinsulation to 345 kV Turkey Hill-Cahokia 345 kV - Reinsulate the existing Turkey Hill-Cahokia 138 kV Line 1492 (approx. 19 miles) to 345 kV service.

IL $1,000,000 6/1/2017 6/1/2017 Proposed 345 C Y

C Central AmerenIL 3014 Cape-Joppa 161 kV Line Reconductoring Cape-Joppa 161 kV Line - Reconductor line (40.27 miles) to 1600 A Summer Emergency Capability.

IL $12,100,000 6/1/2018 6/1/2018 Proposed 161 C Y

C Central AmerenIL 3015 Grand Tower-E.W Frankfort 345 kV Line Grand Tower-E.W. Frankfort 345 kV - New 41 mile, 345 kV, 3000 A line. 345 kV PCBs: 2-Grand Tower; 2- E.W. Frankfort

IL $82,000,000 6/1/2018 6/1/2018 Conceptual 345 C Y

C Central AmerenIL 3016 Galesburg Substation Transformer Addition Galesburg 345/138 kV Substation - 1-560 MVA 345/138 kV transformer, 3-345 kV PCBs, 1-138 kV PCB

IL $18,480,000 11/15/2019 11/15/2019 Conceptual 345 138 C Y

C Central AmerenIL 3018 Tazewell-Tremont 138 kV Line Tazewell-Tremont 138 kV Line - Physically inspect 3 miles of existing deenergized 477 kcmil ACSR line near Tremont Tap (Havana-Danvers 138 kV Line 1352). Construct 3 miles of new 138 kV line with 1200 A summer emergency capability to extend line to Tazew

IL $2,922,000 6/1/2018 6/1/2018 Conceptual 138 C Y

C Central AmerenIL 3019 Oglesby 345/138 kV Transformer Addition Oglesby 345/138 kV Substation - 1-560 MVA 345/138 kV transformer, 1-138 kV PCB

IL $6,000,000 6/1/2018 6/1/2018 Conceptual 345 138 C Y

C Central AmerenIL 3021 Mound City-Charleston 161 kV Line Mound City-Charleston 161 kV Line - New 20 mile, 1200 A summer emergency capability line. 3-161 kV PCBs: 2-Mound City, 1-Charleston.

IL $23,000,000 6/1/2018 6/1/2018 Conceptual 161 C Y

C Central AmerenIL 3023 E. Collinsville-Porter Road 138 kV Reconductoring

E. Collinsville-Porter Road 138 kV Line 1432 - Reconductor 5.15 miles of 477 kcmil ACSR with conductor capable of carrying 2000 A under summer emergency conditions.

IL $1,600,000 6/1/2018 6/1/2018 Proposed 138 C Y

C Central AmerenIL 3026 Havana Plant-138 kV Connection for R.A.T. Havana Plant 138 kV Switchyard - Add 138 kV Connection for new Reserve Auxiliary Transformer needed to supply new pollution control load.

IL $100,000 6/1/2019 6/1/2019 Conceptual 138 C Y

C Central AmerenIL 3029 Gibson City Plant - Increase Outlet Line Capacity

Gibson City Plant 138 kV Outlet - Increase capability of Gibson City-Brokaw and Gibson City-Paxton 138 kV lines.

IL $6,750,000 6/1/2019 6/1/2019 Conceptual 138 C Y

C Central AmerenIL 3033 Dupo Area 345/138 kV Substation Dupo Area 345/138 kV Substation - 1-560 MVA Transformer, 8-138 kV PCBs. New 8 mi. 3000 A 345 kV line from Cahokia Substation, 2-345 kV PCBs @ Cahokia, and 138 kV Outlet to Cahokia-Meramec circuits near Lemay Taps. New Dupo-Dupo Ferry 138 kV 2000 A line.

IL $22,192,000 6/1/2019 6/1/2019 Conceptual 345 138 C Y

C Central AmerenIL 3035 Kinmundy-Salem, West 138 kV - Increase Ground Clearance

Kinmundy-Salem, West 138 kV line - Increase clearances to ground.

IL $1,100,000 6/1/2019 6/1/2019 Conceptual 138 C Y

C Central AmerenIL 3036 Latham Substation 2nd. 345/138 kV Transformer

Latham 345/138 kV Substation - Install 2nd. 345/138 kV, 448 MVA Transformer. 1-345 kV PCB, 1-138 kV PCB.

IL $5,000,000 6/1/2019 6/1/2019 Conceptual 345 138 C Y

C Central AmerenIL 3037 Rush Island-Dupo 345 kV Line Rush Island-Dupo 345 kV Line - New 27 mile, 3000 A summer emergency capability line. Design for double-circuit. 2-345 kV PCBs: 1-Rush Island, 1-Dupo.

IL $49,000,000 6/1/2019 6/1/2019 Conceptual 345 C Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

C Central AmerenIL 3039 Grand Tower-Joppa 345 kV Line Grand Tower-Joppa 345 kV Line - New 50 mile 345 kV, 3000 A line. 345 kV PCBs: 2-Grand Tower; 1-Joppa.

IL $100,000,000 6/1/2020 6/1/2020 Conceptual 345 C Y

C Central AmerenIL 3040 Tazewell-S. Bloomington 345 kV Line Tazewell-South Bloomington 345 kV Line - New 35 mile, 345 kV, 3000 A line. 345 kV PCBs: 2 at Tazewell, 3 at South Bloomington switching station.

IL $87,500,000 6/1/2020 6/1/2020 Conceptual 345 C Y

C Central AmerenIL 3043 LaSalle-Oglesby 345 kV Line LaSalle-Oglesby 345 kV Line - New 22 mi. 3000 A summer emergency capability line; 1-345 kV PCB at LaSalle, 1-138 kV PCB at Oglesby.

IL $44,000,000 6/1/2020 6/1/2020 Conceptual 345 C Y

C Central AmerenIL 3044 Roxford-Pawnee 345 kV Line Roxford-Pawnee 345 kV Line - New 60 mile, 3000 A summer emergency capability line. 3-345 kV PCBs (1-Roxford, 2-Pawnee). Install WAMS - PMU at Pawnee on new line terminal.

IL $120,000,000 6/1/2021 6/1/2021 Conceptual 345 C Y

C Central AmerenIL 3175 Palmyra Tap-Pawnee 765 kV Line New 117 mile 765 kV, approx. 4000 A line IL $347,557,224 6/1/2020 6/1/2020 Conceptual 765 C YC Central AmerenIL 3176 Pawnee-Breed 765 kV Line New 140 mile 765 kV, approx. 4000 A line IL $404,702,844 6/1/2020 6/1/2020 Conceptual 765 C YC Central AmerenIL 3177 Pawnee 765/345 kV Substation New 2250 MVA, 765/345 kV Substation IL $28,200,000 6/1/2020 6/1/2020 Conceptual 765 345 C YC Central AmerenIL 3178 Pawnee-Powerton 765 kV Line New 79 mile 765 kV, approx. 4000 A line IL $224,509,670 6/1/2020 6/1/2020 Conceptual 765 C YC Central AmerenIL 3183 Grand Tower 765/345 kV Substation New 2250 MVA, 765/345 kV Substation IL $28,200,000 6/1/2020 6/1/2020 Conceptual 765 345 C YC Central AmerenIL 3184 Grand Tower-Rockport 765 kV Line New 172 mile 765 kV, approx. 4000 A line IL $494,506,712 6/1/2020 6/1/2020 Conceptual 765 C YC Central AmerenIL 3349 East Galesburg Breaker Replacement Replace breaker at East Galesburg with 1200 A breaker.

Replace terminal equipment to 1200 A capability.IL $1,000,000 6/1/2020 6/1/2020 Conceptual 138 C Y

C Central AmerenIL 3350 East Kewanee-Princeton Tap of Hennepin-East Kewanee Reconductor

Reconductor 477 kcmil ACSR conductor to 1200 A summer emergency capability. Replace terminal equipment at East Kewanee to 1200 A capability.

IL $2,656,000 12/1/2012 12/1/2012 Planned 138 C Y

C Central AmerenIL, Non-MISO

2197 MTEP08 Reference Future EHV Overlay - St. Francois to Rockport

Builds 765 kV circuit from St. Francois Station in Missouri to Rockport Station in Indiana (Located in 3 States: 15% in MO, 56% in IL, 29% in IN

IL IN,MO $599,000,000 8/1/2018 8/1/2018 Conceptual 765 C Y

C Central AmerenIL, Non-MISO

2215 MTEP08 Reference Future EHV Overlay - Coffeen to Sullivan

Build 765 kV circuit from Coffeen Station in Illinois to Sullivan Station in Indiana

IL IN $322,000,000 8/1/2018 8/1/2018 Conceptual 765 C Y

C Central AmerenMO 2122 Belleau - GM - 3 to AECI Enon Substation 161 kV line

Belleau - GM - 3 to AECI Enon Substation 161 kV line MO $1,896,500 11/17/2011 11/17/2011 Planned 161 C Y

C Central AmerenMO 2292 Kelso 345/161 kV Substation Replace 336 MVA, 345/161 kV Transformer with 450 MVA Transformer

MO BaseRel $6,134,000 6/1/2016 6/1/2016 Proposed 345 161 C Y

C Central AmerenMO 2987 Taum Sauk Capacitor Banks Taum Sauk 138 kV Capacitor Banks - 2-30 Mvar banks; 2-138 kV synchronous PCBs.

MO $1,500,000 6/1/2014 6/1/2014 Conceptual 138 C Y

C Central AmerenMO 2990 Conway-Tyson-3 and -4 Increase Ground Clearance

Conway-Tyson-3 and -4 138 kV - Increase ground clearance on Tyson-Orchard Gardens sections (7 miles)

MO $700,000 6/1/2014 6/1/2014 Proposed 138 C Y

C Central AmerenMO 2991 Mason Transformer Replacement Mason 345/138 kV Substation - Replace 345/138 kV, 560 MVA Transformer #2 with a 700 MVA unit

MO $5,000,000 6/1/2014 6/1/2014 Proposed 345 138 C Y

C Central AmerenMO 2993 Dupo Ferry-Buck Knob Reconductoring Dupo Ferry-Buck Knob 138 kV Line - Replace 22 mi. of 2-300 ACSR with maximum size conductor existing towers will support.

MO $6,600,000 6/1/2014 6/1/2014 Proposed 138 C Y

C Central AmerenMO 2996 Montgomery-Spencer Creek - Increase Ground Clearance

Montgomery-Spencer Creek 345 kV - Increase ground clearance on 28 miles of 795 kcmil ACSR conductor and upgrade terminal equipment at Montgomery Substation.

MO $9,500,000 6/1/2015 6/1/2015 Proposed 345 C Y

C Central AmerenMO 2998 Overton 2nd. Transformer Overton 345/161 kV Substation - 2nd Transformer - 450 MVA; 1-161 kV PCB, 2-345 kV PCBs, 345 kV Ring Bus

MO $5,000,000 6/1/2015 6/1/2015 Conceptual 345 161 C Y

C Central AmerenMO 3000 Miller Substation Transformer Addition Miller 138/161 kV Substation - Install a new 300 MVA 138/161 kV transformer to convert Miller-Zion line to 161 kV operation and increase voltage support to Jefferson City, Missouri area.

MO $5,000,000 6/1/2015 6/1/2015 Proposed 345 161 C Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

C Central AmerenMO 3007 Camden-Ullman 138 kV Line Camden-Ulman 138 kV Line - Construct approximately 16 miles of 138 kV line between Camden Substation and Ulman (switching station connecting to Maries-Osage-1 138 kV line), with 1600 A summer emergency capability. Install 300 MVA, 161/138 kV transformer

MO $29,000,000 6/1/2016 6/1/2016 Proposed 161 138 C Y

C Central AmerenMO 3008 Overton Capacitor Bank Overton 161 kV Capacitor Bank - 1-90 Mvar capacitor bank, 1-161 kV synchronous PCB, 1-161 kV reactor.

MO $1,500,000 6/1/2016 6/1/2016 Conceptual 161 C Y

C Central AmerenMO 3020 Overton-Columbia Terminal Upgrade Overton-Huntsdale-Columbia 161 kV - Replace 800 A CT at Overton Terminal with 1200 A unit.

MO $50,000 6/1/2018 6/1/2018 Proposed 161 C Y

C Central AmerenMO 3025 Rivermines-N. Farmington - Second 138 kV Line

Rivermines-N. Farmington 138 kV Line - Construct a second 5.5 mile 138 kV line.

MO $7,500,000 6/1/2019 6/1/2019 Proposed 138 C Y

C Central AmerenMO 3027 Campbell Substation 2nd. 345/138 kV Transformer

Campbell 345/138 kV Substation - 2nd 560 MVA transformer; New 12.8 mi. Roxford-Campbell 345 kV 3000 A summer emergency capability line; 2-345 kV PCBs (1-Campbell, 1-Roxford); 1-138 kV PCB @ Campbell.

MO Shared $6,000,000 6/1/2019 6/1/2019 Conceptual 345 138 C Y

C Central AmerenMO 3028 Campbell-Euclid-Page 138 kV Line Rebuild Campbell-Euclid-Page 138 kV Line - Rebuild 5.25 mi. double-circuit 138 kV 2000 A SE capability. 3-138 kV PCBs (2-Campbell, 1-Page). Operate Euclid 138 kV Bus-Tie normally closed.

MO $21,300,000 6/1/2019 6/1/2019 Conceptual 345 C Y

C Central AmerenMO 3030 Labadie-Mason 345 kV Line #3 Labadie-Mason 345 kV Line #3 - New 25 mi. 3000 A summer emergency capability line designed for double-circuit. 345 kV PCBs: 1-Labadie, 1- Mason. Install WAMS - PMU at Labadie on new line terminal

IL MO $44,250,000 6/1/2019 6/1/2019 Conceptual 345 C Y

C Central AmerenMO 3031 Page Area 345/138 kV Substation Page Area 345/138 kV Substation - 2-560 MVA transformers. 9-138 kV PCBs: 2-transformer, 1-bus-tie, 6-line (2-Warson, 2-Page, 2-Hunter).

MO $11,000,000 6/1/2019 6/1/2019 Conceptual 345 138 C Y

C Central AmerenMO 3032 Campbell-Page-Mason 345 kV Line Campbell-Page-Mason 345 kV Line - New 16.5 mi. 3000 A summer emergency capability line, plus reutilization of 14.5 miles of existing Page-Sioux-4 at 345 kV.

MO $35,750,000 6/1/2019 6/1/2019 Proposed 345 C Y

C Central AmerenMO 3034 Loose Creek-Kingdom City 345 kV Line Loose Creek-Kingdom City 345 kV Line - New 25 mile 345 kV, 3000 A line. 2-345 kV PCBs at Loose Creek, 2-345 kV PCBs at Kingdom City..

MO $52,000,000 6/1/2019 6/1/2019 Conceptual 345 C Y

C Central AmerenMO 3038 Loose Creek-Barnett-Windsor-Pleasant Hill 345 kV Line

Loose Creek-Barnett-Windsor-Pleasant Hill 345 kV Line - New 138 mile 345 kV, 3000 A line. 560 MVA, 345/161 kV transformer at Barnett Substation. 345 kV PCBs: 2 at Loose Creek, 2 at Barnett, 2 at Windsor, 2 at Pleasant Hill.

MO $249,000,000 6/1/2019 6/1/2019 Conceptual 345 C Y

C Central AmerenMO 3042 Palmyra-Thomas Hill-Fairport 345 kV Line Palmyra-Thomas Hill-Fairport - New 122 mile 345 kV, 3000 A line. 345 kV PCBs: 2 at Palmyra, 2 at Thomas Hill, 2 at Fairport.

MO $220,000,000 6/1/2020 6/1/2020 Conceptual 345 C Y

C Central AmerenMO 3045 St. Francois-Fletcher 345 kV Line St. Francois-Fletcher 345 kV Line - New 48 mi. 3000 A SE capability. 345 kV terminals at St. Francois & Fletcher. Install WAMS - PMU at St. Francois on new line terminal.

MO $86,000,000 6/1/2021 6/1/2021 Conceptual 345 C Y

C Central AmerenMO 3171 West Adair-Fairport 345 kV Line New 113 mile 345 kV, 3000 A line MO $171,818,625 6/1/2018 6/1/2018 Conceptual 345 C YC Central AmerenMO 3173 Fairport-Palmyra Tap 765 kV Line New 176 mile 765 kV, approx. 4000 A line MO $500,335,836 6/1/2020 6/1/2020 Conceptual 765 C YC Central AmerenMO 3174 Palmyra Tap 765/345 kV Substation New 2250 MVA, 765/345 kV Substation MO $28,200,000 6/1/2020 6/1/2020 Conceptual 765 345 C YC Central AmerenMO 3179 Palmyra Tap-Montgomery 765 kV Line New 68 mile 765 kV, approx. 4000 A line MO $192,436,860 6/1/2020 6/1/2020 Conceptual 765 C YC Central AmerenMO 3180 Montgomery 765/345 kV Substation New 2250 MVA, 765/345 kV Substation MO $28,200,000 6/1/2020 6/1/2020 Conceptual 765 345 C YC Central AmerenMO 3181 Montgomery-St. Francois 765 kV Line New 104 mile 765 kV, approx. 4000 A line MO $295,069,852 6/1/2020 6/1/2020 Conceptual 765 C YC Central AmerenMO 3182 St. Francois-Grand Tower 765 kV Line New 63 mile 765 kV, approx. 4000 A line MO $193,607,736 6/1/2020 6/1/2020 Conceptual 765 C YC Central AmerenMO 3187 St. Francois 765/345 kV Substation New 2250 MVA, 765/345 kV Substation MO $28,200,000 6/1/2020 6/1/2020 Conceptual 765 345 C YC Central AmerenMO,

AmerenIL2195 MTEP08 Reference Future EHV Overlay -

Montgomery to CoffeenBuilds 765 kV circuit from Montgomery Station in Missouri to Coffeen Station in Illinois

MO IL $343,000,000 8/1/2018 8/1/2018 Conceptual 765 C Y

C Central BREC 3435 Rome Junction to West Owensboro 69 kV reconductor.

Reconductor 5.8 miles of 3/0 and 267 MCM ACSR with 336 MCM ACSS

KY $440,000 12/31/2017 12/31/2017 Proposed 69 C Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

C Central BREC 3436 Wilson to Sacremento 69 kV line addition New 11 mile line and line terminal at Wilson KY $2,100,000 12/31/2018 12/31/2018 Proposed 69 C YC Central BREC 3437 Thruston Junction to East Owensboro

reconductor.Reconductor .4 miles of 3/0 ACSR with 336 MCM ACSR KY $40,000 12/31/2018 12/31/2018 Proposed 69 C Y

C Central BREC 3438 Daviess County to Philpot Tap reconductor. Reconductor 7.7 miles of 267 MCM ACSR with 336 MCM ACSS

KY $580,000 12/31/2018 12/31/2018 Proposed 69 C Y

C Central BREC 3439 Ensor 161/69 kV Substation Construct new 161/69 kV substation with 56 MVA transfomer.

KY $6,200,000 12/31/2022 12/31/2022 Proposed 161 69 C Y

C Central BREC 3440 Reid EHV 161/69 kV transformer Add a 56 MVA transformer to the existing Reid EHV substation.

KY $5,000,000 12/31/2024 12/31/2024 Proposed 161 69 C Y

C Central BREC 3441 Olivet Church Road to Olivet Church Road Tap 69 kV reconductor.

Reconductor 1.4 miles of 4/0 ACSR with 336 MCM ACSS

KY $150,000 12/31/2020 12/31/2020 Proposed 69 C Y

C Central BREC 3442 White Oak transformer addition Add a second 56 MVA transformer to the White Oak 161/69 kV substation.

KY $1,900,000 12/31/2024 12/31/2024 Proposed 161 69 C Y

C Central BREC 3443 Hardinsburg 161/69 transformer replacements

Replace both 50 MVA 161/69 kV transformers with 100 MVA transformers.

KY $4,000,000 12/31/2017 12/31/2017 Proposed 161 69 C Y

C Central BREC 3444 Meade County 161/69 transformer addition Add a third 56 MVA transformer to the existing Meade County substation.

KY $700,000 12/31/2020 12/31/2020 Proposed 161 69 C Y

C Central BREC 3445 Brandenburg 69 kV capacitor addition Add a 6 MVAR capacitor in the Brandenburg/Battletown area.

KY $300,000 12/31/2020 12/31/2020 Proposed 69 C Y

C Central BREC 3446 Hardinsburg No. 1 to Harned 69 kV reconductor.

Reconductor 2 miles of 3/0 ACSR with 336 MCM ACSS KY $170,000 12/31/2022 12/31/2022 Proposed 69 C Y

C Central DEM 840 Rushville 69kV Cap Add 14.4 MVAR 69kV capacitor at Rushville. IN Other Not Shared $510,845 6/1/2016 6/1/2016 Planned 69 C NTC Central DEM 1249 Frankfort 230 36MVAR 69kV capacitor Install 36 MVAR 69kV capacitor IN Other Not Shared $632,358 12/31/2016 12/31/2016 Planned 69 C NTC Central DEM 1264 Speed Replace existing 345/138 transformer at Speed with a

new transformer rated at 3,000A or higher.IN BaseRel Shared $7,541,500 6/1/2022 6/1/2022 Alternative 345 138 C Y

C Central DEM 1518 Curliss 138/69 Install new Curliss 138-69 kV sub in the 5884 ckt, 150 MVA xfmr, Install one 69 kV circuit. Convert Glen Este and Batavia dist subs from 34 to 69kV primary voltage.

OH Other Not Shared $9,818,000 6/1/2016 6/1/2016 Proposed 138 69 C Y

C Central DEM 1571 Rockville (IPL) to Avon East new 138KV line

Construct 4.3 miles / 954ACSR of 138kv line from IPL Rockville to Avon East

IN Other $2,980,000 6/1/2015 6/1/2015 Alternative 138 C Y

C Central DEM 1900 Avon Industrial Park 138 (or 69)-12kV new dist sub

Avon Industrial Park (aka Central Logistics) - Construct 69/138-12kV - 22.4 MVA sub and 2.6 mile - 69kV radial line from roughly the Avon South sub - unknown if this will be a 69 or 138 kv sub

IN Other $923,000 6/1/2015 6/1/2015 Proposed 138 12 C NT

C Central DEM 1904 Batesville to Hillenbrand 69kV uprate Uprate 69kV Batesville to Hillenbrand to 100C – 4/0acsr – 2.1 miles – 69107 ckt

IN Other Not Shared $115,961 6/1/2015 6/1/2015 Planned 69 C NT

C Central DEM 2124 Brooklyn to HE Brooklyn 69kV Reconductor Brooklyn Sub to HE Brooklyn Sub reconductor 1.28 miles of 6940 line 4/0 Cu with 954ACSR@100C


C Central DEM 2125 Centerton 138/69kV Bk 1 replacement Upgrade/replace existing 75MVA 138/69kV bank with 120MVA bank

IN Other $3,091,000 6/1/2020 6/1/2020 Planned 138 69 C NT

C Central DEM 2129 Plainfield S. to HE Mooresville Jct 69kV reconductor

Plainfield South to HE Mooresville Jct 69kV reconductor 4/0Cu with 954ACSR - 2.03 miles


C Central DEM 2135 Franklin 230 Sub 69kV Cap Franklin 230 Sub 69kV Cap - Install 36MVAR 69kV bus capacitor bank


C Central DEM 2139 Greenwood West Sub 69kV #2 switch upgrade

Greenwood West Sub - upgrade (or replace, if required) 69kV Loadbreak switch #2 for 1200amp capacity in the 6999 ckt.


C Central DEM 2140 Greenwood West to Lenore Jct 69kV reconductor

Greenwood West to Lenore Jct reconductor 69kV - 6949 ckt. with 477ACSR @ 100C conductor

IN Other $1,377,500 6/30/2015 6/30/2015 Planned 69 C NT

C Central DEM 2144 Franklin 230 to Earlywood 69kv Reconductor

Franklin 230kV sub to Earlywood sub reconductor 1.06 mile - 69kV - 69165 line with 954ACSR@100C


C Central DEM 2145 Franklin 230/69 Bks 1&2 Replacement Franklin 230 sub - Replace 230/69kV banks 1&2 each with a 200MVA LTC transformer

IN Other $4,800,000 6/1/2020 6/1/2020 Planned 230 69 C Y

C Central DEM 2146 HE Honey Creek Jct to Frances Creek Jct 69kv reconductor

HE Honey Creek Jct to Frances Creek Jct. reconductor 69kV - 1.12 mile line section of the 69102 ckt. with 954ACSR 100C conductor.



Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

C Central DEM 2147 Whiteland to Madison J 69kv reconductor Whiteland Sub to Greenwood North Tap to Madison Ave Jct reconductor 3.44 mile 69kV - 6997 line with 954ACSR 100C conductor.

IN Other $1,376,000 6/30/2015 6/30/2015 Planned 69 C NT

C Central DEM 2247 MTEP08 Reference Future EHV Overlay - 'Gwynn 765/345 Autotransformation

Add Gwynn 765/345 kV autotransformer in Indiana IN $20,000,000 8/1/2018 8/1/2018 Conceptual 765 345 C Y

C Central DEM 2328 Speed to HE Bethany 69kV - 6955 Reconductor Ph2

Speed to HE Bethany 69kV - 6955 Reconductor Ph2 - Replace 1.6 miles of 4/0 ACSR with 477 ACSR (new limiter 600A switches)


C Central DEM 2329 Clarksville to Indiana Arsenal 69kv - 6955 ckt. reconductor

Clarksville to Indiana Arsenal 69kv - 6955 ckt. reconductor 1.1 miles of 4/0acsr with 477ACSR at 100C (this is Phase 2 remainder of 4/0ACSR in this line section)


C Central DEM 2330 New Albany to HE Georgetown 69kv - 6970 ckt. Reconductor

New Albany to HE Georgetown 69kv - 6970 ckt. Reconductor 1.24 miles of 4/0acsr with 477acsr@100C


C Central DEM 2864 Centeron to Martinsville 69kV - 69163 ckt. Reconductor

Reconductor the 69kV-69163 ckt - 3.47 miles of 366ACSR 80C and 0.23 miles of 477ACSR 80C to 954ACSR 100C

IN $1,110,000 6/1/2020 6/1/2020 Planned 69 C NT

C Central DEM 2868 Fairfax to Senco 69kV - F868 Reconductor F868 - Reconductor Fairfax to Senco - Replace 4/0 ACSR with 954 ACSR - Approx 4.6 miles

OH $1,711,992 6/1/2014 6/1/2014 Proposed 69 C NT

C Central DEM 2873 Danville E. 69kV looped feed Construct new Danville East substation near HRH hospital - single 22.4MVA transformer - 6945 ckt to be looped through

IN $500,000 6/1/2018 6/1/2018 Proposed 69 12 C NT

C Central DEM 3382 Vincennes Vigo St. 138kV Dist Sub Build new radial 138kV line and add breaker at Vincennes 138kV sub to convert Vigo St. sub from 34kV to 138kV

IN $1,800,000 12/31/2017 12/31/2017 Planned 138 12 C Y

C Central DEM, IPL 2783 Wheatland - Bloomington 345 kV line Build new 345 kV circuits from Wheatland Power Facility to Bloomington substation

IN $105,000,000 5/1/2012 5/1/2012 Proposed 345 C Y

C Central DEM, Non-MISO 2203 MTEP08 Reference Future EHV Overlay - Greentown to Blue Creek

Build 765 kV circuit from Greentown Station to Blue Creek Station in Indiana

IN $191,000,000 8/1/2018 8/1/2018 Conceptual 765 C Y

C Central DEM, Non-MISO 2213 MTEP08 Reference Future EHV Overlay - Ghent to Buffinton

Build 345 kV circuit from Ghent Station to Buffington Station in Kentucky

KY $47,000,000 8/1/2018 8/1/2018 Conceptual 345 C Y

C Central IPL 2246 MTEP08 Reference Future EHV Overlay - Pete 765/345 Autotransformation

Add Pete 765/345 kV autotransformer in Indiana IN $20,000,000 8/1/2018 8/1/2018 Conceptual 765 345 C Y

C Central IPL 2897 Petersburg - Frances Creek - Hanna 345 kV line rating upgrade

Increase line rating from 956 to 1195 MVA IN BaseRel Not Shared $2,500,000 6/1/2013 6/1/2013 Proposed 345 C Y

C Central IPL 2898 Hanna - Southeast 138 kV line rating upgrade

Increase line rating from 287 to 574 MVA. Remove operating guide # 2007-S-012-C Hanna-Southeast-138-IPL.

IN BaseRel Not Shared $4,000,000 6/1/2014 6/1/2014 Proposed 138 C Y

C Central IPL 2899 Guion - Whitestown 345 kV line rating upgrade

Increase line rating from 956 to 1195 MVA IN BaseRel Not Shared $1,000,000 6/1/2015 6/1/2015 Proposed 345 C Y

C Central ITCM, Non MISO 2198 MTEP08 Reference Future EHV Overlay - Rockcreek to Pontiac

Builds 765 kV circuit from Rock Creek Station in Iowa to Pontiac Station in Illinois

IA IL $378,000,000 8/1/2018 8/1/2018 Conceptual 765 345 C Y

C Central MEC, AmerenMo 2194 MTEP08 Reference Future EHV Overlay - Toledo to Montgomery

Builds 765 kV circuit from Toledo Station in Iowa to Montgomery Station in Missouri

IA MO $871,000,000 8/1/2018 8/1/2018 Conceptual 765 C Y

C Central Non-MISO 2199 MTEP08 Reference Future EHV Overlay - Pontiac to Dequine

Builds 765 kV circuit from Pontiac Station in Illinois to Dequine Station in Indiana

IL IN $265,000,000 8/1/2018 8/1/2018 Conceptual 765 C Y

C Central Non-MISO 2200 MTEP08 Reference Future EHV Overlay - Dequine to "Chicago"

Build 765 kV circuit from Dequine Station to New South Chicago Station in Indiana

IN $161,000,000 8/1/2018 8/1/2018 Conceptual 765 C Y

C East ATC LLC, ITC 2208 MTEP08 Reference Future EHV Overlay - Dead River to Livingston

Build 345 kV circuit from Dead River Station to Livingston Station in Michigan

MI $329,000,000 8/1/2018 8/1/2018 Conceptual 345 C Y

C East ITC 694 Saratoga Station Saratoga 345/120 kV switching station MI 12/31/2018 12/31/2018 Proposed 345 120 C YC East ITC 908 Lulu Station Tap the Majestic to Lemoyne and Milan to Allen Junction

to Monroe 3-4 345 kV circuits into a new 345 kV Switching Station at the Lulu site. Project also adds three miles 345 kV double circuit tower from Monroe to cut the Lulu-Leymoyne circuit into Monroe, moving the Leymone 345 kV interconnection with First Energy to the Monroe 3-4 345 kV bus

MI 6/1/2018 6/1/2018 Proposed 345 C Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

C East ITC 1012 Wayne - Newburg Split Establish new Wayne-Newburgh 120 kV circuit 3 using currently paralleled wire from existing Wayne-Newburgh circuit 2

MI 6/1/2014 6/1/2014 Proposed 120 C Y

C East ITC 1295 Quaker to Southfield #2 120 kV Rebuild the existing Quaker - Drexel - Southfield line to double-circuit and construct a new Quaker - Southfield #2 120 kV line (7.5 miles total).

