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Regulatory Matters | 12 Months Ended
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Dec. 31, 2024
Regulated Operations [Abstract] |
Regulatory Matters | REGULATORY MATTERS Electric Rates. Entities within our Regulated Operations segment file for periodic rate revisions with the MPUC, PSCW or FERC. As authorized by the MPUC, Minnesota Power also recognizes revenue under cost recovery riders for transmission, renewable and environmental investments and expenditures. (See Transmission Cost Recovery Rider, Renewable Cost Recovery Rider, Solar Cost Recovery Rider and Environmental Improvement Rider.) Revenue from cost recovery riders was $20.0 million in 2024 ($57.0 million in 2023; $38.8 million in 2022). Minnesota Retail Rates. Minnesota Power’s retail base rates through 2022 were based on a 2018 MPUC retail rate order that allowed for a 9.25 percent return on common equity and a 53.81 percent equity ratio. Interim rates were implemented in Minnesota Power’s 2022 general rate case beginning in January 2022, and the resolution of Minnesota Power’s 2022 general rate case changed the allowed return on equity to 9.65 percent and the equity ratio to 52.50 percent beginning October 1, 2023. (See 2022 Minnesota General Rate Case.) Minnesota Power expects to implement updated rates based on the 2024 MPUC retail rate order in the first quarter of 2025. This order allows for a return on equity 9.78 percent and an equity ratio of 53.00 percent. 2024 Minnesota General Rate Case. On November 1, 2023, Minnesota Power filed a retail rate increase request with the MPUC seeking an average increase of approximately 12.00 percent for retail customers, net of rider revenue incorporated into base rates. The rate filing sought a return on equity of 10.30 percent and a 53.00 percent equity ratio. On an annualized basis, the requested final rate increase would have generated approximately $89 million in additional revenue. In separate orders dated December 19, 2023, the MPUC accepted the filing as complete and approved an annual interim rate increase of approximately $64 million, net of rider revenue, beginning January 1, 2024, subject to refund. On May 3, 2024, Minnesota Power entered into a settlement agreement with the Minnesota Department of Commerce, Minnesota Office of the Attorney General, Residential Utilities Division, and Large Power Intervenors to settle the retail rate increase request. As part of the settlement agreement, the parties agreed on all issues, including an overall rate increase of $33.97 million, net of rider revenue and amounts transferring to the fuel adjustment clause, a return on equity of 9.78 percent, an equity ratio of 53.00 percent, all non-financial items and cost allocation. In an order dated November 25, 2024, the MPUC approved the settlement agreement. Final rates are expected to be implemented in the first quarter of 2025; interim rates will be collected through this period with reserves recorded as necessary. As a result of the settlement, Minnesota Power recorded a reserve for an interim rate refund of $23.0 million pre-tax as of December 31, 2024, which is subject to MPUC approval of Minnesota Power’s refund calculation. 2022 Minnesota General Rate Case. In an order dated February 28, 2023, the MPUC made determinations regarding Minnesota Power’s general rate case including allowing a return on common equity of 9.65 percent and a 52.50 percent equity ratio. In March 2023, Minnesota Power filed a petition for reconsideration with the MPUC requesting reconsideration and clarification of certain decisions in the MPUC’s order. The MPUC denied the requests for reconsideration in an order dated May 15, 2023. In an order dated September 29, 2023, the MPUC approved Minnesota Power’s final rates, which were implemented beginning on October 1, 2023. The MPUC order also approved Minnesota Power’s interim rate refund plan. Interim rates were collected through the third quarter of 2023 with reserves recorded as necessary. Minnesota Power recorded a reserve for an interim rate refund of approximately $39 million pre-tax as of September 30, 2023 (approximately $18 million as of December 31, 2022), which was refunded to customers during the fourth quarter of 2023. Minnesota Power appealed with the Minnesota Court of Appeals (Court) specific aspects of the MPUC’s February 2023 and May 2023 rate case orders for the ratemaking treatment of Taconite Harbor and Minnesota Power’s prepaid pension asset. On September 9, 2024, the Court affirmed the MPUC’s Taconite Harbor treatment, but reversed and remanded the treatment of Minnesota Power’s prepaid pension asset back to the MPUC. The Court directed the MPUC to determine the amount of Minnesota Power’s prepaid pension asset to be included in rate base. The MPUC has not yet determined the next procedural steps in implementing the Court’s decision. NOTE 4. REGULATORY MATTERS (Continued) Electric Rates (Continued) FERC-Approved Wholesale Rates. Minnesota Power has wholesale contracts with 14 non-affiliated municipal customers in Minnesota and SWL&P. Two of the wholesale contracts include a termination clause requiring a three-year notice to terminate. Minnesota Power’s wholesale electric contract with the Nashwauk Public Utilities Commission is effective through December 31, 2037. The wholesale electric service contract with SWL&P is effective through February 29, 2028. Under the agreement with SWL&P, no termination notice has been given. The rates included in these two contracts are set each July 1 based on a cost-based formula methodology, using estimated costs and a rate of return that is equal to Minnesota Power’s authorized rate of return for Minnesota retail customers. The formula-based rate methodology also provides