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

6.6    Twin Cities Zone

6.6.1  Needed Projects

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

Bunker Lake 345 kV Ring Bus

MPUC Tracking Number: 2021-TC-N7

Utility: Great River Energy (GRE)

Project Description: The project plans to build a 345 kV ring bus at Bunker lack by replacing switches 30JSM1, 30JSM4, and 30JSM5 with 345 kV breakers such that Sherco-Bunker Lake and Bunker Lake-Coon Creek are separate, breakered 345 kV line sections. The 345kV yard will need to be built out to accommodate a ring bus design with breaker and a half optionality. This will require site grading, and a line move for Xcel’s 0984 line.

Need Driver: GRE has identified that widespread transient stability violations can occur (transient voltage violations and rotor angle oscillations) under certain faults . Because the transient voltage violations are widespread and the rotor angle oscillations involve large plants, adding 345 kV breakers at Bunker Lake greatly improves system stability by allowing breakers at Sherco, Bunker Lake and Coon Creek to more quickly clear line faults.

Alternatives:

Transmission Alternatives

This project is the only option considered to address the reliability concerns.

Non-Wires Alternatives

This a reliability improvement at the substation and no alternatives were considered.

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

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

General Impacts: This project is located on GRE owned property. Construction is expected to be completed in 18 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.

Medina Breaker Addition and Replacement

MPUC Tracking Number: 2021-TC-N8

Utility: Great River Energy (GRE)

Project Description: Add a breaker at Medina substation on the Crow River – Medina 115 kV line. Add a breaker at the Medina substation on the 115/69 kV transformer. Replace breaker 55WB2.

Need Driver: The Crow River to Medina 115 kV line terminates with a switch at the Medina substation. A fault on the line would trip the entire substation. A fault on certain facilities could result in tripping the entire substation. The breaker being replaced is hydraulic. There are limited parts available and there have been past maintenance issues with this breaker.

Alternatives:

Transmission Alternatives

The need required installation of a breaker to protect the substation from tripping due to a fault. The project was the only alternative considered to address the problem.

Non-Wires Alternatives

This a reliability improvement at the substation and no alternatives were considered.

Analysis: Replacement of the 115 kV switch with a breaker improves the reliability and resiliency of service at the Medina substation. These replacement projects are done within the substation fence and have minimal impact on landowners in the area.

Schedule: The project is planned to be in service by summer 2033.

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.

Blue Earth-South Bend Area Upgrades

MPUC Tracking Number: 2023-TC-N1

Utility: Xcel Energy (XEL)

Project Description: Rebuild approximately 30 miles of 161 kV line and upgrade South Bend TR6 to a 448 MVA transformer.

Need Driver: Address Thermal violations in multiple sensitivity cases.

Alternatives:

Transmission Alternatives

None.

Non-Wires Alternatives

This a reliability improvement to an existing line and transformer and no alternatives were considered.

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

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

NSPM Metro Steel Pole Replacement

MPUC Tracking Number: 2023-TC-N3

Utility: Xcel Energy (XEL)

Project Description: Address painted poles concerns between Riverside Sub and Main Street Sub. Approximately 4-mile of triple circuit structure(35-structures) to be either replaced, painted or a combination of replace/paint.

Need Driver: The existing structures were installed in the 1980s and are experiencing paint peeling and steel deterioration.

Alternatives:

Transmission Alternatives

None.

Non-Wires Alternatives

None.

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

Schedule: The project is planned to be in service by June 2027.
General Impacts: Replacement and/or painting of existing structures. 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. The right of way will be restored at the end of the project.

STY Install TR3 & 115kV Bus Tie

MPUC Tracking Number: 2023-TC-N9

Utility: Xcel Energy (XEL)

Need Driver: Needed to accommodate third distribution transformer due to capacity, location, and load.

Alternatives:

Transmission Alternatives

None.

Non-Wires Alternatives

None

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

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

General Impacts: Additional bus tie and switches in existing substation to support transmission reliability. 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.