MI 6/30/2016 6/30/2016 Proposed 120 C Y

C East ITC 1382 Michigan 765 kV Backbone Project constructs a 765 kV circuit from AEP's Cook statioMI IN,OH $2,500,000,000 12/31/2016 12/31/2016 Proposed 765 138 C YC East ITC 1550 Hager - Sunset 120 kV Transposes the existing cabled line entrance of the

Hager-Sunset 120 kV Line with the overhead line entrance of the Sunset-Southfield 120 kV line to increase the thermal rating of Hager-Sunset.

MI 5/31/2015 5/31/2015 Proposed 120 C Y

C East ITC 1854 Trenton Channel - Riverview 120kV Install a new 120 kV circuit from Trenton Channel to Riverview utilizing the existing de-energized Trenton Channel to Jefferson circuit to get from Trenton Channel to Jefferson, or rebuild it if required, and then from Jefferson to Riverview either install a new 120 kV single circuit tower line or replace the existing double circuit towers with triple circuit towers. Also reconductor/rebuild Trenton Channel to Jefferson 120 kV #4 circuit (3.53 miles).

MI 6/1/2018 6/1/2018 Proposed 120 C Y

C East ITC 1858 Wayne 345 kV Overloaded S.E. Replacement

Replace various pieces of station equipment that are overloaded at Wayne station under normal conditions and for various contingencies.

MI 41426 41426 Proposed 345 C Y

C East ITC 2205 MTEP08 Reference Future EHV Overlay - Evans to Spreague

Build 765 kV circuit from Evans Station to Spreague Station in Michigan

MI $304,000,000 8/1/2018 8/1/2018 Conceptual 765 C Y

C East ITC 2206 MTEP08 Reference Future EHV Overlay - Spreague to Bridgewater

Build 765 kV circuit from Spreague Station to Bridgewater Station in Michigan

MI $135,000,000 8/1/2018 8/1/2018 Conceptual 765 345 C Y

C East ITC 2933 Superior - Wayne 120 kV Rebuild Rebuild the 10.5 miles of the Superior to Wayne 120 kV circuit from 477 ACSR to 954 ACSR on new structures.

MI BaseRel Shared $8,800,000 6/1/2013 6/1/2013 Proposed 120 C Y

C East ITC 3129 Belle River - Bunce Creek 230 kV Construct a new 230 kV line between Belle River and Bunce Creek substations. This project includes a 345/230 kV transformer at Belle River and 230/120 kV transformer at Bunce Creek (13.5 miles total).

MI 6/1/2017 6/1/2017 Proposed 345 230 C Y

C East ITC 3130 Thumb Area 120 kV Capacitors Install a 50 MVAR capacitor at the Stratford and Wabash 120 kV stations.

MI 6/1/2013 6/1/2013 Proposed 120 C Y

C East ITC 3140 Belle River - St. Clair #2 345 kV Build a second 345 kV circuit from Belle River to St. Clair (1.12 miles total).

MI 6/1/2017 6/1/2017 Proposed 345 C Y

C East ITC 3141 Redrun - Chestnut #2 120 kV & L-N-NW - Lincoln 120 kV

Build a new 120 kV line between Redrun and Chestnut (5 miles total)

MI 6/1/2014 6/1/2014 Proposed 120 C Y

C East ITC 3142 L-N-NW - Lincoln 120 kV Rebuild 2.95 miles of 477 ACSR to 954 ACSR on the L-N-NW - Lincoln 120 kV line

MI 6/1/2016 6/1/2016 Proposed 120 C Y

C East ITC 3143 Northwest - Southfield 120 kV Rebuild 0.13 mile of 477 ACSR to 1431 ACSR and replace the line entrance at Northwest substation.

MI 6/1/2019 6/1/2019 Proposed 120 C Y

C East ITC 3147 Phoenix 120 kV Capacitor Install a 75 MVAR 120 kV capacitor at Phoenix. MI 6/1/2013 6/1/2013 Proposed 120 C YC East ITC 3148 Riverview - I-N-RV 120 kV Replace wavetrap at Riverview. MI 6/1/2013 6/1/2013 Proposed 120 C YC East ITC 3496 NERC Alert Facility Ratings for 2012 Verify and remediate facilities as required due to the

industry-wide NERC alertMI 12/31/2012 12/31/2012 Planned C Y

C East ITC 3497 NERC Alert Facility Ratings for 2013 Verify and remediate facilities as required due to the industry-wide NERC alert

MI 12/31/2013 12/31/2013 Planned C Y

C East ITC 3498 NERC Alert Facility Ratings for 2014 Verify and remediate facilities as required due to the industry-wide NERC alert

MI 12/31/2014 12/31/2014 Planned C Y

C East ITC, Non-MISO 2204 MTEP08 Reference Future EHV Overlay - Cook to Evans

Build 765 kV circuit from Cook Station to Evans Station in Michigan

MI $319,000,000 8/1/2018 8/1/2018 Conceptual 765 345 C Y

C East ITC, Non-MISO 2207 MTEP08 Reference Future EHV Overlay - Bridgewater to Blue Creek

Build 765 kV circuit from Bridgewater Station in Michigan to Blue Creek Station in Indiana (1% in Indiana, 26% in OH, 73% in MI)

MI $447,000,000 8/1/2018 8/1/2018 Conceptual 765 345 C Y

C East ITC, Non-MISO 2209 MTEP08 Reference Future EHV Overlay - Bridgewater to South Canton

Build 765 kV circuit from Bridgewater Station in Michigan to South Canton Station in Ohio

MI OH $538,000,000 8/1/2018 8/1/2018 Conceptual 765 C Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

C East METC 642 Argenta - Hazelwood(Sag) 138 ckt # 1 Argenta - Hazelwood(Sag) 138 ckt # 1 MI Excluded $50,000 6/1/2017 6/1/2017 Proposed 138 C YC East METC 987 Emmet - Stover 138 kV Line Build 30 miles new 138 kV line, 795 ACSS MI $10,250,000 6/1/2013 6/1/2013 Proposed 138 C YC East METC 1432 Withey Lake-Twining 138kV line Rebuild 0.2 miles of Withey Lake-Twining 138kV line MI $100,000 6/1/2015 6/1/2015 Proposed 138 C YC East METC 1573 Donaldson Creek 138kV Capacitor Install minimum 23.3 MVAR 138kV capacitor MI 6/1/2011 6/1/2011 Proposed 138 C YC East METC 1657 Terminal Equipment Upgrade throughout system MI Proposed C YC East METC 1795 David Jct. - Bingham 138kV Rebuild 19 miles of 138kV 336.4 ACSR to 954 ACSR. MI BaseRel TBD $11,700,000 6/1/2012 6/1/2012 Proposed 138 C YC East METC 1800 Argenta-Riverview 138kV Fix Sag limit, Retap or upgrade 1200A CT's at both

ends, Upgrade 1200A Breaker 377 and 1200A Switch 377 at Riverview

MI 6/1/2013 6/1/2013 Proposed 138 C Y

C East METC 1804 Marquette - Easton Jct. 138kV Upgrade relaying at Marquette MI 6/1/2013 6/1/2013 Proposed 138 C YC East METC 1805 Livingston-Emmet-Oden 138kV Rebuild the Livingston-Emmet and Emmet-Oden 138kV

circuits with 954 ACSR DCT, creating two circuits from both Livingston-Emmet and Emmet-Oden. Total line rebuild is 33 miles

MI 6/1/2015 6/1/2015 Proposed 138 C Y

C East METC 1807 Murphy - Bullock 230kV Swap the existing Bullock-Gleaner and Tittabawassee-Begole 138 kV lines, and open the Begole-Tittabawassee 138 kV line, and build 3.2 miles of new DCT into Richland, creating Bullock -Richland, Richland-Begole, and Tittabawassee-Gleaner 138 kV lines. Convert 8.3 miles of the new Bullock to Richland 138 kV line to 230 kV 954 ACSR. Install a new 345/230 kV transformer at Richland and a new 230/138 kV transformer at Bullock.

MI 6/1/2016 6/1/2016 Proposed 345 138 C Y

C East METC 1808 Four Mile - Cowan Lake Jct. Rebuild 15.5 miles of 336/477 to 954 ACSR. MI 6/1/2017 6/1/2017 Proposed 138 C YC East METC 1811 Keystone - Gray Rd. 138kV Construct a new 9 mile 138kV 954 ACSR circuit from

Keystone to Gray Road.MI 6/1/2018 6/1/2018 Proposed 138 C Y

C East METC 1816 Mecosta - Croton 138kV Rebuild 22 miles of 138kV 110 CU to 954 ACSR. Prebuild to 230kV construction.

MI 6/1/2014 6/1/2014 Proposed 138 C Y

C East METC 1831 Northern Michigan 230 kV Loop Cut in the existing Hampton -Tittabawassee 345 kV and Thetford -- Tittabawassee 2 345 kV circuits to a new 345 kV station, Crane Rd. Construct a 230 kV loop from Crane Rd to Twining to Mio to Livingston to Plum to Keystone to Tippy to a new station, Sunoco, which is formed by reconfiguring the Ludington -- Kenowa 1 345 kV circuit into it. Install 345/230 kV transformers at Crane Rd, Mio, Livingston, Keystone, and Sunoco, and 230/138 kV transformers at Twining, Mio, Livingston, Plum, Keystone, and Tippy. The total 230 kV circuit mileage would be approximately 330 miles and roughly 320 miles would be along the existing ROW.

MI 6/1/2019 6/1/2019 Proposed 345 138 C Y

C East METC 2490 North Belding - Vergennes 138kV Upgrade terminal equipment. MI BaseRel Not Shared $550,000 6/1/2013 6/1/2013 Proposed 138 C YC East METC 2810 Delhi - Canal Jct 138kV Rebuild 7.5 miles of 138kV line to 954 ACSR MI $5,500,000 6/1/2014 6/1/2014 Proposed 138 C YC East METC 2811 East Tawas - Karn 138kV Rebuild 56 miles of 138kV to 954 ACSR. Does not

include the 12.3 miles of rebuild from 2011 MTEP project Cottage Grove - East Tawas 138kV rebuild.

MI $51,000,000 6/1/2015 6/1/2015 Proposed 138 C Y

C East METC 3103 Gallagher 345 kV additional breakers Add two 345kV breakers and convert the Gallagher 345 kV side to a three breaker ring

MI BaseRel Not Shared $5,000,000 12/31/2014 12/31/2014 Proposed 345 C Y

C East METC 3128 Emmet - Riggsville and Livingston - Riggsville #2 138 kV Lines

Construct a new 138 kV circuit from Emmet to Riggsville (25 miles total), 954 ACSR and install Livingston to Riggsville 138 kV circuit #2 (40 miles total)

MI 6/1/2015 6/1/2015 Proposed 138 C Y

C East METC 3131 Bil-Mar Jct.- Port Sheldon Jct. 138 kV Sag Remediation

Improve sag clearance MI 6/1/2015 6/1/2015 Proposed 138 C Y

C East METC 3132 Tallmadge - Tyler 138 kV Sag Remediation Improve sag clearance MI 6/1/2015 6/1/2015 Proposed 138 C Y

C East METC 3133 Claremont - Cornell 138 kV #2 Rebuild/Reconductor the Bell Rd to N. Corunna and the Cornell to N. Corunna sections of 115 CU (4.34 miles).

MI 6/1/2014 6/1/2014 Proposed 138 C Y

C East METC 3134 Weadock Station 138 kV Terminal Equipment upgrade at Weadock MI 6/1/2012 6/1/2012 Proposed 138 C Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

C East METC 3135 Airport - Alpena #2 138 kV Rebuild the existing Airport - Alpena circuit on DCT's while creating a second circuit from Airport to Alpena.

MI 6/1/2016 6/1/2016 Proposed 138 C Y

C East METC 3136 Alpena - Iosco 138 kV Rebuild 20 miles from Alpena to Spruce Rd and replace limiting station equipment.

MI 6/1/2017 6/1/2017 Proposed 138 C Y

C East METC 3137 Bard Road - Warren 138 kV Rebuild 20 miles from Bard Rd to Warren and replace limiting station equipment.

MI 6/1/2014 6/1/2014 Proposed 138 C Y

C East METC 3138 Mio-Gaylord 138 kV Terminal Equipment upgrade at Mio MI 6/1/2014 6/1/2014 Proposed 138 C YC East METC 3144 Argenta - Morrow 138 kV Terminal Equipment upgrade at Morrow MI 6/1/2013 6/1/2013 Proposed 138 C YC East METC 3145 Blackstone - Leoni 138 kV #1, #2 and #3 Replace the 636 ACSR trainers at Blackstone

substation. Upgrade the relaying at Leoni and Blackstone.

MI 6/1/2014 6/1/2014 Proposed 138 C Y

C East METC 3146 Battle Creek - Verona # 2 138 kV Replace the 795 ACSR trainer at Verona substation. MI 6/1/2013 6/1/2013 Proposed 138 C YC East METC 3149 Four Mile Station 138 kV Replace the 2-4/0 Cu trainer at Four Mile. MI 6/1/2013 6/1/2013 Proposed 138 C YC East METC 3150 North Belding - Bricker Jct 138 kV Replace the 336.4 ACSR trainer at North Belding. MI 6/1/2014 6/1/2014 Proposed 138 C YC East METC 3151 Spaulding - Pettis Jct. 138 kV Replace the 795 ACSR trainer at Spaulding. MI 6/1/2014 6/1/2014 Proposed 138 C YC East METC 3152 Riggsville to McGulpin 138 kV Replace 266.8 ACSR trainer at McGulpin and 336.4

ACSR trainer at Riggsville.MI 6/1/2016 6/1/2016 Proposed 138 C Y

C East METC 3153 Oden to McGulpin 138 kV Replace 336.4 ACSR trainer at McGulpin. MI 6/1/2016 6/1/2016 Proposed 138 C YC East METC 3300 Stover - Livingston Rebuild Rebuild 22.2 miles 138 kV line MI 6/1/2015 6/1/2015 Proposed 138 C YC East METC 3492 NERC Alert Facility Ratings for 2012 Verify and remediate facilities as required due to the

industry-wide NERC alertMI 12/31/2012 12/31/2012 Planned C Y

C East METC 3493 NERC Alert Facility Ratings for 2013 Verify and remediate facilities as required due to the industry-wide NERC alert

MI 12/31/2013 12/31/2013 Planned C Y

C East METC 3494 NERC Alert Facility Ratings for 2014 Verify and remediate facilities as required due to the industry-wide NERC alert

MI 12/31/2014 12/31/2014 Planned C Y

C East MPPA 2079 SA Switches Replacing 600 Amp switches with 1200 Amp switches at the South Airport Sub.

MI $200,000 7/1/2015 7/1/2015 Planned 69 C NT

C East MPPA 2080 BWX Switches Replacing 600 Amp switches with 1200 Amp switches at the Barlow Junction.

MI $200,000 7/1/2019 7/1/2019 Planned 69 C NT

C East MPPA 2081 CDX Switches Replacing 600 Amp switches with 1200 Amp switches at the Cass Road Junction.

MI $200,000 7/1/2019 7/1/2019 Planned 69 C NT

C East NIPS 1973 Leesburg to Northeast -- Upgrade Capacity Increase circuit capacity between Leesburg and Northeast (8.5 mi.). Upgrade to 954 KCM ACSR.

IN BaseRel Not Shared $5,279,000 12/1/2017 12/1/2017 Conceptual 138 C Y

C East NIPS 1979 Maple Sub - 69 kV Switched Capacitors Add two steps of 8.1 MVAR capacitors on the Maple Substation 69 kV bus.

IN Other Not Shared $1,080,000 12/1/2014 12/1/2014 Conceptual 69 C Y

C East NIPS 1980 Babcock Sub - 69 kV Switched Capacitors Add two to three steps of 9.0 MVAR capacitors on the Babcock Substation 69 kV bus. .


C East NIPS 1981 Kreitzburg Sub - 69 kV Switched Capacitors Add two steps of 9.0 MVAR capacitors on the Kreitzburg Substation 69 kV bus. .

IN Other Not Shared $1,052,000 12/1/2013 12/1/2013 Proposed 69 C Y

C East NIPS 1983 Dekalb Sub - Upgrade 138/69 Transformer Replace the existing No.1 138/69 KV 56 MVA transformer with a 138/69 kV 112 MVA transformer.

IN BaseRel Not Shared $1,700,000 12/1/2016 12/1/2016 Conceptual 138 69 C Y

C East NIPS 1984 South Knox - New 138/69 kV Substation South Knox- New 138-69 KV, 1-168 MVA Transformer Substation


C East NIPS 1985 Circuit 6959 Wolcotville to S. Milford Reconductor

Reconductor 5.4 miles of Circuit 6959's existing 2/0 Cu to 336.4 kCM ACSR.


C East NIPS 1989 Upgrade Circuit 6959 - S Milford to Helmer Tap

Reconductor 4.73 miles of Circuit 6959's existing 2/0 Cu to 336.4 kCM ACSR.


C East NIPS 1990 Upgrade Circuit 6986 - Dekalb to Angola Substation

Rebuild 16.5 miles of Circuit 6986's existing 2/0 Cu line to 336.4 kCM ACSR.


C East NIPS 1993 South Valparaiso - New 138/69 kV Substation

South Valparaiso - New 138/69 Substation, (3) 69 kV line extensions


C East NIPS 1994 Circuit 6977 - Midway to Bristol Subs - Recond 4.1 miles

Upgrade (reconductor) 4.1 miles of 69 KV line to 336.4 KCM ACSR between Midway and Bristol Substations.

IN Other Not Shared $656,000 12/1/2011 12/1/2011 Planned 69 C Y

C East NIPS 1998 Circuits 6962 & 6937 - Lawton to E. Winamac - Rebuild 4.5 Miles

Rebuild existing double circuit 69 kV line between East Winamac and Lawton. Rebuild with new poles and conductors for 4.5 miles.

IN Other Not Shared $1,339,000 12/1/2013 12/1/2013 Proposed 69 C Y

C East NIPS 2000 Circuit 6977 - Goshen Jct to Model Sub Tap Upgrade (reconductor) .5 miles of 69 KV line to 336.4 KCM ACSR.



Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

C East NIPS 2003 Circuit 6937 Sw 854 to Bruce Lake Sub - Rebuild

Rebuild existing 69 kV line between Bruce Lake Substation and Switch 854.

IN Other Not Shared $957,800 12/1/2014 12/1/2014 Proposed 69 C Y

C East NIPS 2244 MTEP08 Reference Future EHV Overlay - should be Stillwell to Burr Oak

Build 345 kV circuit from Stillwell to Burr Oak station in Indiana

IN $28,000,000 8/1/2018 8/1/2018 Conceptual 345 C Y

C East NIPS 2319 South Chalmers MO 62 load breaks and switch replacement.

Upgrade Switch and install Load breaks IN Other Not Shared $25,000 5/1/2013 5/1/2013 Proposed 69 C Y

C East NIPS 2320 Circuits 13874-Pole Replacement Circuit 13874 - Replace 58 wood poles up to 70 poles if needed upon inspection, inspect and replace static wire as needed. First half of a two part project which will complete work begun in 2008.


C East NIPS 2321 Miller Sub - Add 138KV Capacitors - 100.0 MVAR

Add one step of 100 MVAR capacitors on the Miller Substation 138 kV bus. Engineering only in 2010.

IN BaseRel Not Shared $974,838 9/1/2017 9/1/2017 Conceptual 138 C Y

C East NIPS 2323 Hiple Sub to Northport Sub - New 138 kV Line

Add new 138 kV terminals at Hiple and Northport Substations, and construct a new 10 mile 954 KCM ACSR 138 kV line between these two substations. Engineering only on 2008.


C East NIPS 2324 East Plymouth - New 345-138 Substation Add East Plymouth 345/138 kV, 1-560 MVA Transformer Sub - New

IN BaseRel Shared $18,884,017 5/1/2016 5/1/2016 Conceptual 345 138 C Y

C East NIPS 2792 Northwest circuit reconfiguration Phase I: Reconfigure 138 kV circuits at Mitchell switchyard to address SF-6 breaker maintenance. Reconfigure Chicago Avenue 138 kV line terminals.Phase II: Split existing Dune Acres Substation 138 kV bus into two sections to form a double bus. Add (2) new POT's and additional system protection (differential relaying) to provide adequate protection for a normally split 138 kV bus.


C East NIPS 3399 Circuit 6964 rebuild Rebuild/ Reconductor 6964 from Kentland Sub to Goodland Sub to Pine Creek Sub.

IN $5,567,000 12/1/2010 12/1/2010 Proposed 69 C Y

C East NIPS 3400 Extend 6951 to Palmira Substation Extend 6951 to Palmira Substation IN $123,000 12/1/2012 12/1/2012 Conceptual 69 C YC East NIPS 3401 Circuit 6913 Rebuild Reconductor Circuit 6913 Rebuild Reconductor IN $2,131,000 12/1/2013 12/1/2013 Conceptual 69 C YC East NIPS 3402 Circuit 6981 Rebuild Reconductor Circuit 6981 Rebuild Reconductor IN $5,563,000 12/1/2013 12/1/2013 Conceptual 69 C YC East NIPS 3403 Circuit 6987 Rebuild Reconductor Circuit 6987 Rebuild Reconductor IN $1,383,000 12/1/2012 12/1/2012 Conceptual 69 C YC East NIPS 3404 Circuit 6998, Switch 151 to Warsaw Sub

Reconductor RebuildCircuit 6998, Switch 151 to Warsaw Sub Reconductor Rebuild

IN $461,000 12/1/2015 12/1/2015 Conceptual 69 C Y

C East NIPS 3405 Circuit 69-107 Reconductor Circuit 69-107 Reconductor IN $360,000 12/1/2015 12/1/2015 Conceptual 69 C YC West AmerenIL, ATC

LLC, GRE, ITCM, TP, XEL

2773 Green Power Express 765kV Construct a 765kV network including 11 new 765/345kV substations (13 new 765/345kV TRFs) and approximately 3000 miles of new 765kV line. Proposed substation locations include 2 in North Dakota, 1 in South Dakota, 4 in Minnesota, and 3 in Iowa. This 765kV network wil tie to the existing 765kV substations in Plano, IL and Sullivan, IN.

IA WI $11,510,000,000 12/31/2020 12/31/2020 Conceptual 765 345 C Y

C West ATC LLC 89 Mill Road 345/138 kV substation and transformer

Mill Road transformer - 345/138 ckt , Sum rate 500 WI $29,200,000 6/1/2050 6/1/2050 Conceptual 345 138 C Y

C West ATC LLC 341 Rockdale-Mill Road 345 kV line projects Construct Rockdale-Concord 345 kV line in parallel with existing 138 kV on existing double-width right-of-way. Construct a 345 kV bus and install a 345/138 kV, 500 MVA transformer at Concord. Convert Bark River-Mill Road 138 kV line to 345 kV. Construct

WI $94,600,000 6/1/2050 6/1/2050 Conceptual 345 138 C Y

C West ATC LLC 1621 New Birchwood-Lake Delton 138-kV line Construct new Birchwood-Lake Delton 138-kV line WI TBD TBD $5,806,000 6/1/2020 6/1/2020 Conceptual 138 C YC West ATC LLC 1625 North Randolph Transformer Install a 500 MVA 345/138 kV transformer at the North

Randolph 138 kv SS by looping in the Columbia-South Fond du Lac 345-kV line

WI BaseRel Shared $16,552,836 12/31/2025 12/31/2025 Conceptual 345 138 C Y

C West ATC LLC 1697 Brick Church-Walworth 69 kV line Uprate Brick Church-Walworth 69 kV line to 115 MVA WI Not Shared $716,000 6/1/2020 6/1/2020 Conceptual 69 C YC West ATC LLC 1703 Boscobel Capacitor Banks Install one 8.16 MVAR capacitor bank at Boscobel 69 kV

substation and upgrade existing 5.4 MVAR bank with an 8.16 MVAR bank

WI Not Shared $1,335,173 6/1/2019 6/1/2019 Conceptual 69 C Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

C West ATC LLC 1707 Holmes-Chandler 69 kV line Rebuild/convert Holmes-Chandler 69 kV line to 138 kV operation

MI WI $56,300,000 6/1/2050 6/1/2050 Conceptual 138 C Y

C West ATC LLC 1708 Metomen and Mackford Prairie area upgrades

Construct Fairwater-Mackford Prairie 69 kV line, Reconfigure the North Randolph-Ripon 69-kV line to form a second Ripon-Metomen 69-kV line and retire the circuit between Metomen and the Mackford Prairie tap

WI Other Not Shared $8,879,773 6/1/2018 6/1/2018 Conceptual 69 C Y

C West ATC LLC 1709 Eden Capacitor Banks Install two 16.33 MVAR 69 kV capacitor banks at Eden Substation


C West ATC LLC 1710 Mazomanie capacitor banks Install two 12.25 MVAR 69 kV capacitor banks at Mazomanie substation


C West ATC LLC 1712 Horicon-East Beaver Dam 138 kV line Construct a Horicon-East Beaver Dam 138 kV line WI TBD TBD $18,186,000 6/1/2022 6/1/2022 Conceptual 138 C YC West ATC LLC 1717 Glenview 138/69 kV transformers Replace two existing 138/69 kV transformers at

Glenview Substaion with 100 MVA transformersWI Not Shared $3,440,000 6/1/2020 6/1/2020 Conceptual 138 69 C Y

C West ATC LLC 1718 Custer 138/69 kV transformer Install a 138/69 kV transformer at Custer substation WI Not Shared $4,904,268 6/1/2022 6/1/2022 Conceptual 138 69 C YC West ATC LLC 1719 Shoto-Custer 138 kV line Construct a Shoto-Custer 138 kV line WI TBD TBD $22,938,000 6/1/2022 6/1/2022 Conceptual 138 C YC West ATC LLC 1720 Wautoma 138/69 kV transformer Install a second 138/69-kV transformer at Wautoma

SubstationWI Not Shared $1,440,000 6/1/2017 6/1/2017 Conceptual 138 69 C Y

C West ATC LLC 1721 Pulliam area 69 kV reconductor projects Reconductor Pulliam-Danz 69kV line, reconductor Danz-Henry Street 69 kV line, reconductor Pulliam-Van Buren 69 kV line

WI Not Shared 6/1/2050 6/1/2050 Conceptual 69 C Y

C West ATC LLC 1723 Sunset Point transformer replacement Replace two existing 138/69-kV transformers at Sunset Point Substation with 100 MVA transformers

WI Not Shared $3,540,000 6/1/2024 6/1/2024 Conceptual 138 69 C Y

C West ATC LLC 1726 Uprate Royster-Sycamore 69 kV line Uprate Royster-Sycamore 69 kV line to 115 MVA WI Not Shared $790,000 6/1/2019 6/1/2019 Conceptual 69 C YC West ATC LLC 1727 Dunn Road-Egg Harbor 69 kV line Construct a second Dunn Road-Egg Harbor 69 kV line WI Other Not Shared $37,194,000 6/1/2018 6/1/2018 Conceptual 69 C YC West ATC LLC 1730 Cardinal-Blount 138 kV line Construct a Cardinal-Blount 138 kV line WI Not Shared $60,810,250 6/1/2020 6/1/2020 Conceptual 138 C YC West ATC LLC 2029 Brick Church 138 & 69kV Caps Install 1-24.5 Mvar 138-kV capacitor bank and 1-18

Mvar 69-kV capacitor bank at Brick ChurchWI Not Shared 6/1/2017 6/1/2017 Conceptual 138 C Y

C West ATC LLC 2030 Concord 4x24.5 138 kV Caps Install 4-24.5 Mvar 138-kV capacitor bank at Concord WI Not Shared $3,358,282 6/1/2020 6/1/2020 Conceptual 138 C YC West ATC LLC 2031 Y-32 Rebuild (Colley Rd-Brick Church 69

kV)Y-32 Rebuild (Colley Rd-Brick Church 69 kV) WI Not Shared $11,225,500 6/1/2018 6/1/2018 Conceptual 69 C Y

C West ATC LLC 2038 Spring Valley-S Lake Geneva 138 kV Construct Spring Valley-Twin Lakes-S Lake Geneva 138 kV


C West ATC LLC 2040 Sun Prairie 69kV Caps Install 2x16.33 Mvar 69 kV capacitor banks at Sun Prairie


C West ATC LLC 2042 Dam Heights 69kV Caps Install 2x16.33 Mvar 69 kV caps at Dam Heights WI Not Shared $2,896,361 6/1/2019 6/1/2019 Conceptual 69 C YC West ATC LLC 2043 Convert Necedah from 69 to 138 kV Convert Necedah from 69 to 138 kV and tap into the

Petenwell-Council Creek 138 kV lineWI Not Shared $761,500 6/1/2018 6/1/2018 Conceptual 138 C Y

C West ATC LLC 2046 North Monroe 69 kV Caps Install 2x16.33 Mvar 69 kV capacitor banks at North Monroe


C West ATC LLC 2056 Uprate Oak Creek-Pennsylvania 138 kv Uprate Oak Creek-Pennsylvania 138 kV WI Not Shared $2,409,559 6/1/2020 6/1/2020 Conceptual 138 C YC West ATC LLC 2162 2nd McCue-LaMar 69 kV line Construct a 2nd McCue-LaMar 69 kV line WI Not Shared $5,009,085 6/1/2017 6/1/2017 Conceptual 69 C YC West ATC LLC 3117 Reconductor X-12 from Townline Rd to

Bass CreekReconductor X-12 from Townline Rd to Bass Creek WI $1,900,000 6/1/2021 6/1/2021 Conceptual 138 C Y

C West ATC LLC 3124 construct a 2nd Forsyth-Gwinn 69kV line construct a 2nd Forsyth-Gwinn 69kV line MI $1,000,000 6/1/2018 6/1/2018 Conceptual 69 C YC West ATC LLC 3164 Point Beach-Ludington HVDC line Construct a HVDC line under Lake Michigan between

Point Beach and Ludington and construct HVDC converter stations

MI WI/MI $828,000,000 6/1/2020 6/1/2020 Conceptual 350 C Y

C West ATC LLC 3165 Elm Rd- DC Cook HVDC line Construct a HVDC line under Lake Michigan between Elm Road and DC Cook and construct HVDC converter stations

MI WI/MI $1,071,000,000 6/1/2020 6/1/2020 Conceptual 765 345 C Y

C West ATC LLC 3166 2nd Hillman 138/69kV transformer Install a 2nd Hillman 138/69kV transformer WI $4,843,288 6/1/2018 6/1/2018 Conceptual 138 69 C YC West ATC LLC 3167 Y-87 North Monroe-South Monroe 69 kV

Line UprateY-87 North Monroe-South Monroe 69 kV Line Uprate WI $7,080,193 6/1/2018 6/1/2018 Conceptual 69 C Y

C West ATC LLC 3189 Uprate line Y-93 from Ripon to Northwest Ripon

Uprate line Y-93 from Ripon to Northwest Ripon from 167 deg F to SN/SE

WI $2,205,426 6/1/2019 6/1/2019 Conceptual 69 C Y

C West ATC LLC 3190 Rebuild line Y-103 from Sunset Point to Winneconne

Rebuild line Y-103 from Sunset Point to Winneconne to SN/SE = 200/300 deg F

WI $12,366,239 6/1/2019 6/1/2019 Conceptual 69 C Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

C West ATC LLC 3207 Replace Harrison 138/69kV Tr Replace the Harrison 56 MVA 138/69kV Tr with a 100 MVA unit

WI $3,229,974 6/1/2016 6/1/2016 Conceptual 138 69 C Y

C West ATC LLC 3208 Replace Caroline 115/69kV Tr Replace the Caroline 33 MVA 1115/69kV Tr with a dual high side 138-115/69-kV 100 MVA unit

WI $4,010,542 6/1/2018 6/1/2018 Conceptual 115 69 C Y

C West ATC LLC 3429 Sun ValleyTap-Oregon 69kV line rebuild Rebuild the Sun ValleyTap-Oregon 69kV line WI $5,561,798 6/1/2020 6/1/2020 Conceptual 69 C YC West ATC LLC 3430 Dyckesville-Sawyer 69kV rebuild Rebuild the Dyckesville-Brusbay-Sawyer 69 kV line WI $11,814,128 6/1/2016 6/1/2016 Conceptual 69 C YC West ATC LLC 3486 Oak Creek-Bluemound Uprate Uprate 138 kV line to 275 F WI $1,400,000 6/1/2021 6/1/2021 Conceptual 138 C YC West ATC LLC 3487 West Middleton-Pheasant Branch 69 kV

new circuitReplace existing single circuit from WMD-Pheasant Branch 69 kV with double circuit 69 kV lines.

