Studies and Reports > 2025 Biennial Report > Transmission Projects Report 2021

6.5    West Central Zone

6.5.1  Needed Projects

The following table provides a list of transmission needs identified in the West Central Zone by MISO utilities. There were no projects identified in this zone by non-MISO utilities.

Ortonville 115/41.6 kV Transformer

MPUC Tracking Number: 2015-WC-N3
Utility: Otter Tail Power Company (OTP)
Project Description: Replace existing Ortonville 115/41.6 kV transformer with a new 40 MVA 115/41.6 kV transformer.

Need Driver: This area is experiencing local load growth and continual growth may cause the current 115/41.6 kV Ortonville transformer to become overloaded and created reliability concerns.

Alternatives:

Transmission Alternatives

With the most recent load forecasts, this project is not presently planned for construction. Alternatives may be considered if or when loads drive the need for this project.

Non-Wires Alternatives

Non-wires alternatives may be considered if this project were to move forward in development; however, they would likely come with a higher cost than replacing this transformer.

Analysis: The replacement of the Ortonville 115/41.6 kV transformer with a larger transformer will address the local load growth that this area is experiencing and will provide reliable service to the customers in the area. This project is the most cost-effective and environmentally responsible project to address the local needs in the Ortonville area.
Schedule: While prior studies identified this need, current load growth projections show no need to replace this transformer based on OTP’s Ten Year Development Study. However, faster load growth could create a need for this project, and continued studies will monitor this transformer’s loading.
General Impacts: The new transformer would replace the existing transformer and would require no additional new land or expansion. Since it will replace the existing transformer, there likely would be no major environmental impacts. This project may require a temporary project crew. If so, this may bring some business to the area in the form of room and board. This is an existing substation and would likely not require any permits or fees from the local government. This project is the product of a reliability measure and will probably not have a substantial or lasting impact on the community in terms of population or other social characteristics.

Appleton – Benson 115 kV Line

MPUC Tracking Number: 2021-WC-N6

Certificate of Need Number: CN-24-263
Utility: Great River Energy (GRE), Otter Tail Power (OTP), Missouri River Energy Services (MRES)
Project Description: Construct approximately 29 miles of new 115 kV transmission line starting from the MRES owned Appleton substation in the city of Appleton to GRE’s Benson substation in the city of Benson.

The Project will include upgrading, rebuilding or reconductoring, and/or constructing new transmission lines between the following substations: Appleton, Shible Lake, Moyer, Danvers, Benson, and Benson Municipal Substations. The Shible Lake, Benson, and Benson Municipal substations are existing substations that will be modified and/or expanded to accommodate the project’s 115 kV connection. The project also includes the construction of new Appleton substations. The Moyer and Danvers Substations will be expanded or relocated to accommodate connection to the Project.

The new the Appleton Substation will involve construction of a ring bus with four breakers and a 25 MVAr capacitor bank.

Need Driver: The Project is needed to meet load serving needs in the Project area and avoid low voltage issues under certain contingency scenarios driven by the retirement of the 55 MW FibroMinn Energy Center near the City of Benson. The system is currently experiencing low voltages resulting in insufficient capacity to reliably serve all load under contingency conditions. The Project will provide an additional 47 MW of system capacity under the worst single (N-1) contingency, which is expected to meet the demand for electricity for decades to come. Additionally, it will address low voltage concerns during N-2 contingencies that may otherwise result in voltage collapse within the project areas.

Alternatives: Alternatives were studied to confirm that the project was the best performing project for the Study Area. The proposed project will already be an upgrade of existing lines mainly utilizing existing corridor; there are no other existing transmission lines that could be upgraded as an alternative to the project. Different project options were chosen with the aim of providing a new high voltage source into the Study Area that centers on Benson. A voltage of 115 kV was chosen for these alternatives because Benson is at the center of an existing 115 kV network. The Benson Substation also contains 69 kV line terminations. However, the 69 kV transmission system currently has a need for improvement and networking additional 69 kV lines would not provide reliable service to 115 kV connected loads.

Transmission Alternatives

The following alternatives were considered, but were not preferred:

Alexandria – Benson 115 kV ~47-mile line
MN Valley – Benson 115 kV ~44-mile line
Willmar – Benson 115 kV ~35-mile line
Six Mile Grove 230/115 kV substation

Study analysis shows that each alternative configuration performs similarly to address single contingency (N-1) low voltage concerns. Neither the Willmar-Benson nor the Minnesota Valley- Benson alternatives perform better than the Project. Because of their longer lengths, they would also have greater losses and relatively higher cost and impacts, as compared to the project.

Non-Wires Alternatives

Both technical and economic analysis proves that a Non-Wires Alternative (NWA) is not viable for the area of study. In addition to that, the technical solution shows that NWA fails to address some of the issues which can be addressed by the proposed transmission solution, for example P6 contingency low voltage concerns in the Morris to Canby 115 kV system. A report is available upon request.

Analysis: In 2020, Great River Energy, Otter Tail Power, MRES, and Xcel Energy completed a study to evaluate the shutdown of the 55 MW FibroMinn Energy Center near Benson, Minnesota. The FibroMinn plant had played a significant role in supplying power and regulating the reactive power need in the local area. The retirement created near-term load-serving reliability concerns. The Benson Area Load Serving Study (2020) (BAL Study) concluded the need for this transmission project. Since the 2020 BAL Study, several system modifications have been completed and updated forecasts have been made available. A planning study update was performed in 2024 which reanalyzed the load serving need in the area based on the topology changes as updated from the MISO Transmission Expansion Plan (MTEP) 2018 data series to the MTEP 2023 data series. The analysis incorporated the most recent load forecasts for the distribution substations. This analysis confirms the need for additional load-serving support. In summary analysis has shown that:

The Appleton – Benson 115 kV line is the best value plan that addresses the load serving reliability issues in the area that in part was caused by generation retirement in the area. By in large, this project utilizes existing transmission line corridor and will upgrade existing 41.6 kV transmission lines to 115 kV. As such, among the alternatives considered, it is the most environmentally friendly project that addresses reliability issues and fosters economic development in wider area.