for a yearly true-up calculation for actual costs incurred. Minnesota Power’s wholesale electric contracts with 13 other municipal customers were extended in January 2022 and are effective through 2029. These contracts are based on fixed prices for capacity and energy. The base energy charge for each year is adjusted annually for updated fuel and purchased power costs. Transmission Cost Recovery Rider. Minnesota Power has an approved cost recovery rider in place to charge retail customers on a current basis for certain transmission investments and expenditures, including a return on the capital invested. Current customer billing rates are based on an MPUC order dated March 5, 2024. On November 13, 2024, Minnesota Power submitted its latest transmission factor filing. Following approval of the filing by the MPUC, Minnesota Power will be authorized to include updated billing rates on customer bills. Renewable Cost Recovery Rider. Minnesota Power has an approved cost recovery rider in place to charge retail customers on a current basis for the costs of certain renewable investments and expenditures, including a return on the capital invested. Current customer billing rates for the renewable cost recovery rider were approved by the MPUC in an order dated June 25, 2024. Solar Cost Recovery Rider. Minnesota Power has an approved cost recovery rider in place to charge retail customers on a current basis for solar costs related to investments and expenditures for meeting the state of Minnesota’s solar energy standard. Current customer billing rates were approved by the MPUC in an order dated December 26, 2023. On October 8, 2024, Minnesota Power submitted its latest solar factor filing. Following approval of the filing by the MPUC, Minnesota Power will be authorized to include updated billing rates on customer bills. Fuel Adjustment Clause. Fuel and purchased power costs related to Minnesota Power’s retail customers are recovered from customers through the fuel adjustment clause. The method of accounting for all Minnesota electric utilities is a monthly budgeted, forward-looking fuel adjustment clause with annual prudence review and true-up to actual allowed costs. Minnesota Power incurred higher fuel and purchased power costs in 2022 than those factored in its fuel adjustment forecast filed in May 2021 for 2022, which resulted in the recognition of an approximately $13 million regulatory asset as of December 31, 2022. The MPUC approved recovery of the regulatory asset in an order dated July 31, 2023; recovery of the regulatory asset began in the third quarter of 2023 and ended in mid-2024. Minnesota Power incurred lower fuel and purchased power costs in 2023 than those factored in its fuel adjustment forecast filed in May 2022 for 2023, which resulted in the recognition of a $15.5 million regulatory liability as of December 31, 2023. Minnesota Power requested to refund the regulatory liability over 12 months beginning in the third quarter of 2024 as part of its annual true-up filing submitted to the MPUC on March 1, 2024. In an order dated July 1, 2024, the MPUC approved the filing, and authorized Minnesota Power to refund the regulatory liability over 12 months beginning on September 1, 2024. Minnesota Power incurred higher fuel and purchased power costs in 2024 than those factored in its fuel adjustment forecast filed in May 2023 for 2024, which resulted in the recognition of a $4.5 million regulatory asset as of December 31, 2024. Minnesota Power expects to request recovery of the regulatory asset as part of its annual true-up filing with the MPUC in March 2025. Minnesota Power’s filed its annual forecasted fuel and purchased power rates for 2025 on May 1, 2024, which was subsequently approved by the MPUC in an order dated November 8, 2024. The fuel and purchased power rates for Minnesota Power retail customers are based on this filing beginning January 1, 2025. NOTE 4. REGULATORY MATTERS (Continued) Electric Rates (Continued) Deferred Accounting Petition. On December 30, 2024, Minnesota Power submitted a petition with the MPUC seeking deferral accounting treatment for investigative costs and the increase in depreciation expense resulting from compliance costs that will be incurred related to the new Coal Combustion Rule (CCR) Legacy Rule, which was published in the Federal Register on May 8, 2024. (See Note 9. Commitments, Guarantees and Contingencies.) Compliance with the CCR Legacy Rule is expected to result in a significant increase to our MPUC-approved decommissioning costs for Boswell and Laskin. If the MPUC approves our request for deferral accounting treatment, these costs would be deferred for recovery to our next rate case or other regulatory proceeding. In 2024, we recorded depreciation expense related to this rule, of which $4.2 million pre-tax would be moved to a deferred tracking account for MPUC review through a future rate case or other proceeding if the MPUC approves our request for deferral accounting treatment. We are unable to predict the outcome of this proceeding. Wisconsin Retail Rates. SWL&P’s retail rates through 2022 were based on a December 2018 order by the PSCW that allowed for a return on equity of 10.40 percent and a 55.00 percent equity ratio. The resolution of SWL&P’s 2022 general rate case changed the allowed return on equity to 10.00 percent and maintained an equity ratio of 55.00 percent. (See 2022 Wisconsin General Rate Case.) The resolution of SWL&P’s 2024 general rate case further changed the allowed return on equity to 9.80 percent and continued to maintain an equity ratio of 55.00 percent beginning January 1, 2025. (See 2024 Wisconsin General Rate Case.) 2024 Wisconsin General Rate Case. On March 29, 2024, SWL&P filed a rate increase request for its electric, gas and water utilities with the PSCW. The filing sought an overall return on equity of 10.00 percent and a 55.00 percent equity ratio. On an annualized basis, the requested change would have increased rates by approximately 5.90 percent for retail customers and generated an estimated $7.3 million of additional revenue. In an order dated December 12, 2024, the PSCW approved an annual increase of approximately $5.5 million reflecting a return on equity of 9.80 percent and a 55.00 percent equity ratio. Final rates went into effect January 1, 2025. 