WI $22,711,186 6/1/2022 6/1/2022 Conceptual 69 C Y

C West ATC LLC 3512 Pleasant Prairie-Cook HVDC line Construct a HVDC line under Lake Michigan between Pleasant Prairie and Cook and construct HVDC converter stations

MI WI/MI $828,000,000 6/1/2020 6/1/2020 Conceptual 350 C Y

C West ATC LLC, ALTW 2230 MTEP08 Reference Future EHV Overlay - Salem to West Middleton

Build 345 kV circuit from West Middleton in Wisconsin to Salem Station in Iowa

WI $102,000,000 8/1/2018 8/1/2018 Conceptual 345 138 C Y

C West ATC LLC, XEL 2211 MTEP08 Reference Future EHV Overlay - Longwood to Greenwood

Build 345 kV circuit from Longwood Station to Greenwood Station in Wisconsin

WI $200,000,000 8/1/2018 8/1/2018 Conceptual 345 C Y

C West DPC, ATC LLC 2231 MTEP08 Reference Future EHV Overlay - LaCrosse-Columbia

Build 345 kV circuit from LaCrosse to Columbia Station in Wisconsin

WI $186,000,000 43313 43313 Conceptual 345 138 C Y

C West GRE 2691 Orrock 345/115 kV source and Orrock-Waco-Liberty 115 kV line.

Orrock 345/115 kV source and Orrock-Waco-Liberty 115 kV line.

MN $19,661,825 6/1/2017 6/1/2017 Conceptual 345 69 C Y

C West ITCM 1738 Bertram-Hills 161kV Reconductor Reconductor 33 miles of 161kV from Bertram to new Rose Hollow to Hills

IA BaseRel Shared $22,540,000 12/31/2017 12/31/2017 Proposed 161 C Y

C West ITCM 1742 Split Rock-Heron Lake 161kV Rebuild Rebuild from Split Rock-Magnolia-Elk-Heron Lake 161kV line.

MN BaseRel Shared $33,404,000 12/31/2014 12/31/2016 Proposed 161 C Y

C West ITCM 2830 Lakefield Jct. – Rutland 345kV Build a new 345kV station at Rutland and add a new 345/161kV transformer. Build a new 345kV circuit from Lakefield Jct station to Rutland 345kV station.

MN $98,500,000 1/1/2014 1/1/2014 Proposed 345 161 C Y

C West ITCM 3086 8th Street-Kerper-Lore 161kV Rebuild Rebuild the dubuque area 8th Street-Kerper-Lore 161kV line.

IA BaseRel Shared $7,056,500 12/31/2013 12/31/2014 Proposed 161 C Y

C West ITCM 3087 Lansing-Harmony 161kV Rebuild Rebuild portion of the line in IA due to structure condition.

IA Other Not Shared $30,000,000 12/31/2016 12/31/2016 Proposed 161 C Y

C West ITCM 3500 NERC Alert Facility Ratings for 2012 Verify and remediate facilities as required due to the industry-wide NERC alert

IA 12/31/2012 12/31/2012 Planned C Y


IA 12/31/2013 12/31/2013 Planned C Y


IA 12/31/2014 12/31/2014 Planned C Y

C West ITCM, XEL 2223 MTEP08 Reference Future EHV Overlay - Lakefield to Adams

Build 345 kV double circuit line from Lakefield to Adams Station in Minnesota

MN $334,000,000 8/1/2018 8/1/2018 Conceptual 345 161 C Y

C West MDU 3082 NW Bismarck Ring Bus Install 115kV ring bus at the NW Bismarck substation ND TBD $3,050,000 6/1/2014 6/1/2014 Planned 115 C YC West MDU 3084 East Bismarck Bus Split Install 115 kV Bus Tie breaker and 2nd 115 kV WAPA

TieND TBD $2,500,000 12/1/2015 12/1/2015 Proposed 115 C Y

C West MDU 3456 Glenham transformer replacement Replace the smaller Glenhame transformer and rebuild Glenhame 230 kV bus into a ring configuration

SD $7,000,000 6/1/2016 6/1/2016 Planned 230 115 C Y

C West MDU, NON-MISO 2214 MTEP08 Reference Future EHV Overlay - Glenham to Ellendale

Build 345 kV circuit from Glenham in South Dakota to Ellendale in North Dakota

SD SD/ND $47,000,000 8/1/2018 8/1/2018 Conceptual 345 230 C Y

C West MEC 2941 Sub T - Boone Jct 161 kV Line Upgrade Uprate MEC's portion of the Sub T - Boone Jct 161 kV line.

IA BaseRel TBD $1,600,000 12/31/2014 12/31/2014 Proposed 161 C Y

C West MEC 2943 Hills 2nd 345-161 kV XFMR Install 2nd 560 MVA 345-161 kV transformer at Hills Substation. Expand 345 and 161 kV ring busses to accommodate new transformer.

IA BaseRel TBD $12,000,000 6/1/2020 6/1/2020 Conceptual 345 161 C Y

C West MEC 2944 Hills - Sub E 161 kV Line Reconductor Reconductor the Hills - Sub E Iowa City 161 kV line. IA BaseRel TBD $1,800,000 6/1/2019 6/1/2019 Conceptual 161 C YC West MEC 2945 Grimes Sub Add 2nd 345-161 kV

TransformerAdd a second transformer at the Grimes Substation and expand the 345 and 161 kV ring buses by one breaker.

IA BaseRel Shared? $11,900,000 6/1/2019 6/1/2019 Conceptual 345 161 C Y

C West MEC 2946 Reconductor Greenfield Plaza-Army Post-Ashawa 161 kV line.

Reconductor the Greenfield Plaza-Army Post-Ashawa 161 kV line.



Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

C West MEC 2947 North Grimes 161-13 kV Substation Construct the North Grimes Substation by tapping the Bittersweet Road-Granger Tap 161 kV line with in and out breakered line terminals. The Granger Tap is located on the Grimes-100th & 54th 161 kV line.

IA Other Not Shared Distribution $3,900,000 6/1/2012 6/1/2018 Planned 161 13.2 C Y

C West MEC 2948 West Waukee 161-13 kV Substation Construct the West Waukee Substation. The Substation will tap (non-breakered in and out) a new 161 kV line from the Booneville Substation to the Grimes Substation.

IA $10,650,000 6/1/2018 6/1/2018 Proposed 161 13.2 C Y

C West MEC 2949 West Waukee 161-69 kV Transformer Add a 161-69 kV transformer and 161 kV circuit breakers at the West Waukee Substation.

IA Other Not Shared Reliability $3,100,000 6/1/2020 6/1/2020 Conceptual 161 69 C Y

C West MEC 2951 Boston 161-13 kV Substation Contruct the Boston Substation by tapping (non-breakered in and out) the Sycamore-Forest & Vermont 161 kV line.

IA Other Not Shared $2,000,000 6/1/2018 6/1/2018 Conceptual 161 13 C Y

C West MEC 2952 East Altoona 161-13 kV Substation Construct the East Altoona Substation and the Metro East - E Altoona and E Altoona-Bondurant 161 kV lines. Includes the addition of a breakered line terminal at Bondurant and the addition of breakers on the two existing line terminals at Metro East.

IA Other Not Shared $11,340,000 6/1/2016 6/1/2016 Conceptual 161 13 C Y

C West MEC 2953 Page County 345-161 kV Substation Construct a 345-161 kV Substation that taps the Atchison County-Booneville 345 kV line and the Clarinda-Hastings 161 kV line. The substation will consist of a three (3) breaker 345 kV ring bus, a three (3) breaker 161 kV ring bus, and a 345-161 kV autotransformer. Reconductor the Page County-Clarinda 161 kV line.

IA $18,600,000 6/1/2020 6/1/2020 Conceptual 345 161 C Y

C West MEC 2954 Clarinda 161 kV Capacitor Install a 50 MVAR, 161 kV capacitor at the Clarinda Substation


C West MEC 3217 Kewanee - Scott County 765 kV Line Construct 765 kV line from new Kewanee 765 kV bus to Scott County Substation and associated substation equipment additions.

IA IA/IL $193,000,000 12/31/2019 12/31/2019 Proposed 765 C Y

C West MEC 3219 Kewanee - Louisa 765 kV Line Construct 765 kV line from Kewanee to Louisa and associated substation equipment additions.

IA IA/IL $283,000,000 12/31/2019 12/31/2019 Proposed 765 345 C Y

C West MEC 3224 Woodbury County (Raun) - Hoskins 345 kV Lines

Construct double circuit 345 kV line from either Raun or new substation in Woodbury County to Hoskins Substation and associated substation equipment additions.

IA NE $167,000,000 12/31/2019 12/31/2019 Proposed 345 C Y

C West MEC 3225 Woodbury County (Raun) - Broadland 345 kV Lines

Construct double circuit 345 kV line from either Raun or new substation in Woodbury County to Broadland Substation and associated substation equipment additions.

IA SD $591,000,000 12/31/2019 12/31/2019 Proposed 345 C Y

C West MEC 3226 Pocahontas Co. - Woodbury County (Raun) 765 kV Line

Construct 765 kV line from new Pocahontas County Substation to either Raun Substation or new substation in Woodbury County and associated substation equipment additions.

IA $296,000,000 12/31/2024 12/31/2024 Proposed 765 345 C Y

C West MEC 3227 Pocahontas Co. - Hoskins 765 kV Line Construct 765 kV line from new Pocahontas County Substation to Hoskins Substation and associated substation equipment additions.

IA NE $461,000,000 12/31/2024 12/31/2024 Proposed 765 C Y

C West MEC 3229 Pocahontas Co. - Osceola Co. 765 kV Line Construct 765 kV line from new Pocahontas County Substation to new Osceola County 765 kV substation and associated substation equipment additions.

IA $220,000,000 12/31/2024 12/31/2029 Proposed 765 345 C Y

C West MEC 3230 Osceola Co. - Chanarambie 765 kV Line Construct 765 kV line from new Osceola County substation to new Chanarambie substation and associated substation equipment additions.

IA MN $366,000,000 12/31/2029 12/31/2029 Proposed 765 C Y

C West MEC 3231 Pocahontas Co. - Adair Co. 765 kV Line Construct 765 kV line from new Pocahontas County Substation to new Adair County Substation and associated substation equipment additions.

IA $499,000,000 12/31/2029 12/31/2029 Proposed 765 345 C Y

C West MEC 3232 Adair Co. - St. Joseph 765 kV Line Construct 765 kV line from new Adair County Substation to St. Joseph Substation and associated substation equipment additions.

IA MO $407,000,000 12/31/2029 12/31/2029 Proposed 765 C Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

C West MEC 3233 Adair Co. - Hills 765 kV Line Construct 765 kV line from new Adair County Substation to Hills Substation and associated substation equipment additions.

IA $691,000,000 12/31/2029 12/31/2029 Proposed 765 C Y

C West MEC 3234 Hills - Kincaid 765 kV Line Construct 765 kV line from Hills to Kincaid Substation and associated substation equipment additions.

IA IL $745,000,000 12/31/2029 12/31/2029 Proposed 765 C Y

C West MEC 3237 Avoca-Page County-Maryville 345 kV line Construct a new 345 kV line from Avoca-Page County-Maryville with 161 kV underbuild and associated substation equipment additions.

IA IA/MO $203,000,000 6/1/2020 6/1/2020 Conceptual 345 161 C Y

C West MEC 3238 CBEC-S3456 345 kV Line Construct second 345 kV line from CBEC-OPPD's 3456 Sub and associated substation equipment additions.

IA NE $29,100,000 6/1/2019 6/1/2019 Conceptual 345 C Y

C West MEC 3239 Bunge-Hastings-Page County 161 kV Rebuild

Rebuild 161 kV Line from Bunge-Hastings and associated substation equipment additions.

IA $29,100,000 6/1/2018 12/1/2018 Conceptual 161 C Y

C West MEC 3240 Denison-Avoca 161 kV Line New 161 kV line from Denison-Avoca and associated substation equipment additions.

IA $20,900,000 6/1/2020 6/1/2020 Conceptual 161 C Y

C West MEC 3241 CBEC-Sub 701 161 kV Line Construct a 161 kV line from CBEC-Sub 701 and associated substation equipment additions.

IA BaseRel TBD $4,600,000 6/1/2018 6/1/2018 Conceptual 161 C Y

C West MEC 3242 Quick-Sub 701 161 kV Line Construct a 161 kV line from Quick to Sub 701 and associated substation equipment additions.

IA $7,700,000 6/1/2018 6/1/2018 Conceptual 161 C Y

C West MEC 3243 Quick-Avoca 161 kV line Construct a 161 kV line from Quick to Avoca and associated substation equipment additions.

IA $11,700,000 6/1/2016 6/1/2016 Conceptual 161 C Y

C West MEC 3246 Webster South-Lehigh 161 kV line Construct new 161 kV line between future 161 kV terminals at the Lehigh Substation and Webster South switching station and associated substation equipment additions.

IA $3,500,000 6/1/2016 6/1/2016 Conceptual 161 C Y

C West MEC 3247 Lehigh 345-161 kV Transformer Install a 345-161 kV transformer at the Lehigh Substation

IA $7,500,000 6/1/2016 6/1/2016 Conceptual 345 161 C Y

C West MEC 3250 West Grand-88th St 161 kV Line West Grand-88th St 161 kV Line and associated substation equipment additions.

IA $1,800,000 6/1/2018 6/1/2018 Conceptual 161 C Y

C West MEC 3251 Army Post-West Grand 161 kV Line Army Post-West Grand 161 kV Line and associated substation equipment additions.

IA $4,400,000 6/1/2018 6/1/2018 Conceptual 161 C Y

C West MEC 3252 Norwalk-Scotch Ridge 161 kV Line Norwalk-Scotch Ridge 161 kV Line and associated substation equipment additions.

IA $7,100,000 6/1/2020 6/1/2020 Conceptual 161 13.2 C Y

C West MEC 3253 Scotch Ridge-Avon Lake 161 kV Line Scotch Ridge-Avon Lake 161 kV Line and associated substation equipment additions.

IA $5,700,000 6/1/2020 6/1/2020 Conceptual 161 13.2 C Y

C West MEC 3254 Avon Lake-DPS 161 kV Line or SE Polk Avon Lake-DPS 161 kV Line or SE Polk and associated substation equipment additions.

IA $1,400,000 6/1/2020 6/1/2020 Conceptual 161 C Y

C West MEC 3255 Sub 91 - Cordova 345 kV Line 345 kV line from Cordova - Sub 91, convert Sub 91 345 to ring bus and associated substation equipment additions.

IA IL $23,400,000 6/1/2015 6/1/2015 Conceptual 345 C Y

C West MEC 3256 Sub 39 - Cordova 345 kV ckt 2 2nd 345 kV line from Sub 39 to Cordova and associated substation equipment additions.

IL $20,800,000 6/1/2015 6/1/2015 Conceptual 345 C Y

C West MEC 3257 Eagle - LeMars - Spencer - Sioux County 161 kV Lines

Eagle - LeMars - Spencer - Sioux County 161 kV Line and associated substation equipment additions.

IA $54,100,000 6/1/2016 6/1/2016 Conceptual 161 C Y

C West MEC 3258 Little Sioux-Monona 161 kV line Little Sioux-Monona 161 kV line and associated substation equipment additions.

IA $18,700,000 6/1/2020 6/1/2020 Conceptual 161 C Y

C West MEC 3259 Carroll-Denison 161 kV line New Carroll County-Denison 161 kV line and associated substation equipment additions.

IA $16,500,000 6/1/2020 6/1/2020 Conceptual 161 C Y

C West MEC 3260 Odebolt-Carroll 345 kV line New Odebolt-Carroll County 345 kV line with 161 kV underbuild and associated substation equipment additions.

IA $57,000,000 6/1/2020 6/1/2020 Conceptual 345 C Y

C West MEC 3261 Wisdom-Odebolt 345 kV line Wisdom-Buena Vista-Sac-Odebolt 345 kV line with 161 kV underbuild and associated substation equipment additions.

IA $79,300,000 6/1/2020 6/1/2020 Conceptual 345 C Y

C West MEC 3267 NW Sioux City 230-69 kV Substation Add 230-69 kV sub and associated 230 kV and 69 kV ties and associated substation equipment additions.

IA Other Shared Reliability $10,500,000 6/1/2016 6/1/2016 Conceptual 230 69 C Y

C West MEC 3269 Blackhawk-Hazleton 161 kV Rebuild Increase 161 kV line rating. IA BaseRel Not Shared $3,400,000 6/1/2012 6/1/2012 Planned 161 C YC West MEC 3371 Hills-Parnell 161 kV Line Upgrade Upgrate the Hills-Parnell 161 kV line IA BaseRel Not Shared $90,000 12/31/2014 12/31/2014 Proposed 161 C YC West MEC 3372 Parnell-Poweshiek 161 kV Line Upgrade Upgrade the Parnell-Poweshiek 161 kv line IA BaseRel Not Shared $540,000 12/31/2014 12/31/2014 Proposed 161 C Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

C West MEC 3477 Oak Grove-Galesburg 161 kV Upgrade Rebuild the Oak Gove-Galesburg 161 kV line to increase capacity

IL 12/1/2014 12/1/2014 Proposed 161 138 C Y

C West MEC 3478 Webster-Black Hawk-Hazleton 161 kV Rebuild

Rebuild approx. 115 miles of existing 161 kV line from Webster to Black Hawk to Hazleton to increase capacity.

IA $23,680,000 12/31/2018 12/31/2018 Planned 161 C Y

C West MEC, ALTW 2193 MTEP08 Reference Future EHV Overlay - Lehigh to Toledo

Builds 765 kV circuit from Lehigh Station to Toledo Station in Iowa

IA $313,000,000 8/1/2018 8/1/2018 Conceptual 765 C Y

C West MEC, ITCM 2950 Polk City 161-13 kV Substation Construct the Polk City Substation. The Substation will tap the ITC Midwest 161 kV line from Bittersweet Road to NE Ankeny with in and out breakered line terminals.

IA $1,500,000 6/1/2018 6/1/2018 Conceptual 161 13.2 C Y

C West MEC, ITCM 3218 Scott County - Hazleton 765 kV Line Construct 765 kV line from Scott County to Hazleton Substation and associated substation equipment additions.

IA $459,000,000 12/31/2019 12/31/2019 Proposed 765 345 C Y

C West MEC, ITCM 3220 Louisa-Hazleton 765 kV Construct 765 kV line from Louisa to Hazleton and associated substation equipment additions.

IA $257,000,000 12/31/2019 12/31/2019 Proposed 765 C Y

C West MEC, ITCM 3221 Hazleton - Pocahontas Co. 765 kV Line Construct 765 kV line from Hazleton to new Pocahontas County Substation and associated substation equipment additions.

IA $837,000,000 12/31/2019 12/31/2019 Proposed 765 345 C Y

C West MEC, ITCM 3222 Hills - Hazleton 345 kV Line Construct 345 kV line from Hills to Hazleton Substation and associated substation equipment additions.

IA $83,000,000 12/31/2019 12/31/2019 Proposed 345 C Y

C West MEC, ITCM 3223 Hazleton - Adams 345 kV Lines Construct double circuit 345 kV line from Hazleton to Adams Substation and associated substation equipment additions.

IA MN $227,000,000 12/31/2019 12/31/2019 Proposed 345 C Y

C West MEC, ITCM 3228 Hills - Hazleton 765 kV Line Construct 765 kV line from Hills to Hazleton Substation and associated substation equipment additions.

IA $215,000,000 12/31/2024 12/31/2024 Proposed 765 345 C Y

C West MEC, ITCM 3235 Osceola Co. - Lakefield Jct. 765 kV Line Construct 765 kV line from new Osceola County Substation to Lakefield Jct. Substation and associated substation equipment additions.

IA MN $230,000,000 12/31/2029 12/31/2029 Proposed 765 C Y

C West MEC, ITCM 3236 Hazleton - Adams 765 kV Line Construct 765 kV line from Hazleton to Adams Substation and associated substation equipment additions.

IA MN $312,000,000 12/31/2029 12/31/2029 Proposed 765 C Y

C West MEC, ITCM 3244 OGS-Pleasant Corner-Beacon-Pella-Reasnor 161 kV Line

Construct a new 161 kV line from OGS-Pleasant Corner-Beacon-Pella-Reasnor with 69 kV underbuild and associated substation equipment additions.

IA $38,650,000 6/1/2017 6/1/2017 Conceptual 161 C Y

C West MEC, ITCM 3245 Lucas County-Knoxville-Pella-Reasnor 161 kV Line

Construct a 161 kV line from Lucas County-Knoxville-Pella-Reasnor and associated substation equipment additions.

IA $34,100,000 6/1/2017 6/1/2017 Conceptual 161 C Y

C West MEC, ITCM 3248 DPS/Reasnor Sub - East Altoona 161 kV Line

New 161 kV line from switching station on DPS-Reasnor line to East Altoona and associated substation equipment additions.

IA $6,500,000 6/1/2016 6/1/2016 Conceptual 161 C Y

C West MEC, ITCM 3249 East Altoona-NE Ankeny/Jasper County Sub 161 kV line

New 161 kV line from East Altoona to a new sub off NE Ankeny/Jasper County line and associated substation equipment additions.

IA $7,800,000 6/1/2016 6/1/2016 Conceptual 161 C Y

C West MEC, ITCM 3262 Odebolt-Adair 345 kV line Odebolt-Grand Junction-Adair 345 kV line and associated substation equipment additions.

IA $204,100,000 6/1/2020 6/1/2020 Conceptual 345 C Y

C West MEC, ITCM 3263 Adair-Sub T 345 kV line Adair-Ottumwa-Sub T 345 kV line and associated substation equipment additions

IA $244,000,000 6/1/2020 6/1/2020 Conceptual 345 C Y

C West MEC, ITCM 3264 S.E. Polk - Ottumwa 161 kV Line New S.E. Polk-Ottumwa 161 kV line and associated substation equipment additions.

IA $40,000,000 6/1/2020 6/1/2020 Conceptual 161 C Y

C West MEC, ITCM 3265 Carroll-Adair 161 kV line New Carroll County-Grand Junction-Adair 161 kV line and associated substation equipment additions.

IA $60,500,000 6/1/2020 6/1/2020 Conceptual 161 C Y

C West MH, OTP 2180 MTEP08 Reference Future EHV Overlay - Riel to Maple River

Builds 500 kV circuit from Riel Station in Manitoba to Maple River Station in North Dakota

ManitobND $374,000,000 8/1/2018 8/1/2018 Conceptual 500 115 C Y

C West MP 2548 Hilltop Add second 230/115 kV Transformer capacity and 230 kV line

MN TBD 6/1/2019 6/1/2019 Proposed 230 115 C Y

C West MP 2551 28L Tap Remove Tap and put line on its own breaker & upgrade capacity

MN BaseRel Not Shared $1,250,000 6/30/2014 6/30/2014 Proposed 115 C Y

C West OTP 2746 Turtle Lake-Mercer 41.6 kV Line Upgrade Rebuild Existing 18-Mile 41.6 kV Line ND Other Not Shared $500,000 11/1/2015 11/1/2015 Proposed 41.6 C NTC West OTP 2857 Green Valley 41.6 kV Line Upgrade Rebuild Existing 4-Mile 41.6 kV Line MN Other Not Shared $550,000 12/31/2014 12/31/2014 Proposed 41.6 C Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

C West OTP 3484 Big Stone AQCS Addition Install a new 230/13.8 kV transformer to accommodate a new load increase at Big Stone related to new pollution control equipment

SD $3,000,000 7/1/2015 7/1/2015 Proposed 230 13.8 C Y

C West OTP, GRE 2225 MTEP08 Reference Future EHV Overlay - Big Stone-Crow River

Build 345 kV double circuit line from Big Stone in South Dakota to Crow River in Minnesota

MN MN/SD $328,000,000 8/1/2018 8/1/2018 Conceptual 345 115 C Y

C West OTP, MDU 2219 MTEP08 Reference Future EHV Overlay - Maple River to Ellendale

Build 345 kV double circuit line from Maple River to Ellendale in North Dakota

ND $239,000,000 8/1/2018 8/1/2018 Conceptual 345 230 C Y

C West OTP, NON-MISO 2182 MTEP08 Reference Future EHV Overlay - Maple River to Watertown

Builds 345 kV circuit from Maple River Station in North Dakato to Watertown Station in South Dakota

ND SD $202,000,000 8/1/2018 8/1/2018 Conceptual 345 C Y

C West OTP, XEL 2181 MTEP08 Reference Future EHV Overlay - Maple River to Blue Lake

Builds 500 kV circuit from Maple River Station in North Dakota to Blue Lake Station in Minnesota

MN SD/MN $401,000,000 8/1/2018 8/1/2018 Conceptual 500 345 C Y

C West OTP, XEL 2224 MTEP08 Reference Future EHV Overlay - Bigstone to Morris to Alexandria

Build 345 kV double circuit line from Big Stone in South Dakota to Morris and then to Alexandria Station in Minnesota

MN SD\MN $215,000,000 8/1/2018 8/1/2018 Conceptual 345 230 C Y

C West West 3513 Bison Substation Bison 345/230 kV substation, associated breakers, 2-345/230 kV transformers

ND $17,635,000 3/31/2015 3/31/2015 Planned 345 230 C Y

C West XEL 2177 RES (230 kV Corridor study) Convert Minn Valley - Panther - McLeod - Blue Lake 230 kV line to Double circuit 345 kV from Hazel to McLeod to West Waconia to Blue Lake.

MN Other Not Shared 6/1/2016 6/1/2016 Proposed 345 115 C Y

C West XEL 2184 MTEP08 Reference Future EHV Overlay - Splitrock to "New Blue Earth Sub"

Builds 345 kV circuit from Splitrock Station in South Dakota to a New Blue Earth Station in Minnesota

MN SD/MN $205,000,000 8/1/2018 8/1/2018 Conceptual 765 345 C Y

C West XEL 2185 MTEP08 Reference Future EHV Overlay - Adams to Hampton Corners

Builds 765 kV circuit from Adams Station in Minnesota to Hampton Corners Station in Minnesota

MN $15,000,000 8/1/2018 8/1/2018 Conceptual 765 345 C Y

C West XEL 2186 MTEP08 Reference Future EHV Overlay - Sherburne County to Chisago City

Builds 345 kV circuit from Sherbourne County Station to Chisago County Station in Minnesota

MN $69,000,000 8/1/2018 8/1/2018 Conceptual 345 C Y

C West XEL 2187 MTEP08 Reference Future EHV Overlay - Sherburne County to "New SW MPLS Sub"

Builds 345 kV circuit from Sherbourne County Station to New SW Minneapolis Station in Minnesota

MN $68,000,000 8/1/2018 8/1/2018 Conceptual 345 C Y

C West XEL 2188 MTEP08 Reference Future EHV Overlay - "New SW MPLS Sub" to Hampton Corners

Builds 765 kV circuit from Hampton Corner Station to New SW Minneapolis Station in Minnesota

MN $260,000,000 8/1/2018 8/1/2018 Conceptual 765 C Y

C West XEL 2189 MTEP08 Reference Future EHV Overlay - Hampton Corners to Chisago Cty (east mpls loop)

Builds 345 kV circuit from Hampton Corner Station to Chisago County Station in Minnesota

MN $103,000,000 8/1/2018 8/1/2018 Conceptual 345 C Y

C West XEL 2191 MTEP08 Reference Future EHV Overlay - "New SW MPLS Sub" to "New Blue Earth Sub"

Builds 765 kV circuit from New SW Minneapolis Station to New Blue Earth Station in Minnesota

MN $215,000,000 8/1/2018 8/1/2018 Conceptual 765 C Y

C West XEL 2217 MTEP08 Reference Future EHV Overlay - Granite Falls-Twin Cities

Build 345 kV circuit from Granite Falls (Hazel sub) to Blue Lake (Twin Cities) in Minnesota

MN $162,000,000 8/1/2018 8/1/2018 Conceptual 345 C Y

C West XEL 2222 MTEP08 Reference Future EHV Overlay - Minn Valley-Blue Lk 230

Build 230 kV double circuit line from Minnesota Valley to West Waconia Station in Minnesota

MN $274,000,000 8/1/2018 8/1/2018 Conceptual 345 230 C Y

C West XEL 2226 MTEP08 Reference Future EHV Overlay - Adams-N Rochester

Build 345 kV double circuit line from Adams Station to North Rochester in Minnesota

MN $101,000,000 8/1/2018 8/1/2018 Conceptual 345 C Y

C West XEL 2227 MTEP08 Reference Future EHV Overlay - Monticello-W Waconia-Helena

Build 345 kV double circuit line from Monticello to West Waconia to Helena in Minnesota

MN $102,000,000 8/1/2018 8/1/2018 Conceptual 345 C Y

C West XEL, ATC LLC 2210 MTEP08 Reference Future EHV Overlay - Chisago Cty to Longwood

Build 345 kV circuit from Chisago County Station in Minnesota to Longwood Station in Wisconsin

MN WI $165,000,000 8/1/2018 8/1/2018 Conceptual 345 C Y

C West XEL, ITCM 2212 MTEP08 Reference Future EHV Overlay - Adams to Rockcreek

Build 765 kV circuit from Adams Station in Minnesota to Rock Creek Station in Iowa

MN IA $627,000,000 8/1/2018 8/1/2018 Conceptual 765 C Y

C West XEL, MEC 2192 MTEP08 Reference Future EHV Overlay - "New Blue Earth Sub" to Lehigh

Builds 765 kV Circuit from New Blue Earth Station in Minnesota to Lehigh Station in Iowa

IA MN/IA $273,000,000 8/1/2018 8/1/2018 Conceptual 765 345 C Y

C West XEL, MH, GRE, OTP, MP, MRE

3398 Dorsey-Split Rock 500 kV line Option W6: Dorsey(Manitoba)-Bison(ND)-Brookings(SD)-Split Rock (SD) 500 kV with 345/500 kV transformers. Also included is a 2nd 345 kV circuit on the Fargo-Alexandria-Quarry-Monticello 345 kV project (Project 286) and works in concert with the Brookings, SD - SE Twin Cities 345 kV project (Project ID 1203) and the Corridor project (Project ID 2177)

MB SD $1,627,000,000 12/31/2017 12/31/2017 Proposed 500 345 C Y


Target Appendix

Planning Region



Expected ISD (Min)

Expected ISD (Max)

Min of Plan Status

Max kV

Min kV App ABC

MISO Facility

C West XEL, Non-MISO 2183 MTEP08 Reference Future EHV Overlay - Watertown to Split Rock

Builds 345 kV circuit from Watertown Station in South Dakota to Splitrock station in South Dakota

SD $131,000,000 8/1/2018 8/1/2018 Conceptual 345 C Y

C West, Central, East

ITCM, AmerenIL 2785 Northwest Iowa (New Substation)-Sorenson HVDC

Build new +/- 800 kV bi-pole HVDC line from a new Northwest Iowa substation to the existing Sorenson substation. The project will be capable of transferring approximately 1,500 MW independently or up to 7,900 MW coupled with the complimentary project (PrjID 2794). The project(s) also envision a regional collector system that will be vetted through the RGOS stakeholder process.