The Project will provide the necessary transmission system improvements to service current load and forecasted load for decades to come. The proposed Project addresses NERC standard reliability violations including contingency low voltage and thermal concerns on the 115-kV system, addresses existing N-2 contingency voltage collapse on the 115-kV system, accommodates future load growth in the 41.6-kV and 115-kV transmission systems which is expected to reach a peak demand of 101.61 MW in 2028 and 106.87 MW in 2033, and reduces losses in the Study Area. Overall, the Project will provide an additional 47 MW of system capacity under the worst single (N-1) contingency and an additional 77 MW of capacity under the worst double (N-2) contingency.

Schedule: The project is planned to be in service by March 2030.

General Impacts: The project will require approximately 29 miles of new 115 kV transmission line from Appleton substation to Benson substation. The project is located in predominantly agricultural lands. Prior to construction, GRE and/or OTP will acquire the necessary right-of-way and permits for construction of the project. GRE anticipates acquiring a 100-foot easement to facilitate construction and operation of the line. The preliminary design follows existing road rights-of-way to minimize impacts to nearby residents and environmental features. Prior to construction, GRE will complete a desktop review of environmental features that may be present in the right of way and will work with the appropriate permitting agencies, as required, to minimize impacts during construction. Construction is expected to be completed in 24 months. During this time, GRE and/or their contractors will be working in the area and will contribute positively to the local economy. No significant traffic impacts are anticipated. The right-of-way will be restored following construction. As compared to available alternatives, the project minimizes the length of transmission line through sensitive areas.

Big Swan 115 kV Ring Bus and Capacitor Bank Addition

MPUC Tracking Number: 2021-WC-N8

Utility: Great River Energy (GRE)

Project Description: Rebuild the 115 kV side of the Big Swan substation in a ring bus configuration to accommodate installation of a new capacitor bank and to reterminate the Big Swan to Crow River 115 kV line into a breaker position. Upgrade 115 kV and 69 kV relaying to ensure all protection is redundant. Install a new 40 MVAr capacitor into a position in the ring bus.

Need Driver:

Ring bus addition:
The Big Swan 115 kV bus has an incomplete topology, missing a 115 kV breaker on the Big Swan 115 kV line. For 115 kV line faults between Big Swan and Crow River, three 115 kV lines (all BES) and Big Swan 115/69 kV TR1 need to be tripped to clear the fault. The addition of a 115 kV breaker and 115kV bus connected capacitor bank in the current configuration would create a five- position straight bus. GRE cannot add the new positions to the existing box structure and maintain required electrical clearances. A 115 kV ring bus will allow for safe clearances, higher system reliability/resilience, allow for future expansion, and aligns with GRE standards for a 115 kV facility.

Capacitor bank addition:
The Hutchinson area study identified low voltage concerns in the 115 kV system that is between Hutchinson, Wakefield and Crow River. NERC category P6 contingencies involving prior outages, such as McLeod – Hutchinson 115 kV line, Crow River – Brooks Lake 115 kV line and Wakefield – Stockade 115 kV line causes low voltage problems at 115 kV side of GRE member substations and Hutchinson Municipal substation.

The Hutchinson area study also identified low voltage and overload concerns in the 69 kV transmission system for the loss of the Hutchinson 115/69 kV transformer. Several options have been evaluated to address the voltage concerns and all the options involved installation of capacitor bank at Big Swan to improve the 115 kV system post contingent voltage profile and a second Hutchinson 115/69 kV transformer to address low voltage and overload concerns in the 69 kV system. Per discussion with Xcel Energy and MRES, GRE will be responsible for the installation of the 40 MVAr capacitor bank at Big Swan and Hutchinson Municipal Commission will be responsible for the installation of a second 115/69 kV transformer at Hutchinson substation.

Alternatives:

Transmission Alternatives

Several transmission alternatives were considered, including installation of the capacitor bank at the Hutchinson substation. However, this option was not favored due to the proximity of Hutchinson substation to an industrial plant that could be highly sensitive to voltage transients. As for reterminating the 115 kV line from Crow River with a breaker at Big Swan, no other alternatives were considered.

Non-Wires Alternatives

NWA were not considered for this project. This project modifies existing substations that lack a breaker to re-termination of an existing line. The installation of the capacitor bank is contained within the existing substation fence, making the NWA unnecessary.

Analysis: The addition of capacitor bank at the existing Big Swan substation was found to be the best value and environmentally friendly plan that addresses reliability issues in the area. The Big Swan 115 kV side of the substation is deficient of a line termination breaker for the Crow River to Big Swan 115 kV line and is not up to GRE’s current design standard. GRE plans to bring the Big Swan 115 kV side of the substation up to the current design standard while installing the capacitor bank and breaker at the Big Swan substation. This project is contained within GRE’s existing property, therefore, it will have minimal impact on landowners in the area.

Schedule: The project is planned to be in service by January 2027.

General Impacts: This project is located on GRE owned property. Construction is expected to be completed in 6 months. During this time, GRE and/or their contractors will be working in the area and will contribute positively to the local economy. No significant traffic impacts are anticipated.

Milbank, SD Area Upgrades

Utility: Otter Tail Power Company (OTP)

Project Description: Phase 1 of the project will consist of constructing a new 12-mile 115 kV line from the Big Stone 230/115 kV substation (located near Big Stone City, SD) to a new 115/12.5 kV substation located near Milbank, SD. In addition, a portion of the town of Milbank, SD will be moved to the 115 kV system. Phase 1 of the project is located entirely within South Dakota. Phase 2 of the project will consist of construction a new 18.5-mile 115 kV line from the new 115/12.5 kV substation located near Milbank, SD to a new switching station on the Big Stone – Marietta 115 kV line located in Minnesota.