Parkers Lake TR09 ELR

MPUC Tracking Number: 2023-TC-N12
Utility: Xcel Energy (XEL)

Project Description: Replace Parkers Lake 345/115 kV TR09 (3 phases).
Need Driver: The ELR transformer program is to proactively replace aging transformers that have past their operational service life and are showing increase signs of degradation.

Alternatives:

Transmission Alternatives

None.

Non-Wires Alternatives

None.

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

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

Line 0893 NSS-BCK Rebuild

MPUC Tracking Number: 2023-TC-N13

Utility: Xcel Energy (XEL)

Project Description: Rebuild 3.4 miles of 115 kV line between North Star Steel and Battle Creek substations. Portions of this line are double circuited with 0892, this project will separate the two circuits.

Need Driver: Needed to increase reliability and performance of the line due to deterioration from age and wet environment.

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: Verifying the secondary limit on the Farmington – Lake Marion 69 kV line, and limit may need to be replaced. No other immediate overloads or voltage concerns.

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

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

Line 0718 Arlington - Winthrop Rebuild

MPUC Tracking Number: 2023-TC-N14

Utility: Xcel Energy (XEL)

Project Description: Rebuild 15 miles line 0718 69 kV from Arlington - Winthrop.

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 June 2026.

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

Edina Switch Replacement

MPUC Tracking Number: 2023-TC-N15
Utility: Xcel Energy (XEL)

Project Description: Replace 115 kV switch at Edina, which is limiting the rating of the Edina - St. Louis Park 115 kV line.

Need Driver: Remediates overloads on the Edina - St. Louis Park 115 kV line.

Alternatives:

Transmission Alternatives

None.

Non-Wires Alternatives

None.

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

Schedule: The project is went into service August 2025.

General Impacts: Switch replacement in existing substation to support transmission reliability. 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.

Line 0859 Str 16 to Chemolite Rebuild

Utility: Xcel Energy (XEL)

Project Description:   Rebuild 6.9 miles of line 0859 115 kV from Chemolite substation to structure 16.

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 March 31, 2026.

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

Line 0771 Rebuild

MPUC Tracking Number: 2023-TC-N21

Utility: Xcel Energy (XEL)

Project Description: Rebuild 2 miles of line 0771 from Young America - Carver County 69 kV substations and add OPGW.

Need Driver: Needed to increase reliability and performance of the line due to deterioration from age and wet environment.

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.

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

Line 0840 Elliot Park Pumping Plants

MPUC Tracking Number: 2023-TC-N22

Utility: Xcel Energy (XEL)

Project Description: Upgrades to pumping station for HPFF.

Need Driver: Pumping plant is required to maintain electrical supply to the substation.

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 May 2026.

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

Lake Pulaski TR05 ELR

MPUC Tracking Number: 2023-TC-N23

Utility: Xcel Energy (XEL)

Project Description: Replace Lake Pulaski 115/69 kV TR05.

Need Driver: The ELR transformer program is to proactively replace aging transformers that have past their operational service life and are showing increase signs of degradation.

Alternatives:

Transmission Alternatives

None.

Non-Wires Alternatives

None.

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

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

General Impacts: Transformer replacement in existing substation to support transmission reliability. 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.

Inver Grove TR02 ELR

MPUC Tracking Number: 2023-TC-N24

Utility: Xcel Energy (XEL)

Project Description: Replace Inver Grove 115/69 kV TR02.

Need Driver: The ELR transformer program is to proactively replace aging transformers that have past their operational service life and are showing increase signs of degradation.

Alternatives:

Transmission Alternatives

None.

Non-Wires Alternatives

None.

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

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

General Impacts: Transformer replacement in existing substation to support transmission reliability. 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.

Prairie Island TR10 ELR

MPUC Tracking Number: 2023-TC-N25

Project Description: Replace Prairie Island 345/161 kV TR10.

