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

6.8  Southeast Zone

6.8.1  Needed Projects

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

Adams to Stewartville 69 kV Rebuild

MPUC Tracking Number: 2019-SE-N2

Utility: ITC Midwest (ITCM)

Project Description: The approximately 35 miles-long Adams to Stewartville 69 kV line will be reconstructed on the existing right of way.

Need Driver: The Adams to Stewartville 69 kV line was built over 50 years ago, and increased maintenance costs will require the line to be reconstructed due to its age and condition.

Alternatives:

Transmission Alternatives

A rebuild on existing ROW was the sole alternative considered to solve the age and condition issue.

Non-Wires Alternatives

Non-wire alternatives are not viable because they cannot address concerns related to age and condition on the Adams to Stewartville 69 kV circuit.

Analysis: The plan to replace the over 50-years-old transmission line with new poles, conductor and shield wire will solve the reliability concern caused be the age and condition of the 69 kV line.

Schedule: Initial rebuild of the line is expected to be completed in 2028.

General Impacts: The line is near the end of its useful life. No new landowners will be impacted by construction, although some additional temporary workspace may be required. Unique environmental features will be addressed to minimize environmental impacts that could occur during construction. ITCM will work with the appropriate permitting agencies to receive necessary approvals. ITCM contractors and personnel will contribute positively to the local economy. No significant traffic impacts are anticipated. The right-of-way will be restored following construction. The rebuild of the line will increase the reliability of electric service in the area.

Line 0749 Rebuild

MPUC Tracking Number: 2023-SE-N2

Utility: Xcel Energy (XEL)

Project Description: Rebuild 6.7 miles of 69 kV line 0749 from Waseca - ITC Tap and add OPGW.
Need Driver: Needed for age and condition rebuild.

Alternatives:

Transmission Alternatives

Line may be used as is, but this runs the risk of reliability and overloading issues. No alternatives were considered.

Non-Wires Alternatives

This is replacing an existing asset.

Analysis: Age and condition rebuild. No immediate overloads or voltage concerns.

Schedule: The project went in service June 30, 2025.

General Impacts: No environmental issues have been identified. Line rebuild will have minimal impacts to existing system performance and footprint.

Line 0714 Medelia - Watonwan Rebuild

MPUC Tracking Number: 2023-SE-N3

Utility: Xcel Energy (XEL)

Project Description: Rebuild 22 miles of line 0714 69 kV from Medelia - Watonwan.

Need Driver: Needed for age and condition rebuild.

Alternatives:

Transmission Alternatives

Line may be used as is, but this runs the risk of reliability and overloading issues. No alternatives were considered.

Non-Wires Alternatives

This is replacing an existing asset.

Analysis: Age and condition rebuild. No immediate overloads or voltage concerns.

Schedule: The project is planned to be in service by December 31, 2025.

General Impacts: No environmental issues have been identified. Line rebuild will have minimal impacts to existing system performance and footprint.

Line 0708 STR 78 to 476 Rebuild

MPUC Tracking Number: 2023-SE-N4

Utility: Xcel Energy (XEL)

Project Description: Rebuild 16 miles of line 0708 69 kV from Eagle Lake - Waterville and add OPGW.

Need Driver: Needed to address galloping issues on this line.

Alternatives:

Transmission Alternatives

Line may be used as is, but this runs the risk of reliability issues. No alternatives were considered.

Non-Wires Alternatives

This is replacing an existing asset.

Analysis: Rebuilding to address galloping concerns. No immediate overloads or voltage concerns.

Schedule: The project is planned to be in service by December 31, 2027.

General Impacts: No environmental issues have been identified. Line rebuild will have minimal impacts to existing system performance and footprint.

Gaiter Lake Substation

MPUC Tracking Number: 2023-SE-N5

Utility: Xcel Energy (XEL)

Project Description: Build new Gaiter Lake substation in Waseca to pick up load off of Clarks Grove, Meridan, and Waseca substations. Retire Clarks Grove and Meridan substations.

Need Driver: Needed due to age and condition of Clarks Grove and Merdian substations, as well as capacity needs.