Need Driver: Planned load growth in Milbank, SD will bring the area’s 41.6 kV transmission system beyond its capacity. Low voltages have been identified on the 41.6 kV transmission system in studies for the loss of the Highway 12 115 kV source. This project will move load to the 115 kV system and free up capacity on the area’s 41.6 kV system.

Alternatives:

Transmission Alternatives

Several transmission alternatives were studied. The selected project is able to maintain system reliability at a low cost and is able to meet the timelines of the load expansion.

•  New 230/41.6 kV substation on the Big Stone – Blair 230 kV line

•  Big Stone 115 kV – Milbank 115 kV – New 230/115 kV substation on the Big Stone – Blair 230 kV line

•  Radial-only 115 kV service for load expansion

•  Highway 12 115 kV – Milbank 115 kV – new switching station on Big Stone – Marietta 115 kV line

Non-Wires Alternatives

This project is related to a load expansion, and non-wires alternatives would not provide sufficient availability or reliability to support the load.

Analysis: OTP performed a study to investigate projects to serve a load expansion in Milbank, SD. This analysis reviewed the selected project, as well as the transmission alternatives listed above. The analysis identified the selected project as the lowest-cost option while maintaining system reliability and meeting the timeline of the load expansion.

Schedule: The Minnesota portion of the project is expected to be completed by the end of 2026.

General Impacts: This project will require approximately 30.5 miles of new 115 kV transmission line (approximately 4 miles in Minnesota) from the Big Stone 230/115 kV substation to a new 115/12.5 kV substation near Milbank, SD to a new switching station on the Big Stone – Marietta 115 kV line. The project is located in predominantly agricultural lands. Prior to construction OTP will acquire the necessary right-of-way and permits for construction of the project. The preliminary design follows existing road rights-of-way to minimize impacts to nearby residents and environmental features. During this time, OTP and/or contractors will be working in the area and will contribute positively to the local economy. No significant traffic impacts are anticipated. The right-of-way will be restored following construction.

Big Stone South – Alexandria – Big Oaks 345 kV

MPUC Tracking Number: 2023-WC-N3

Utility: Great River Energy (GRE), Minnesota Power (MP), Missouri River Energy Services (MRES), Otter Tail Power Company (OTP), Xcel Energy (XEL)

Project Description: GRE, MP, MRES, OTP, and XEL are jointly developing the Big Stone South – Alexandria – Big Oaks 345 kV line, located in western and central Minnesota. The project consists of two major segments of transmission line construction:

1. Eastern Segment: Adding a second circuit to existing 345 kV structures originally built as part of the CapX2020 Fargo – St. Cloud and St. Cloud – Monticello projects between Alexandria and a new substation near the Sherco power plant in Becker.
2. Western Segment: Constructing a new 345 kV transmission line between the Big Stone South 345 kV substation in South Dakota to the Alexandria 345 kV substation in Minnesota.

Need Driver: This project will help ensure electric reliability, increase resiliency to extreme weather events, reduce transmission congestion, and increase access to low-cost energy in the region. With growth of wind energy projects in the Dakotas and Western Minnesota, there is not enough capacity on the transmission system to transfer that energy from the Dakotas and Western Minnesota to the Twin Cities load center.

Alternatives:

Transmission Alternatives

As part of MISO’s LRTP Tranche 1 studies, numerous projects were studied and optimized into the full Tranche 1 project portfolio. Full details of the alternatives analysis are available in the LRTP Addendum to the MTEP21 report.

Non-Wires Alternatives

None.

Analysis: Full details of MISO’s LRTP Tranche 1 analysis are available in the LRTP Addendum to the MTEP21 report.

Schedule: The Eastern Segment is expected to be completed in 2026 -2027. The Western Segment is planned to be completed by the end of 2030.

General Impacts: This project will require approximately new 345 kV transmission line from the Big Stone 345 kV substation to the Alexandria 345 kV substation. The project is located in predominantly agricultural lands. Prior to construction, necessary right-of-way and permits will be acquired for construction of the project. The preliminary design follows existing road rights-of- way to minimize impacts to nearby residents and environmental features. During this time, GRE, MP, MRES, OTP, and XEL and/or contractors will be working in the area and will contribute positively to the local economy. No significant traffic impacts are anticipated. The right-of-way will be restored following construction.

Willmar Litchfield – Forest City – Hutchinson Rebuild and 115 kV Conversion

MPUC Tracking Number: 2023-WC-N5

Utility: Great River Energy (GRE), Missouri River Energy Services (MRES), Southern Minnesota Municipal Power Agency (SMMPA)

Project Description: Rebuild existing 69 kV transmission lines between the existing substations of Willmar, Litchfield and Hutchinson to a 115 kV standard for a future 115 kV operation. In addition, build a new 115 kV line from Litchfield to the Stockade distribution substation and a new 115 kV breaker station, Forest City, at the current Stockade tap switch point. Existing lines and infrastructure are owned by GRE, SMMPA, Litchfield Municipal, and Hutchinson Municipal. This project will be carried out jointly by these parties.

Need Driver: The lines between Willmar, Litchfield and Hutchinson have a need to be rebuilt due to age and condition concerns. These lines are some of the oldest 69 kV transmission lines in the area. The line rebuild projects will be done in such a way that it makes the load serving transmission system more resilient, creates opportunities for increased penetration of large loads and renewable resources, and solves existing or future reliability concerns in the transmission system.

Alternatives:

Transmission Alternatives

The driver for the line rebuild is primarily age and condition of the transmission line. GRE could rebuild the transmission line to 69 kV standard, but this will limit the load serving capacity of the transmission system in the Litchfield area. In addition, rebuilding the line to 69 kV will not address low voltage problems in the Hutchinson and Glencoe areas.