IA IN $1,900,500,000 5/1/2014 5/1/2014 Proposed 800 C Y












MTEP11 MISO Transmission Expansion Plan 2011 Appendix CAppendix C: Project Facility Table 9/7/2011




Max kV


Miles Upg.


Cost Shared

Postage Stamp


C Central ALTW, Non MISO 2198 4066 8/1/2018 Pontiac Transformer 1 765 345 2767.5 new transformer IL Conceptual $15,000,000 Y CC Central ALTW, Non MISO 2198 4038 8/1/2018 Rock Creek Pontiac 1 765 3768 new line IA/IL 108 Conceptual $348,000,000 Y CC Central Ameren 1539 2616 6/1/2015 Roxford Stallings 1 345 1195 Install PCB at Roxford Substation IL Proposed $1,000,000 Y CC Central AmerenIL 1536 2613 6/1/2014 Latham Mason City 1 138 255 Reconductor Latham Tap-Kickapoo Tap IL 15.75 Proposed $4,670,000 Y CC Central AmerenIL 1538 2615 6/1/2015 Pana, North Ramsey, East 1 138 240 Rebuild line for operation at 120 degrees C IL 18.43 Proposed $5,500,000 Y CC Central AmerenIL 1540 2617 6/1/2014 Sidney Windsor 1 138 321 Reconductor to 1600 A Summer Emergency IL 13.1 Proposed $3,900,000 Y CC Central AmerenIL 2232 4146 8/1/2018 Kewanee Transformer 1 345 138 336 new transformer IL Conceptual $10,000,000 Y CC Central AmerenIL 2232 4102 8/1/2018 Kewanee East Moline 1 345 1793 new line IL 30.6 Conceptual $34,000,000 Y CC Central AmerenIL 2233 4147 8/1/2018 Kewanee Tazewell 1 345 1793 new line IL 60 Conceptual $85,000,000 Y CC Central AmerenIL 2242 4156 6/1/2020 Norris City Albion 1 345 1793 new line IL 25.8 Conceptual $50,000,000 Y CC Central AmerenIL 2283 4199 6/1/2014 South Bloomington 138 kV Bus 138 Install two new 2000 A, 138 kV Bus-Tie

BreakersIL Proposed $1,030,000 Y C

C Central AmerenIL 2289 4205 6/1/2014 Benton W. Frankfort 1 138 175 Reconductor 350 kcmil Copper with 1200 A summmer emergency capability

IL 9.62 Proposed $1,871,000 Y C

C Central AmerenIL 2290 4206 6/1/2015 Joppa 2nd. 345/161 kV Transformer

345 161 560 Install 2nd. 345/161 kV, 560 MVA Transformer

IL Proposed $4,000,000 Y C

C Central AmerenIL 2293 4209 6/1/2014 N. Lasalle La Salle Jct. 1 138 321 Reconductor 477 kcmil ACSR w/ 1600 A summer emergency capability in L1556A

IL 9.68 Proposed $2,515,000 Y C

C Central AmerenIL 2294 4210 6/1/2013 Stallings 345/138 kV Substation

138 kV Bus-Tie Position 1302

138 478 Reconnect or replace 1200 A CT to 2000 A IL Proposed Y C

C Central AmerenIL 2295 4211 6/1/2015 W. Mt. Vernon E. W. Frankfort 1 345 1200 Upgrade terminal equipment to 3000 A IL Proposed $1,366,000 Y CC Central AmerenIL 2299 4215 6/1/2015 Fargo 138-69 kV

Substation138 kV Capacitor Bank 138 Install 138 kV Capacitor Bank (size to be

determined)IL Proposed $1,500,000 Y C

C Central AmerenIL 2300 4216 6/1/2019 Hennepin Plant 2-3000 A PCB's 138 Install 2-3000 A, 138 kV Bus-Tie Breaker IL Proposed $9,124,000 Y CC Central AmerenIL 2301 4217 6/1/2014 Hennepin Oglesby Line 1556 1 138 321 Reconductor 477 kcmil ACSR to 1600 A

summer emergency capabilityIL 8.37 Proposed $4,215,000 Y C

C Central AmerenIL 2302 4218 6/1/2015 Madison Industrial Madison State Street 1 138 240 Reconductor 795 SAC to 1200 A summer emergency capability

IL 2.35 Proposed $710,000 Y C

C Central AmerenIL 2305 4220 6/1/2013 Monmouth 138/69 kV Substation

30 Mvar, 138 kV Capacitor Bank

138 Install 30 Mvar, 138 kV Capacitor Bank IL Proposed $1,022,000 Y C

C Central AmerenIL 2983 5186 6/1/2014 Mt. Carmel Install Capacitor Bank(s) 138 Mt. Carmel - Install capacitor bank(s). IL Proposed $1,500,000 Y CC Central AmerenIL 2985 5188 6/1/2014 Monmouth Blvd. Sub. Install 138 kV, 30 Mvar

Capacitor Bank138 30 Monmouth Blvd 138/69 kV Substation -

Install 138 kV 30 Mvar capacitor bank and circuit breaker.


C Central AmerenIL 2994 5199 6/1/2015 Wood River-N.Staunton-1436

Supply to Gillespie Macoupin 138-34.5 kV Sub.

1 138 280 Gillespie Macoupin 138-34.5 kV Substation - Tap Wood River-North Staunton 138 kV Line 1436 and make a 138 kV 'in-out' arrangement at the substation with installation of the 2nd. 138-34.5 kV transformer. 2-2000 A, 138 kV PCB's


C Central AmerenIL 2995 5200 6/1/2015 Brokaw Normal East 1 138 240 Brokaw 345/138 kV Substation - Replace 477 kcmil ACSR Bus Conductor in Brokaw-Normal East 138 kV Line 1578 position with conductor capable of carrying 1200 A continuously.

IL Proposed $100,000 Y C

C Central AmerenIL 2999 5205 6/1/2015 LaSalle Oglesby 1496 138 240 LaSalle-Oglesby Main 138 kV Line 1496 - Reconductor 2.16 miles of 477 kcmil ACSR and 336 kcmil ACSR with conductor capable of carrying 1200 A under summer emergency conditions.


C Central AmerenIL 3001 5208 6/1/2015 Baldwin-Pr. State 345 kV Supply to Mascoutah Sub.

1 345 1195 Mascoutah Area 345/138 kV Substation - Supply from the Baldwin-Prairie State 345 kV line.

IL 1 Proposed $1,000,000 Y C

C Central AmerenIL 3001 5207 6/1/2015 Mascoutah Area New 345/138 kV Xfmr 1 345 138 560 Mascoutah Area 345/138 kV Substation - Install a new 345/138 kV Substation. 1-560 MVA 345/138 kV transformer, 3-345 kV PCB's, 1-138 kV PCB.







Max kV


Miles Upg.


Cost Shared

Postage Stamp


C Central AmerenIL 3002 5209 6/1/2015 N. Decatur Clinton Rt. 54 1313 138 240 N. Decatur-Clinton Rt. 54 138 kV Line 1313 - Reconductor 5.41 miles of 336 kcmil ACSR conductor in the N. Decatur-County Hwy. 20 line section with conductor capable of carrying 1200 A under summer emergency conditions.

IL 5.41 Proposed $1,650,000 Y C

C Central AmerenIL 3004 5211 6/1/2015 Gilman Sub Install 138 kV capacitor bank

1 138 Gilman 138-69 kV Substation - Install 138 kV capacitor bank and PCB


C Central AmerenIL 3005 5212 12/1/2015 S. Belleville Tilden 1526 138 280 S. Belleville-Tilden 138 kV Line 1526 - Replace 1200 A terminal equipment (PCB, CT's, and bus conductor) at S. Belleville Substation with equipment capable of carrying 2000 A continuously.


C Central AmerenIL 3006 5213 6/1/2016 Vermilion Champaign 1396 138 240 Vermilion-Champaign 138 kV Line 1396 - Reconductor 26.8 miles of 477 kcmil ACSR with minimum 1200 A SE capability.

IL 26.8 Conceptual $8,100,000 Y C

C Central AmerenIL 3011 5221 6/1/2017 Joppa Mound City 1 161 280 Joppa-Mound City 161 kV Line - Reconductor 23.4 mi. 556 ACSR with conductor capable of carrying 1200 A under summer emergency conditions.


C Central AmerenIL 3012 5222 6/1/2017 Brokaw Normal, East 1 138 287 Normal East 138/34 kV Substation - Upgrade 600 A terminal equipment to minimum 1200 A SE capability in the Brokaw-Normal East 138 kV line terminal.

IL Proposed $100,000 Y C

C Central AmerenIL 3013 5223 6/1/2017 Turkey Hill Cahokia 1492 345 1793 Turkey Hill-Cahokia 345 kV - Reinsulate the existing Turkey Hill-Cahokia 138 kV Line 1492 (18.8 miles) to 345 kV service.

IL 18.8 Proposed $1,000,000 Y C

C Central AmerenIL 3015 5225 6/1/2018 Grand Tower Plant E. W. Frankfort 1 345 1793 Grand Tower-E.W. Frankfort 345 kV - New 41 mile, 345 kV, 3000 A line. 345 kV PCBs: 2-Grand Tower; 2- E.W. Frankfort

IL 41 Conceptual $82,000,000 Y C

C Central AmerenIL 3016 5226 11/15/2019 Galesburg Sub Install 345/138 kV Xfmr 1 345 138 560 Galesburg 345/138 kV Substation - 1-560 MVA 345/138 kV transformer, 3-345 kV PCBs for 345 kV ring bus

IL Conceptual $18,480,000 Y C

C Central AmerenIL 3018 5228 6/1/2018 Tazewell Tremont Tap 1 138 160 –Meredosia-Ipava 345 kV Line – New 43 mi. double-circuit line from Meredosia to Ipava.

IL 3 3 Conceptual $2,922,000 Y C

C Central AmerenIL 3019 5229 6/1/2018 Oglesby Substation New 345/138 kV Xfmr 1 345 138 560 –3-Position 345 kV Ring Busses at Meredosia, Quincy, Ipava


C Central AmerenIL 3021 5231 6/1/2018 Mound City Charleston 1 161 280 Mound City-Charleston 161 kV Line - New 20 mile, 1200 A summer emergency capability line. 3-161 kV PCBs: 2-Mound City, 1-Charleston.


C Central AmerenIL 3023 5233 6/1/2018 E. Collinsville Porter Rd. 1432 138 411 E. Collinsville-Porter Road 138 kV Line 1432 -Reconductor 5.15 miles of 477 kcmil ACSR with conductor capable of carrying 2000 A under summer emergency conditions.

IL 5.15 Proposed $1,600,000 Y C

C Central AmerenIL 3024 5234 6/1/2015 Bunsonville Sub Install 2nd. 345/138 kV Xfmr

345 138 Bunsonville 345/138 kV Substation - Install 2nd. 560 MVA Transformer.


C Central AmerenIL 3026 5236 6/1/2019 Havana Plant Connection to R.A.T. 1 138 Havana Plant 138 kV Switchyard - Add 138 kV Connection for new Reserve Auxiliary Transformer needed to supply new pollution control load.

IL Conceptual $100,000 Y C

C Central AmerenIL 3029 5241 6/1/2019 Gibson City Brokaw 1 138 240 Gibson City Plant 138 kV Outlet - Increase capabilty of Gibson City-Brokaw and Gibson City-Paxton 138 kV lines.







Max kV


Miles Upg.


Cost Shared

Postage Stamp


C Central AmerenIL 3030 5242 6/1/2019 Gibson City Paxton 1 138 240 Gibson City Plant 138 kV Outlet - Increase capabilty of Gibson City-Brokaw and Gibson City-Paxton 138 kV lines.


C Central AmerenIL 3033 5249 6/1/2019 Dupo Dupo Ferry 1 138 411 New Dupo-Dupo Ferry 138 kV 2000 A line. IL 0.5 Conceptual $1,500,000 Y CC Central AmerenIL 3033 5248 6/1/2019 Cahokia Dupo 1 345 1793 New 8 mi. 3000 A 345 kV line from Cahokia

Substation, 2-345 kV PCBs @ Cahokia, and 138 kV Outlet to Cahokia-Meramec circuits near Lemay Taps. New Dupo-Dupo Ferry 138 kV 2000 A line.


C Central AmerenIL 3033 5247 6/1/2019 Dupo Sub New 345/138 kV Xfmr 1 345 138 560 Dupo Area 345/138 kV Substation - 1-560 MVA Transformer, 8-138 kV PCBs.


C Central AmerenIL 3035 5251 6/1/2019 Kinmundy Salem, West 1 138 240 Kinmundy-Salem, West 138 kV line - Increase clearances to ground.


C Central AmerenIL 3036 5252 6/1/2019 Latham Sub Install 2nd. 345/138 kV Xfmr

2 345 138 448 Latham 345/138 kV Substation - Install 2nd. 345/138 kV, 448 MVA Transformer. 1-345 kV PCB, 1-138 kV PCB.


C Central AmerenIL 3037 5253 6/1/2019 Rush Island Dupo 1 345 1793 Rush Island-Dupo 345 kV Line - New 27 mile, 3000 A summer emergency capability line. Design for double-circuit. 2-345 kV PCBs: 1-Rush Island, 1-Dupo.


C Central AmerenIL 3039 5255 6/1/2020 Grand Tower Plant Joppa Plant 1 345 1793 Grand Tower-Joppa 345 kV Line - New 50 mile 345 kV, 3000 A line. 345 kV PCBs: 2-Grand Tower; 1-Joppa.


C Central AmerenIL 3040 5256 6/1/2020 Tazewell S. Bloomington 1 345 1793 Tazewell-South Bloomington 345 kV Line - New 35 mile, 345 kV, 3000 A line. 345 kV PCBs: 2 at Tazewell, 3 at South Bloomington switching station.


C Central AmerenIL 3043 5259 6/1/2020 LaSalle Oglesby 1 345 1793 LaSalle-Oglesby 345 kV Line - New 22 mi. 3000 A summer emergency capability line; 1-345 kV PCB at LaSalle, 1-138 kV PCB at Oglesby.


C Central AmerenIL 3044 5260 6/1/2021 Roxford Pawnee 1 345 1793 Roxford-Pawnee 345 kV Line - New 60 mile, 3000 A summer emergency capability line. 3-345 kV PCBs (1-Roxford, 2-Pawnee). Install WAMS - PMU at Pawnee on new line terminal.


C Central AmerenIL 3175 5606 6/1/2020 Palmyra Tap Pawnee 1 765 3975 Construct new 765 kV Line IL 117.7 Conceptual $347,557,224 y CC Central AmerenIL 3176 5607 6/1/2020 Pawnee Breed 1 765 3975 Construct new 765 kV Line IL 140.4 Conceptual $404,702,844 y CC Central AmerenIL 3177 5608 6/1/2020 Pawnee Substation 765 345 2250 Install 765/345 kV Transformer IL Conceptual $28,200,000 y CC Central AmerenIL 3178 5609 6/1/2020 Pawnee Powerton 1 765 3975 Construct new 765 kV Line IL 79.2 Conceptual $224,509,670 y CC Central AmerenIL 3182 5613 6/1/2020 St. Francois Grand Tower 1 765 3975 Construct new 765 kV Line MO 63.4 Conceptual $193,607,736 y CC Central AmerenIL 3183 5614 6/1/2020 Grand Tower Substation 765 345 2250 Install 765/345 kV Transformer IL Conceptual $28,200,000 y CC Central AmerenIL 3184 5615 6/1/2020 Grand Tower Rockport 1 765 3975 Construct new 765 kV Line IL 172 Conceptual $494,506,712 y CC Central AmerenIL 3197 5652 5/1/2014 Kewanee Transformer 1 161 138 new transformer IL Proposed $4,000,000 Y CC Central AmerenIL 3197 5651 6/1/2017 Oak Grove Kewanee 1 161 new line IL 38 Proposed $57,000,000 Y CC Central AmerenIL 3198 5654 5/1/2014 Kewanee Transformer 1 345 138 new transformer IL Proposed $5,000,000 Y CC Central AmerenIL 3198 5655 5/1/2014 Kewanee Transformer 1 345 138 new transformer IL Proposed $5,000,000 Y CC Central AmerenIL 3198 5653 6/1/2017 Oak Grove Kewanee 1 345 new line IL 38 Proposed $76,000,000 Y CC Central AmerenIL 3336 6201 6/1/2014 Gilman Watseka 1 138 322 Reconductor to 1600 A summer emergency

capabilityIL 15.21 Proposed $4,763,000 Y C

C Central AmerenIL 3338 6203 6/1/2013 Lanesville 1 345 138 560 Replace existing transformer with a 560 MVA unit


C Central AmerenIL 3339 6204 6/1/2014 Pana, North Taylorville, South 1 138 322 Reconductor to 1600 A summer emergency capability. Upgrade terminal equipment to match

IL 12.91 Proposed $4,073,000 Y C

C Central AmerenIL 3340 6205 6/1/2016 Pawnee, North Taylorville, South 1 138 240 Replace bus conductor at both terminals to 1200 A summer emergency capability







Max kV


Miles Upg.


Cost Shared

Postage Stamp


C Central AmerenIL 3341 6206 6/1/2015 Diamond Star West Washington Street 1 138 240 Reconductor 336 kcmil ACSR conductor to 1200 A summer emergency capability


C Central AmerenIL 3342 6207 6/1/2015 Diamond Star McClean County Sw. Station

1 138 160 Increase ground clearance on 477 kcmil ACSR conductor


C Central AmerenIL 3343 6208 6/1/2015 Raab Rd White Oak Tap 1 138 160 Increase ground clearance on 477 kcmil ACSR conductor


C Central AmerenIL 3344 6209 6/1/2015 El Paso Tap Minonk Tap 1 138 160 Increase ground clearance on 477 kcmil ACSR conductor

IL 13.88 Proposed $1,300,000 Y C

C Central AmerenIL 3345 6210 6/1/2016 R. S. Wallace E. Peoria 1 138 159 Increase ground clearance on 477 kcmil ACSR


C Central AmerenIL 3346 6211 6/1/2016 Mason Holland 1 138 240 Reconductor 795 kcmil ACSR to 1200 A summer emergency capability


C Central AmerenIL 3347 6212 6/1/2016 Mason San Jose Rail 1 138 240 Reconductor 795 kcmil ACSR to 1200 A summer emergency capability


C Central AmerenIL 3348 6213 6/1/2017 Pawnee Sub Install 2nd. 345/138 kV xfmr

1 345 138 560 Pawnee, West 345/138 kV Substation - Replace existing transformer with 560 MVA unit


C Central AmerenIL 3349 6214 6/1/2020 East Galesburg Monmouth Blvd. 1 138 160 Replace breaker at East Galesburg with 1200 A breaker. Replace terminal equipment to 1200 A capability.


C Central AmerenIL 3350 6215 12/1/2012 East Kewanee Princeton Tap 1 138 240 Reconductor 477 kcmil ACSR conductor to 1200 A summer emergency capability. Replace terminal equipment at East Kewanee to 1200 A capability.

IL 15.33 Planned $2,656,000 Y C

C Central AmerenIL 3351 6216 6/1/2015 Wood River Sub Install 2-138 kV Bus-Tie Breakers

138 478 Install 2-2000 A, 138 kV bus-tie breakers IL Proposed $2,000,000 Y C

C Central AmerenIL 3352 6217 6/1/2013 West Tilton Sub Install 40 Mvar Cap Bank

138 Install 40 Mvar, 138 kV capacitor bank. IL Proposed $1,500,000 Y C

C Central AmerenIL 3353 6218 6/1/2012 Edwards Keystone 1 138 382 Replace 138 kV, 1200 A breaker and terminal equipment at Keystone terminal to 2000 A capability

IL 3.27 Proposed $1,100,000 Y C

C Central AmerenIL 3354 6219 6/1/2014 Edwards Caterpillar Sub 1 1 138 220 Increase ground clearand on 795 kcmil ACSR and 927 ACAR conductor


C Central AmerenIL 3362 6229 9/30/2013 California Ridge Switching Station

Generator connection 138 Install a 3-position ring bus to facilitate connection of wind farm (H100) to the Sidney-Rantoul Jct. 138 kV line.


C Central AmerenIL 3369 6240 6/1/2012 Quincy, East Replace 138-34.5 kV Trnsformer Bank #3

138 112 Replace 138-34.5 kV Transformer Bank #3 with a 112 MVA unit. Replace 600 A, 138 kV disconnect switch with minimum 800 A capability

IL Planned $100,000 Y C

C Central AmerenIL, Non-MI 2197 4061 8/1/2018 St. Francois Rockport 1 765 2904 new line MO/IL/IN 186 Conceptual $599,000,000 Y CC Central AmerenIL, Non-MI 2215 4064 8/1/2018 Coffeen Sullivan 1 765 3768 new line IL/IN 100 Conceptual $322,000,000 Y CC Central AmerenMO 2122 3977 11/17/2011 Point Prairie 161-34.5 kV

SubAECI Enon Substation 1 161 280 Extend 1 mile of line to AECI Enon

SubstationMO 1 Planned $1,896,500 Y C

C Central AmerenMO 2292 4208 6/1/2016 Kelso 345/161 kV, 336 MVA Transformer

345 161 450 Replace 345/161 kV, 336 MVA Transformer w/ 450 MVA Transformer

MO Proposed $6,134,000 Y C

C Central AmerenMO 2296 4212 6/1/2013 Belleau 345/138 kV Substation

2nd. 345/138 kV, 560 MVA Transformer

345 138 560 Install 2nd. 345/138 kV, 560 MVA Transformer


C Central AmerenMO 2297 4213 6/1/2013 Belleau 345/138 kV Substation

120 Mvar, 138 kV Capacitor Bank

138 Install 120 Mvar, 138 kV Capacitor Bank (Install as 2-60 Mvar stages)


C Central AmerenMO 2298 4214 6/1/2013 AECI's Enon 345/161 kV Substation

2-345 kV PCB's 345 Install 2-PCB's on incoming 345 kV lines at AECI's Enon Substation


C Central AmerenMO 2975 5176 12/1/2012 Dupo Ferry-Selma-1 Connection to Wings Enterprises

1 138 287 Dupo Ferry-Selma-1 138 kV Line - Install 3 position 138 kV ring bus and extend 138 kV line to serve a customer substation (Wings Enterprises). 3-138 kV, 1200A PCB's







Max kV


Miles Upg.


Cost Shared

Postage Stamp


C Central AmerenMO 2987 5191 6/1/2014 Taum Sauk Plant Install 2-30 Mvar, 138 kV Capacitor Banks

138 60 Taum Sauk 138 kV Capacitor Banks - 2-30 Mvar banks; 2-138 kV synchronous PCBs.

MO Conceptual $1,500,000 Y C

C Central AmerenMO 2990 5194 6/1/2014 Conway Tyson 3 138 240 Conway-Tyson-3 138 kV - Increase ground clearance on Tyson-Orchard Gardens sections (7 miles)

MO 7 Proposed $350,000 Y C

C Central AmerenMO 2990 5195 6/1/2014 Conway Tyson 4 138 240 Conway-Tyson-4 138 kV - Increase ground clearance on Tyson-Orchard Gardens sections (7 miles)

MO 7 Proposed $350,000 Y C

C Central AmerenMO 2991 5196 6/1/2014 Mason 345/138 kV Sub Replace Xfmr #2 2 345 138 700 Mason 345/138 kV Substation - Replace 345/138 kV, 560 MVA Transformer #2 with a 700 MVA unit


C Central AmerenMO 2993 5198 6/1/2014 Dupo Ferry Buck Knob 1 138 275 Dupo Ferry-Buck Knob 138 kV Line - Replace 22 mi. of 2-300 ACSR with maximum size conductor existing towers will support.

MO 22 Proposed $6,600,000 Y C

C Central AmerenMO 2996 5201 6/1/2015 Montgomery Spencer Creek 1 345 1072 Montgomery-Spencer Creek 345 kV - Increase ground clearance on 28 miles of 795 kcmil ACSR conductor and upgrade terminal equipment at Montgomery Substation.


C Central AmerenMO 2998 5204 6/1/2015 Overton Substation 2nd. 345/161 kV Xfmr 2 345 161 450 Overton 345/161 kV Substation - 2nd Transformer - 450 MVA; 1-161 kV PCB, 2-345 kV PCBs, 345 kV Ring Bus


C Central AmerenMO 3000 5206 6/1/2015 Miller New 138/161 kV Xfmr 1 345 161 300 Miller 138/161 kV Substation - Install a new 300 MVA 138/161 kV transformer to convert Miller-Zion line to 161 kV operation and increase voltage support to Jefferson City, Missouri area.


C Central AmerenMO 3007 5215 6/1/2016 Camden Install 161/138 kV Xfmr 1 161 138 300 Install 300 MVA, 161/138 kV autotransformer at Camden


C Central AmerenMO 3007 5214 6/1/2016 Camden Ullman 1 138 322 Camden-Ullman 138 kV Line - Construct 16 miles of 138 kV between Camden Substation and Ullman, with 1600 A summer emergency capability. Install 300 MVA, 161/138 kV autotransformer at Camden


C Central AmerenMO 3008 5216 6/1/2016 Overton Sub Install 161 kV, 90 Mvar Capacitor Bank

1 161 90 Overton 161 kV Capacitor Bank - 1-90 Mvar capacitor bank, 1-161 kV synchronous PCB, 1-161 kV reactor.


C Central AmerenMO 3014 5224 6/1/2018 Cape Joppa 1 161 375 Cape-Joppa 161 kV Line - Reconductor line (40.27 miles) to 1600 A Summer Emergency Capability.

IL 40.27 Proposed $12,100,000 Y C

C Central AmerenMO 3020 5230 6/1/2018 Overton Columbia 1 161 250 Overton-Huntsdale-Columbia 161 kV - Replace 800 A CT at Overton Terminal with 1200 A unit.

MO Proposed $50,000 Y C

C Central AmerenMO 3025 5235 6/1/2019 Rivermines N. Farmington 2 138 240 Rivermines-N. Farmington 138 kV Line - Construct a second 138 kV line.

MO 5.5 Proposed $7,500,000 Y C

C Central AmerenMO 3027 5237 6/1/2019 Campbell Substation Install 2nd. 345/138 kV Xfmr

2 345 138 560 Campbell 345/138 kV Substation - 2nd 560 MVA transformer; 2-345 kV PCBs (1-Campbell, 1-Roxford); 1-138 kV PCB @ Campbell.


C Central AmerenMO 3028 5240 6/1/2019 Campbell Page 2 138 411 Campbell-Euclid-Page 138 kV Line - Rebuild 5.25 mi. double-circuit 138 kV 2000 A SE capability. 3-138 kV PCBs (2-Campbell, 1-Page). Operate Euclid 138 kV Bus-Tie normally closed.

MO 5.25 Proposed $4,250,000 Y C






Max kV


Miles Upg.


Cost Shared

Postage Stamp


C Central AmerenMO 3028 5239 6/1/2019 Campbell Page 1 138 411 Campbell-Euclid-Page 138 kV Line - Rebuild 5.25 mi. double-circuit 138 kV 2000 A SE capability. 3-138 kV PCBs (2-Campbell, 1-Page). Operate Euclid 138 kV Bus-Tie normally closed.

MO 5.25 Proposed $4,250,000 Y C

C Central AmerenMO 3028 5238 6/1/2019 Campbell Roxford 1 345 1793 New 12.8 mi. Roxford-Campbell 345 kV 3000 A summer emergency capability line

MO 12.8 Conceptual $12,800,000 Y C

C Central AmerenMO 3030 5243 6/1/2019 Labadie Mason 3 345 1793 Labadie-Mason 345 kV Line #3 - New 25 mi. 3000 A summer emergency capability line designed for double-circuit. 345 kV PCBs: 1-Labadie, 1- Mason.


C Central AmerenMO 3031 5245 6/1/2019 Page Area Sub Install 345/138 kV Xfmr 2 345 138 560 Page Area 345/138 kV Substation -Second of 2-560 MVA transformers. 9-138 kV PCBs: 2-transformer, 1-bus-tie, 6-line (2-Warson, 2-Page, 2-Hunter).


C Central AmerenMO 3031 5244 6/1/2019 Page Area Sub Install 345/138 kV Xfmr 1 345 138 560 Page Area 345/138 kV Substation - First of 2-560 MVA transformers. 9-138 kV PCBs: 2-transformer, 1-bus-tie, 6-line (2-Warson, 2-Page, 2-Hunter).


C Central AmerenMO 3032 5246 6/1/2019 Campell Mason 1 345 1793 Campbell-Page-Mason 345 kV Line - New 16.5 mi. 3000 A summer emergency capability line, plus reutilization of 14.5 miles of existing Page-Sioux-4 at 345 kV.