Alternatives:

Transmission Alternatives

Rebuild of existing substations would not increase load serving capability, leaving load at risk and would involve full rebuild of two substations opposed to construction of one new substation.

Non-Wires Alternatives

None.

Analysis: Transferring load from existing substations to new substation in same area. No immediate overloads or voltage concerns.

Schedule: The project went in service June 30, 2025.

General Impacts: The project will install a new substation along existing 69 kV line and retirement of two existing substations. During construction the company or contractors will be working in the area and will contribute positively to the local economy. No significant traffic impacts are anticipated.

Rock Dell to Pleasant Valley 69 kV Rebuild

MPUC Tracking Number: 2023-SE-N6

Utility: Dairyland Power Cooperative (DPC)

Project Description: Rebuild 2.2 miles of DPC’s Maple Leaf to Airport 69 kV line between the Rock Dell and Pleasant Valley distribution substations on existing and new right-of-way.
Need Driver: DPC purchased this line from People’s Energy Cooperative in July of 2022. This line was identified for rebuild due to age and condition.

Alternatives:

Transmission Alternatives

A rebuild solely on existing right-of-way was considered. However, a portion of the existing right-of way runs through a lower lying area that is also in the Rock Dell Wildlife Management Area. For this reason, a mix of existing and new right-of way is also being considered.

Non-Wires Alternatives

None.

Analysis: The 2.2-mile section 69 kV transmission line rebuild will address the reliability concerns due to age and condition. The potentially relocated section of this rebuild will also improve accessibility for maintenance.

Schedule: Construction of the line is expected to be completed by early-2028.

General Impacts: The line is near the end of its useful life. Dairyland construction crews will rebuild this line in early-2028, requiring approximately three weeks to construct. The portion of the rebuild on existing right-of-way will have minimal impacts, while the portion being considered for new right-of-way will improve accessibility.

Genoa to Ringe 69 kV Rebuild

MPUC Tracking Number: 2023-SE-N7

Utility: Dairyland Power Cooperative (DPC)

Project Description: Rebuild 8.9 miles of DPC’s Maple Leaf to Rochester 69 kV line between the Genoa and Ringe distribution substations on existing and new right-of-way.

Need Driver: DPC purchased this line from People’s Energy Cooperative in July of 2022. This line was identified for rebuild due to age and condition.

Alternatives:

Transmission Alternatives

A rebuild solely on existing right-of-way was considered. Relocating portions of the line has added reliability benefits.

Non-Wires Alternatives

None.

Analysis: The 8.9-mile section 69 kV transmission line rebuild will address the reliability concerns due to age and condition. The relocated section of this rebuild will also improve line exposure and reliability.

Schedule: Construction of the line is expected to be completed by late 2028.

General Impacts: The line is near the end of its useful life. Dairyland construction crews will rebuild this line in 2028, requiring approximately eleven weeks to construct.

J898 Interconnection at Beaver Creek 161 kV

MPUC Tracking Number: 2023-SE-N8

Utility: Dairyland Power Cooperative (DPC)

Project Description: Replace the 161 kV Beaver Creek Tap three-way switches with a 4-breaker substation approximately 6 miles south of the Beaver Creek Tap to allow for the interconnection of 100 MW of wind-powered generation with the potential for additional capacity in the future. A 6-mile portion of 161 kV transmission line on new right-of-way will be constructed to connect the new transmission substation back to the existing Harmony to Beaver Creek 161 kV transmission line. A 4-mile stretch of existing 161 kV transmission line between Harmony and the Beaver Creek Tap will be retired.

Need Driver: The new 3-breaker substation and 6-mile portion of 161 kV transmission line are required as part of the MISO Tariff for the interconnection of 100 MW of wind-powered generation for project J898.

Alternatives:

Transmission Alternatives

The interconnection for J898 was evaluated under MISO’s DPP August 2017 West system impact study. An alternative of upgrading the 69 kV transmission to the south of SMMPA’s Rice substation was considered.

Non-Wires Alternatives

None.