Non-Wires Alternatives

The primary driver of this project is the age and deteriorating condition of the transmission system, which connects multiple sources across a wide service area. Due to the nature of the reliability challenges and infrastructure requirements, non-wires alternatives are not considered viable solutions for addressing the core needs of this project. As the project proceeds through the Minnesota Certificate of Need filing process, a detailed analysis demonstrating the infeasibility of non-wires alternatives will be included in the Certificate of Need documentation.

Analysis: Transmission system assessment studies have shown that the existing transmission system is not resilient and doesn't have margin to serve new or growing loads in the Hutchinson and Glencoe areas. The Hutchinson and Glencoe areas experience low voltage problems for NERC category P6 contingencies. To improve system, post contingent voltage, address reliability concerns due to the transmission line age and condition, and make capacity available to serve large loads in the system, GRE will coordinate with SMMPA and MRES to construct a 115 kV line between Willmar and Hutchinson substations, via Litchfield and Stockade. Most of this future 115 kV line will involve an upgrade of existing 69 kV lines to 115 kV voltage that will continue to operate at 69 kV until the line is permitted for 115 kV operation.

Operating the transmission at 115 kV would require double circuiting the line between Willmar and Svea (SH), rebuilding the line between Svea substation and Hutchinson (DS/HN), rebuilding the SMMPA operated line between Litchfield Municipal and the Willmar-Hutchinson line (LT) to a double circuit for an in-and-out configuration to Litchfield Municipal, rebuilding the GRE line between Litchfield Municipal and the Big Swan-Atwater line (LN) and construction of 8 miles of new 115 kV line from Litchfield Municipal North Tap to connect to the Stockade substation.

GRE, SMMPA and MRES would first complete the following projects to address age and condition concerns in the transmission system:

• Rebuild DS line to 115 kV standard with 795 ACSS conductor
• Rebuild SH line to double circuit 115 kV / 69 kV. Svea distribution substation will remain at 69 kV service.
• Rebuild LT line as a double circuit to 115 kV standard with 795 ACSS conductor
• Rebuild LN line to 115 kV standard with 795 ACSS conductor
• Rebuild HN line to 115 kV standard with 795 ACSS conductor

Following the completion of the above age and condition related line rebuild projects, GRE, SMMPA and MRES will work on the following projects to operate the transmission system at 115 kV:

• Rebuild the Litchfield Municipal breaker station and installation of 2x20 MVAr capacitor banks
• Construct Forest City 115 kV breaker station
• Construct a new 8-mile 115 kV line from Litchfield Municipal North to the Stockade substation.
• Upgrade Litchfield Municipal distribution substation from 69 kV to 115 kV service

The line rebuild projects bring efficiency improvement as there will be less power loss on the transmission line. It also provides better load serving reliability as it will be new, consist of larger conductor and be constructed to the 115 kV standard. The line rebuild makes capacity available in the transmission system for a new load that may come to the areas.

Schedule: This project is scheduled for Q4 2031 completion.

General Impacts: The project will be constructed on an existing 100-foot right-of-way that is largely located on agricultural lands. While this project is at the end of the planning phase and although some additional temporary workspace may be required, no new landowners are expected to be impacted due to the line rebuild projects. Construction of a new 8-mile 115 kV line from Litchfield Municipal North to the Stockade substation require acquiring new route and easement and will impact new landowners along the transmission line.

Benton County Solar Farm (J1426)

MPUC Tracking Number: 2023-WC-N11

Utility: Great River Energy (GRE)

Project Description: Add a new 115 kV breaker and a half row and tap line to accommodate the interconnection of the 100 MW solar farm for J1426.

Need Driver: MISO project J1426 has requested interconnection to the 115 kV bus at Benton County. Project J1426 is a 100 megawatt (MW) solar energy generating facility, a 100 MW battery energy storage system, and a 0.4 mile long, 115 kilovolt high voltage transmission line within Minden Township, Benton County, Minnesota.

Alternatives:

Transmission Alternatives

The interconnection was evaluated under the MISO’s DPP system impact studies. No alternatives for the interconnections were identified.

Non-Wires Alternatives

Non-wires alternatives are not considered for new generation interconnections as the POI is determined by the interconnection customer.

Analysis: The expansion of facilities at Benton County are required to provide a point of interconnection for project J1426.

Schedule: The Benton County Solar Farm project is planned to be in-service by fall 2026.

General Impacts: This project is located on GRE owned property. Construction is expected to be completed in 6 months. During this time, GRE and/or their contractors will be working in the area and will contribute positively to the local economy. No significant traffic impacts are anticipated.

Alexandria Light and Power Southeast Substation

MPUC Tracking Number: 2023-WC-N13

Utility: Missouri River Energy Services (MRES)

Project Description: Alexandria Light & and Power (ALP) will build a new distribution substation on the southeast part of town. The substation will tap and existing 115 kV line with an in and out substation. The substation will have a 115 kV to distribution transformer.

Need Driver: Distribution studies showed deficiencies present in the existing distribution system and to the need for a new distribution substation to support additional load growth within the City of Alexandria.

Alternatives:

Transmission Alternatives

None.

Non-Wires Alternatives

This is a distribution system improvement, and no alternatives were considered.

Analysis: The need for a new distribution substation to support load growth was identified in Distribution System Planning Update report. The new distribution substation allows for more load growth within the City of Alexandria.

Schedule: The project is planned to be in-service by Q4 2028.

General Impacts: This project is located at the outer edge of town not near residential homes. Construction is expected to be completed in 18 months. During this time the ALP, and/or their contractors will be working in the area and will contribute positively to the local economy. No significant traffic impacts are anticipated.

Alexandria Substation Expansion

MPUC Tracking Number: 2023-WC-N14

Utility: Missouri River Energy Services (MRES)
Project Description: Alexandria Substation will be expanded to add positions for new 345 kV transmission line to Big Oaks and Big Stone South substations.
Need Driver: The BSSA/ABP Project, along with the other LRTP Tranche 1 Portfolio of transmission projects, are needed to provide reliable, resilient, and cost-effective delivery of energy as the generation resource mix.