Need Driver: The ELR transformer program is to proactively replace aging transformers that have past their operational service life and are showing increase signs of degradation.

Alternatives:

Transmission Alternatives

None.

Non-Wires Alternatives

None.

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

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

General Impacts: Transformer replacement in existing substation to support transmission reliability. 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.

Monticello TR06 & TR10 ELR

MPUC Tracking Number: 2023-TC-N26Utility: Xcel Energy (XEL)

Project Description: Replace Monticello 345/230 kV TR06 and 345/115 kV TR10.

Need Driver: The ELR transformer program is to proactively replace aging transformers that have past their operational service life and are showing increase signs of degradation.

Alternatives:

Transmission Alternatives

None.

Non-Wires Alternatives

None.

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

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

Line 0892 RRK-BCK Rebuild

MPUC Tracking Number: 2023-TC-N27

Utility: Xcel Energy (XEL)

Project Description: Rebuild 3.4 miles of 115 kV line between Red Rock and Battle Creek substations. Portions of this line are double circuited with 0893, this project will separate the two circuits.

Need Driver: Needed to increase reliability and performance of the line due to deterioration from age and wet environment.

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 August 2026.

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

Line 0736 Arden Hills - Lawrence Creek Rebuild

MPUC Tracking Number: 2023-TC-N28

Utility: Xcel Energy (XEL)

Project Description: Rebuild 33 miles of line 0736 69 kV from Arden Hills - Lawrence Creek and add OPGW.

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, 2027.

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

Line 0721 STR 71 to 476 Rebuild

MPUC Tracking Number: 2023-TC-N29

Utility: Xcel Energy (XEL)

Project Description: Rebuild 22 miles line 0721 69 kV from Structure 71 - Structure 476.

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 November 2028.

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

Pilot Knob to Burnsville Area Projects

MPUC Tracking Number: 2023-TC-N37

Utility: Great River Energy (GRE)

Project Description The Pilot Knob Substation will be rebuilt to a breaker and a half configuration due to the age and condition of the current equipment. In addition, the DA-PD line from Deerwood substation to Pilot Knob substation will be rebuilt to increase the capacity. The line upgrade will be built to 115 kV standards but operated at 69 kV. The underground portion of the DA-PLX line at Pilot Knob will be retired and replaced with an overhead line. The DA-RE line from Pilot Knob Road to Black Hawk Road will be retired. along with the DA-PKX line from Pilot Knob to Cliff Road.

Need Driver: Pilot Knob substation is old and in poor condition, the substation configuration is non-standard and does not allow for expansion. DA-RE line needs to be retired to allow for the county to upgrade the section of Pilot Knob Road. Following the upgrade, the DA-PKX and DA- RE lines are no longer needed and would be retired.

Alternatives:

Transmission Alternatives

The project is to rebuild outdated, aging infrastructure and support future load requirements and has been identified as the optimal solution for the region.

 

Rebuilding the line at 69kV standard was considered, but the developments in the area necessitated the rebuild of this transmission line to 115kV standard. GRE will rebuild the line to 115 kV standard and operate at 69 kV until all associated 69 kV lines and distribution substations are upgraded and the Pilot Knob substation is reconfigured to create a 115 kV looped service between Pilot Knob and Burnsville. High-capacity transmission lines are needed in the area to reliably serve communities that are dependent on this transmission line. In addition, growing industrial developments in the area can only be served with high capacity 15 kV transmission lines.

Non-Wires Alternatives

The driver for the line rebuild is primarily age and condition of the transmission line; therefore, non-wires alternatives were not considered for this project.