MO 14.5 16.5 Proposed $35,750,000 Y C

C Central AmerenMO 3034 5250 6/1/2019 Loose Creek Kingdom City 1 345 1793 Loose Creek-Kingdom City 345 kV Line - New 25 mile 345 kV, 3000 A line. 2-345 kV PCBs at Loose Creek, 2-345 kV PCBs at Kingdom City..

MO 25 Conceptual $52,000,000 Y C

C Central AmerenMO 3038 5254 6/1/2019 Loose Creek Pleasant Hill 1 345 1793 Loose Creek-Barnett-Windsor-Pleasant Hill 345 kV Line - New 138 mile 345 kV, 3000 A line. 560 MVA, 345/161 kV transformer at Barnett Substation. 345 kV PCBs: 2 at Loose Creek, 2 at Barnett, 2 at Windsor, 2 at Pleasant Hill.


C Central AmerenMO 3042 5258 6/1/2020 Palmyra Fairport 1 345 1793 Palmyra-Thomas Hill-Fairport - New 122 mile 345 kV, 3000 A line. 345 kV PCBs: 2 at Palmyra, 2 at Thomas Hill, 2 at Fairport.


C Central AmerenMO 3045 5261 6/1/2021 St. Francois Fletcher 1 345 1793 St. Francois-Fletcher 345 kV Line - New 48 mi. 3000 A SE capability. 345 kV terminals at St. Francois & Fletcher. Install WAMS - PMU at St. Francois on new line terminal.


C Central AmerenMO 3171 5602 6/1/2018 West Adair Fairport 1 345 1793 Construct new 345 kV Line MO 113.2 Conceptual $171,818,625 y CC Central AmerenMO 3173 5604 6/1/2020 Fairport Palmyra Tap 1 765 3975 Construct new 765 kV Line MO 176.6 Conceptual $500,335,836 y CC Central AmerenMO 3174 5605 6/1/2020 Palmyra Tap Substation 765 345 2250 Install 765/345 kV Transformer MO Conceptual $28,200,000 y CC Central AmerenMO 3179 5610 6/1/2020 Palmyra Tap Montgomery 1 765 3975 Construct new 765 kV Line MO 67.9 Conceptual $192,436,860 y CC Central AmerenMO 3180 5611 6/1/2020 Montgomery Substation 765 345 2250 Install 765/345 kV Transformer MO Conceptual $28,200,000 y CC Central AmerenMO 3181 5612 6/1/2020 Montgomery St. Francois 1 765 3975 Construct new 765 kV Line MO 104.1 Conceptual $295,069,852 y CC Central AmerenMO 3187 5625 6/1/2020 St. Francois Substation 765 345 2250 Install 765/345 kV Transformer MO Conceptual $28,200,000 Y CC Central AmerenMO 3356 6222 12/1/2012 Tegeler Osage 1 138 128 Replace 138 kV disconnect switch at

Freeburg with new 1200 A switchMO Planned $200,000 Y C

C Central AmerenMO 3364 6231 6/1/2015 Franklin Sub. Install 3-1200 A breakers 138 Install 3-1200 A breakers to accommodate 138 kV supplies to Prairie Dell 138-34.5 kV Substation


C Central AmerenMO 3364 6235 6/1/2015 Gray Summit Sub. Prairie Dell 138 240 Install 138 kV breakers, build 3.1 miles of new double circuit 138 kV line, and connect 9.6 miles of existing 138 kV line presently operated at 34.5 kV to establish supplies to Prairie Dell Substation

MO 7.1 3.1 Proposed $1,550,000 Y C






Max kV


Miles Upg.


Cost Shared

Postage Stamp


C Central AmerenMO 3364 6234 6/1/2015 Franklin Prairie Dell 138 240 Install 138 kV breakers, build 3.1 miles of new double circuit 138 kV line, and connect 9.6 miles of existing 138 kV line presently operated at 34.5 kV to establish supplies to Prairie Dell Substation

MO 2.5 3.1 Proposed $1,550,000 Y C

C Central AmerenMO 3364 6233 6/1/2015 Prairie Dell Sub. Install 4-1200 A breakers 138 Install 4-1200 A breakers to accommodate 138 kV supplies to Prairie Dell 138-34.5 kV Substation


C Central AmerenMO 3364 6232 6/1/2015 Gray Summit Sub. Install 1-1200 A breaker 138 Install 1-1200 A breaker to accommodate 138 kV supplies to Prairie Dell 138-34.5 kV Substation


C Central AmerenMO 3365 6236 12/1/2011 Delbridge Install 2000 A breaker and disconnect switches

138 367 Install 2000 A breaker and 2-2000 A 138 kV motor operated disconnect switches


C Central AmerenMO 3366 6237 12/1/2011 Wallen Creek Install 1200 A breaker and disconnect switches

138 240 Install 2000 A breaker and 2-2000 A 138 kV motor operated disconnect switches


C Central AmerenMO 3367 6238 9/1/2013 Pershall Taps to Berkeley-Sioux-1 138 kV

138 240 Install 4-2000 A breaker ring bus and connect to Berkeley-Sioux-1 138 kV to establish 138 kV connections for Pershall 138-12.47 kV Sub


C Central AmerenMO, Amere 2195 4042 8/1/2018 Montgomery Coffeen 1 765 3576 new line MO/IL 111 Conceptual $343,000,000 Y CC Central ATC LLC 3486 6443 6/1/2021 Bluemound Oak Creek 1 138 574 Uprate 138 kV line to 275 F WI 40 Conceptual $1,400,000 Y CC Central BREC 3435 6338 12/31/2017 Rome Junction West Owensboro 1 69 72 MVA reconductor line KY 5.8 0 Proposed $440,000 Y CC Central BREC 3436 6339 12/31/2018 Wilson Sacremento 1 69 72 MVA new line KY 0 11 Proposed $2,100,000 Y CC Central BREC 3437 6340 12/31/2018 Thruston Junction East Owensboro 1 69 67 MVA reconductor line KY 0.4 0 Proposed $40,000 Y CC Central BREC 3438 6341 12/31/2018 Daviess County Philpot Tap 1 69 72 MVA reconductor line KY 7.7 0 Proposed $580,000 Y CC Central BREC 3439 6342 12/31/2022 Ensor 161 kV Ensor 69 kV 161 69 56 MVA new substation KY Proposed $6,200,000 Y CC Central BREC 3440 6343 12/31/2024 Reid EHV 161 kV Reid EHV 69 kV 161 69 56 MVA new transformer KY Proposed $5,000,000 Y CC Central BREC 3441 6344 12/31/2020 Olivet Church Road Olivet Church Road Tap 1 69 72 MVA reconductor line KY 1.4 0 Proposed $150,000 Y CC Central BREC 3442 6345 12/31/2024 White Oak 161 kV White Oak 69 kV 161 69 56 MVA new transformer KY Proposed $1,900,000 Y CC Central BREC 3443 6346 12/31/2017 Hardinsburg 161 kV Hardinsburg 69 kV 161 69 100 MVA new transformers KY Proposed $4,000,000 Y CC Central BREC 3444 6347 12/31/2020 Meade Coutny 161 kV Meade County 69 kV 161 69 56 MVA new transformer KY Proposed $700,000 Y CC Central BREC 3445 6348 12/31/2020 Brandenburg 1 69 6 MVAR new capacitor KY Proposed $300,000 Y CC Central BREC 3446 6349 12/31/2022 Hardinsburg No. 1 Harned 1 69 72 MVA reconductor line KY 2 0 Proposed $170,000 Y CC Central DEM 840 819 6/1/2016 Rushville Capacitor 69 14.4 MVAR Add capacitor IN Planned $510,845 NT CC Central DEM 1249 1957 12/31/2016 Frankfort 230 Capacitor 69 36 MVAR Install 36 MVAR 69kV capacitor IN Planned $632,358 NT CC Central DEM 1264 1981 6/1/2022 Speed 345 138 717 Replace existing 345/138 transformer at

Speed with a new transformer rated at 3,000A or higher.

IN Alternative $7,541,500 Y C

C Central DEM 1518 2594 6/1/2016 Curliss transformer 1 138 69 150 Install new Curliss 138-69 kV sub in the 5884 ckt, 150 MVA xfmr, Install one 69 kV circuit. Convert Glen Este and Batavia dist subs from 34 to 69kV primary voltage.

OH 12.18 Proposed $9,818,000 Y C

C Central DEM 1571 3123 6/1/2015 IPL Rockville Avon East 1 138 306 Construct 4.3 miles / 954ACSR of 138kv line from IPL Rockville to Avon East

IN 4.3 Alternative $2,980,000 Y C

C Central DEM 1900 3796 6/1/2015 Avon Industrial Park new dist sub 1 138 12 306 Avon Industrial Park (aka Central Logistics) - Construct 69/138-12kV - 22.4 MVA sub and 2.6 mile - 69kV radial line from roughly the Avon South sub - unknown if this will be a 69 or 138 kv sub

IN 2.6 Proposed $923,000 NT C

C Central DEM 1904 3801 6/1/2015 Batesville Hillenbrand 1 69 53 Uprate 69kV Batesville to Hillenbrand to 100C – 4/0acsr – 2.1 miles – 69107 ckt

IN 2.1 Planned $115,961 NT C

C Central DEM 2124 2909 6/1/2020 Brooklyn HE Brooklyn 1 69 153 Brooklyn Sub to HE Brooklyn Sub reconductor 1.28 miles of 6940 line 4/0 Cu with 954ACSR@100C


C Central DEM 2125 2910 6/1/2020 Centerton transformer 1 138 69 168 Upgrade/replace existing 75MVA 138/69kV bank with 150MVA bank

IN Planned $3,091,000 NT C






Max kV


Miles Upg.


Cost Shared

Postage Stamp


C Central DEM 2129 2914 6/1/2020 Plainfield South HE Mooresville Jct 1 69 153 Plainfield South to HE Mooresville Jct 69kV reconductor 4/0Cu with 954ACSR 2.03 miles


C Central DEM 2135 2920 6/15/2014 Franklin 230 capacitor 69 36 MVAR Franklin 230 Sub 69kV Cap - Install 36MVAR 69kV bus capacitor bank

IN Planned $400,000 NT C

C Central DEM 2139 2924 6/30/2016 Greenwood West switch 69 143 Greenwood West Sub - upgrade (or replace, if required) 69kV Loadbreak switch #2 for 1200amp capacity in the 6999 ckt.

IN Planned $50,000 NT C

C Central DEM 2140 2925 6/30/2015 Greenwood West Lenore Jct. 1 69 100 Greenwood West to Lenore Jct reconductor 69kV - 6949 ckt. with 477ACSR @ 100C conductor

IN 5.51 Planned $1,377,500 NT C

C Central DEM 2144 2930 6/30/2015 Franklin 230 Earlywood 1 69 143 Franklin 230kV sub to Earlywood sub reconductor 1.06 mile - 69kV - 69165 line with 954ACSR@100C


C Central DEM 2145 2932 6/1/2020 Franklin 230 Bank 2 2 230 69 239 Replace 230/69kV bank 2 with a 200MVA LTC transformer

IN Planned $2,400,000 Y C

C Central DEM 2145 2931 6/1/2020 Franklin 230 Bank 1 1 230 69 239 Replace 230/69kV bank 1 with a 200MVA LTC transformer

IN Planned $2,400,000 Y C

C Central DEM 2146 2933 6/30/2015 HE Honey Creek Jct Frances Creek Jct 1 69 143 HE Honey Creek Jct to Frances Creek Jct. reconductor 69kV - 1.12 mile line section of the 69102 ckt. with 954ACSR 100C conductor.


C Central DEM 2147 2934 6/30/2015 Whiteland Madison Ave Jct 1 69 143 Whiteland Sub to Greenwood North Tap to Madison Ave Jct reconductor 3.44 mile 69kV -6997 line with 954ACSR 100C conductor.

IN 3.44 Planned $1,376,000 NT C

C Central DEM 2247 4076 8/1/2018 Gwynn Transformer 1 765 345 2767.5 new transformer IN Conceptual $20,000,000 Y CC Central DEM 2328 4260 6/1/2015 Speed HE Bethany 1 69 71.7 Speed to HE Bethany 69kV - 6955

Reconductor Ph2 - Replace 1.6 miles of 4/0 ACSR with 477 ACSR (new limiter 600A switches)


C Central DEM 2329 4261 6/1/2014 Clarksville Indiana Arsenal 1 69 100 Clarksville to Indiana Arsenal 69kv - 6955 ckt. reconductor 1.1 miles of 4/0acsr with 477ACSR at 100C (this is Phase 2 remainder of 4/0ACSR in this line section)


C Central DEM 2330 4262 6/1/2014 New Albany HE Georgetown 1 69 100 New Albany to HE Georgetown 69kv - 6970 ckt. Reconductor 1.24 miles of 4/0acsr with 477acsr@100C


C Central DEM 2795 4917 5/1/2015 Rockport (AEP) Greentown (DEM) 1 765 New 765 kV line from Rockport (AEP) to Greentown (DEM)

IN 240 Proposed $1,000,000,000 Y C

C Central DEM 2862 5015 6/1/2016 Staunton Lone Star Jct 1 138 160 Uprate Staunton to Greencastle Jct to Lonestar Jct 13802 circuit 336ACSR for 100C cond temp operation (Lone Star Jct switches may also need upgraded to 1200A)

IN 19.98 Planned $350,000 Y C

C Central DEM 2864 5017 6/1/2020 Centeron Martinsville 1 69 153 Reconductor the 69kV-69163 ckt - 3.47 miles of 366ACSR 80C and 0.23 miles of 477ACSR 80C to 954ACSR 100C

IN 3.7 Planned $1,110,000 NT C

C Central DEM 2868 5021 6/1/2014 Fairfax Senco Sta. 2 1 69 153 F868 - Reconductor Fairfax to Senco - Replace 4/0 ACSR with 954 ACSR - Approx 4.6 miles

OH 4.6 Proposed $1,711,992 NT C

C Central DEM 2873 5026 6/1/2018 Danville East new dist sub 1 69 12 Construct new Danville East substation near HRH hospital - single 22.4MVA transformer - 6945 ckt to be looped through

IN 0.5 Proposed $500,000 NT C

C Central DEM 3382 6255 12/31/2017 Vincennes Vigo St. convert distribution sub 1 138 12 287 Build new radial 138kV line and add breaker at Vincennes 138kV sub to convert Vigo St. sub from 34kV to 138kV

IN 2.3 Planned $1,800,000 Y C

C Central DEM, IPL 2783 3105 5/1/2012 Wheatland Bloomington 1 345 1200 new line IN 61 Proposed $105,000,000 Y CC Central DEM, Non-MISO 2213 4087 8/1/2018 Buffington Ghent 1 345 1000 new line KY 33.2 Conceptual $47,000,000 Y CC Central IPL 2246 4075 8/1/2018 Petersburg Transformer 1 765 345 2767.5 new transformer IN Conceptual $20,000,000 Y C






Max kV


Miles Upg.


Cost Shared

Postage Stamp


C Central IPL 2897 5070 6/1/2013 Petersburg Hanna/Frances Creek 1 345 1195 Increase line rating from 956 to 1195 MVA IN 111.42 Proposed $2,500,000 Y CC Central IPL 2898 5071 6/1/2014 Hanna Southeast 1 138 574 Increase line rating from 287 to 574 MVA IN Proposed $4,000,000 Y CC Central IPL 2899 5072 6/1/2015 Guion Whitestown 1 345 1195 Increase line rating from 956 to 1195 MVA IN 11.14 Proposed $1,000,000 Y CC Central IPL 2901 5076 Petersburg Duke Wheatland 1 345 1386 Increase line rating from 956 to 1386 MVA IN 11.22 Proposed $4,000,000 Y CC Central IPL 2901 5075 Duke Wheatland Bus Tie Breakers 345 Closing the Wheatland bus tie breakers

connects the IPL Petersburg - Duke Wheatland - AEP Breed line into the Duke Wheatland 345 kV Substation

IN Proposed $0 Y C

C Central IPL 2901 5074 Hanna/Franklin Township

HE Bloomington 1 345 1195 New IN 45 Proposed $60,400,000 Y C

C Central IPL 2901 5077 Duke Wheatland AEP Breed 1 345 1386 Increase line rating from 956 to 1386 MVA IN 40.27 Proposed $6,500,000 Y CC Central MEC, AmerenMo 2194 4041 8/1/2018 Montgomery Toledo 1 765 2640 new line IA/MO 275 Conceptual $871,000,000 Y CC Central Non-MISO 2199 4039 8/1/2018 Pontiac Dequine 1 765 4368 new line IL/IN 87 Conceptual $265,000,000 Y CC Central Non-MISO 2200 4050 8/1/2018 Dequine South Chicago 1 765 5376 new line IN 64 Conceptual $161,000,000 Y CC East ATC LLC, ITC 2208 4082 8/1/2018 Livingston Dead River 1 345 488 new line MI 232 Conceptual $329,000,000 Y CC East DEM, Non-MISO 2203 4069 8/1/2018 Blue Creek Greentown 1 765 6000 new line IN 59 Conceptual $191,000,000 Y CC East ITC 694 1388 12/31/2018 Saratoga 120 kV Bunce Creek 120 kV 1 120 313 MI 12.5 0.6 Proposed Y CC East ITC 694 1385 12/31/2018 Saratoga 345/120 kV

(sw sta provisions)transformer 345 120 MI Proposed Y C

C East ITC 694 1387 12/31/2018 Saratoga 120 kV Wabash 120 kV 1 120 299 MI 13.6 0.6 Proposed Y CC East ITC 694 1389 12/31/2018 Saratoga 120 kV Burns 2 120 kV 1 120 313 MI 17.7 0.6 Proposed Y CC East ITC 694 1390 12/31/2018 Saratoga 345 kV Greenwood 345 kV 1 345 2241 MI 13.4 Proposed Y CC East ITC 694 1391 12/31/2018 Saratoga 345 kV Greenwood 345 kV 2 345 2552 MI 13.4 Proposed Y CC East ITC 694 1392 12/31/2018 Saratoga 345 kV Pontiac 345 kV 1 345 1769 MI 42.9 Proposed Y CC East ITC 694 1393 12/31/2018 Saratoga 345 kV Belle River 345 1 345 2259 MI 16.5 4.2 Proposed Y CC East ITC 694 1394 12/31/2018 Saratoga 345/120 kV transformer 1 345 120 700 MI Proposed Y CC East ITC 694 1386 12/31/2018 Saratoga 120 kV Robin 120 kV 1 120 444 MI 23.3 0.6 Proposed Y CC East ITC 908 936 6/1/2018 Lulu Monroe 3-4 1 345 New switching station with Majestic-Lemoyne

and Milan-Allen cut in. New line to Monroe 1-2 and cut Lemoyne-Lulu into Monroe 3-4

MI 15 Proposed Y C

C East ITC 908 3711 6/1/2018 Lulu 345 kV New Switching Station 345 New switching station with Majestic-Lemoyne and Milan-Allen cut in. New line to Monroe 1-2 and cut Lemoyne-Lulu into Monroe 3-4

MI Proposed Y C

C East ITC 908 938 6/1/2018 Lulu Allen Junction 1 345 New switching station with Majestic-Lemoyne and Milan-Allen cut in. New line to Monroe 1-2 and cut Lemoyne-Lulu into Monroe 3-4

MI 19 Proposed Y C

C East ITC 908 937 6/1/2018 Lulu Lemoyne 1 345 New switching station with Majestic-Lemoyne and Milan-Allen cut in. New line to Monroe 1-2 and cut Lemoyne-Lulu into Monroe 3-4

MI 42 Proposed Y C

C East ITC 908 935 6/1/2018 Lulu Milan 1 345 switching station Majestic-Lemoyne and Milan-Allen cut in. New Monroe 1-2 and Lemoyne-Lulu into Monroe 3-4

MI 16 Proposed Y C

C East ITC 908 934 6/1/2018 Lulu Majestic 1 345 New switching station with Majestic-Lemoyne and Milan-Allen cut in. New line to Monroe 1-2 and cut Lemoyne-Lulu into Monroe 3-4

MI 51 Proposed Y C

C East ITC 908 1579 6/1/2018 Lulu Monroe 1-2 1 345 New switching station with Majestic-Lemoyne and Milan-Allen cut in. New line to Monroe 1-2 and cut Lemoyne-Lulu into Monroe 3-4

MI 12.1 3 Proposed Y C

C East ITC 908 1580 6/1/2018 Lemoyne Monroe 3-4 1 345 2000 MI 33.1 3 Proposed Y CC East ITC 1012 1582 6/1/2014 Wayne Newburg 3 120 New line (un-six wire Newburg - Wayne 2) MI 2.8 Proposed Y CC East ITC 1295 5485 6/30/2016 Quaker 120 Southfield 120 2 120 242/290 Rebuild the existing Quaker - Drexel -

Southfield 120 kV line to double circuit and build a new Quaker - Southfield 120 kV line (7.5 miles) on the common structures.

MI 7.35 Proposed Y C






Max kV


Miles Upg.


Cost Shared

Postage Stamp


C East ITC 1295 2124 6/30/2016 Quaker 120 To Drexel to Southfield 120

1 120 242/290 Rebuild the existing Quaker - Drexel - Southfield 120 kV line to double circuit and build a new Quaker - Southfield 120 kV line (7.5 miles) on the common structures.


C East ITC 1382 2370 12/31/2016 Sprague Creek 765 kV Bridgewater 765 kV 1 765 4465 50 miles of new 765 kV line and new 765 kV Bridgewater Station

MI 50 Proposed $225,000,000 Y C

C East ITC 1382 2375 12/31/2016 Bridgewater 345 kV Majestic 345 kV 1 345 1828 Taps the majestic end of the Allen Junction-Maj-Monroe 3 ender

MI Proposed $10,000,000 Y C

C East ITC 1382 2374 12/31/2016 Bridgewater 765 kV South Canton 765 kV 1 765 4465 170 miles of new 765 kV line MI/OH 170 Proposed $600,000,000 Y CC East ITC 1382 2373 12/31/2016 Site A 765 kV Marysville 765 kV 1 765 4465 Taps Current Marysville-Dumont 765 kV line IN/OH Proposed $10,000,000 Y CC East ITC 1382 2371 12/31/2016 Bridgewater 765 kV Site A 765 kV 1 765 4465 135 miles of new 765 kV line and new 765 kV

Site A StationIN/OH 135 Proposed $530,000,000 Y C

C East ITC 1382 2369 12/31/2016 Sprague Creek 765 kV Denver 765 kV 1 765 4465 100 miles of new 765 kV line and new 765 kV Sprague Creek Station

MI 100 Proposed $400,000,000 Y C

C East ITC 1382 2368 12/31/2016 Kenowa 765 kV Denver 765 1 765 4465 30 miles of new 765 kV line and new 765 kV Denver Station

MI 30 Proposed $150,000,000 Y C

C East ITC 1382 2367 12/31/2016 Cook 765 kV Kenowa 765 kV 1 765 4465 100 miles of new 765 kV line and new 765 kV Kenowa Station

MI 100 Proposed $400,000,000 Y C

C East ITC 1382 2376 12/31/2016 Bridgewater 345 kV Majestic 345 kV 2 345 1828 Taps the Majestic-Milan 345 kV Circuit MI Proposed $10,000,000 Y CC East ITC 1382 2384 12/31/2016 Bridgewater 765/345 kV transformer 2 765 345 3040 New 765/345 kV Xfmr at Bridgewater MI Proposed $25,000,000 Y CC East ITC 1382 2372 12/31/2016 Site A 765 kV Dumont 765 kV 1 765 4465 Taps Current Marysville-Dumont 765 kV line IN/OH Proposed $10,000,000 Y CC East ITC 1382 2377 12/31/2016 Bridgewater 345 kV Milan 345 kV 1 345 1828 Taps the Majestic-Milan 345 kV Circuit MI Proposed $10,000,000 Y CC East ITC 1382 2383 12/31/2016 Bridgewater 765/345 kV transformer 1 765 345 3040 New 765/345 kV Xfmr at Bridgewater MI Proposed $25,000,000 Y CC East ITC 1382 2382 12/31/2016 Sprague Creek 765/345

kVtransformer 1 765 345 3040 New 765/345 kV Xfmr at Sprague Creek MI Proposed $25,000,000 Y C

C East ITC 1382 2381 12/31/2016 Denver 765/138 kV transformer 1 765 138 1119 New 765/138 kV Xfmr at Denver MI Proposed $25,000,000 Y CC East ITC 1382 2378 12/31/2016 Sprague Creek 345 kV Blackfoot 345 kV 1 345 795 Taps the Blackfoot-Madrid 345 kV Circuit MI Proposed $10,000,000 Y CC East ITC 1382 2379 12/31/2016 Sprague Creek 345 kV Madrid 345 kV 1 345 795 Taps the Blackfoot-Madrid 345 kV Circuit MI Proposed $10,000,000 Y CC East ITC 1382 2380 12/31/2016 Kenowa 765/354 kV transformer 1 765 345 3040 New 765/345 kV Xfmr at Kenowa MI Proposed $25,000,000 Y CC East ITC 1550 2639 5/31/2015 Hager 120 kV Sunset 120 kV 1 120 351 Transpose line entrance with the Sunset-

Southfield 120 kV circuitMI 0.1 Proposed Y C

C East ITC 1854 3740 6/1/2018 Riverview Ironton 1 120 Replace Wave Trap MI Proposed Y CC East ITC 1854 3739 6/1/2018 Trenton Channel Jefferson 1 120 reconductor/rebuild line MI 2.2 Proposed Y CC East ITC 1854 3738 6/1/2018 Trenton Channel Jefferson 1 120 New Line (existing ROW) MI Proposed Y CC East ITC 1858 3747 6/1/2013 Wayne 345 kV Substation Equipment 345 replace overloaded station equipment MI Proposed Y CC East ITC 2205 4045 8/1/2018 Evans Spreague 1 765 4008 new line MI 95 Conceptual $304,000,000 Y CC East ITC 2206 4048 8/1/2018 Spreague Transformer 1 765 345 2767.5 new transformer MI Conceptual $15,000,000 Y CC East ITC 2206 4046 8/1/2018 Spreague Bridgewater 1 765 6000 new line MI 42 Conceptual $120,000,000 Y CC East ITC 2933 5105 6/1/2013 Superior Wayne 1 120 Rebuild the 10.5 miles of the Superior to

Wayne 120 kV circuit from 477 ACSR to 954 ACSR on new structures.

MI 10.5 Proposed $8,800,000 Y C

C East ITC 3129 5505 6/1/2017 Belle River Bunce Creek 230 kV 1 230 Construct 13.5 miles 954 ACSR 138 kV circuit from Belle River to Bunce Creek


C East ITC 3129 5504 6/1/2017 Belle River Transformer 1 345 230 New Transformer MI Proposed Y CC East ITC 3130 5506 6/1/2013 Stratford Stratford-New Capacitor 120 50 Mvar New 50 Mvar Capacitor MI Proposed Y CC East ITC 3130 5507 6/1/2013 Wabash Wabash-New Capacitor 120 50 Mvar New 50 Mvar Capacitor MI Proposed Y CC East ITC 3140 5518 6/1/2017 Belle River St. Clair 2 345 Construct 1.12 miles 345 kV circuit from Belle

River to St. ClairMI 1.12 Proposed Y C

C East ITC 3141 5519 6/1/2014 Redrun Chestnut 2 120 Construct 5 miles 120 kV circuit from Redrun to Chestnut

MI 5 Proposed Y C

C East ITC 3142 5520 6/1/2016 L-N-NW Lincoln 1 120 Rebuild the section L-N-NW - Lincoln of the Lincoln-Northeast-Northwest 120 kV circuit to 954 ACSR conductor.


C East ITC 3147 5527 6/1/2013 Phoenix New Capacitor 120 75 Mvar New 75 Mvar Capacitor MI Proposed Y CC East ITC 3148 5528 6/1/2013 Riverview Ironton 1 120 Replace Wave Trap at Riverview MI Proposed Y CC East ITC 3496 6456 12/31/2012 NERC Alert Facility


due to the industry-wide NERC alertMI Planned Y C






Max kV


Miles Upg.