Alternatives:

Transmission Alternatives

None.

Non-Wires Alternatives

None

Analysis: The generation resource mix is changing as more renewable and variable energy, such as wind and solar, is added to the system and aging coal-fired generation plants are retired. The BSSA/ABP Project, along with the other LRTP Tranche 1 Portfolio of transmission projects, are needed to provide reliable, resilient, and cost-effective delivery of energy as the generation resource mix continues to evolve over the coming years.

Schedule: The project is planned to be fully in-service by Q2 2030. Part of it will be completed by Q2 2027.

General Impacts: The Alexandra Substation is located on the south end of Alexandria, MN. The substation will be expanded to accommodate the transmission lines to Big Oaks and Big Stone South. The project is located in predominantly agricultural lands. Construction is expected to be completed in 24 months. During this time, MRES and/or their contractors will be working in the area and will contribute positively to the local economy. No significant traffic impacts are anticipated.

Benton County Terminal Upgrade

MPUC Tracking Number: 2023-WC-N16

Utility: Great River Energy (GRE)

Project Description: Upgrade terminal equipment to 2000 A rating.

Need Driver: This terminal equipment current rating has caused market congestion in the past and is projected to continue to cause market congestion into the future.

Alternatives:

Transmission Alternatives

No transmission alternatives were considered since this project is replacing equipment in an existing substation.

Non-Wires Alternatives

No non-wires alternatives were considered since this project is replacing equipment in an existing substation.

Analysis: The equipment upgrade will increase the ratings of the 230 kV lines out of Benton County, reducing the likelihood of these lines causing congestion in the market.

Schedule: The project is planned to be in service by spring 2026.

General Impacts: This project is located on GRE owned property. Construction is expected to be completed in 6 months. During this time, GRE and/or their contractors will be working in the area and will contribute positively to the local economy. No significant traffic impacts are anticipated.

Darnen Distribution Substation

MPUC Tracking Number: 2025-WC-N1

Utility: Great River Energy (GRE)

Project Description: The Great River Energy (GRE) owned “AG-MB” 115 kV line between Morris and Walden will be tapped to serve a new distribution substation with an ‘in-and-out’ configuration.

Need Driver: Agralite Electric Cooperative requires a new distribution substation to serve power to a new dairy processing plant. Agralite requested transmission service from GRE to serve this new load. In addition to the new industrial load some existing load will be reallocated to this substation from other nearby Agralite substations to better serve their members. Due to the size of the new interconnected load and the potential for multiple distribution transformers served in a double-ended configuration, the transmission line will be configured in-and-out with the transmission path going into the distribution substation and back out, thereby providing redundant service from Morris or Walden.

Alternatives:

Transmission Alternatives

No transmission alternative can adequately address the need for a new distribution substation to serve the growing load in the area. The nearest potential alternative for interconnecting the Darnen distribution Substation is the 41.6 kV transmission system. However, this system generally has lower capacity and reliability performance compared to the proposed 115 kV transmission system. Given the expected load at Darnen, the 41.6 kV system is not a suitable option.

Non-Wires Alternatives

As the new load cannot be served from existing distribution system a new transmission interconnection is required and therefore NWA was not considered.

Analysis: Power flow analysis was performed and showed no adverse impact on the existing transmission system.

Distribution analysis showed the need for the new transmission interconnection due to insufficient capacity on existing distribution feeders.

Schedule: The project is planned to be in service by fall 2026.

General Impacts: The project will be constructed on a site on the existing 115 kV transmission line with under 1500 feet of new line required. The project is in predominantly agricultural lands. Construction is expected to be completed in 6 months. During this time, GRE and/or their contractors will be working in the area and will contribute positively to the local economy. No significant traffic impacts are anticipated. The right-of-way will be restored following construction.

Kimball Area Projects

MPUC Tracking Number: 2025-WC-N2

Utility: Great River Energy (GRE)

Project Description: Meeker Cooperative Light and Power Association (MCLP) plans to build a new distribution substation to serve load in the area. GRE will construct approximately 3 miles of 115 kV transmission line with 477 ACSR conductor to the high side of MCLP’s new Kimball distribution substation.

Need Driver: MCLP needs to establish a new substation north of the city of Kimball to serve growing loads and address low voltage problems in the distribution system.

Alternatives:

Transmission Alternatives

Transmission line alternatives were considered. The original choice was to serve the substation from nearby 69 kV line. This option was not chosen as routing of Xcel Energy’s MN Energy Connect project went through the proposed 69 kV route and therefore another route had to be chosen. The 115 kV line was the next best alternative with minimal new line being needed and fewer landowners affected.

Non-Wires Alternatives

As the new load cannot be served from existing distribution system a new transmission interconnection is required and therefore NWA was not considered.

Analysis: Power flow analysis was performed and showed no adverse impact on the existing transmission system.

Distribution analysis showed the need for the new transmission interconnection due to insufficient capacity on existing distribution feeders. The analysis also showed low voltage problems within the distribution system necessitating a new delivery point closer to the load center.

Schedule: The project is planned to be in service by fall 2027.

General Impacts: The project will require approximately 3 miles of new 115 kV transmission line from the existing line to the new substation. The project is located in predominantly agricultural lands. Prior to construction, GRE will acquire the necessary right-of-way and permits for construction of the project. GRE anticipates acquiring a 100-foot easement to facilitate construction and operation of the line. The preliminary design follows existing road rights-of-way to minimize impacts to nearby residents and environmental features. Prior to construction, GRE will complete a desktop review of environmental features that may be present in the right of way and will work with the appropriate permitting agencies, as required, to minimize impacts during construction. Construction is expected to be completed in 12 months. During this time, GRE and/or their contractors will be working in the area and will contribute positively to the local economy. No significant traffic impacts are anticipated. The right-of-way will be restored following construction. As compared to available alternatives, the project minimizes the length of transmission line through sensitive areas.