Analysis:

With rising load demand in the Eagan, MN area, there is a need to rebuild the existing 69 kV lines to allow for future operation at 115 kV. Following the upgrade of Lebanon Hills to 115 kV service and the retirement of the 69 kV line between Pilot Knob and Lebanon Hills, the DA-RE and DA- PKX lines between Pilot Knob and Deerwood tap are also scheduled for retirement, resulting in only one remaining 69 kV path between Pilot Knob and Burnsville via Deerwood substation. After the retirement project, the Pilot Knob to Deerwood line requires an upgrade, as it reaches its capacity during a loss of Burnsville to River Hills 69kV line. Although upgrading to a higher capacity 69 kV conductor is possible, analysis supports GRE’s recommendation to rebuild to the 115 kV standard to provide reliable service and support economic development in the area. The project analysis demonstrated benefits such as reduced voltage drop, improved ability to serve large future loads, and improved reliability in the area.

Schedule: This project is planned to be in-service by December 2028.

General Impacts: The project is located on existing property and exiting GRE 69 kV right of way corridor. 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 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.

Laketown Distribution Substation

MPUC Tracking Number: 2023-TC-N38

Utility: Great River Energy (GRE)

Project Description: Construct about 3 to 5 miles 115 kV transmission line from GRE’s 115 kV line near Victoria Tap. The interconnecting lines will be constructed as an in-and-out design to accommodate a future double-ended sub.

Need Driver: Minnesota Valley Electric Cooperative (MVEC) is requiring the new Laketown substation because of the additional load planned in Laketown Township. The existing substations in this area will be at capacity and will not be able to serve the additional load in the future.
The majority of MVEC load in this area is concentrated between Waconia and Victoria, north of Airport Road. It is preferred that a new substation be located close to this load center rather than have most of the load at the end of feeders. Shorter feeders close to the load centers improve the reliability of the feeders and reduces voltage drop. Nearly all the load growth expected of around
8.5 MW will be in this area which does not currently have a substation located nearby.
Augusta is not a good substation to serve this growing load as the feed currently from Augusta is
8.1 miles to end of feeder, with the majority of the load at the end. Voltage regulators are already in use on these feeders. Currently 87% of the load served by Victoria is on the northern feeders. The proposed Laketown substation site will be much closer to the load center than either Augusta or Victoria. With the projected load in the Laketown area backfeeding will become very difficult if not impossible. It would fall on Waconia and Victoria to support each other in addition to the new Laketown area growth. That is a reliability and system integrity risk that would be greatly alleviated with the addition of the Laketown substation. Transmission reliability will also be improved with the addition of a bus-tie breaker to sectionalize the transmission system at Laketown.

Alternatives:

Transmission Alternatives

Alternative 115 kV connections were considered but did not sectionalize the system as well as connecting to the MV-VTT line between Augusta and Victoria. This section provided the best reliability and resiliency.

Non-Wires Alternatives

Non-wires alternatives for this project were not considered due to new load needing to be fed with no existing transmission infrastructure in the area.

Analysis: A distribution analysis was performed. This showed the need for a new substation in the area due to lack of feeder redundancy, load growth in an area with no distribution substation, and future feeder overload and voltage issues on lines already with voltage regulators in use

Analysis in the distribution system showed that an alternative distribution wasn’t feasible:

1. Additional transformers
   1. Neither the Victoria nor Augusta substation have the land space to add a second transformer. Augusta and Victoria are already two of MVEC’s most heavily loaded substations with more load expected to come (several developments and large C&I).
   2. Augusta won’t be able help serve the Laketown area as its capacity will be needed for future load growth expected around Augusta.
   3. Waconia doesn’t have space for a second transformer, but upsizing the transformer is possible. However, the cost of upgrading the Waconia transformer could also be put towards the Laketown substation which solves more reliability and capacity concerns.
2. Additional feeders
   1. A new Victoria feeder is currently being built to support growth south of the Victoria substation. This new line could potentially pick up some of the Laketown area. However, with Augusta tied up, there is no way to back feed Laketown or much of the Victoria substation, which puts a large amount of load at risk for reliability issues.
   2. Any new feeders out of Augusta will go towards the new loads by the Augusta substation.
   3. At least one line out of Waconia will need to go to the Laketown area regardless for backfeeding purposes. For a normal feed from Waconia, MVEC would likely want two feeders, which again is an additional cost that could go towards a Laketown substation.
3. Regulators and Capacitors
   1. There’s currently already a bank of regulators and capacitors on the feed for Laketown area. Additional banks can be added but for long term growth this isn’t a sustainable solution.
   2. Voltage isn’t as big of a driving factor as capacity and reliability. Having the Laketown substation would reduce feeder lengths and would remove the need for additional regulators and capacitor banks.