Analysis: The interconnection of project J898 was evaluated under MISO’s DPP August 2017 West and 2020 West system impact study. Potential overloads of the underlying 69 kV system under contingent conditions were identified. The proposed project was determined to be the most reliable and cheapest mitigation for these overloads.

Schedule: The in-service date for the substation portion of the project is late-2026, while the new 161 kV transmission line portion of the project is late-2027.

General Impacts: The 161 kV transmission line portion of this project will be built on new right- of-way, with approximately 4 miles of existing transmission line to be retired. The resulting configuration will replace the existing 3-terminal 161 kV transmission line between Harmony, Adams and Rice with three 2-terminal transmission lines, providing additional reliability benefits. The Commission considered the potential route permit impacts in Docket No. ET3/TL-24-95.

Kellogg 161 kV Transmission Substation

MPUC Tracking Number: 2023-SE-N9

Utility: Dairyland Power Cooperative (DPC)

Project Description: Construct a new 5-breaker 161/69 kV transmission substation, named Kellogg on DPC’s Wabaco to Alma 161 kV transmission line. Construct 9 miles of 161 kV transmission line on new right-of-way, connecting between Wabaco and Kellogg from existing transmission into the Kellogg substation. Install a 112 MVA 161/69 kV transformer at Kellogg and reterminate DPC’s Utica to Alma 69 kV transmission line into the Kellogg substation. Retire the remaining 2.5-mile Mississippi River crossing portion of the 69 kV transmission line between Alma and the Weaver distribution substation.

Need Driver: These projects are required by MISO’s Long Range Transmission Plan (LRTP) and are included in the identified Tranche 1 projects to address needs associated with the changing resource mix across the MISO Midwest subregion. The new DPC facilities are required to replace the 69 kV Mississippi River crossing between Alma and the Weaver distribution substation with the North Rochester to Tremval 345 kV transmission line.

Alternatives:

Transmission Alternatives

The MISO LRTP planning efforts considered several alternatives to the recommended Tranche 1 projects.

Non-Wires Alternatives

None.

Analysis: The Kellogg substation, new 161 kV transmission line and 69 kV retermination frees up the Mississippi River crossing for the new North Rochester to Tremval 345 kV transmission line, without sacrificing local reliability.

Schedule: The in-service date for the project is late-2027 to early-2028.

General Impacts: The new Kellogg substation and 69 kV retermination will have minimal need for new right-of-way, but will allow for new 345 kV Mississippi River crossing on existing right- of-way. The 9 miles of new 161 kV transmission will be constructed on new right-of-way. The LRTP Tranche 1 projects are renewable-enabling, allowing for reliable, green energy in the future.

Loon Lake Substation Modernization

MPUC Tracking Number: 2023-SE-N10

Utility: Southern Minnesota Municipal Power Agency

Project Description: Current breakers were installed in 1985, and they have become unreliable and difficult to maintain with their age. Along with these breakers, the associated switches and relays will also be replaced with newer and more reliable equipment. The new equipment includes new PTs, arresters, and new solid-state relay panels.

Need Driver: Old breakers have become difficult to maintain with reoccurring problems and parts shortages, effectively driving maintenance costs up. Other equipment upgrades are being made to switch from electromechanical to the more reliable solid-state equipment.

Alternatives:

Transmission Alternatives:

None.

Non-Wires Alternatives:

None.

Analysis: N/A

Schedule: New equipment expected to be in service by June 01, 2026.

General Impacts: This project is located on SMMPA owned property. No significant traffic impacts are anticipated. Relevant permits and approvals will be received prior to construction. Contractors and personnel will contribute positively to the local economy.

Pleasant Valley Area Projects

MPUC Tracking Number: 2023-SE-N11

Utility: Great River Energy (GRE)

Project Description: This project involves expansion of the 161 kV bus at the Pleasant Valley substation to accommodate the Phase 1 Wind (170 MW) and Phase 2 Wind (150 MW) Wind Farms interconnection. It also includes expansion of the control house to accommodate additional equipment.