Detroit Lakes Jet Substation

MPUC Tracking Number: 2025-WC-N3

Utility: Missouri River Energy Services (MRES)

Project Description: Detroit Lakes Public Utilities (DLPU) plans to construct a new line-breaker substation adjacent to the existing Detroit Lakes Industrial Substation in order to relocate the existing distribution transformer at Detroit Lakes Industrial Substation, as well as add a second distribution transformer in the new line-breaker substation.

Need Driver: Distribution studies showed deficiencies present in the existing distribution system and the need for a new distribution substation to support additional load growth within the City of Detroit Lakes.

Alternatives:

Transmission Alternatives

None.

Non-Wires Alternatives

This is a distribution system improvement, and no alternatives were considered.

Analysis: The need for a new distribution substation to support load growth was identified. The new distribution substation allows for more load growth within the City of Detroit Lakes. The new substation will also electrically isolate the load served by the Industrial substation sufficiently to not risk the potential of coincident loss of both the Industrial and Front Street substation load for a single outage event. This is a project that is most economical and least impactful to landowners.

Schedule: The project is planned to be in-service by Q4 2026.

General Impacts: This project is located at the outer edge of town not near an industrial park. DLPU and/or their contractors will be working in the area and will contribute positively to the local economy. No significant traffic impacts are anticipated.

Hutchinson Substation

Utility: Missouri River Energy Services (MRES)

Project Description: This project will add a second 115/69 kV transformer to the existing City of Hutchinson MN, Hutchinson Substation. The project will also rebuild the Hutchinson 115 kV into a four position ring bus.

Need Driver: Project needed to address multiple low voltage and thermal violations in the area.

Alternatives:

Transmission Alternatives None

Non-Wires Alternatives

This is a reliability improvement, so no alternatives were considered.

Analysis: This is a cost-effective system resiliency solution.

Schedule: The projects are set to go in-service in Q4 2026.

General Impacts: The project will be constructed at an existing 115/69 kV substation. Some land outside of the existing substation will need to be acquired to construct the expansion. During construction HUC and/or their contractors will be working in the area and will contribute positively to the local economy. No significant impacts are anticipated. The area around the acquired expansion property will be restored following construction.

Priam Second Transformer and St John’s Lake Breaker Station

MPUC Tracking Number: 2025-WC-N5

Utility: Missouri River Energy Services (MRES)

Project Description: Willmar Municipal Utilities (WMU) plans to add a second 115/69 kV transformer at the Priam substation near Willmar and expand the substation buses. They also plan to construct a new 69 kV breaker station near Willmar and rebuild the 69 kV line from the Willmar Municipal Utilities (WMU) tap to this new breaker station to a double circuit line.

Need Driver: Project needed to address multiple low voltage and thermal violations in the area.

Alternatives:

Transmission Alternatives

Option 1: Hawick Breaker Station. Estimated in-service date 2027.

Option 2: Second Priam transformer with a new 115 kV position, Pennock 69 kV Loop, Hawick Breaker Station, St. Johns Lake Breaker Station, rebuild 69 kV from St.
Johns Lake Breaker Station to Willmar Tap to double circuit. Estimated in- service date 2029.

Option 3: Second Priam transformer with a new 115 kV position, Pennock 69 kV loop to Power Plant, Hawick Breaker Station, Breaker Additions at Willmar Plant / Southwest, rebuild 69 kV from St. Johns Lake Area to Willmar Plant to double circuit, and rebuild 69 kV at Willmar Southwest to double circuit. Estimated in- service date 2029.

Option 4: Replace WMU 230/69 kV transformer and upgrade Willmar Southwest Tap to Willmar 69 kV line. Estimated in-service date 2028.

Option 5: Stockade to Willmar 115 kV.

Option 6: Separating Kerkhoven and Maynard sources into two sources that connect to Priam 115 kV.

Non-Wires Alternatives

This is a reliability improvement, so no alternatives were considered.

Analysis: This is a cost-effective system resiliency solution.

Schedule: The projects are set to go in-service in Q4 2029.

General Impacts: The projects will be constructed at an existing 115/69 kV substation and at an existing 69 kV line from Willmar Municipal Utilities (WMU) tap to a new breaker station. Some land outside of the City of Willmar (near St Johns Lake) will need to be acquired to construct the breaker station. During construction Willmar Municipal Utilities and/or their contractors will be working in the area and will contribute positively to the local economy. No significant traffic impacts are anticipated. The area around the acquired breaker station property and the right-of- way along the existing Willmar Municipal Utilities (WMU) tap to a new breaker station line will be restored following construction.

Erie Road Substation Rebuild

MPUC Tracking Number: 2025-WC-N6

Utility: Missouri River Energy Services (MRES)

Project Description:    Marshall Municipal Utilities (MMU) plans to rebuild the Erie Road substation in Marshall with new 115 kV breakers and other equipment..

Need Driver: Project needed to address age and condition issues, and add reliability.

Alternatives:

Transmission Alternatives

None

Non-Wires Alternatives

This is a age and condition / reliability improvement, so no alternatives were considered.

Analysis: This is a cost-effective system resiliency solution.

Schedule: The project is set to go in-service by Q1 2029.

General Impacts: The projects will be constructed at an existing substation. Some land outside of the existing substation may need to be acquired to rebuilt it. During construction MMU and/or their contractors will be working in the area and will contribute positively to the local economy. No significant impacts are anticipated. The area around the substation will be restored following construction.

Bellingham 115 kV Delivery

MPUC Tracking Number: 2025-WC-N7

Utility: Otter Tail Power Company (OTP)

Project Description: This project involves a new tap along the Big Stone – Marietta 115 kV transmission line to connect a new distribution substation serving the town of Bellingham, MN. A new 115 kV tap switch will be installed and connected directly to a new distribution substation. Additionally, several miles of new 12.5 kV line will be constructed to connect to the existing distribution network in Bellingham.