Transmission analysis showed that adding the new substation did not negatively impact the transmission system, and that including a bus-tie breaker at Laketown contributed to system reliability.

Schedule: The Laketown Substation project is planned to be in-service by fall 2028.

General Impacts: The project will require approximately 3 to 5 miles of new 115 kV transmission line to the Laketown 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 primarily 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.

Burnsville Substation Upgrade

MPUC Tracking Number: 2023-TC-N42

Utility: Great River Energy (GRE)

Project Description: This project involves the following at Burnsville substation: replace and relocate EEE (all new panels/relays/etc.), soil correction at new EEE site, northwest fence line expansion, replacement of 5M197, and add breakers with new 115 kV ring bus configuration on north end of substation.

Need Driver:

• The Electrical Equipment Enclosure (EEE) in the Burnsville substation continues to sink due to unstable, waterlogged soil and persistent flooding. Soil correction is required, as the current conditions are undermining the foundation and causing equipment to gradually settle, threatening both structural integrity and operational safety. Standing water and poor drainage are also accelerating the deterioration of electrical components. The planned rebuild will not only replace aging infrastructure but also include site improvements to correct grading and mitigate flooding risks—ensuring long-term stability and resilience.
• As part of the infrastructure modernization efforts, all electromechanical relays and first- generation microprocessor relays will be systematically replaced. These legacy components have limited diagnostic capabilities and are increasingly prone to failure, creating maintenance challenges and operational risks. The upgrade will deploy modern digital protection relays with enhanced functionality, improved fault analysis, and better integration into SCADA systems. This transition ensures greater reliability, streamlined troubleshooting, and future-readiness of the substation's control systems.
• Prepare site for future to accommodate voltage conversion to 115 kV of existing 69kV transmission lines in the area. Breaker Replacements: these are Siemens BZO breakers with a OA3 Hydraulic mechanism. These breakers have type U bushings with higher power factor test results. Limited spare parts availability. Higher risk scores of the oil breakers left for replacement.

Alternatives:

Transmission Alternatives

This is an equipment reliability improvement project at the existing Burnsville substation and no other transmission alternatives were considered.

Non-Wires Alternatives

This project involves equipment improvement at the substation, and no alternatives were considered.

Analysis: After substation inspection, it was found that much of the equipment at the substation is outdated and increasingly prone to failure, putting system reliability at risk. The EEE site itself is experiencing ground instability, and soil correction is needed to address long-standing drainage and access issues. Without it, the area remains difficult to reach for maintenance vehicles and is unsafe for operations.

Looking ahead, a future project will add a new 115 kV connection to this substation. Preparing for that integration now means fewer outages and smoother implementation down the line. The new
115 kV equipment and bus work will be rated at 3000A to support anticipated load growth in the area.

Taken together, these upgrades will strengthen reliability, improve site access, and prepare the substation for future growth.

Schedule: The Burnsville Substation Upgrade project is planned to be in-service by March 2030.

Blaine to Linwood Area Project

MPUC Tracking Number: 2025-TC-N1

Utility: Great River Energy (GRE)

Project Description: This project will rebuild the Blaine – Linwood 230 kV ‘PR’ line from structure 265 to the Linwood substation. The length of line to rebuild is approx. 12.8 miles.

Need Driver: The line is being replaced due to age and condition.

Alternatives:

Transmission Alternatives

This project replaces existing transmission line due to its age and deteriorating condition. No transmission alternatives were considered for this project, as the proposed project represents the least costly and least impactful solution.