Need Driver: This project is needed to support renewable energy development interconnecting to GRE’s Pleasant Valley substation. GRE will upgrade the Pleasant Valley substation by adding 161 kV transmission bays to connect to the Dodge County and Timber Wind farms, while also expanding the Pleasant Substation westward with an additional breaker row. This configuration will enable smooth integration of wind generation through the 161 kV line and improve fault isolation, enhancing system reliability.

Alternatives:

Transmission Alternatives

This project is driven by wind interconnection, and no transmission alternatives were considered. An alternative design to install dead end and breakers in the existing opening between existing breakers 19QB6 and 19QB7 was however considered in the design phase.. This would eliminate the need to expand the current yard. This alternative design was not further considered as it would require extensive bus outages and limitations on generation at Pleasant Valley to allow for safe installation and maintenance of equipment.

Non-Wires Alternatives

Non-wires alternatives were not considered as it is a wind generation interconnections project driven by an interconnection customer.

Schedule: The Pleasant Valley Area Projects are planned to be in service by the end of 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.

Pleasant Valley Terminal Upgrade

MPUC Tracking Number: 2023-SE-N12

Utility: Great River Energy (GRE)

Project Description: Upgrade terminal equipment to 3000 A ratings.

Need Driver: The 161 kV transmission line between Pleasant Valley and Byron experienced 1169 hours of market congestion between July 2020 and July 2022, according to a study by Grid North Partners. The average shadow price during those hours was $92. The congestion is primarily caused by terminal equipment rated at 2000 A, which restricts the full utilization of the conductor’s capacity. Without upgrades, this limitation is expected to continue contributing to market congestion in the future.

Alternatives:

Transmission Alternatives

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

Non-Wires Alternatives

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

Analysis: Upgrading the circuit breakers at the Pleasant Valley substation from a 2000 A rating to a 3000 A rating would enable full utilization of the Pleasant Valley to Byron 161 kV transmission line’s conductor capacity. This change would eliminate terminal equipment as the limiting factor, allowing the line to operate at its designed capacity and significantly reducing the potential for market congestion.

Addressing the terminal rating constraint through this targeted equipment upgrade is identified as the most cost-effective solution to mitigate congestion, while also improving overall system reliability.

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

Marion Road to Mississippi River 765 kV Transmission Line Segment

MPUC Tracking Number: 2025-SE-N1

Utility: Dairyland Power Cooperative (DPC)

Project Description: Construct a new 110-mile, 765/161 kV double circuit transmission line from southeast Rochester, MN to the Mississippi River south of Brownsville, MN and across the river from Genoa, WI. This project represents a segment of the MISO Long Range Transmission Plan (LRTP) Project 26, which constructs a 273-mile 765 kV transmission line between North Rochester and Columbia County, WI.

Need Driver: These projects are required by MISO’s Long Range Transmission Plan (LRTP) and are included in the identified Tranche 2.1 projects to address needs associated with the changing resource mix across the MISO Midwest subregion.

Alternatives:

Transmission Alternatives

The MISO LRTP planning efforts considered several alternatives to the recommended Tranche 2.1 projects. Additional details regarding MISO’s alternatives analysis for Tranche 2.1 can be found in the LRTP section of the MTEP24 Report.

Non-Wires Alternatives:

None.

Analysis: Full details of MISO’s LRTP Tranche 2.1 analysis are available in the LRTP section of the MTEP24 report.

Schedule: The MISO LRTP Tranche 2.1 projects are targeting in-service dates from 2032 to 2034.

General Impacts: The Marion Road to Mississippi River segment of the MISO LRTP-26 project team is evaluating routing alternatives including utilizing existing 161 kV transmission right-of- way in the area.

Owatonna – 161/69 kV Transmission Expansion

MPUC Tracking Number: 2025-SE-N2

Utility: Southern Minnesota Municipal Power Agency

Project Description: Building of a new 69/12.5 kV distribution substation “NE Owatonna Substation” (NEOS), construction of a new 161/69 kV substation, North Owatonna Substation (NOS) tapping the West Owatonna Substation-South Faribault Substation 161 kV transmission line, and construction of two 69 kV transmission lines, one from NOS to the NEOS and one from NEOS to East Owatonna Substation.