Need Driver: Currently, Bellingham is served by a long 12.5 kV line originating at the Odessa 115 kV substation, with backup service from another long 12.5 kV line originating at the Louisburg-Lac Qui Parle 115 kV substation. Distribution studies have identified deficiencies in the backup service capabilities of the local distribution network. A new 115 kV substation serving Bellingham, located in the middle of this local system, provides sufficient backup service capabilities for it.

Alternatives:

Transmission Alternatives

This project accommodates load growth and improves switching capability on the local distribution system. No alternatives were considered.

Non-Wires Alternatives

This project accommodates load growth and improves switching capability on the local distribution system. No non-wires alternatives were considered.

Analysis: Distribution studies performed in 2023 identified deficiencies in the backup capabilities of the distribution system in the Bellingham area.

Schedule: The project is planned to be in service by the end of 2030.

Minnesota Energy Connection

MPUC Tracking Number: 2025-WC-N8

Utility: Xcel Energy (XEL)

Project Description: Xcel Energy has applied for a certificate of need and a route permit to construct the Minnesota Energy Connection Project. The project consists of two major components: new substations along with upgrades to existing substations and new 345 kilovolt (kV) high voltage transmission lines (HVTLs).
Proposed substation work involves:

• A new substation to be located near Garvin in Lyon County referred to as the Garvin Substation.
• An intermediate substation to be located 20 miles north of the proposed Garvin Substation referred to as the Intermediate Substation.
• A voltage-support substation to be located 80 miles south of the Sherco Substation in either Meeker, Kandiyohi, or Renville County referred to as the Support Substation.
• Modifications to the existing Sherco Substation and Sherco Solar West Substation near Becker in Sherburne County.

Proposed HVTL work involves:

• A new 345 kV double-circuit HVTL between the Garvin Substation and the existing Sherco Solar West Substation. The applicant’s proposed routes are 171 and 174 miles in length and designated as the Purple Route and Blue Route, respectively.
• A new 3.1-mile single-circuit 345 kV transmission line between the existing Sherco Solar West Substation and the Sherco Substation referred to as the Green Segment. The Green Segment would be co-located with applicant’s existing Line 5651, occupying the open position on the existing double-circuit-capable structures.

Need Driver: This project will allow Xcel Energy to retire its Sherco Generation facility and repower the plant with renewable carbon free energy in the West Central and Southwest areas of the state. This line is critical for meeting the carbon goals of Xcel Energy and the State of Minnesota.

Alternatives:

Transmission Alternatives

Different alternatives were analyzed and detailed in the CON application.

Non-Wires Alternatives

This project is aimed to recapture injection rights at Sherco and for this reason a non-wires alternative does not apply.

Analysis: This line when built will provide significant carbon free energy to the system and allow the existing coal power plants at Sherco to retire all while keeping the injection rights.

Schedule: This project will be in service by October of 2028.

General Impacts: The project impacts are detailed extensively in the CON application. For more information on impacts and project details, see the docket number CN-22-132.

0754 Buffalo - Maple Lake Rebuild

MPUC Tracking Number: 2025-WC-N9

Utility: Xcel Energy (XEL)

Project Description: Rebuild 8.2 miles 69 kV from Buffalo - Maple Lake with new structures, new OPGW shield wire, and new conductor.

Need Driver: Age and condition rebuild.

Alternatives:

Transmission Alternatives

As this project is an existing asset in poor asset condition, a rebuild was the most prudent choice as opposed to another transmission option.

Non-Wires Alternatives

As this project is an existing asset in poor asset condition, a NWA was not chosen for this project.

Analysis: The replacement of this line will more than double the existing ratings in addition to replacing the existing structures which have many defected poles.

Schedule: This project will be in service by December of 2027.

General Impacts: This project will have minimal impacts as it is a replacement of an existing asset with no new right of way.

Gaylord Substation Rebuild

MPUC Tracking Number: 2025-WC-N10

Utility: Xcel Energy (XEL)

Project Description: Rebuild Gaylord substation at a new location, converting 4.16kV feeders to 13.8kV.

Need Driver: Age and condition rebuild of existing substation.

Alternatives:

Transmission Alternatives

As this project is an existing asset in poor asset condition, a rebuild was the most prudent choice as opposed to another transmission option.

Non-Wires Alternatives

As this project is an existing asset in poor asset condition, an NWA was not chosen for this project.

Analysis: Gaylord substation is an aging substation with a non-standard voltage of 4.16 kV. There is currently a normal overload on two of the feeders and no contingency available for the substation except with the use of a mobile.

Schedule: This project will be in service by December of 2027.

General Impacts: This project will have minimal impacts.

0891 West St Cloud – Crossroads Rebuild

MPUC Tracking Number: 2025-WC-N11

Utility: Xcel Energy (XEL)

Project Description: Rebuild 4.1 miles 115 kV from West St. Cloud - Crossroads with new structures and new OPGW shield wire.

Need Driver: New poles needed to support fiber upgrades.

Alternatives:

Transmission Alternatives

As this project is to accommodate a fiber project and thus no alternatives were considered.

Non-Wires Alternatives

As this project is to accommodate a fiber project and thus no NWA were considered.

Analysis: The fiber upgrades help assist the company with relaying and protection of assets in the area.

Schedule: This project will be in service by November of 2026.

General Impacts: This project will have minimal impacts as it is a replacement of an existing asset with no new right of way.

Horseshoe Lake Substation

MPUC Tracking Number: 2025-WC-N12

Utility: Xcel Energy (XEL)

Project Description: Build new Horseshoe Lake Substation to transfer load from Richmond Substation

Need Driver: The 69 kV line that Richmond substation is on has high throughflow issues due to the parallel configuration with the 115 kV line. The line serves multiple Xcel and GRE substations along with high exposure there is high risk of outage and impact. Building a new substation and connecting to new line removes some exposure.