Non-Wires Alternatives

This line is critical for maintaining reliable power transfer in the region; therefore, non- wires alternatives were not considered feasible for this project.

Analysis: This rebuild will refresh aging assets, further extending the life of the facility.

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

General Impacts: The Project will be constructed on an existing right-of-way. No new landowners will be impacted by construction, although some additional temporary workspace may be required. GRE has completed 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. No significant traffic impacts are anticipated. The right- of-way will be restored following construction.

0890 Granite City – Crossroads Rebuild

Utility: Xcel Energy (XEL)

Project Description: Rebuild 3.7 miles 115 kV line from Granite City - Crossroads with new structures and new OPGW shield wire.

Need Driver: New poles needed to support fiber upgrades.

Alternatives:

Transmission Alternatives

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

Non-Wires Alternatives

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

Analysis: This project will aid the communication and protection of transmission assets by supporting fiber network upgrades.

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

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

0821 Highbridge – Miriam Park Refurb

MPUC Tracking Number: 2025-TC-N4

Utility: Xcel Energy (XEL)

Project Description: Rebuild 3.3 miles 115 kV with new structures and new OPGW shield wire.

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

Alternatives:

Transmission Alternatives

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

Non-Wires Alternatives

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

Analysis:    This project will fix aging poles and aid the communication and protection of transmission assets by supporting fiber network upgrades.

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

Umore Park 115kV Substation

MPUC Tracking Number: 2025-TC-N5

Utility: Xcel Energy (XEL)

Project Description: New 115kV load serving substation with in-and-out tap to existing Rosemount - Empire 115 kV line 0822. Build 6 miles new double circuit 115 kV line from Umore Park - Inver Grove with one circuit connecting to Inver Hills.

Need Driver: Needed to support new interconnecting load.

Alternatives:

Transmission Alternatives

The project will add new load and thus was chosen as the best option to meet the need.

Non-Wires Alternatives

The project will add new load and thus was chosen as the best option to meet the need.

Analysis: This project builds a new substation to serve a new customer in Rosemount. This project benefits the community with added tax base and local jobs.

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

General Impacts: This project is expected to have low impacts as the transmission line is very near the substation location which is owned by the customer.

Inver Grove – Inver Hills 115kV Rebuild to Double Circuit

MPUC Tracking Number: 2025-TC-N6

Utility: Xcel Energy (XEL)

Project Description: Rebuild 2.2 miles 115 kV line 5507 to double circuit from Inver Grove - Inver Hills. Expand Inver Hills substation. Add 1 breaker at Umore substation.

Need Driver: Age & Condition rebuild. Future load serving support.

Alternatives:

Transmission Alternatives

The project will rebuild aging assets and assist in future load serving and thus was chosen as the best option to meet the need.

Non-Wires Alternatives

The project will rebuild aging assets and assist in future load serving and thus was chosen as the best option to meet the need.

Analysis: This project rebuilds an existing transmission line to double circuit which helps serve new load growth. This allows the community to grow its load as well as replaces aging assets.

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

General Impacts: This project is expected to have low impacts as the transmission line exists today and will be adding a second circuit in the same ROW.

West Maple Grove Substation

MPUC Tracking Number: 2025-TC-N7

Utility: Xcel Energy (XEL)

Project Description: Build new Substation in Northwest Maple Grove to accommodate load growth

Need Driver: New substation needed in the NW Maple Grove area due to substantial load growth in area

Alternatives:

Transmission Alternatives

The project will add new load and thus was chosen as the best option to meet the need.

Non-Wires Alternatives

The project will add new load and thus was chosen as the best option to meet the need.

Analysis: This project builds a new substation to serve growing load in the Maple Grove area. This new substation allows the city to grow their load and city.

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

General Impacts: This project’s impacts are unknown at this time and is under further study.