Need Driver: This project was motivated by Owatonna Public Utilities (OPU) to address their need for a new distribution substation.

Alternatives:

Transmission Alternatives

None.

Non-Wires Alternatives

None.

Analysis: A study was conducted to verify the effectiveness of these additions, and it was able to mitigate voltage violations that were occurring on the Owatonna Subsystem.

Schedule: Expected in-service date is June 01, 2030.

General Impacts: This project is located on SMMPA owned property. No significant traffic impacts are anticipated. Relevant permits and approvals will be received prior to construction. Contractors and personnel will contribute positively to the local economy.

West Owatonna Substation – Cap Bank Addition

MPUC Tracking Number: 2025-SE-N3

Utility: Southern Minnesota Municipal Power Agency

Project Description: Addition of a 50 MVAR Cap Bank on the 161 kV bus at West Owatonna Substation.
Need Driver: Under certain N-1 and N-1-1 contingencies, low voltage violations will occur on the Owatonna Subsystem.

Alternatives:

Transmission Alternatives

A third 161 kV source to the West Owatonna Substation was considered and studied.

Non-Wires Alternatives

None.

Analysis: A study was conducted to verify the effectiveness of this addition, and it was able to mitigate voltage violations that were occurring on the Owatonna Subsystem.

Schedule: Expected in-service date is January 1, 2027.

General Impacts: This project is located on SMMPA owned property. No significant traffic impacts are anticipated. Relevant permits and approvals will be received prior to construction. Contractors and personnel will contribute positively to the local economy.

Byron Substation - Pleasant Valley Terminal Upgrade

MPUC Tracking Number: 2025-SE-N4

Utility: Southern Minnesota Municipal Power Agency

Project Description: Upgrade terminal equipment to 3000 A rating.

Need Driver: Upgrade of terminal equipment of Byron - Pleasant Valley 161kV line to match joint facility owners.

Alternatives:

Transmission Alternatives

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

Non-Wires Alternatives

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

Analysis: This upgrade will prevent terminal equipment from being the binding rating and allow for the line conductor capacity rating to be fully utilized, reducing the likelihood of the line causing congestion in the market.

Schedule: The project is planned to be in service by December 01, 2027.

General Impacts: This project is located on SMMPA owned property. No significant traffic impacts are anticipated. Relevant permits and approvals will be received prior to construction. Contractors and personnel will contribute positively to the local economy.

J1124 Interconnection at Byron 345 kV Substation

MPUC Tracking Number: 2025-SE-N5

Utility: Southern Minnesota Municipal Power Agency

Project Description: Addition of 345kV terminal at Byron substation to support a 100MW solar interconnection.

Need Driver: MISO project J1124 was studied under the MISO business practices, and the expansion of the Byron 345 kV bus to connect project J1124 is required to provide interconnection service to the project under the MISO tariff.

Alternatives:

Transmission Alternatives

None.

Non-Wires Alternatives

None.

Analysis: The interconnection of project J1124 was evaluated as part of the MISO DPP-2018 study. The expansion of facilities at Byron is required to provide a point of interconnection for project J1124.

Schedule: Expected in-service date of November 1, 2027

General Impacts: This project is located on SMMPA owned property. No significant traffic impacts are anticipated. Relevant permits and approvals will be received prior to construction. Contractors and personnel will contribute positively to the local economy.

Byron – Cascade Creek Line Relocation

MPUC Tracking Number: 2025-SE-N6

Utility: Southern Minnesota Municipal Power Agency

Project Description: Relocation of 1.2miles of 161kV transmission lines from Byron Substation to Cascade Creek Substation.
Need Driver: MNDoT requires the line to be moved due to the construction of an interchange at the intersection of Hwy 14 and 44.

Alternatives:

Transmission Alternatives

None.

Non-Wires Alternatives

None.

Analysis: N/A

Schedule: Planned in-service by December 31, 2026.

General Impacts: This project is located on SMMPA owned property. No significant traffic impacts are anticipated. Relevant permits and approvals will be received prior to construction. Contractors and personnel will contribute positively to the local economy.