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C East ITC 3497 6457 12/31/2013 NERC Alert Facility Ratings for 2013

Throughout system Verify and remediate facilities as required due to the industry-wide NERC alert

MI Planned Y C

C East ITC 3498 6458 12/31/2014 NERC Alert Facility Ratings for 2014


MI Planned Y C

C East ITC, Non-MISO 2204 4067 8/1/2018 Cook Evans 1 765 4008 new line MI 99 Conceptual $299,000,000 Y CC East ITC, Non-MISO 2204 4070 8/1/2018 Evans Transformer 1 765 345 2767.5 new transformer MI Conceptual $20,000,000 Y CC East ITC, Non-MISO 2207 4047 8/1/2018 Bridgewater Blue Creek 1 765 3288 new line MI 134 Conceptual $432,000,000 Y CC East ITC, Non-MISO 2207 4049 8/1/2018 Bridgewater Transformer 1 765 345 2767.5 new transformer MI Conceptual $15,000,000 Y CC East ITC, Non-MISO 2209 4068 8/1/2018 Bridgewater South Canton 1 765 3024 new line MI/OH 167 Conceptual $538,000,000 Y CC East ITCM, AmerenIL 2785 4895 5/1/2014 Sorenson +/- 800KV DC converter

station1 800 6400 new +/- 800KV DC converter station IN Proposed $1,900,500,000 Y C

C East METC 642 1325 6/1/2017 Argenta Hazelwood(Sag) 1 138 conductor sag MI 0.1 Proposed $50,000 Y CC East METC 987 1550 6/1/2013 Emmet Stover 1 138 MI Proposed $10,250,000 Y CC East METC 1432 2436 6/1/2015 Withey Lake 138kV Twining 138kV 138 Rebuild 0.2 miles of Withey Lake-Twining

138kV lineMI Proposed $100,000 Y C

C East METC 1573 3125 6/1/2011 Donaldson Creek Donaldson Creek-New Capacitor

138 23.3 Mvar New 23.3 Mvar Capacitor MI Proposed Y C

C East METC 1657 2852 Terminal Equipment Upgrade

throughout system MI Proposed Y C

C East METC 1795 3604 6/1/2012 David Jct. Bingham 1 138 reconductor (removes sag limits) MI 19 Proposed $11,700,000 Y CC East METC 1800 3611 6/1/2013 Argenta Riverview 1 138 Remove sag limits MI Proposed Y CC East METC 1800 3613 6/1/2013 Riverview 138 kV Substation Equipment 138 upgdrade CT, breaker, and switch MI Proposed Y CC East METC 1800 3612 6/1/2013 Argenta 138 kV Substation Equipment 138 upgrade CT MI Proposed Y CC East METC 1804 3620 6/1/2013 Marquette Substation Equipment 138 upgrade station equipment (relaying at

Marquette)MI Proposed Y C

C East METC 1805 3622 6/1/2015 Livingston Emmet 2 138 new line (existing ROW) MI Proposed Y CC East METC 1805 3624 6/1/2015 Emmet Oden 2 138 new line (existing ROW) MI Proposed Y CC East METC 1805 3621 6/1/2015 Livingston Emmet 1 138 Rebuild MI Proposed Y CC East METC 1805 3623 6/1/2015 Emmet Oden 1 138 Rebuild MI Proposed Y CC East METC 1807 3626 6/1/2016 Bullock Murphy 1 138 new line resulting from line re-configuration MI Proposed Y CC East METC 1807 3627 6/1/2016 Begole Richland 1 138 new line resulting from line re-configuration MI Proposed Y CC East METC 1807 3628 6/1/2016 Gleaner Tittabawassee 1 138 new line resulting from line re-configuration MI Proposed Y CC East METC 1807 3630 6/1/2016 Bullock 230/138 kV Transformer 1 230 138 New Transformer MI Proposed Y CC East METC 1807 3629 6/1/2016 Murphy Transformer 1 345 230 New Transformer MI Proposed Y CC East METC 1808 3631 6/1/2017 Cowan Lake Jct Four Mile 1 138 reconductor MI 15.5 Proposed Y CC East METC 1811 3635 6/1/2018 Gray Rd Keystone 1 138 new line (existing WPC ROW) MI 9 Proposed Y CC East METC 1816 3650 6/1/2014 Mecosta Croton 1 138 Rebuild 22 miles from Croton to Nineteen

Mile (230 kV construction, operate at 138 kV)MI 22 Proposed Y C

C East METC 1831 5499 6/1/2019 Mio Twining 1 230 New line (existing ROW) MI 58.65 Proposed Y CC East METC 1831 5500 6/1/2019 Mio Livingston 1 230 New line (existing ROW) MI 41.85 Proposed Y CC East METC 1831 3683 6/1/2019 Tippy Sunoco Dr. 1 230 New line (existing ROW) MI 67.41 Proposed Y CC East METC 1831 3679 6/1/2019 Crane Road Hampton 1 345 new line resulting from line re-configuration MI Proposed Y CC East METC 1831 3680 6/1/2019 Crane Road Tittabawassee 1 345 new line resulting from line re-configuration MI Proposed Y CC East METC 1831 3681 6/1/2019 Keystone Transformer 1 345 230 New Transformer MI Proposed Y CC East METC 1831 3682 6/1/2019 Livingston Transformer 1 230 138 New Transformer MI Proposed Y CC East METC 1831 5501 6/1/2019 Tippy Keystone 1 230 New line (existing ROW) MI 36.79 Proposed Y CC East METC 1831 5498 6/1/2019 Crane Road Twining 1 230 New line (existing ROW) MI 49.35 Proposed Y CC East METC 1831 5497 6/1/2019 Ludington Sunoco Dr. 1 345 new line resulting from line re-configuration MI Proposed Y CC East METC 1831 5496 6/1/2019 Kenowa Sunoco Dr. 1 345 new line resulting from line re-configuration MI Proposed Y CC East METC 1831 5495 6/1/2019 Mio Livingston 1 345 new line resulting from line re-configuration MI Proposed Y CC East METC 1831 5494 6/1/2019 Gallagher Mio 1 345 new line resulting from line re-configuration MI Proposed Y CC East METC 1831 5493 6/1/2019 Crane Road Tittabawassee 2 345 new line resulting from line re-configuration MI Proposed Y CC East METC 1831 5492 6/1/2019 Crane Road Manning 1 345 new line resulting from line re-configuration MI Proposed Y CC East METC 1831 5491 6/1/2019 Tippy Transformer 1 230 138 New Transformer MI Proposed Y CC East METC 1831 5489 6/1/2019 Plum Transformer 1 230 138 New Transformer MI Proposed Y CC East METC 1831 3684 6/1/2019 Livingston Transformer 1 345 230 New Transformer MI Proposed Y CC East METC 1831 5486 6/1/2019 Mio Transformer 1 345 230 New Transformer MI Proposed Y C






Max kV


Miles Upg.


Cost Shared

Postage Stamp


C East METC 1831 5490 6/1/2019 Keystone Transformer 1 230 138 New Transformer MI Proposed Y CC East METC 1831 5487 6/1/2019 Sunoco Dr. Transformer 1 345 230 New Transformer MI Proposed Y CC East METC 1831 3685 6/1/2019 Plum Keystone 1 230 New line (existing ROW) MI 23.03 Proposed Y CC East METC 1831 3686 6/1/2019 Twining Transformer 1 230 138 New Transformer MI Proposed Y CC East METC 1831 3687 6/1/2019 Livingston Plum 1 230 New line (existing ROW) MI 30.7 Proposed Y CC East METC 1831 3688 6/1/2019 Crane Road Transformer 1 345 230 New Transformer MI Proposed Y CC East METC 1831 3689 6/1/2019 Gallagher Tittabawassee 1 345 new line resulting from line re-configuration MI Proposed Y CC East METC 1831 5488 6/1/2019 Mio Transformer 1 230 138 New Transformer MI Proposed Y CC East METC 2490 4487 6/1/2013 Vergennes 138 Terminal equipment upgrade MI Proposed $275,000 Y CC East METC 2490 4486 6/1/2013 North Belding 138 Terminal equipment upgrade MI Proposed $275,000 Y CC East METC 2810 4941 6/1/2014 Delhi Canal Jct 1 138 Rebuild 7.5 miles of 138kV line to 954 ACSR MI 18.7 Proposed $5,500,000 Y CC East METC 2811 4942 6/1/2015 Karn Cottage Grove 1 138 Rebuild 56miles of 138kV to 954 ACSR. MI 56 Proposed $51,000,000 Y CC East METC 3103 5436 12/31/2014 Gallagher breaker 345 new breaker MI Proposed $2,500,000 Y CC East METC 3103 5435 12/31/2014 Gallagher breaker 345 new breaker MI Proposed $2,500,000 Y CC East METC 3128 5502 6/1/2015 Emmet Riggsville 1 138 Construct a new 138 kV 954 ACSR circuit

from Emmet to RiggsvilleMI 25 Proposed Y C

C East METC 3128 5503 6/1/2015 Livingston Riggsville 2 138 Install Livingston to Riggsville 138 kV circuit #2 utilize 954 ACSR conductor

MI 25 Proposed Y C

C East METC 3131 5508 6/1/2015 Bil-Mar Jct. Port Sheldon Jct. 1 138 Improve sag clearance MI Proposed Y CC East METC 3132 5509 6/1/2015 Tallmadge Tyler 1 138 Improve sag clearance MI Proposed Y CC East METC 3133 5510 6/1/2014 Claremont Cornell 1 138 Rebuild/Reconductor the Bell Rd to N.

Corunna and the Cornell to N. Corunna sections of 115 CU to 954 ACSR conductor.


C East METC 3134 5511 6/1/2012 Weadock Disconnect Switch 138 Replace a disconnect switch at Weadock. MI Proposed Y CC East METC 3135 5512 6/1/2016 Airport Alpena 1 138 Rebuild the existing Airport - Alpena circuit

on DCT's to 954 ACSR conductor.MI Proposed Y C

C East METC 3135 5513 6/1/2016 Airport Alpena 2 138 Install a second circuit from Airport to Alpena utilize the 954 ACSR conductor.

MI Proposed Y C

C East METC 3136 5514 6/1/2017 Alpena Iosco 1 138 Rebuild 20 miles from Alpena to Spruce Rd to 954 ACSR conductor and replace limiting station equipment

MI 20 Proposed Y C

C East METC 3137 5515 6/1/2014 Bard Road Warren 1 138 Rebuild 20 miles from Bard Road to Warren to 954 ACSR conductor

MI 20 Proposed Y C

C East METC 3138 5516 6/1/2014 Mio Gaylord 1 138 Replace terminal equipment at Mio MI Proposed Y CC East METC 3143 5521 6/1/2019 Northwest Southfield 1 120 Rebuild the Northwest - Southfield circuit to

1431 ACSR conductor.MI 0.13 Proposed Y C

C East METC 3144 5522 6/1/2013 Argenta Morrow 1 138 Replace terminal equipment at Morrow MI Proposed Y CC East METC 3145 5525 6/1/2014 Blackstone Leoni 3 138 Replace the 636 ACSR trainers at

Blackstone substation. Upgrade the relaying at Leoni and Blackstone.

MI Proposed Y C

C East METC 3145 5524 6/1/2014 Blackstone Leoni 2 138 Replace the 636 ACSR trainers at Blackstone substation. Upgrade the relaying at Leoni and Blackstone.

MI Proposed Y C

C East METC 3145 5523 6/1/2014 Blackstone Leoni 1 138 Replace the 636 ACSR trainers at Blackstone substation. Upgrade the relaying at Leoni and Blackstone.

MI Proposed Y C

C East METC 3146 5526 6/1/2013 Battle Creek Verona 2 138 Replace the 795 ACSR trainer at Verona. MI Proposed Y CC East METC 3149 5529 6/1/2013 Four Mile Trainer 138 Replace the 2-4/0 Cu trainer at Four Mile. MI Proposed Y CC East METC 3150 5530 6/1/2014 North Belding Bricker 1 138 Replace the 336.4 ACSR trainer at North

Belding.MI Proposed Y C

C East METC 3151 5531 6/1/2014 Spaulding Pettis Jct. 1 138 Replace the 795 ACSR trainer at Spaulding. MI Proposed Y CC East METC 3152 5532 6/1/2016 Riggsville McGulpin 1 138 Replace 266.8 ACSR trainer at McGulpin and

336.4 ACSR trainer at Riggsville.MI Proposed Y C

C East METC 3153 5533 6/1/2016 Oden Riggsville 1 138 Replace 336.4 ACSR trainer at McGulpin. MI Proposed Y CC East METC 3300 3619 6/1/2015 Stover Livingston 1 138 Rebuild (230 kV construction, operate at 138

kV)MI Proposed Y C






Max kV


Miles Upg.


Cost Shared

Postage Stamp


C East METC 3492 6452 12/31/2012 NERC Alert Facility Ratings for 2012


MI Planned Y C



MI Planned Y C



MI Planned Y C

C East MPPA 2079 3952 7/1/2015 South Airport Junction Switches 69 1200 Amps Upgrade switches from 600A to 1200A MI Planned $200,000 Y CC East MPPA 2080 3953 7/1/2019 Barlow Junction Switches 69 1200 Amps Upgrade switches from 600A to 1200A MI Planned $200,000 Y CC East MPPA 2081 3954 7/1/2019 Cass Road Junction Switches 69 1200 Amps Upgrade switches from 600A to 1200A MI Planned $200,000 Y CC East NIPS 1973 2763 12/1/2017 Leesburg Northeast 1 138 287 Upgrade Connections and Circuit IN 8.5 Conceptual $5,279,000 Y CC East NIPS 1979 2769 12/1/2014 Maple Capacitor 69 Add two steps of 8.1 MVAR capacitors on the

Maple Substation 69 kV bus.IN Conceptual $1,080,000 Y C

C East NIPS 1980 2770 12/1/2013 Babcock Capacitor 69 Add 2 to 3 - 9 .0 MVAR stages IN Conceptual $1,052,000 Y CC East NIPS 1981 2771 12/1/2013 Kreitzburg Capacitor 69 Add 2 to 3 - 9 .0 MVAR stages IN Proposed $1,052,000 Y CC East NIPS 1983 2773 12/1/2016 Dekalb Transformer 1 138 69 112 Upgrade 138-69 Transformer IN Conceptual $1,700,000 Y CC East NIPS 1984 2774 12/1/2017 South Knox 138/69 kV Substation 138 69 New Substation IN Conceptual $12,568,000 Y CC East NIPS 1985 2775 12/1/2017 Wolcottville South Milford 1 69 81 Circuit 6959 - Reconductor 2/0 CU to

336.4kcm ACSRIN 5.4 Conceptual $1,671,000 Y C

C East NIPS 1989 2779 12/1/2017 South Milford Helmer 1 69 81 Circuit 6959 - Reconductor 2/0 CU to 336.4kcm ACSR

IN 4.7 Conceptual $1,037,000 Y C

C East NIPS 1990 2780 12/1/2016 Dekalb Angola 1 69 81 Circuit 6986 - Reconductor 2/0 CU to 336.4kcm ACSR

IN 16.5 Conceptual $9,253,000 Y C

C East NIPS 1993 2783 12/1/2017 South Valparaiso 138/69 kV Substation 1 138 69 168 New 138/69 kV Substation IN Conceptual $4,917,000 Y CC East NIPS 1994 2784 12/1/2011 Midway Bristol 1 69 81 Circuit 6977 - Reconductor 2/0 ACSR to

336.4kcm ACSRIN 4.1 Planned $656,000 Y C

C East NIPS 1998 2788 12/1/2013 East Winamac Lawton 1 69 Rebuild old pole line. Ckts 6962 & 6937 IN 4.5 Proposed $1,339,000 Y CC East NIPS 2000 2790 12/1/2014 Goshen Junction Model Tap 1 69 81 Circuit 6977 - Reconductor 4/0 ACSR to

336.4kcm ACSRIN 0.5 Planned $52,000 Y C

C East NIPS 2003 2793 12/1/2014 Bruce Lake Sw. 854 1 69 Circuit 6937 - Rebuild old pole line. IN Proposed $957,800 Y CC East NIPS 2244 4158 8/1/2018 Stillwell Burr Oak 1 345 1000 new line IN 19.3 Conceptual $28,000,000 Y CC East NIPS 2319 4245 5/1/2013 South Chalmers Switch #62 69 South Chalmers MO 62 load breaks and

switch replacement.IN Proposed $25,000 Y C

C East NIPS 2320 4246 12/1/2010 Thayer Starke 1 138 Circuit 13874 - Replace 58 wood poles up to 70 poles if need upon inspection, inspect and replace static wire as needed. First half of a two part project which will complete work begun in 2008.

IN Planned $600,000 Y C

C East NIPS 2321 4247 9/1/2017 Miller Capacitor 138 Add one step of 100 MVAR capacitors on the Miller Substation 138 kV bus. Engineering only in 2010.

IN Conceptual $974,838 Y C

C East NIPS 2323 4249 12/1/2016 Hiple Northport 1 138 316 Add new 138 kV terminals at Hiple and Northport Substations, and construct a new 10 mile 954 KCM ACSR 138 kV line between these two substations. Engineering only on 2008.

IN 10 Conceptual $5,770,000 Y C

C East NIPS 2324 4251 5/1/2016 East Plymouth - (2) 345kV Line Extensions

Burr Oak and Leesburg 1 345 Split existing Burr Oak to Leesburg 345kV circuit and tie into new East Plymouth substation

IN Conceptual $2,638,409 Y C

C East NIPS 2324 4252 5/1/2016 East Plymouth - (2) 138kV Line Extensions

Plymouth and Leesburg-Kosciusko

1 138 Split existing Plymouth-Leesburg-Kosciusko 138kV circuit and tie into new East Plymouth substation


C East NIPS 2324 4250 5/1/2016 East Plymouth 345/138 kV

345 138 Add East Plymouth 345/138 kV, 1-560 MVA Transformer Sub - New


C East NIPS 2792 4919 12/1/2012 Northwest circuit reconfiguration 138 Northwest circuit reconfig IN Conceptual $2,771,000 Y CC East NIPS 3399 6285 12/1/2010 Goodland Pine Creek 69 65 Circuit 6964 rebuild IN 29 Proposed $5,567,000 Y CC East NIPS 3400 6286 12/1/2012 Kreitzburg Palmira 69 55 Extend 6951 to Palmira Substation IN Conceptual $123,000 Y CC East NIPS 3401 6287 12/1/2013 East Winamac Bruce Lake 69 65 Circuit 6913 Rebuild Reconductor IN 10 Conceptual $2,131,000 Y C






Max kV


Miles Upg.


Cost Shared

Postage Stamp


C East NIPS 3402 6288 12/1/2013 Goshen Jct Third St. 69 65 Circuit 6981 Rebuild Reconductor IN 26 Conceptual $5,563,000 Y CC East NIPS 3403 6289 12/1/2012 Howe LaGrange 69 65 Circuit 6987 Rebuild Reconductor IN 6.3 Conceptual $1,383,000 Y CC East NIPS 3404 6290 12/1/2015 Switch 151 Warsaw 69 60 Circuit 6998, Switch 151 to Warsaw Sub

Reconductor RebuildIN 1.25 Conceptual $461,000 Y C

C East NIPS 3405 6291 12/1/2015 Switch 934 Switch 836 69 60 Circuit 69-107 Reconductor IN 0.5 Conceptual $360,000 Y CC West ALTW, Non MISO 2198 4065 8/1/2018 Rock Creek Transformer 1 765 345 2767.5 new transformer IA Conceptual $15,000,000 Y CC West ALTW, XEL 2223 4094 8/1/2018 Winnebago Lakefield 1 345 1000 new line MN 55 Conceptual $59,000,000 Y CC West ALTW, XEL 2223 4095 8/1/2018 Hayward Winnebago 1 345 1000 new line MN 50 Conceptual $53,000,000 Y CC West ALTW, XEL 2223 4127 8/1/2018 Adams Transformer 2 345 161 336 new transformer MN Conceptual $10,000,000 Y CC West ALTW, XEL 2223 4126 8/1/2018 Hayward Transformer 1 345 161 336 new transformer MN Conceptual $10,000,000 Y CC West ALTW, XEL 2223 4125 8/1/2018 Winnebago Transformer 1 345 161 336 new transformer MN Conceptual $10,000,000 Y CC West ALTW, XEL 2223 4124 8/1/2018 Hayward Adams 2 345 1000 new line MN 37 Conceptual $40,000,000 Y CC West ALTW, XEL 2223 4123 8/1/2018 Hayward Winnebago 2 345 1000 new line MN 50 Conceptual $53,000,000 Y CC West ALTW, XEL 2223 4122 8/1/2018 Winnebago Lakefield 2 345 1000 new line MN 55 Conceptual $59,000,000 Y CC West ALTW, XEL 2223 4096 8/1/2018 Hayward Adams 1 345 1000 new line MN 37 Conceptual $40,000,000 Y CC West AmerenIL, ITCM 2773 4866 12/31/2020 Plano Hazleton 1 765 3975/4570 MVABuild 215 miles of new 765kV from the

Hazleton substation in IA to the Plano substation in IL.

IA 215 Conceptual $774,000,000 Y C

C West ATC LLC 89 3248 6/1/2050 Mill Rd Bark River 1 138 287/287 Tap Bark River-Germantown into Mill Rd WI Conceptual Y CC West ATC LLC 89 3249 6/1/2050 Mill Rd Germantown 1 138 287/287 Tap Bark River-Germantown into Mill Rd WI Conceptual Y CC West ATC LLC 89 3250 6/1/2050 Mill Rd Sussex 1 138 287/314 Tap Sussex-Tamarack into Mill Rd WI Conceptual Y CC West ATC LLC 89 3251 6/1/2050 Mill Rd Tamarack 1 138 287/314 Tap Sussex-Tamarack into Mill Rd WI Conceptual Y CC West ATC LLC 89 3246 6/1/2050 Mill Rd Cypress 1 345 586/586 Tap Arcadian-Cypress into Mill Rd WI Conceptual Y CC West ATC LLC 89 103 6/1/2050 Mill Road (renamed, was

Lannon Junction)transformer 1 345 138 500 transformer WI Conceptual $29,200,000 Y C

C West ATC LLC 89 3247 6/1/2050 Mill Rd Arcadian 1 345 586/586 Tap Arcadian-Cypress into Mill Rd WI Conceptual Y CC West ATC LLC 341 483 6/1/2050 Rockdale Concord (rebuild to dbl

ckt 138/345)1 345 815 rebuild to dbl ckt 138/345 WI 22.6 Conceptual $22,200,000 Y C

C West ATC LLC 341 477 6/1/2050 Concord 345/138 kV transformer 1 345 138 500 WI Conceptual $12,900,000 Y CC West ATC LLC 341 893 6/1/2050 Concord Bark River 1 345 815 new line WI 19 Conceptual $50,300,000 Y CC West ATC LLC 341 895 6/1/2050 Bark River Mill Road 1 345 815 convert 138 to 345 kV WI 11 Conceptual $800,000 Y CC West ATC LLC 341 894 6/1/2050 Bark River transformer 1 345 138 500 transformer WI Conceptual $8,400,000 Y CC West ATC LLC 1621 3239 6/1/2020 Birchwood Lake Delton 1 138 383 Build a new line between Birchwood & Lake

DeltonWI 5 Conceptual $5,806,000 Y C

C West ATC LLC 1625 3244 12/31/2025 North Randolph South Fond du Lac 1 345 1096 Tap Columbia-South Fond du Lac into North Randolph

WI 32.3 Conceptual Y C

C West ATC LLC 1625 3243 12/31/2025 North Randolph Columbia 1 345 1096 Tap Columbia-South Fond du Lac into North Randolph


C West ATC LLC 1625 3242 12/31/2025 North Randolph Transformer 1 345 138 500 Install a 500 MVA 345/138 kV transformer at the North Randolph 138 kv SS by looping in the Columbia-South Fond du Lac 345-kV line

WI Conceptual $16,552,836 Y C

C West ATC LLC 1689 3468 6/1/2015 Ripon Capacitor bank 69 1x8.2 MVAR Install a new 8.2 MVAR capacitor bank at Ripon 69 kV substation

WI Conceptual Y C

C West ATC LLC 1689 3467 6/1/2015 Ripon Capacitor bank 69 1x8.2 MVAR Upgrade 4.1 MVAR capacitor bank to 8.2 MVAR

WI Conceptual $895,300 Y C

C West ATC LLC 1697 3476 6/1/2020 Brick Church Walworth 1 69 84 MVA Uprate Brick Church-Walworth 69 kV line to 115 MVA

WI 2.3 Conceptual $716,000 Y C

C West ATC LLC 1700 3480 9/30/2015 SW Ripon Ripon-Metomen 1 69 56 MVA Construct a 69 kV line from SW Ripon to the Ripon-Metomen 69 kV line


C West ATC LLC 1703 3484 6/1/2019 Boscobel Capacitor bank 69 8.16 MVAR Upgrade existing 5.4 MVAR bank at Boscobel substation with an 8.16 MVAR bank

WI Conceptual Y C

C West ATC LLC 1703 3483 6/1/2019 Boscobel Capacitor bank 69 8.16 MVAR Install one 8.16 MVAR capacitor bank at Boscobel 69 kV substation


C West ATC LLC 1707 3489 6/1/2050 Holmes Chandler 1 138 290 MVA Rebuild/convert holmes-Chandler 69 kV line to 138 kV operation

MI/WI 56.3 Conceptual $56,300,000 Y C






Max kV


Miles Upg.


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C West ATC LLC 1708 3490 6/1/2018 Fairwater Mackford Prairie 1 69 72 MVA Construct Fairwater-Mackford Prairie 69 kV line

WI 3.5 Conceptual $3,200,000 Y C

C West ATC LLC 1708 3491 6/1/2018 Ripon Metomen 2 69 59 MVA Reconfigure the North Randolph-Ripon 69-kV line to form a second Ripon-Metomen 69-kV line and retire the circuit between Metomen and the Mackford Prairie tap


C West ATC LLC 1709 3492 6/1/2019 Eden Capacitor bank 69 2x16.33 MVARInstall two 16.33 MVAR 69 kV capacitor banks at Eden Substation


C West ATC LLC 1710 3493 6/1/2020 Mazomanie Capacitor bank 69 2x12.25 MVARInstall two 12.25 MVAR 69 kV capacitor banks at Mazomanie substation


C West ATC LLC 1712 3495 6/1/2022 Horicon East Beaver Dam 1 138 293 MVA Construct a Horicon-East Beaver Dam 138 kV line

WI 10 Conceptual $18,186,000 Y C

C West ATC LLC 1717 3503 6/1/2020 Glenview Transformer 2 138 69 100 MVA Replace two existing 138/69 kV transformers at Glenview Substaion with 100 MVA transformers


C West ATC LLC 1717 3502 6/1/2020 Glenview Transformer 1 138 69 100 MVA Replace two existing 138/69 kV transformers at Glenview Substaion with 100 MVA transformers


C West ATC LLC 1718 3504 6/1/2022 Custer Transformer 1 138 69 100 MVA Install a 138/69 kV transformer at Custer substation


C West ATC LLC 1719 3505 6/1/2022 Shoto Custer 1 138 290 MVA Construct a Shoto-Custer 138 kV line WI 9.94 Conceptual $22,938,000 Y CC West ATC LLC 1720 3506 6/1/2017 Wautoma Transformer 2 138 69 100 MVA Install a second 138/69-kV transformer at

Wautoma SubstationWI Conceptual $1,440,000 Y C

C West ATC LLC 1721 3509 6/1/2050 Pulliam Danz 1 69 69 MVA Reconductor Pulliam-Danz 69 kV line WI 2.63 Conceptual Y CC West ATC LLC 1721 3508 6/1/2050 Pulliam Van Buren 1 69 69 MVA Reconductor Pulliam-Van Buren 69 kV line WI 1.88 Conceptual Y CC West ATC LLC 1721 3507 6/1/2050 Danz Henry Street 1 69 57 MVA Reconductor Danz-Henry Street 69 kV line WI 2.77 Conceptual Y CC West ATC LLC 1723 3512 6/1/2024 Sunset Point Transformer 2 138 69 100 MVA Replace two existing 138/69-kV transformers

at Sunset Point Substation with 100 MVA transformers


C West ATC LLC 1723 3511 6/1/2024 Sunset Point Transformer 1 138 69 100 MVA Replace two existing 138/69-kV transformers at Sunset Point Substation with 100 MVA transformers


C West ATC LLC 1726 3515 6/1/2019 Royster Sycamore 1 69 83 MVA Uprate Royster-Sycamore 69 kV line to N/E = 200/275 deg F


C West ATC LLC 1727 3516 6/1/2018 Dunn Road Egg Harbor 2 69 105 MVA Construct a second Dunn Road-Egg Harbor 69 kV line


C West ATC LLC 1730 3520 6/1/2020 Cardinal Blount 1 138 290 MVA Construct a West Middleton-Blount 138 kV line


C West ATC LLC 2029 3903 6/1/2017 Brick Church capacitor 138 1x24.5 Mvar Install 1-24.5 Mvar 138-kV capacitor bank at Brick Church

WI Conceptual Y C

C West ATC LLC 2029 3904 6/1/2017 Brick Church capacitor 69 1x18Mvar Install 1-18 Mvar 69-kV capacitor bank at Brick Church

WI Conceptual Y C

C West ATC LLC 2030 3905 6/1/2020 Concord capacitor 138 4x24.5 Mvar Install 4-24.5 Mvar 138-kV capacitor bank at Concord


C West ATC LLC 2031 3907 6/1/2018 Enzyme Bio Systems Tap

RC3 (Clinton) 1 69 84 MVA Rebuild Enzyme Bio Systems Tap-RC3 (Clinton) 69 kV


C West ATC LLC 2031 3906 6/1/2018 Colley Rd Enzyme Bio Systems Tap

1 69 84 MVA Rebuild Colley Rd-Enzyme Bio Systems Tap 69 kV


C West ATC LLC 2031 3908 6/1/2018 RC3 (Clinton) Clinton Tap 1 69 146 MVA Rebuild RC3 (Clinton)-Clinton Tap 69 kV WI 1.55 Conceptual $1,032,000 Y CC West ATC LLC 2031 3909 6/1/2018 Clinton Tap Sharon Tap 1 69 84 MVA Rebuild Clinton Tap-Sharon Tap 69 kV WI 9 Conceptual $5,992,260 Y CC West ATC LLC 2038 3918 6/2/2018 Spring Valley Twin Lakes 1 138 293 MVA Construct Spring Valley-Twin Lakes 138 kV WI 12 Conceptual $16,642,457 Y CC West ATC LLC 2038 3919 6/2/2018 Twin Lakes S Lake Geneva 1 138 293 MVA Construct Twin Lakes-S Lake Geneva 138

kVWI 12 Conceptual $16,642,457 Y C

C West ATC LLC 2040 3921 6/1/2020 Sun Prairie capacitor 69 2x16.33 Mvar Install 2x16.33 Mvar 69 kV capacitor banks at Sun Prairie


C West ATC LLC 2042 3923 6/1/2019 Dam Heights capacitor 69 2x16.33 Mvar Install 2x16.33 Mvar 69 kV caps at Dam Heights







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C West ATC LLC 2043 3924 6/1/2018 Necedah sub conversion 1 138 Convert Necedah from 69 to 138 kV and tap into the Petenwell-Council Creek 138 kV line

WI Conceptual $761,500 Y C

C West ATC LLC 2046 3930 6/1/2018 North Monroe capacitor 69 2x16.33 Mvar Install 2x16.33 Mvar 69 kV capacitor banks at North Monroe


C West ATC LLC 2056 3943 6/1/2020 Oak Creek Pennsylvania 1 138 478 MVA Uprate Oak Creek-Pennsylvania 138 kV WI 4.5 Conceptual $2,409,559 Y CC West ATC LLC 2162 4001 6/1/2017 McCue LaMar 1 69 95 MVA New 69-kV line with T2 4/0 ACSR WI 3.42 Conceptual $5,009,085 Y CC West ATC LLC 2773 4850 12/31/2020 North Madison New 765/345 kV

substation1 765 345 2640/3040 MVAConstruct a new 765/345kV substation in WI.

Substation will have a single 765/345kV TRF tying to the North Madison 345kV system and a single 765kV line terminal.