Coon Creek Breaker ELR

MPUC Tracking Number: 2025-TC-N8

Project Description: Replace three 345kV and two 115kV breakers at Coon Creek that are at end of life

Need Driver: Breakers are at end of life and are experiencing gas leaks, causing reliability concerns.

Alternatives:

Transmission Alternatives

The project will rebuild aging assets and thus was chosen as the best option to meet the need.

Non-Wires Alternatives

The project will rebuild aging assets and thus was chosen as the best option to meet the need.

Analysis: The replacement of failing substation equipment is key to maintaining reliability of the system.

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

General Impacts: This project is expected to have minimal impacts as work is all inside the existing substation.

Rebuild 0737 Gleason Lake to Mound

MPUC Tracking Number: 2025-TC-N9

Utility: Xcel Energy (XEL)

Project Description: Rebuild line 0737 from Gleason Lake to Mound and add OPGW

Need Driver: The existing structures are at end of life and have numerous defects.

Alternatives:

Transmission Alternatives

The project will rebuild aging assets and assist in future load serving and thus was chosen as the best option to meet the need.

Non-Wires Alternatives

The project will rebuild aging assets and assist in future load serving and thus was chosen as the best option to meet the need.

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

General Impacts: This project is expected to have minimal impacts as the transmission line exists today and will be rebuilt in the same ROW.

Rebuild 0735 St Bonifacius to Mound

MPUC Tracking Number: 2025-TC-N10

Utility: Xcel Energy (XEL)

Project Description: Rebuild line 0735 from St. Bonifacious to Mound and add OPGW

Need Driver: The existing structures are at end of life and have numerous defects.

Alternatives:

Transmission Alternatives

The project will rebuild aging assets and assist in future load serving and thus was chosen as the best option to meet the need.

Non-Wires Alternatives

The project will rebuild aging assets and assist in future load serving and thus was chosen as the best option to meet the need.

Analysis: OPGW installation on the line will likely replace more than 50% of existing structures, triggering a complete rebuild. Significant load growth is forecasted in the area and increased capacity is needed.

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

General Impacts: This project is expected to have minimal impacts as the transmission line exists today and will be rebuilt in the same ROW.

Install Inver Hills TRs and Feeders

MPUC Tracking Number: 2025-TC-N11

Utility: Xcel Energy (XEL)

Project Description: Expand the Inver Hills substation and install two new distribution transformers and feeders to take over the existing Rich Valley loads

Need Driver: Rich Valley substation is currently under loss of load risk due to single bank configuration. This project would add transfer the load from Rich Valley to Inver Hills and add the capacity to support the additional load.

Alternatives:

Transmission Alternatives

The project will rebuild aging assets and adding feeder equipment to serve load. Thus, was chosen as the best option to meet the need.

Non-Wires Alternatives

The project will rebuild aging assets and adding feeder equipment to serve load. Thus, was chosen as the best option to meet the need.

Analysis: The new transformers help the system be flexible, add capacity to serve new area load and provide redundancy.

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

General Impacts: This project is expected to have minimal impacts as most work is inside the existing substation.

King Transmission Connection

MPUC Tracking Number: 2025-TC-N12

Utility: Xcel Energy (XEL)

Project Description: New 230kV ~30mi transmission line, 2 switching stations with capacitors, and associated substation upgrades including 2 230/345kV transformers to bring radial renewable generation to AS King substation to replace existing generation.

Need Driver: Project needed to bring renewable generation in WI to AS King substation to replace existing coal generation.

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 AS King to retire all while keeping the injection rights.

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

General Impacts: This projects impacts are significant overall, however fairly minimal in MN. You can find some information about the MN portion with this docket info: MPUC Docket No. E002/TL-25-255. The full project will require a CPCN in Wisconsin, which will be considered in Docket No. 4220-CE-190.

6.6.2  Completed Projects

The table below identifies those projects by Tracking Number in the Twin Cities Zone that were listed as ongoing projects in the 2023 Biennial Report but have been completed or withdrawn since the 2021 Report was filed with the 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.