Alternatives:

Transmission Alternatives

This project will assist in the throughflow issues seen in the area and was the most prudent choice to solve this problem.

Non-Wires Alternatives

This project helps serve existing load and cannot be achieved without a wires project.

Analysis: This project helps reduce exposure seen by multiple company’s loads as well as cut down on the throughflow in the area.

Schedule: This project will be in service by January of 2027.

General Impacts: This project is not expected to have major impacts at this time.

Rebuild 5400 Richmond to Rich Springs Tap

MPUC Tracking Number: 2025-WC-N13

Utility: Xcel Energy (XEL)

Project Description: Rebuild 2.6 miles of 69kV Line 5400 from Richmond to Rich Springs Tap.

Need Driver: Age and condition rebuild.

Alternatives:

Transmission Alternatives

As this project is an existing asset in poor asset condition, a rebuild was the most prudent choice as opposed to another transmission option.

Non-Wires Alternatives

As this project is an existing asset in poor asset condition, a NWA was not chosen for this project.

Analysis: Replace end of life poles and install shield wire to improve performance and reliability of the line

Schedule: This project will be in service by December of 2028.

General Impacts: This project will have minimal impacts as it is a replacement of an existing asset with no new right of way.

Install Avon Area Substation

MPUC Tracking Number: 2025-WC-N14

Utility: Xcel Energy (XEL)

Project Description: Install new distribution substation to meet load growth in area

Need Driver: Load growth in area is exceeding capability of existing substations

Alternatives:

Transmission Alternatives

This project is needed to serve growing load in the area and is the best project to meet the need.

Non-Wires Alternatives

A NWA may be applicable here, however the cost greatly outweighs the cost of a new substation. For this reason it was not considered.

Analysis: This area’s load is growing and a new substation will help meet the future needs of the area.

Schedule: This project will be in service by December of 2027.

General Impacts: This project is not expected to have major impacts at this time.

Line 0868 Le Sauk – Fischer Hills – St Stephens Rebuild

MPUC Tracking Number: 2025-WC-N15

Utility: Xcel Energy (XEL)

Project Description: Rebuild 0868 from Le Sauk to Fisher Hills to St. Stephens.

Need Driver: Line is frequently binding and is at end of life.

Alternatives:

Transmission Alternatives

As this project is an existing asset in poor asset condition, a rebuild was the most prudent choice as opposed to another transmission option.

Non-Wires Alternatives

As this project is an existing asset in poor asset condition, a NWA was not chosen for this project.

Analysis: This line often binds and has congestion in addition to be at its end of its useful life. This project will help reduce costs by reducing congestion.

Schedule: This project will be in service by December of 2028.

General Impacts: This project will have minimal impacts as it is a replacement of an existing asset with no new right of way.

Knight Substation

MPUC Tracking Number: 2025-WC-N16

Utility: Xcel Energy (XEL)

Project Description: Install new 115/34.5kV substation in the Dayton area to meet area load growth.

Need Driver: Required for load growth in the area.

Alternatives:

Transmission Alternatives

This project is needed to serve growing load in the area and is the best project to meet the need.

Non-Wires Alternatives

A NWA may be applicable here, however the cost greatly outweighs the cost of a new substation. For this reason it was not considered.

Analysis: This area’s load is growing and a new substation will help meet the future needs of the area.

Schedule: This project will be in service by September of 2026.

General Impacts: This project is not expected to have major impacts at this time.

McLeod 230/115 kV Relay Upgrades

MPUC Tracking Number: 2025-WC-N17

Utility: Missouri River Energy Services (MRES)

Project Description: Hutchinson Utilities Commission (HUC) plans to upgrade substation relaying on thei McLeod 230/115 kV substation. The existing 230 kV bus and 230/115 kV transformer have single differential relay schemes. With this relay upgrade, HUC is implementing redundant differential relaying to improve protection.

Need Driver: Redundant relay improvement to avoid single point of failure events.

Alternatives:

Transmission Alternatives

None

Non-Wires Alternatives

This is a protection improvement, so no alternatives were considered.

Analysis: This is a cost-effective system reliability solution.

Schedule: The project is set to go in-service by Q1 2027.

General Impacts: The projects will be constructed at an existing substation. No additional land outside of the existing substation will need to be acquired. During construction HUC and/or their contractors will be working in the area and will contribute positively to the local economy. No significant impacts are anticipated. The area around the substation shouldn’t be disturbed materially.

Reconstruction of Transmission - Erie Rd Sub to Xcel Lyon County Sub

MPUC Tracking Number: 2025-WC-N18

Utility: Missouri River Energy Services (MRES)

Need Driver: Project needed to address age and condition issues and add reliability.

Alternatives:

Transmission Alternatives

None

Non-Wires Alternatives

This is an age and condition / reliability improvement, so no alternatives were considered.

Analysis: This is a cost-effective system resiliency solution.

Schedule: The project is set to go in-service by Q4 2030.

General Impacts: The projects will be constructed on existing right-of-way. Some land around the existing transmission lines may need temporary easements to complete the work. During construction MMU and/or their contractors will be working in the area and will contribute positively to the local economy. No significant impacts are anticipated. The area around the transmission lines will be restored following construction.

6.5.2  Completed Projects

The table below identifies those projects by Tracking Number in the West Central Zone that were listed as ongoing projects in the 2023 Biennial Report but have been completed or withdrawn since the 2023 Report was filed with the Minnesota Public Utilities Commission in November 2023. Information about each of the completed projects is summarized briefly in the table below. More information about these projects and inadequacies can be found in earlier reports. Projects that were listed as being complete in the 2023 Report are not repeated here, but more information about those projects can be found in these earlier reports.