Byron Substation Modernization

MPUC Tracking Number: 2025-SE-N7

Utility: Southern Minnesota Municipal Power Agency

Project Description: Substation contains two breakers that were installed in 1988 and 1995, and they have become unreliable and difficult to maintain with their age. Along with these breakers, the associated switches and relays will also be replaced with newer and more reliable equipment. The new equipment includes new CTs, PTs, arresters, and new solid-state relay panels.

Need Driver: Old breakers have become difficult to maintain with reoccurring problems and parts shortages, effectively driving maintenance costs up. Other equipment upgrades are being made to switch from electromechanical to the more reliable solid-state equipment.

Alternatives:

Transmission Alternatives

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

Non-Wires Alternatives

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

Analysis: N/A

Schedule: TBD

General Impacts: This project is located on SMMPA owned property. No significant traffic impacts are anticipated. Relevant permits and approvals will be received prior to construction. Contractors and personnel will contribute positively to the local economy.

Spring Creek Area Upgrade Projects

MPUC Tracking Number: 2025-SE-N8

Utility: Great River Energy (GRE)

Project Description: Replace the two 161/69 kV 70 MVA transformers with 140 MVA units and complete the 161 kV topology to a ring bus.

Need Driver: This project is needed to address post contingent overloads that have been seen at the Spring Creek 161/69 kV transformers. The GRE Spring Creek substation has 161/69kV, 70 MVA transformers. Each of these transformers overload for loss of the other transformer. This project aims to address the overload by replacing each unit with a 140 MVA transformer. As part of this project, the ring bus design at the Spring Creek substation will be updated to align with current design standards.

Alternatives:

Transmission Alternatives

This transmission project was identified as the most cost-effective and reliable solution for addressing transformer overloads and completing the substation topology at Spring Creek. As a result, no other transmission options were formally evaluated.

However, one alternative was considered during early planning: converting the existing 161/69 kV transformers to a 115/69 kV configuration. This option was ultimately dismissed due to several key factors:

1. Capacity limitations with the 115 kV line would reduce system resilience during contingencies.
2. Higher infrastructure complexity, including the need for dual high-side transformers and a new distribution transformer at Ravenna.
3. Limited strategic benefit, as other substations in the region would continue operating on 161/69 kV, undermining standardization efforts.
4. Reduced need for spares, since installing two 140 MVA units at Spring Creek would sufficiently cover future reliability needs.

In summary, the selected upgrade path—retaining the 161/69 kV configuration and enhancing capacity with 140 MVA units—was deemed the most practical and cost- efficient approach for long-term system performance.

Non-Wires Alternatives
Non-wires alternatives were deemed infeasible for addressing the transformer overload issue and the required upgrade of the ring bus to meet current design standards.

Analysis: Contingency analysis has confirmed overloads at the Spring Creek 161/69 kV transformers during events such as the loss of one transformer or a simultaneous outage involving the 161 kV transmission line and a transformer. These reliability risks are consistently reflected in the planning models, reinforcing the urgency of corrective action. As part of the broader mitigation strategy, the project seeks to complete the existing non-standard configuration by converting it to a ring-bus. Currently, the absence of a high-side breaker on the 161 kV line results in transformer outages whenever there a fault on the 161 kV line. Upgrading to a ring-bus design will improve operational flexibility and resilience during contingency events.

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

Medford Area Projects

MPUC Tracking Number: 2025-SE-N9

Utility: Great River Energy (GRE)

Project Description: Construct a 161 kV tap line from SMMPA’s West Owatonna–South Faribault 161 kV transmission line to the high side of the Medford distribution substation, which will be constructed and owned by Steele-Waseca Electric Cooperative (SWEC).

Need Driver: This project is needed to interconnect SWEC’s Medford distribution substation. SWEC plans to construct the Medford distribution substation to address critical challenges— including voltage drop issues, feeder overloads, limited feeder redundancy, and aging equipment. This project is designed to strengthen system reliability, enhance operational flexibility, and improve overall power quality.