C West ATC LLC 2779 4883 6/1/2014 18th Road Transformer 1 138 69 60 MVA Add a new 138/69 kV 150 MVA xfmr at 18th Road


C West ATC LLC 2779 4882 6/1/2014 18th Road Substation 138 Add a new 138/69 kV SS at 18th Road MI Proposed $11,000,000 Y CC West ATC LLC 2779 4881 6/1/2014 Chandler 18th Road 1 138 348 MVA Buld a new 6-mile 138 kV line from Chandler

to 18th RoadMI 6 Proposed $6,000,000 Y C

C West ATC LLC 2779 5478 6/1/2014 Chandler 18th Road 2 138 348 MVA Buld a new 6-mile 138 kV line from Chandler to 18th Road, that will be operated at 69 kV

MI 6 Proposed $3,000,000 Y C

C West ATC LLC 2779 6483 6/1/2014 18th Road 69 2x4.08 Cap Bank at 18th Road Substation WI Proposed Y CC West ATC LLC 2779 6484 6/1/2014 18th Road Mead 1 69 57 New 18th Rd -Mead 69 kV line WI 0.19 Proposed Y CC West ATC LLC 3096 5422 6/1/2014 Timber Products Seney 1 69 37 MVA Increase ground clearance for the Inland line

Munising-Blaney Park 69kV to 167 deg f (37 MVA) clearance

MI 28.4 Conceptual $11,338,403 Y C

C West ATC LLC 3096 5421 6/1/2014 Munising Timber Products 1 69 37 MVA Increase ground clearance for the Inland line Munising-Blaney Park 69kV to 167 deg f (37 MVA) clearance

MI 6.2 Conceptual $2,478,285 Y C

C West ATC LLC 3096 5423 6/1/2014 Seney Blaney Park 1 69 37 MVA Increase ground clearance for the Inland line Munising-Blaney Park 69kV to 167 deg f (37 MVA) clearance

MI 18 Conceptual $7,186,312 Y C

C West ATC LLC 3117 5461 6/1/2021 Townline Rd Bass Creek 1 138 211 MVA Reconductor X-12 from Townline Rd to Bass Creek with 477 ACSR HAWK


C West ATC LLC 3124 5475 6/1/2018 Forsyth Gwinn 2 69 95 MVA construct a 2nd Forsyth-Gwinn 69kV line MI 0.84 Conceptual $1,000,000 Y CC West ATC LLC 3125 5476 6/1/2015 Arnold transformer 1 345 138 500 MVA Tap the Plains-Dead River 345kV line into

the Arnold 138kV substation and add a 345/138kV transformer


C West ATC LLC 3158 5546 6/1/2015 Petenwell transformer 1 138 69 100 Replace Petenwell Transformer, replace electromechanical relays, install highside circuit switchers on the GSUs for the Petenwell Hydro Plant

WI proposed $3,246,000 Y C

C West ATC LLC 3159 5547 6/1/2015 West Middleton Timberlane Tap 1 69 83 Uprate West Middleton to Timberlane Tap 69 kV Line


C West ATC LLC 3159 5548 6/1/2015 Timberlane Tap Stage Coach 1 69 84 Uprate Timberlane Tap to Stage Coach 69 kV Line


C West ATC LLC 3164 5563 6/1/2020 Point Beach Ludington 1 350 1000 Construct a HVDC line under Lake Michigan from Point Beach to Ludington

WI/MI 64 Conceptual $828,000,000 Y C

C West ATC LLC 3164 5564 6/1/2020 WI HVDC North DC Station for 1000 MW 350 Install a HVDC converter station near Point Beach

WI Conceptual Y C

C West ATC LLC 3164 5565 6/1/2020 MI HVDC North DC Station for 1000 MW 350 Install a HVDC converter station near Ludington

MI Conceptual Y C

C West ATC LLC 3164 5566 6/1/2020 WI HVDC North Point Beach 345 1250 Construct a 345 kV line to connect the WI HVDC North SS to Point Beach


C West ATC LLC 3164 5567 6/1/2020 MI HVDC North Ludington 345 1250 Construct a 345 kV line to connect the MI HVDC North SS to Ludington

MI 0.5 Conceptual Y C

C West ATC LLC 3165 5569 6/1/2020 WI HVDC South substation 350 345 Install a HVDC converter station near Elm Rd WI Conceptual Y C

C West ATC LLC 3165 5570 6/1/2020 MI HVDC South substation 765 350 Install a HVDC converter station near DC Cook

MI Conceptual Y C






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C West ATC LLC 3165 5572 6/1/2020 MI HVDC South DC Cook 765 1250 Construct a 765 kV line to connect the MI HVDC South SS to DC Cook

MI 0.5 Conceptual Y C

C West ATC LLC 3165 5571 6/1/2020 WI HVDC South Elm Rd 345 1250 Construct a 345 kV line to connect the WI HVDC South SS to Elm Rd


C West ATC LLC 3165 5568 6/1/2020 Elm Rd DC Cook 1 350 1000 Construct a HVDC line under Lake Michigan from Elm Rd to DC Cook

WI/MI 91 Conceptual $1,071,000,000 Y C

C West ATC LLC 3166 5573 6/1/2018 Hillman transformer 2 138 69 100 Install a 2nd transformer WI Conceptual $4,843,288 Y CC West ATC LLC 3167 5574 6/1/2018 South Monroe Monroe Central Tap 1 69 84 Increase line clearance for 300 deg F

Summer Emergency operationWI 0.8 Conceptual $871,408 Y C

C West ATC LLC 3167 5575 6/1/2018 Monroe Central Tap Idle Hour Tap 1 69 84 Increase line clearance for 300 deg F Summer Emergency operation


C West ATC LLC 3167 5576 6/1/2018 Idle Hour Tap North Monroe 1 69 84 Increase line clearance for 300 deg F Summer Emergency operation


C West ATC LLC 3189 5630 6/1/2019 Ripon Northwest Ripon 1 69 84 Uprate line Y-93 from Ripon to Northwest Ripon from 167 deg F to SN/SE


C West ATC LLC 3190 5631 6/1/2019 Sunset Point Winneconne 1 69 84 Rebuild line Y-103 from Sunset Point to Winneconne to SN/SE = 200/300 deg F


C West ATC LLC 3207 5974 6/1/2016 Harrison Transformer 1 138 69 100 Replace Harrison 138/69kV Tr with a larger unit and uprate terminal equipment to a minimum of the transformer ratings


C West ATC LLC 3208 5975 6/1/2018 Caroline Transformer 1 115 69 100 Replaces Caroline 115/69-kV transformer with a dual high side 138-115/69-kV 100 MVA transformer and uprate terminal equipment to a minimum of the transformer ratings


C West ATC LLC 3429 6324 6/1/2020 Sun Valley Tap Oregon 1 69 80 Rebuild Sun Valley Tap-Oregon WI 6.7 Conceptual $5,561,798 Y CC West ATC LLC 3430 6326 6/1/2016 Brusbay Sawyer 1 69 64 Rebuild Brusbay-Sawyer 69 kV WI 7.9 Conceptual $3,793,968 Y CC West ATC LLC 3430 6325 6/1/2016 Dyckesville Brusbay 1 69 80 Rebuild Dyckesville-Brusbay 69 kV WI 16.7 Conceptual $8,020,160 Y CC West ATC LLC 3487 6445 6/1/2022 West Middleton Pheasant Branch 2 69 173 Replace existing single circuit from WMD-

Pheasant Branch 69 kV with double circuit 69 kV lines.


C West ATC LLC 3487 6444 6/1/2022 West Middleton Pheasant Branch 1 69 153 Replace existing single circuit from WMD-Pheasant Branch 69 kV with double circuit 69 kV lines.


C West ATC LLC 3506 6475 12/31/2012 Vinburn Deforest 1 69 80 Y-104c, 1/4 mile of double circuit (minimum rating of 706 Amps, SN, 961 amps, SE) for the loop through feed off of line Y104

WI 0.25 Proposed Y C

C West ATC LLC 3506 6473 12/31/2012 Vinburn Hampden 1 69 72 Y-104a, 1/4 mile of single circuit (minimum rating of 706 amps SN, 961 amps SE) to serve the Hampden tap

WI 0.25 Proposed $3,362,287 Y C

C West ATC LLC 3506 6474 12/31/2012 Vinburn Sun Prairie Business Park

1 69 80 Y-104b, 1/4 mile of double circuit (minimum rating of 706 Amps, SN, 961 amps, SE) for the loop through feed off of line Y104

WI 0.25 Proposed Y C

C West ATC LLC 3507 6476 3/1/2012 Shoto Manrap 1 69 80 Uprate of C-55 (MANRAP - SHOTO 69KV) WI 7.65 Proposed $319,044 Y CC West ATC LLC 3508 6477 1/1/2012 Revere N. East 1 69 83 Uprate of C-103 (REVERE - N.EAST 69KV) WI 2.32 Proposed $171,475 Y CC West ATC LLC 3510 6482 6/1/2017 Edgewood St. Martins 1 138 287 3013 Edgewood-St. Martins 138-kV rebuild WI 7.07 Proposed $9,200,000 Y CC West ATC LLC 3510 6481 6/1/2017 Mukwonago Edgewood 1 138 293 671K61 Mukwonago-Edgewood 138-kV

rebuildWI 7.19 Proposed $10,000,000 Y C

C West ATC LLC 3511 6485 11/14/2011 Edgewater Saukville 1 345 785 uprate Edgewater to Saukville 345 kV line WI Proposed $1,798,252 Y CC West ATC LLC 3512 6490 6/1/2020 MI HVDC North Cook 1 345 Construct a 345 kV line to connect the MI

HVDC North SS to LudingtonMI 0.5 Conceptual Y C

C West ATC LLC 3512 6489 6/1/2020 WI HVDC North Pleasant Prairie 1 345 Construct a 345 kV line to connect the WI HVDC North SS to Point Beach


C West ATC LLC 3512 6488 6/1/2020 MI HVDC North DC Station for 1000 MW 350 Install a HVDC converter station near Ludington

MI Conceptual Y C

C West ATC LLC 3512 6487 6/1/2020 WI HVDC North DC Station for 1000 MW 350 Install a HVDC converter station near Point Beach

WI Conceptual Y C






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C West ATC LLC 3512 6486 6/1/2020 Pleasant Prairie Cook 1 350 Construct a HVDC line under Lake Michigan from Point Beach to Ludington

WI/MI 86 Conceptual $828,000,000 Y C

C West ATC LLC 3515 6495 12/31/2011 Granville Tosa 1 138 293 Uprate Granville-Tosa 138 kV line WI Proposed $1,136,322 Y CC West ATC LLC 3515 6496 12/31/2011 Granville Butler 1 138 293 Uprate Granville-Butler 138 kV line WI Proposed Y CC West ATC LLC, ALTW 2230 4143 8/1/2018 Spring Green West Middleton 1 345 1412 new line WI 18 Conceptual $23,000,000 Y CC West ATC LLC, ALTW 2230 4144 8/1/2018 Spring Green Transformer 1 345 138 336 new transformer WI Conceptual $10,000,000 Y CC West ATC LLC, ALTW 2230 4105 8/1/2018 Spring Green Salem 1 345 1412 new line WI 54 Conceptual $69,000,000 Y CC West ATC LLC, XEL 2211 4037 8/1/2018 Longwood Greenwood 1 345 1000 new line WI 14 Conceptual $200,000,000 Y CC West ATC LLC, XEL 2773 4857 12/31/2020 North Madison Adams 1 765 3975/4570 MVABuild 250 miles of new 765kV from the

Adams substation in southeast MN to the North Madison substaton in WI.

MN/WI 250 Conceptual $900,000,000 Y C

C West DEM, AmerenIL, IT 2773 4867 12/31/2020 Sullivan Grimes 1 765 3975/4570 MVABuild 455 miles of new 765kV from the Grimes substation in IA to the Sullivan substation in IN.

IA/MO/IL/IN 455 Conceptual $1,638,000,000 Y C

C West DPC, ATC LLC 2231 4106 8/1/2018 Hilltop Columbia 1 345 1195 new line WI 50 Conceptual $68,000,000 Y CC West DPC, ATC LLC 2231 4107 8/1/2018 Hilltop Transformer 1 345 138 500 new transformer WI Conceptual $10,000,000 Y CC West DPC, ATC LLC 2231 4145 8/1/2018 Hilltop LaCrosse 1 345 1195 new line WI 80 Conceptual $108,000,000 Y CC West GRE 2569 4580 12/2/2013 Shoal Lake Nashwauk Tap 1 115 Distribution conversion to 115 kV MN 8 Planned $6,450,515 Y CC West GRE 2600 4611 10/30/2015 Big Sandy Big Sandy Tap 1 69 New Distribution MN 4 Planned $5,149,000 NT CC West GRE 2632 4643 12/1/2013 Onigum Birch Lake 1 115 140 Onigum 115 kV conversion, Birch Lake 115

kV breaker and deadendMN 9.45 Proposed $5,300,000 Y C

C West GRE 2691 4709 6/1/2017 Orrock Waco 1 115 69 315.9/135.9 Double Circuit MN 3.5 Conceptual Y CC West GRE 2691 4711 6/1/2017 Liberty Thompson Lake 1 115 135.9 Reconductor MN 3.29 Conceptual Y CC West GRE 2691 4708 6/1/2017 Orrock transformer 1 345 115 336 MN Conceptual $19,661,825 Y CC West GRE 2691 4710 6/1/2017 Thompson Lake Waco 1 115 69 315.9/135.9 Double Circuit MN 10.33 Conceptual Y CC West GRE 3393 6266 11/1/2013 Peterson 115 kV distribution tap

switch115 0 Convert Peterson 24 kV substation to 115 kV MN 0 0 Planned $742,690 N Y C

C West GRE 3470 6397 12/1/2011 G667 MN Planned $118,182 Y CC West GRE, OTP 2773 4865 12/31/2020 Antelope Valley New North Dakota 1 765 3975/4570 MVABuild 135 miles of new 765kV from the

Chisago substation in MN to the new North Dakota substation in ND.

SD/ND/IA 135 Conceptual $486,000,000 Y C

C West GRE, OTP, XEL 2773 4864 12/31/2020 Chisago New North Dakota 1 765 3975/4570 MVABuild 355 miles of new 765kV from the Chisago substation in MN to the new Nroth Dakota substation in ND.

SD/ND/IA 355 Conceptual $1,278,000,000 Y C

C West GRE, XEL 2773 4844 12/31/2020 Helena New 765/345 kV substation

1 765 345 2640/3040 MVAConstruct a new 765/345kV substation in MN. Substation will have a single 765/345kV TRF tying to the Helena 345kV system and three 765kV line terminals.

MN Conceptual $120,000,000 Y C

C West GRE, XEL 2773 4854 12/31/2020 Helena Chisago 1 765 3975/4570 MVABuild 160 miles of new 765kV from the Helena Substation to the Adams substation in southeast MN.

MN 160 Conceptual $576,000,000 Y C

C West GRE, XEL 2773 4855 12/31/2020 Helena Adams 1 765 3975/4570 MVABuild 130 miles of new 765kV from the Helena Substation to the Adams substation in southeast MN.


C West GRE, XEL 2773 4853 12/31/2020 Helena Lakefield 1 765 3975/4570 MVABuild 115 miles of new 765kV from the Helena Substation to the Lakefield substation in southwest MN.


C West ITCM 1738 3536 12/31/2017 Bertram Hills 1 161 446/446 MVA Reconductor the Bertram-Rose Hollow-Hills IA 32.2 Proposed $22,540,000 Y CC West ITCM 1742 4392 12/31/2014 Brewster Heron Lake 1 161 446 MVA Rebuild existing line MN 14.64 Proposed $10,220,000 Y CC West ITCM 1742 3544 12/31/2015 Elk Brewster 1 161 326/326 MVA Rebuild existing line MN 3.32 Proposed $2,324,000 Y CC West ITCM 1742 3543 12/31/2015 Magnolia Elk 1 161 326/326 MVA Rebuild existing line MN 18.75 Proposed $13,160,000 Y CC West ITCM 1742 3542 12/31/2016 Split Rock Magnolia 1 161 446/446 MVA Rebuild existing line MN 11 Proposed $7,700,000 Y CC West ITCM 1746 3549 12/31/2011 Fox Lake Rutland 1 161 446/446 MVA Rebuild existing line MN 17 Proposed $11,900,000 Y CC West ITCM 1746 3550 12/31/2012 Rutland Winnebago 1 161 446/446 MVA Rebuild existing line MN 14.6 Proposed $10,220,000 Y CC West ITCM 1746 3552 12/31/2014 Winnebago Hayward 1 161 446/446 MVA Rebuild existing line MN 49.09 Proposed $34,370,000 Y CC West ITCM 1746 3553 12/31/2015 Hayward Adams 1 161 446/446 MVA Rebuild existing line MN 36.39 Proposed $25,480,000 Y CC West ITCM 1746 3551 12/31/2015 Lakefield Jct Fox 1 161 446/446 MVA Rebuild existing line MN 22.3 Proposed $15,610,000 Y C






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C West ITCM 2773 4849 12/31/2020 Hazleton New 765/345 kV substation

1 765 345 2640/3040 MVAConstruct a new 765/345kV substation in IA. Substation will have a single 765/345kV TRF tying to the Hazleton 345kV system and two 765kV line terminals.

IA Conceptual $110,000,000 Y C

C West ITCM 2773 4847 12/31/2020 Iowa new substation New 765/345 kV substation

1 765 345 2640/3040 MVAConstruct a new 765/345kV substation in IA. Substation will have a single 765/345kV TRF and three 765kV line terminals.


C West ITCM 2773 4845 12/31/2020 Lakefield New 765/345 kV substation

1 765 345 2640/3040 MVAConstruct a new two TRF 765/345kV substation in southwest MN. Substation will have two 765/345kV TRFs tying to the Lakefield 345kV system and four 765kV line terminals.


C West ITCM 2773 4860 12/31/2020 Lakefield New IA Substation 1 765 3975/4570 MVABuild 100 miles of new 765kV from the Lakefield substation in southwest MN to a new IA substation in western IA.

MN/IA 100 Conceptual $360,000,000 Y C

C West ITCM 2773 4858 12/31/2020 Lakefield Adams 1 765 3975/4570 MVABuild 140 miles of new 765kV from the Lakefield substation in southwest MN to the Adams substation in southeast MN.


C West ITCM 2773 4862 12/31/2020 Fort Thompson New IA Substation 1 765 3975/4570 MVABuild 305 miles of new 765kV from the new IA substation to the Fort Thompson substation in SD.

SD/IA 305 Conceptual $1,098,000,000 Y C

C West ITCM 2830 4971 1/1/2014 Lakefield Jct Rutland 1 345 1500 MN 39.4 Proposed $98,500,000 Y CC West ITCM 2830 4972 1/1/2014 Rutland 345/161 kV transformer 1 345 161 336 MN Proposed Y CC West ITCM 2950 5137 6/1/2018 Polk City NE Ankeny 1 161 Polk City Sub dbl ckt line tap (cost is included

with Bittersweet Road-Polk City line tap)IA 3.5 Conceptual Y C

C West ITCM 2950 5136 6/1/2018 Bittersweet Road Polk City 1 161 Polk City Sub dbl ckt line tap IA 3.5 Conceptual Y CC West ITCM 3086 5394 12/31/2013 8th Street Kerper 1 161 326 MVA Rebuild 161kV line IA 2.6 Proposed $1,430,000 Y CC West ITCM 3086 5395 12/31/2014 Kerper Lore 1 161 326 MVA Rebuild 161kV line IA 10.23 Proposed $5,626,500 Y CC West ITCM 3087 5396 12/31/2016 Lansing Harmony 1 161 326 MVA Rebuild part of IA line sections IA Proposed $30,000,000 Y CC West ITCM 3500 6460 12/31/2012 NERC Alert Facility


due to the industry-wide NERC alertIA Planned Y C

C West ITCM 3501 6461 12/31/2013 NERC Alert Facility Ratings for 2013


IA Planned Y C

C West ITCM 3502 6462 12/31/2014 NERC Alert Facility Ratings for 2014


IA Planned Y C

C West ITCM, AmerenIL 2785 4893 5/1/2014 New Substation in NW Iowa

+/- 800KV DC converter station

1 800 6400 new +/- 800KV DC converter station IA Proposed Y C

C West ITCM, MEC 2773 4861 12/31/2020 Grimes New IA Substation 1 765 3975/4570 MVABuild 115 miles of new 765kV from the new IA substation to Grimes substation near Des Moines, IA.

IA 115 Conceptual $414,000,000 Y C

C West ITCM, XEL 2773 4856 12/31/2020 Hazleton Adams 1 765 3975/4570 MVABuild 85 miles of new 765kV from the Hazleton substation in IA to the Adams substation in southeast MN.

MN/IA 85 Conceptual $306,000,000 Y C

C West ITCM, XEL 2773 4859 12/31/2020 Lakefield Fort Thompson 1 765 3975/4570 MVABuild 240 miles of new 765kV from the Lakefield substation in southwest MN to the Fort Thompson substation in SD.

MN/SD 240 Conceptual $864,000,000 Y C

C West MDU 3082 5362 6/1/2014 NW Bismarck 3 PCB 115 Create a ring bus ND Planned $3,050,000 Y CC West MDU 3084 5370 12/1/2015 East Bismarck Termial Equipment 115 Upgrade Terminal Equip. to increase line

ratingND Proposed $100,000 Y C

C West MDU 3084 5369 12/1/2015 East Bismarck Bismarck (WAPA) 1 115 200 New line Segment ND 0.1 Proposed $400,000 Y CC West MDU 3084 5368 12/1/2015 East Bismarck 4 PCB 115 Add bus tie breaker & new line terminal ND Proposed $2,000,000 Y CC West MDU 3456 6334 6/1/2016 Glenham Transformer 1 230 115 50/40/20 Replacement 230/115/41.6 transformer SD Planned $2,500,000 Y CC West MDU 3456 6335 6/1/2016 Glenham 2 PCB 230 Create a ring bus SD Planned $2,500,000 Y CC West MDU 3456 6336 6/1/2016 Glenham 2 PCB 115 Add low side transformer breakers SD Proposed $2,000,000 Y CC West MDU, NON-MISO 2214 4080 8/1/2018 Glenham Ellendale 1 345 872 new line SD/ND 86 Conceptual $37,000,000 Y CC West MDU, NON-MISO 2214 4081 8/1/2018 Glenham Transformer 1 345 230 336 new transformer SD Conceptual $10,000,000 Y C






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C West MEC 2773 4848 12/31/2020 Grimes New 765/345 kV substation

1 765 345 2640/3040 MVAConstruct a new 765/345kV substation in IA. Substation will have a single 765/345kV TRF tying to the Grimes 345kV system and two 765kV line terminals.


C West MEC 2941 5118 12/31/2014 Sub T Fort Dodge Boone Jct 1 161 167 Replace structures to increase operating temp

IA 13.24 Proposed $1,600,000 Y C

C West MEC 2943 5120 6/1/2020 Hills Hills 2 345 161 560 Install 2nd 560 MVA 345-161 kV transformer at Hills Substation. Expand 345 and 161 kV ring busses to accommodate new transformer.


C West MEC 2944 5121 6/1/2019 Hills Sub E 1 161 410 Reconductor the Hills - Sub E Iowa City 161 kV Line.

IA 6.5 Conceptual $1,800,000 Y C

C West MEC 2945 5122 6/1/2019 Grimes Transformer 2 345 161 560 Add second transformer at Grimes IA Conceptual $11,900,000 Y CC West MEC 2946 5123 6/1/2018 Greenfield Plaza Army Post 1 161 335 Reconductor IA 5.25 Proposed $1,200,000 Y CC West MEC 2947 5125 6/1/2012 North Grimes 161 13.2 33 New North Grimes 161-13 kV distribution sub IA Planned $2,700,000 Y C

C West MEC 2947 5126 6/1/2012 Granger North Grimes 1 161 410 North Grimes Substation line tap IA 0.1 Planned $100,000 Y CC West MEC 2947 5127 6/1/2012 North Grimes Grimes Tap 1 161 410 North Grimes Substation line tap IA 0.1 Planned $100,000 Y CC West MEC 2947 5124 6/1/2018 Army Post Ashawa 1 161 335 Reconductor IA 4.27 Proposed $1,000,000 Y CC West MEC 2948 5131 6/1/2018 W. Waukee Tap

StructureW. Waukee 1 161 410 Add 161 kV tap into and out of sub IA 0.2 Proposed $250,000 Y C

C West MEC 2948 5133 6/1/2018 Grimes 161 Add line terminal at Grimes IA Proposed $700,000 Y CC West MEC 2948 5128 6/1/2018 W. Waukee 161 13.2 33 Add W. Waukee distribution sub IA Proposed $2,700,000 Y CC West MEC 2948 5134 6/1/2018 Booneville 161 Add line terminal at Booneville IA Proposed $700,000 Y CC West MEC 2948 5129 6/1/2018 Grimes W. Waukee Tap

Structure1 161 410 Add Grimes-W Waukee 161 kV line IA 9.2 Proposed $3,500,000 Y C

C West MEC 2948 5130 6/1/2018 W. Waukee Tap Structure

Booneville 1 161 410 Add W Waukee-Booneville 161 kV line IA 7.4 Proposed $2,800,000 Y C

C West MEC 2949 5132 6/1/2020 W. Waukee 161/69 transformer 1 161 69 Add 161-69 kV transformer and 161 kV circuit breakers


C West MEC 2950 5135 6/1/2018 Polk City 161 13.2 33 Add Polk City distribution sub IA Conceptual $1,500,000 Y CC West MEC 2951 5140 6/1/2018 Boston Forest & Vermont 1 161 410 Boston Substation line tap IA 0.1 Conceptual $300,000 Y CC West MEC 2951 5138 6/1/2018 Boston 161 13 33 Add Boston distribution sub IA Conceptual $1,400,000 Y CC West MEC 2951 5139 6/1/2018 Sycamore Boston 1 161 410 Boston Substation line tap IA 0.1 Conceptual $300,000 Y CC West MEC 2952 5147 6/1/2016 D.M. Energy Center 161 Relay upgrade for Metro East line IA Conceptual $100,000 Y CC West MEC 2952 5146 6/1/2016 Altoona 161 Relay upgrade for Metro East line IA Conceptual $40,000 Y CC West MEC 2952 5141 6/1/2016 East Altoona 161 13 33 Add E Altoona distribution sub IA Conceptual $1,400,000 Y CC West MEC 2952 5142 6/1/2016 Metro East East Altoona 1 161 410 Add Metro E-E Altoona 161 kV line IA 7 Conceptual $4,900,000 Y CC West MEC 2952 5143 6/1/2016 East Altoona Bondurant 1 161 410 Add E Altoona-Bondurant 161 kV line IA 4 Conceptual $2,900,000 Y CC West MEC 2952 5144 6/1/2016 Metro East 161 Add breakers at Metro E Substation IA Conceptual $900,000 Y CC West MEC 2952 5145 6/1/2016 Bondurant 161 Add breaker/line term at Bondurant IA Conceptual $1,100,000 Y CC West MEC 2953 5151 6/1/2020 Page County Clarinda 1 161 Reconductor line IA 3 Conceptual $900,000 Y CC West MEC 2953 5148 6/1/2020 Page County Bus 345 345 kV terminals for Page County

SubstationIA Conceptual $1,500,000 Y C

C West MEC 2953 5149 6/1/2020 Page County Transformer 1 345 161 345-161 kV transformer at new Page County Substation


C West MEC 2953 5150 6/1/2020 Page County Bus 161 161 kV terminals for Page County Substation IA Conceptual $700,000 Y CC West MEC 2954 5152 6/1/2018 Clarinda Capacitor 161 New capacitor IA Proposed $1,000,000 Y CC West MEC 3217 6000 12/31/2019 Scott County 765 New 765 kV Substation in Iowa Quad Cities

in Scott County, IowaIA 0 0 Proposed $71,000,000 Y C

C West MEC 3217 6001 12/31/2019 Kewanee Scott County 1 765 7140 New 765 kV line from Kewanee to Scott County and associated substation equipment additions.

IA/IL 0 45 Proposed $122,000,000 Y C

C West MEC 3218 6004 12/31/2019 Hazleton 1 765 345 1200 Expand Hazleton Substation to include 765 kV yard and 765-345 kV transformation

IA 0 0 Proposed $66,000,000 Y C






Max kV


Miles Upg.


Cost Shared

Postage Stamp


C West MEC 3219 6003 12/31/2019 Kewanee Louisa 1 765 7140 New 765 kV line from Kewanee to Louisa and associated substation equipment additions.

IA/IL 0 80 Proposed $217,000,000 Y C

C West MEC 3219 6002 12/31/2019 Louisa 1 765 345 1200 Expand Louisa Substation to include 765 kV yard and 765-345 kV transformation

IA 0 0 Proposed $66,000,000 Y C

C West MEC 3221 6007 12/31/2019 Pocahontas County 765 345 New 765-345 kV Substation in Pocahontas County, Iowa. Station includes two 765-345 kV transformers and taps the Raun-Lehigh 345 kV line

IA 0 0 Proposed $92,000,000 Y C

C West MEC 3221 6008 12/31/2019 Pocahontas County Hazleton 1 765 3810 New 765 kV line from Pocahontas County to Hazleton and associated substation equipment additions.

IA 0 275 Proposed $745,000,000 Y C

C West MEC 3224 6011 12/31/2019 Woodbury County (Raun)

Hoskins 345 New double circuit 345 kV line from either Raun or new substation in Woodbury County to Hoskins and associated substation equipment additions.

IA/NE 0 85 Proposed $167,000,000 Y C


Broadland 345 New double circuit 345 kV line from either Raun or new substation in Woodbury County to Broadland and associated substation equipment additions.

IA/SD 0 300 Proposed $591,000,000 Y C

C West MEC 3226 6013 12/31/2024 Pocahontas County Woodbury County (Raun)

1 765 4760 New 765 kV line from Pocahontas County to Raun or new substation in Woodbury County and associated substation equipment additions.

IA 0 85 Proposed $230,000,000 Y C


1 765 345 1200 New Substation in Woodbury County or Expansion of Raun Substation to include 765 kV yard and 765-345 kV transformation

IA 0 0 Proposed $66,000,000 Y C

C West MEC 3227 6015 12/31/2024 Pocahontas County Hoskins 1 765 5300 New 765 kV line from Pocahontas County to Hoskins and associated substation equipment additions.

IA/NE 0 170 Proposed $461,000,000 Y C

C West MEC 3228 6017 12/31/2024 Hills 1 765 345 1200 Expand Hills Substation to include 765 kV yard and 765-345 kV transformation

IA 0 0 Proposed $66,000,000 Y C

C West MEC 3229 6019 12/31/2024 Osceola County 1 765 345 1200 New 765-345 kV Substation in Osceola County, Iowa. Station includes one 765-345 kV transformer and taps the Raun-Lakefield Jct. 345 kV line

IA 0 0 Proposed $71,000,000 Y C

C West MEC 3229 6018 12/31/2029 Pocahontas County Osceola County 1 765 4760 New 765 kV line from Pocahontas County to Osceola County and associated substation equipment additions.

IA 0 55 Proposed $149,000,000 Y C

C West MEC 3230 6020 12/31/2029 Osceola County Chanarambie 1 765 4760 New 765 kV line from Osceola County to Chanarambie and associated substation equipment additions.

IA/MN 0 135 Proposed $366,000,000 Y C

C West MEC 3231 6021 12/31/2029 Pocahontas County Adair County 1 765 4760 New 765 kV line from Pocahontas County to Adair County and associated substation equipment additions.

IA 0 150 Proposed $407,000,000 Y C

C West MEC 3231 6022 12/31/2029 Adair County 765 345 1200 New 765-345 kV Substation in Adair County, Iowa. Station includes two 765-345 kV transformers and taps the Atchison County-Booneville and Council Bluffs-Madison County 345 kV lines near the crossing point of these two 345 kV circuits.

IA 0 0 Proposed $92,000,000 Y C

C West MEC 3232 6023 12/31/2029 Adair County St. Joe 1 765 3810 New 765 kV line from Adair County to St. Joe and associated substation equipment additions.

IA/MO 0 150 Proposed $407,000,000 Y C

C West MEC 3233 6024 12/31/2029 Adair County Hills 1 765 2620 New 765 kV line from Adair County to Hills and associated substation equipment additions.

IA 0 255 Proposed $691,000,000 Y C






Max kV


Miles Upg.


Cost Shared

Postage Stamp


C West MEC 3234 6025 12/31/2029 Hills Kincaid 1 765 2380 New 765 kV line from Hills to Kincaid and associated substation equipment additions.