Alternatives:

Transmission Alternatives:

Interconnection to the 69 kV transmission system was considered; however, the 161 kV transmission system located much closer to the Medford distribution substation was determined to offer superior reliability and capacity to support long-term reliable service to the substation

Non-Wires Alternatives:

This project is to interconnect SWEC’S Medford distribution substation to the transmission system. Non-wires alternatives were not considered viable option.

Analysis: Power flow analysis was performed and showed no adverse impact on the existing transmission system.
Distribution analysis showed the need for the new delivery point due to challenges including voltage drop issues, feeder overloads, limited feeder redundancy, and aging equipment.

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

General Impacts: The project will be constructed on a site on the existing 161 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.

0774 Goodview – Str 444 Rebuild

MPUC Tracking Number: 2025-SE-N10

Utility: Xcel Energy (XEL)

Project Description: Rebuild 3 miles 69 kV with new structures, new OPGW shield wire, and new conductor.

Need Driver: Age & Condition rebuild, wood polls reaching end of life.

Alternatives:

Transmission Alternatives

The project is replacing existing assets and was chosen as the best option to meet the need.

Non-Wires Alternatives

The project is replacing existing assets and was chosen as the best option to meet the need.

Analysis: The plan to replace the transmission line with new poles, conductor and shield wire will solve the reliability concern caused by the age and condition of the 69 kV line.

Schedule: Construction of the line is expected to be completed by December of 2025.

General Impacts: This project is expected to have minimal impacts as its replacing existing infrastructure.

Rebuild Wabasha Substation

MPUC Tracking Number: 2025-SE-N11

Utility: Xcel Energy (XEL)

Project Description: Rebuild Wabasha substation at a nearby location due to flooding concerns.

Need Driver: Wabasha substation is susceptible to flooding during early spring season.

Alternatives:

Transmission Alternatives

The project will rebuild the existing substation that is in a location that floods and thus was chosen as the best option to meet the need.

Non-Wires Alternatives

The project will rebuild the existing substation that is in a location that floods and thus was chosen as the best option to meet the need.

Analysis: The project will rebuild the existing substation that is in a location where flooding occurs seasonally. This project will move the substation to a dry location.

Schedule: The project is planned to be in service by December of 2028.

General Impacts: The project is expected to have minimal impacts because it moves the substation out of an area of flooding to a dryer location.

Cleveland – Sheas Lake Rebuild

MPUC Tracking Number: 2025-SE-N12

Utility: ITC Midwest (ITCM)

Project Description: GRE will be rebuilding their portion of the existing Cleveland – Sheas Lake 69 kV line to address loading and congestion. GRE requested ITC Midwest also rebuild the ITC Midwest portion of the line, approximately 10 miles, to allow a significant increase in the thermal rating of the line instead of the very marginal increase that would only be achieved with a GRE only rebuild. Approximately 10 miles of the ITC Midwest portion Cleveland – Sheas Lake 69 kV line will be reconstructed on the existing right of way. The line will be re-constructed with a larger conductor size and will also be insulated to allow a potential conversion to a higher operating voltage in the future.

Need Driver: In addition to the needed increased thermal rating on the ITC Midwest portion of the Cleveland – Sheas Lake line, the ITC Midwest portion of the line was built over 50 years ago.

Alternatives:

Transmission Alternatives

A rebuild on existing ROW was the sole alternative considered to increase the thermal rating of the line and also address the age and condition issue.

Non-Wires Alternatives

Non-wire alternatives are not viable because they cannot address concerns related to age and condition on the circuit.

Analysis: The plan to replace the over 50-years-old transmission line with new poles, conductor and shield wire will solve the reliability concern caused be the age and condition of the 69 kV line. By using a new larger standard conductor as part of the rebuild, the contingent loading concerns are addressed. By re-constructing the line to higher operating voltage standards, the area will be better situated for a future conversion to a higher operating voltage.

Schedule: Initial rebuild of the line is expected to be completed in 2029.

General Impacts: The line is near the end of its useful life. No new landowners will be impacted by construction, although some additional temporary workspace may be required. Unique environmental features will be addressed to minimize environmental impacts that could occur during construction. ITCM will work with the appropriate permitting agencies to receive necessary approvals. ITCM contractors and personnel will contribute positively to the local economy. No significant traffic impacts are anticipated. The right-of-way will be restored following construction. The rebuild of the line will increase the reliability of electric service in the area.

Hayward – County Line – Ellendale 69 kV Rebuild

MPUC Tracking Number: 2025-SE-N13

Utility: ITC Midwest (ITCM)

Project Description: The approximately 19 miles-long Hayward – County Line - Ellendale 69 kV line will be reconstructed on the existing right of way.

Need Driver: The Hayward – County Line - Ellendale 69 kV line was built over 50 years ago, and in addition, there has been increased contingent loading on this line and due to the increased time of the year when an operating guide is required to address contingent loading, a line rebuild was determined to be required to increase the thermal rating of the line.

Alternatives:

Transmission Alternatives

A rebuild on existing ROW was the sole alternative considered to solve the age and condition issue. In addition, use of the existing right of way to rebuild the line and increase the thermal rating while limiting impacts to land owners.

Non-Wires Alternatives

Non-wire alternatives are not viable because they cannot address concerns related to age and condition on the Hayward – County Line - Ellendale 69 kV circuit.

Analysis: The plan to replace the over 50-years-old transmission line with new poles, conductor and shield wire will solve the reliability concern caused be the age and condition of the 69 kV line. By using a new larger standard conductor as part of the rebuild, the contingent loading concerns are addressed.

Schedule: Initial rebuild of the line is expected to be completed in 2028.

General Impacts: The line is near the end of its useful life. No new landowners will be impacted by construction, although some additional temporary workspace may be required. Unique environmental features will be addressed to minimize environmental impacts that could occur during construction. ITCM will work with the appropriate permitting agencies to receive necessary approvals. ITCM contractors and personnel will contribute positively to the local economy. No significant traffic impacts are anticipated. The right-of-way will be restored following construction. The rebuild of the line will increase the reliability of electric service in the area.

Gopher to Badger Link

LRTP Project #26

MPUC Tracking Number: 2025-SE-N14

Utility: Xcel Energy (XEL) and Dairyland Power Cooperative (DPC)

Project Description: The Project consists of a (1) single-circuit 765 kV high voltage transmission line between the existing North Rochester Substation and a point near Marion, Minnesota; (2) a 765 kV/161 kV double-circuit high voltage transmission line from near Marion, Minnesota, to the Wisconsin border; and (3) a new three-circuit breaker 161 kV switching station in Houston County, Minnesota; a specific location has not yet been identified. The 161 kV switching station will connect to two existing 161 kV transmission lines from Harmony, Minnesota, and Lansing, Iowa, and an existing single-circuit 161 kV line between the new switching station and the existing Genoa Substation in Wisconsin.

Need Driver: The Project was studied, reviewed, and approved as part of the MISO LRTP Tranche
2.1 Portfolio. The Project is needed to maintain regional and local system reliability amid fundamental changes in demand for electricity and the type and amount of generation interconnected to the grid within the MISO footprint.

Alternatives:

Transmission Alternatives

Transmission system alternatives will be addressed in the Certificate of Need Application. Details of MISO’s LRTP Tranche 2.1 analysis are available in the LRTP section of the MTEP24 report.

Non-Wires Alternatives

Non-Wire Alternatives will be addressed in the Certificate of Need Application. Details of MISO’s LRTP Tranche 2.1 analysis are available in the LRTP section of the MTEP24 report.

Analysis: The need for Gopher to Badger Link and the benefits of the Project will be summarized in the Certificate of Need Application. Details of MISO’s LRTP Tranche 2.1 analysis are available in the LRTP section of the MTEP24 report.

Schedule: The Project planned to be in-service in 2034.

General Impacts: Project routing discussions will occur in late 2025 and 2026. XEL and DPC will consider all relevant human, environmental, and community interests in the area and will actively engage impacted stakeholders in routing and siting of the project. During construction, XEL, DPC, and/or their contractors will be working in the area and will contribute positively to the local economy. The right-of-way will be restored following construction.

6.8.2  Completed Projects

The table below identifies those projects by Tracking Number in the Southeast 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.