IA/IL 0 275 Proposed $745,000,000 Y C

C West MEC 3237 6031 6/1/2020 Avoca 345-161 kV Sub Page County Substation 1 345 1700 New 345 kV line from the Avoca 345--161 kV substation to the Page County Substation with 161 kV underbuild

IA 0 70 Conceptual $125,000,000 Y C

C West MEC 3237 6030 6/1/2020 Page County Substation Maryville Substation 1 345 1700 New 345 kV line from the Page County substation to the Maryville Substation with 161 kV underbuild and associated substation equipment additions.

IA/MO 0 35 Conceptual $63,000,000 Y C

C West MEC 3237 6029 6/1/2020 Page County Substation 1 345 161 560 Construct a new 345-161 kV substation and associated substation equipment on the Booneville-Atchison County 345 kV line and the Clarinda-Hastings 161 kV line


C West MEC 3237 6028 6/1/2020 Avoca Substation 1 345 161 560 Expand the Avoca Substation to add a 345 kV Yard and a 345-161 kV transformer and associated substation equipment additions.


C West MEC 3238 6032 6/1/2019 CBEC S3456 2 345 1700 New 345 kV line from the CBEC substation to OPPD's S3456 substation and associated substation equipment additions.

IA/NE 9.19 Conceptual $29,100,000 Y C

C West MEC 3239 6033 6/1/2018 Bunge Hastings 1 161 410 Rebuild the Bunge-Hastings 161 kV line and associated substation equipment additions.


C West MEC 3239 6034 12/1/2018 Hastings Clarinda 1 161 410 Rebuild the Hastings-Clarinda 161 kV line and associated substation equipment additions.

IA 31.2 0 Conceptual $17,200,000 Y C

C West MEC 3239 6035 12/1/2018 Clarinda Page County Substation 1 161 410 Rebuild the Clarinda-Page County 161 kV line and associated substation equipment additions.

IA 2 0 Conceptual $900,000 Y C

C West MEC 3240 6036 6/1/2020 Denison Avoca 1 161 410 New 161 kV line from NIPCO's Denison substation to the Avoca Sub and associated substation equipment additions.


C West MEC 3241 6037 6/1/2018 CBEC Sub 701 1 161 410 New 161 kV line from CBEC substation to Sub 701 and associated substation equipment additions.

IA 0 8.31 Conceptual $4,600,000 Y C

C West MEC 3242 6038 6/1/2018 Quick Sub 701 1 161 410 New 161 kV line from Quick substation to Sub 701 and associated substation equipment additions.


C West MEC 3243 6039 6/1/2016 Quick Avoca 1 161 410 New 161 kV line from the Quick substation to the Avoca substation and associated substation equipment additions.

IA 0 21.3 Conceptual $11,700,000 Y C

C West MEC 3244 6044 6/1/2017 Pleasant Corner Substation

161 New 161 kV substation IA Conceptual $3,500,000 Y C

C West MEC 3244 6042 6/1/2017 Beacon Pella 1 161 410 New 161 kV line from the Beacon substation to Pella and associated substation equipment additions.


C West MEC 3244 6040 6/1/2017 OGS Pleasant Corner Substation

1 161 410 New 161 kV line from the OGS substation to the Pleasant Corner substation and associated substation equipment additions.


C West MEC 3244 6041 6/1/2017 Pleasant Corner Substation

Beacon 1 161 410 New 161 kV line from the Pleasant Corner substation-Beacon substation and associated substation equipment additions.


C West MEC 3245 6046 6/1/2017 Knoxville Pella 1 161 410 New 161 kV line from the Knoxville substation to Pella and associated substation equipment additions.


C West MEC 3246 6065 6/1/2016 Webster South Lehigh 1 161 410 Webster South-Lehigh 161 kV Line IA 0 6.9 Conceptual $3,500,000 Y CC West MEC 3247 6066 6/1/2016 Lehigh Lehigh 345 161 560 Lehigh 345-161 kV transformer IA 0 0 Conceptual $7,500,000 Y C






Max kV


Miles Upg.


Cost Shared

Postage Stamp


C West MEC 3248 6050 6/1/2016 DPS DPS-Reasnor Switching Station

1 161 325 Bisect existing DPS-Reasnor 161 kV line and associated substation equipment additions.

IA 0.1 Conceptual $100,000 Y C

C West MEC 3248 6049 6/1/2016 DPS-Reasnor Switching Station

161 New 161 kV breakered switching station off the DPS-Reasnor 161 kV line


C West MEC 3248 6048 6/1/2016 DPS-Reasnor Switching Station

East Altoona 1 161 410 New 161 kV line from switching station on DPS-Reasnor line to East Altoona and associated substation equipment additions.


C West MEC 3250 6056 6/1/2018 West Grand 88th St 1 161 410 West Grand-88th St 161 kV Line and associated substation equipment additions.


C West MEC 3251 6057 6/1/2018 Army Post West Grand 1 161 410 Army Post-West Grand 161 kV Line and associated substation equipment additions.


C West MEC 3252 6058 6/1/2020 Norwalk Scotch Ridge 1 161 410 Norwalk-Scotch Ridge 161 kV Line and associated substation equipment additions.


C West MEC 3252 6059 6/1/2020 Scotch Ridge 161 13.2 33 New 161 kV distribution substation IA Conceptual $2,700,000 Y CC West MEC 3253 6061 6/1/2020 Avon Lake 161 13.2 33 New 161 kV distribution substation and

associated substation equipment additions.IA Conceptual $2,700,000 Y C

C West MEC 3253 6060 6/1/2020 Scotch Ridge Avon Lake 1 161 410 Scotch Ridge-Avon Lake 161 kV Line and associated substation equipment additions.


C West MEC 3254 6062 6/1/2020 Avon Lake SE Polk 1 161 410 Avon Lake-SE Polk 161 kV Line and associated substation equipment additions.


C West MEC 3255 6063 6/1/2015 Sub 91 Cordova 1 345 1738 Sub 91-Cordova 345 kV Line and associated substation equipment additions.

IA/IL 18 Conceptual $23,400,000 Y C

C West MEC 3256 6064 6/1/2015 Sub 39 Cordova 1 345 1738 Sub 39-Cordova 345 kV Line and associated substation equipment additions.


C West MEC 3257 6081 6/1/2016 LeMars Sioux County 1 161 410 New 161 kV line from a new LeMars substation to a new Sioux Co substation


C West MEC 3257 6084 6/1/2016 Sioux County Substation 161 New 161 kV substation IA Conceptual $3,500,000 Y CC West MEC 3257 6083 6/1/2016 Spencer Sioux County 1 161 410 New 161 kV line from the Spencer substation

to a new Sioux Co. substationIA 0 50 Conceptual $27,500,000 Y C

C West MEC 3257 6082 6/1/2016 Eagle Sioux County 1 161 410 New 161 kV line from the Eagle substation to a new Sioux Co. substation


C West MEC 3258 6067 6/1/2020 Little Sioux Monona 1 161 410 Little Sioux-Monona 161 kV line IA 0 34 Conceptual $18,700,000 Y CC West MEC 3259 6068 6/1/2020 Carroll Denison 1 161 410 Carroll-Denison 161 kV line IA 0 30 Conceptual $16,500,000 Y CC West MEC 3260 6069 6/1/2020 Odebolt Carroll 1 161 410 Odebolt-Carroll 161 kV line IA 20 16 Conceptual $18,000,000 Y CC West MEC 3260 6070 6/1/2020 Odebolt Carroll 1 345 1700 Odebolt-Carroll 345 kV line IA 0 36 Conceptual $39,000,000 Y CC West MEC 3261 6071 6/1/2020 Wisdom Buena Vista 1 345 1700 Wisdom-Buena Vista 345 kV line IA 0 20 Conceptual $26,000,000 Y CC West MEC 3261 6073 6/1/2020 Sac County Odebolt 1 345 1700 Sac County-Odebolt 345 kV line IA 0 17 Conceptual $22,100,000 Y CC West MEC 3261 6072 6/1/2020 Buena Vista Sac County 1 345 1700 Buena Vista-Sac County 345 kV line IA 0 24 Conceptual $31,200,000 Y CC West MEC 3262 6074 6/1/2020 Odebolt Grand Junction 1 345 1700 Odebolt-Grand Junction 345 kV line IA 0 68 Conceptual $88,400,000 Y CC West MEC 3265 6079 6/1/2020 Carroll Grand Junction 1 161 410 Carroll-Grand Junction 161 kV line IA 32 0 Conceptual $16,000,000 Y CC West MEC 3267 6086 6/1/2016 NW Sioux City 230 69 150 NW Sioux City 230-69 kV Sub IA Conceptual $10,000,000 Y CC West MEC 3267 6087 6/1/2016 NW Sioux City TWIN CH4 230.00 1 230 319 Bisect existing 230 kV line IA 0.1 Conceptual $250,000 Y CC West MEC 3267 6088 6/1/2016 NW Sioux City Sioux City 1 230 319 Bisect existing 230 kV line IA 0.1 Conceptual $250,000 Y CC West MEC 3269 6092 6/1/2012 Black Hawk Hazleton 161 410 Blackhawk-Hazleton 161 kV Rebuild (MEC

Section)IA 11.8 Planned $3,400,000 Y C

C West MEC 3371 6242 12/31/2014 Hills Parnell 1 161 278 Replace structures to increase operating temp.

IA Proposed $90,000 Y C

C West MEC 3372 6243 12/31/2014 Parnell Poweshiek 1 161 289 Replace structures to increase operating temp.

IA Proposed $540,000 Y C

C West MEC 3477 6420 12/1/2014 Oak Grove Galesburg 1 161 138 410 Rebuild Oak Grove - Galesburg 161 kV line IL 32 Proposed Y CC West MEC 3478 6421 12/31/2018 Webster Wright 1 161 410 Rebuild Webster-Wright 161 kV line. IA 11.77 Planned $6,768,000 Y CC West MEC 3478 6422 12/31/2018 Wright Wall Lake 1 161 410 Rebuild Wright-Wall Lake 161 kV. IA 11.65 Planned $6,700,000 Y CC West MEC 3478 6423 12/31/2018 Wall Lake Franklin 1 161 410 Rebuild Wall Lake-Franklin 161 kV line. IA 17.76 Planned $10,212,000 Y CC West MEC, ALTW 2193 4043 8/1/2018 Lehigh Toledo 1 765 4008 new line IA 97 Conceptual $313,000,000 Y C






Max kV


Miles Upg.


Cost Shared

Postage Stamp


C West MEC, ITCM 3218 6005 12/31/2019 Scott County Hazleton 1 765 4760 New 765 kV line from Scott County to Hazleton and associated substation equipment additions.

IA 0 145 Proposed $393,000,000 Y C

C West MEC, ITCM 3220 6006 12/31/2019 Louisa Hazleton 1 765 4760 New 765 kV line from Louisa to Hazleton and associated substation equipment additions.

IA 0 95 Proposed $257,000,000 Y C

C West MEC, ITCM 3222 6009 12/31/2019 Hills Hazleton 2 345 1700 New 345 kV line from Hills to Hazleton and associated substation equipment additions.

IA 0 55 Proposed $83,000,000 Y C

C West MEC, ITCM 3223 6010 12/31/2019 Hazleton Adams 345 New double circuit 345 kV line from Hazleton to Adams and associated substation equipment additions.

IA/MN 0 115 Proposed $227,000,000 Y C

C West MEC, ITCM 3228 6016 12/31/2024 Hills Hazleton 1 765 4760 New 765 kV line from Hills to Hazleton and associated substation equipment additions.

IA 0 55 Proposed $149,000,000 Y C

C West MEC, ITCM 3235 6026 12/31/2029 Osceola County Lakefield Jct. 1 765 4760 New 765 kV line from Osceola County to Lakefield Jct. and associated substation equipment additions.

IA/MN 0 85 Proposed $230,000,000 Y C

C West MEC, ITCM 3236 6027 12/31/2029 Hazleton Adams 1 765 4760 New 765 kV line from Hazleton to Adams and associated substation equipment additions.

IA/MN 0 115 Proposed $312,000,000 Y C

C West MEC, ITCM 3244 6043 6/1/2017 Pella Reasnor Switching Station

1 161 410 New 161 kV line from Pella to Reasnor Switching Station with 69 kV underbuild


C West MEC, ITCM 3245 6045 6/1/2017 Lucas County Knoxville 1 161 410 New 161 kV line from Lucas County Substation to the Knoxville Substation and associated substation equipment additions.


C West MEC, ITCM 3245 6047 6/1/2017 Pella Reasnor Switching Station

1 161 410 New 161 kV line from Pella to Reasnor Switching Station and associated substation equipment additions.


C West MEC, ITCM 3248 6051 6/1/2016 DPS-Reasnor Switching Station

Reasnor Switching Station

1 161 325 Bisect existing DPS-Reasnor 161 kV line and associated substation equipment additions.


C West MEC, ITCM 3249 6053 6/1/2016 NE Ankeny/Jasper County Sub

161 New 161 kV breakered switching station off the NE Ankeny-Jasper 161 kV line.


C West MEC, ITCM 3249 6054 6/1/2016 NE Ankeny NE Ankeny/Jasper County Sub

1 161 240 Bisect existing NE Ankeny-Jasper County 161 kV line and associated substation equipment additions.


C West MEC, ITCM 3249 6055 6/1/2016 NE Ankeny/Jasper County Sub

Jasper County 1 161 240 Bisect existing NE Ankeny-Jasper County 161 kV line and associated substation equipment additions.


C West MEC, ITCM 3249 6052 6/1/2016 East Altoona NE Ankeny/Jasper County Sub

1 161 410 New 161 kV line from East Altoona to a new sub off NE Ankeny/Jasper County line and associated substation equipment additions.


C West MEC, ITCM 3262 6075 6/1/2020 Grand Junction Adair County 1 345 1700 Grand Junction-Adair County 345 kV line IA 0 89 Conceptual $115,700,000 Y CC West MEC, ITCM 3263 6078 6/1/2020 Ottumwa Sub T 1 345 1700 Ottumwa-Sub T 345 kV line IA 0 70 Conceptual $100,500,000 Y CC West MEC, ITCM 3263 6076 6/1/2020 Adair County Ottumwa 1 345 1700 Adair-Ottumwa 345 kV line IA 0 100 Conceptual $143,500,000 Y CC West MEC, ITCM 3264 6077 6/1/2020 S.E. Polk Ottumwa 1 161 410 S.E. Polk-Ottumwa 161 kV line IA 0 80 Conceptual $40,000,000 Y CC West MEC, ITCM 3265 6080 6/1/2020 Grand Junction Adair County 1 161 410 Grand Junction-Adair County 161 kV line IA 0 89 Conceptual $44,500,000 Y CC West MH 3398 6273 12/31/2017 Dorsey US/MB Border 1 500 1732 Dorsey-US/Manitoba Border 500 kV line MB 80 80 Proposed $204,000,000 Y CC West MH, OTP 2180 4055 8/1/2018 Maple River Transformer 1 500 230 1200 new transformer ND Conceptual $15,000,000 Y CC West MH, OTP 2180 4031 8/1/2018 Riel Maple River 1 500 2673 new line Manitoba/ND 203 Conceptual $344,000,000 Y CC West MH, OTP 2180 4054 8/1/2018 Riel Transformer 1 500 115 430 new transformer Manitoba Conceptual $15,000,000 Y CC West MISO 3085 5375 6/1/2017 Helena 500kV Helena 345kV 2 500 345 1200 New transformer MN Proposed $60,000,000 Y CC West MISO 3085 5374 6/1/2017 Helena 500kV Helena 345kV 1 500 345 1200 New transformer MN Proposed $60,000,000 Y CC West MISO 3085 5373 6/1/2017 Maple River 500kV Helena 500kV 1 500 1732 New 500kV line Maple River to Helena MN 200 Proposed $500,000,000 Y CC West MISO 3085 5372 6/1/2017 Maple River 500kV Maple River, 345kV 1 500 345 1200 New transformer MN Proposed $60,000,000 Y CC West MISO 3085 5371 6/1/2017 Dorsey 500kV, Manitoba Maple River 500kV, MN 1 500 1732 New 500kV line from Dorsey to Maple River MN 200 Proposed $500,000,000 Y C

C West MP 2548 4565 6/1/2019 Hilltop Arrowhead 230 470 Upgrade 115 kV line to 230 kV MN 10 Proposed y y C






Max kV


Miles Upg.


Cost Shared

Postage Stamp


C West MP 2548 4564 6/1/2019 Hilltop Substation Equipment 230 115 366 Add second 183 MVA 230/115 kV Transformer

MN Proposed y y C

C West MP 2551 4562 6/30/2014 Boswell Deer River 1 115 Move 28L Tap to it own Breaker MN 0.5 Proposed $1,250,000 Y CC West MP 2551 4563 6/30/2014 Boswell Substation Equipment 1 115 115 kV Line entrance MN Proposed Y CC West MP 2551 6590 6/30/2014 Boswell Deer River 1 115 182 rebuild to higher capacity MN 8 0 proposed Y CC West Non-MISO 2773 4842 12/31/2020 Fort Thompson New 765/345 kV

substation1 765 345 2640/3040 MVAConstruct a new two TRF 765/345kV

substation in SD. Substation will have two 765/345kV TRFs tying to the Fort Thompson 345kV system and three 765kV line terminals.

SD Conceptual $205,000,000 Y C

C West Non-MISO 2773 4851 12/31/2020 Plano Line tap and terminal equipment

1 765 345 2640/3040 MVAConstruct a new 765kV tap & associated 765kV terminal equipment into the Plano substation in IL


C West Non-MISO 2773 4840 12/31/2020 Antelope Valley New 765/345 kV substation

1 765 345 2640/3040 MVAConstruct a new 765/345kV substation in ND. Substation will have a single 765/345kV TRF tying to the Antelope Valley 345kV system and a single 765kV line terminal.

ND Conceptual $85,000,000 Y C

C West Non-MISO 2773 4852 12/31/2020 Sullivan Line tap and terminal equipment

1 765 345 2640/3040 MVAConstruct a new 765kV tap & associated 765kV terminal equipment into the AEP Sullivan substation in IN.


C West OTP 2746 4769 11/1/2015 Turtle Lake 41.6 kV Mercer 41.6 kV 41.6 30 MVA Rebuild Existing 18-Mile 41.6 kV Line ND Proposed $500,000 NT CC West OTP 2773 4841 12/31/2020 North Dakota new

substationNew 765/345 kV substation

1 765 345 2640/3040 MVAConstruct a new 765/345kV substation in ND. Substation will have a single 765/345kV TRF and three 765kV line terminals.

ND Conceptual $120,000,000 Y C

C West OTP 2857 5010 12/31/2014 Green Valley 41.6 kV Marshall 41.6 kV 41.6 34 MVA Rebuild Existing 4-Mile 41.6 kV Line MN Proposed $550,000 Y CC West OTP 3484 6441 7/1/2015 Big Stone 230 kV Big Stone 13.8 kV 1 230 13.8 50 MVA Install a new 230/13.8 kV transformer to

accommodate a new load increase at Big Stone related to new pollution control equipment

SD Proposed $3,000,000 Y C

C West OTP 3513 6492 3/31/2015 Bison 345/230 transformer 2 345 230 336 new transformer and terminal works ND Planned $8,817,500 Y CC West OTP 3513 6491 3/31/2015 Bison 345/230 transformer 1 345 230 336 new transformer and terminal works ND Planned $8,817,500 Y CC West OTP, GRE 2225 4099 8/1/2018 Willmar Big Stone 1 345 972 new line MN/SD 75 Conceptual $159,000,000 Y CC West OTP, GRE 2225 4101 8/1/2018 Crow River Big Swan 1 345 1000 new line MN 25.3 Conceptual $54,000,000 Y CC West OTP, GRE 2225 4131 8/1/2018 Willmar Transformer 1 345 230 336 new transformer MN Conceptual $10,000,000 Y CC West OTP, GRE 2225 4133 8/1/2018 Crow River Transformer 1 345 115 448 new transformer MN Conceptual $10,000,000 Y CC West OTP, GRE 2225 4132 8/1/2018 Big Swan Transformer 1 345 115 448 new transformer MN Conceptual $10,000,000 Y CC West OTP, GRE 2225 4100 8/1/2018 Big Swan Willmar 1 345 1000 new line MN 40 Conceptual $85,000,000 Y CC West OTP, MDU 2219 4115 8/1/2018 Ellendale Transformer 1 345 230 336 new transformer ND Conceptual $10,000,000 Y CC West OTP, MDU 2219 4091 8/1/2018 Ellendale Maple River 1 345 740 new line ND 103 Conceptual $229,000,000 Y CC West OTP, NON-MISO 2182 4083 8/1/2018 Maple River Watertown 1 345 600 new line ND/SD 142 Conceptual $202,000,000 Y CC West OTP, XEL 2181 4032 8/1/2018 Maple River Blue Lake 1 500 1540 new line SD/MN 222 Conceptual $381,000,000 Y CC West OTP, XEL 2181 4056 8/1/2018 Blue Lake Transformer 1 500 345 2000 new transformer MN Conceptual $20,000,000 Y CC West OTP, XEL 2224 4129 8/1/2018 Morris Transformer 1 345 230 336 new transformer MN Conceptual $10,000,000 Y CC West OTP, XEL 2224 4098 8/1/2018 Morris Johnson Junction 1 345 1000 new line MN 16 Conceptual $34,000,000 Y CC West OTP, XEL 2224 4128 8/1/2018 Morris Alexandria 1 345 1000 new line MN 44 Conceptual $93,000,000 Y CC West OTP, XEL 2224 4097 8/1/2018 Johnson Junction Big Stone 1 345 1000 new line SD\MN 32 Conceptual $68,000,000 Y CC West OTP, XEL 2224 4130 8/1/2018 Johnson Junction Transformer 1 345 230 336 new transformer MN Conceptual $10,000,000 Y CC West OTP, XEL 3204 5950 12/31/2015 Sheyenne 230 kV Audubon 230 kV 1 230 350 MVA Upgrade Existing 230 kV line for Maple River

Wind Interconnection by replacing structures to increase operating temperature of line.

ND/MN 44 Planned $6,000,000 Y C

C West XEL 2177 4019 6/1/2016 West Waconia Blue Lake 1 345 2066 MVA Upgrade McLeod - Blue Lake 230 kV line to double circuit 345 kV with a step down to 115 kV at WestWaconia.

MN Proposed Y C

C West XEL 2177 4020 6/1/2016 West Waconia transformer 1 345 115 448 MVA 345/115 kV transformer at West Waconia MN Proposed Y C






Max kV


Miles Upg.


Cost Shared

Postage Stamp


C West XEL 2177 4018 6/1/2016 McLeod Blue Lake 2 345 2066 MVA Upgrade McLeod - Blue Lake 230 kV line to double circuit 345 kV with a step down to 115 kV at WestWaconia.

MN Proposed Y C

C West XEL 2177 4017 6/1/2016 McLeod West Waconia 1 345 2066 MVA Upgrade McLeod - Blue Lake 230 kV line to double circuit 345 kV with a step down to 115 kV at WestWaconia.

MN Proposed Y C

C West XEL 2177 4016 6/1/2016 Hazel McLeod 2 345 2066 MVA Upgrade Minn Valley - McLeod 230 kV line to double circuit 345 kV

MN Proposed Y C

C West XEL 2177 4015 6/1/2016 Hazel McLeod 1 345 2066 MVA Upgrade Minn Valley - McLeod 230 kV line to double circuit 345 kV

MN Proposed Y C

C West XEL 2184 4052 8/1/2018 Blue Earth Transformer 1 765 345 2767.5 new transformer MN Conceptual $20,000,000 Y CC West XEL 2184 4078 8/1/2018 Blue Earth Split Rock 1 345 628 new line SD/MN 130 Conceptual $185,000,000 Y CC West XEL 2185 4058 8/1/2018 Adams Transformer 1 765 345 2767.5 new transformer MN Conceptual $15,000,000 Y CC West XEL 2186 4085 8/1/2018 Sherbourne County Chisago County 1 345 1000 new line MN 48.4 Conceptual $69,000,000 Y CC West XEL 2187 4079 8/1/2018 SW Minneapolis Sherbourne County 1 345 1000 new line MN 47.9 Conceptual $68,000,000 Y CC West XEL 2188 4035 8/1/2018 SW Minneapolis Hampton Corner 1 765 4008 new line MN 93 Conceptual $260,000,000 Y CC West XEL 2189 4086 8/1/2018 Hampton Corner Chisago County 1 345 972 new line MN 72.2 Conceptual $103,000,000 Y CC West XEL 2191 4036 8/1/2018 SW Minneapolis Blue Earth 1 765 4776 new line MN 73 Conceptual $215,000,000 Y CC West XEL 2217 4110 8/1/2018 West Waconia Blue Lake 2 345 2066 new line MN 20 Conceptual $25,000,000 Y CC West XEL 2217 4109 8/1/2018 West Waconia Blue Lake 1 345 2066 new line MN 20 Conceptual $25,000,000 Y CC West XEL 2217 4088 8/1/2018 West Waconia Hazel 1 345 800 new line MN 92.3 Conceptual $112,000,000 Y CC West XEL 2222 4121 8/1/2018 West Waconia Transformer 2 345 230 448 new transformer MN Conceptual $10,000,000 Y CC West XEL 2222 4093 8/1/2018 West Waconia McLeod 1 230 600 new line MN 26 Conceptual $78,000,000 Y CC West XEL 2222 4118 8/1/2018 Minnesota Valley Panther 1 230 600 Rebuild Line MN 30.4 Conceptual $91,000,000 Y CC West XEL 2222 4120 8/1/2018 West Waconia Transformer 1 345 230 448 new transformer MN Conceptual $10,000,000 Y CC West XEL 2222 4119 8/1/2018 McLeod Panther 1 230 600 Rebuild Line MN 28.2 Conceptual $85,000,000 Y CC West XEL 2226 4134 8/1/2018 Adams Pleasant Valley 2 345 1000 new line MN 16.8 Conceptual $39,000,000 Y CC West XEL 2226 4135 8/1/2018 Byron Pleasant Valley 2 345 1000 new line MN 16.3 Conceptual $38,000,000 Y CC West XEL 2226 4136 8/1/2018 North Rochester Byron 2 345 1000 new line MN 10 Conceptual $24,000,000 Y CC West XEL 2227 4139 8/1/2018 Crow River West Waconia 1 345 1000 new line MN 23.9 Conceptual $34,000,000 Y CC West XEL 2227 4140 8/1/2018 West Waconia Helena 1 345 1000 new line MN 26 Conceptual $37,000,000 Y CC West XEL 2227 4138 8/1/2018 Dickinson Crow River 1 345 1000 new line MN 3.8 Conceptual $6,000,000 Y CC West XEL 2227 4137 8/1/2018 Monticello Dickinson 1 345 1000 new line MN 17.4 Conceptual $25,000,000 Y CC West XEL 2773 4846 12/31/2020 Adams New 765/345 kV

substation1 765 345 2640/3040 MVAConstruct a new 765/345kV substation in

MN. Substation will have a single 765/345kV TRF tying to the Adams 345kV system and a four 765kV line terminals.


C West XEL 2773 4843 12/31/2020 Chisago New 765/345 kV substation

1 765 345 2640/3040 MVAConstruct a new 765/345kV substation in MN. Substation will have a single 765/345kV TRF tying to the Chisago Co. 345kV system and two 765kV line terminals.


C West XEL, ALTW 2212 4044 8/1/2018 Adams Rock Creek 1 765 2808 new line MN/IA 204 Conceptual $627,000,000 Y CC West XEL, ATC LLC 2210 4060 8/1/2018 Longwood Chisago County 1 345 692 new line MN/WI 116 Conceptual $165,000,000 Y CC West XEL, GRE, OTP, M 3398 6283 12/31/2017 Alexandria SS Quarry 2 345 2085 Alexandria SS-Quarry 345 kV 2nd ckt MN 65 65 Proposed $15,000,000 Y CC West XEL, GRE, OTP, M 3398 6281 12/31/2017 Bison SD/MN Border 2 345 2085 Bison-SD/MN Border 345 kV 2nd ckt ND 20 20 Proposed $5,000,000 Y CC West XEL, GRE, OTP, M 3398 6284 12/31/2017 Quarry Monticello 2 345 2085 Quarry-Monticello 345 kV 2nd ckt MN 30 30 Proposed $8,000,000 Y CC West XEL, GRE, OTP, M 3398 6282 12/31/2017 SD/MN Border Alexandria SS 2 345 2085 SD/MN Border-Alexandria SS 345 kV 2nd ckt MN 110 110 Proposed $24,000,000 Y C

C West XEL, GRE, OTP, M 3398 6279 12/31/2017 Brookings Transformer 1 500 345 1200 Brookings 1200 MVA345/500 kV transformer SD Proposed $25,000,000 Y CC West XEL, GRE, OTP, M 3398 6278 12/31/2017 Bison Transformer 1 500 345 1200 Bison 1200 MVA 345/500 kV transformer ND Proposed $25,000,000 Y CC West XEL, GRE, OTP, M 3398 6277 12/31/2017 Brookings Split Rock 1 500 1732 Brookings-Split Rock 500 kV line SD 95 95 Proposed $325,000,000 Y CC West XEL, GRE, OTP, M 3398 6276 12/31/2017 ND/SD Border Brookings 1 500 1732 ND/SD Border-Brookings 500 kV line SD 130 130 Proposed $349,000,000 Y CC West XEL, GRE, OTP, M 3398 6274 12/31/2017 US/MB Border Bison 1 500 1732 US/Manitoba Border-Bison 500 kV line ND 165 165 Proposed $421,000,000 Y CC West XEL, GRE, OTP, M 3398 6275 12/31/2017 Bison ND/SD Border 1 500 1732 Bison-ND/SD Border 500 kV line ND 75 75 Proposed $201,000,000 Y CC West XEL, GRE, OTP, M 3398 6280 12/31/2017 Split Rock Transformer 1 500 345 1200 Split Rock 1200 MVA345/500 kV transformer SD Proposed $25,000,000 Y CC West XEL, MEC 2192 4057 8/1/2018 Lehigh Transformer 1 765 345 2767.5 new transformer IA Conceptual $15,000,000 Y CC West XEL, MEC 2192 4033 8/1/2018 Blue Earth Lehigh 1 765 4368 new line MN/IA 85 Conceptual $258,000,000 Y C






Max kV


Miles Upg.


Cost Shared

Postage Stamp


C West XEL, Non-MISO 2183 4084 8/1/2018 Watertown Split Rock 1 345 800 new line SD 92.4 Conceptual $131,000,000 Y CC West, Ce ITCM, AmerenIL 2785 4894 5/1/2014 New Substation in NW

IowaSorenson 1 800 6400 new +/- 800KV DC line IA, IL, IN 667 Proposed Y C


Documents

· MISO Transmission Expansion Plan 2011 Table of contents 2 1. Executive Summary