2022 Wisconsin General Rate Case. In an order dated December 20, 2022, the PSCW approved an annual increase of $3.3 million reflecting a return on equity of 10.00 percent and a 55.00 percent equity ratio. Final rates went into effect January 1, 2023. Integrated Resource Plan. On February 1, 2021, Minnesota Power filed its latest IRP, which was approved by the MPUC in an order dated January 9, 2023. The approved IRP, which reflects a joint agreement reached with various stakeholders, outlines Minnesota Power’s clean-energy transition plans through 2035. These plans include expanding its renewable energy supply, achieving coal-free operations at its facilities by 2035, and investing in a resilient and flexible transmission and distribution grid. As part of these plans, Minnesota Power anticipates adding up to 700 MW of new wind and solar energy resources, and ceasing coal operations at Boswell Units 3 and 4 by 2030 and 2035, respectively. Minnesota Power’s plans recognize that advances in technology will play a significant role in completing its transition to carbon-free energy supply, reliably and affordably. Minnesota Power expects to file its next IRP in March 2025. Solar Energy Request For Proposals. On October 2, 2023, Minnesota Power filed a notice with the MPUC of its intent to issue a RFP for up to 300 MW of solar energy resources. Minnesota Power issued the RFP on November 15, 2023, which were accepted through January 17, 2024. Minnesota Power announced plans to build an 85 MW solar project and a 119.5 MW solar project in northern Minnesota, both of which are expected to be in service in mid-2027, subject to MPUC approval. Wind Energy Request For Proposals. On December 15, 2023, Minnesota Power filed a notice with the MPUC of its intent to issue a RFP for up to 400 MW of wind energy resources. Minnesota Power issued the RFP on February 15, 2024, which were accepted through April 11, 2024. NOTE 4. REGULATORY MATTERS (Continued) ECO Plan. Minnesota requires electric utilities to spend a minimum of 1.5 percent of gross operating revenues, excluding revenue received from exempt customers, from service provided in the state on ECOs each year. On April 1, 2024, Minnesota Power submitted its 2023 ECO annual filing, formerly known as the conservation improvement program, detailing Minnesota Power’s ECO plan results and proposed financial incentive, which was approved by the MPUC on November 8, 2024. As a result, Minnesota Power recognized revenue of $2.2 million in 2024 for the approved financial incentive ($2.2 million in 2023 and $1.9 million in 2022). The financial incentives are recognized in the period in which the MPUC approves the filing. On June 30, 2023, Minnesota Power submitted its triennial filing for 2024 through 2026 to the MPUC and Minnesota Department of Commerce, which outlines Minnesota Power’s ECO spending and energy-saving goals for those years. Minnesota Power’s investment goals are $12.7 million for 2025 and $12.8 million for 2026. MISO Return on Equity Complaints. MISO transmission owners, including ALLETE and ATC, had an authorized return on equity of 10.02 percent, or 10.52 percent including an incentive adder for participation in a regional transmission organization based on a 2020 FERC order which was subject to various legal challenges related to the return on equity calculation and refund period ordered by the FERC. In August 2022, the U.S. Court of Appeals for the District of Columbia Circuit vacated and remanded the 2020 FERC order back to the FERC. On October 17, 2024, FERC ordered a return on equity of 9.98 percent, or 10.48 percent including an incentive adder for participation in a RTO, effective September 28, 2016. (See Note 6. Equity Investments.) Minnesota Solar Energy Standard. Minnesota law requires at least 1.5 percent of total retail electric sales, excluding sales to certain customers, to be generated by solar energy. At least 10 percent of the 1.5 percent mandate must be met by solar energy generated by or procured from solar photovoltaic devices with a nameplate capacity of 40 kW or less and community solar garden subscriptions. Minnesota Power has met both parts of the solar mandate to date. Minnesota Distributed Solar Energy Standard. Minnesota law requires at least 3 percent of Minnesota Power’s retail electric sales to be generated from distributed solar energy resources by 2030. Minnesota Power expects to need between 65 MW and 85 MW of distributed solar capacity to meet this requirement. On January 30, 2025, Minnesota Power issued a RFP seeking distributed solar projects as part of its compliance with this distributed solar energy standard. The RFP seeks proposals for solar generating facilities of 10 MW or less that will be connected to Minnesota Power’s distribution system. Regulatory Assets and Liabilities. Our regulated utility operations are subject to accounting standards for the effects of certain types of regulation. Regulatory assets represent incurred costs that have been deferred as they are probable for recovery in customer rates. Regulatory liabilities represent obligations to make refunds to customers and amounts collected in rates for which the related costs have not yet been incurred. The Company assesses quarterly whether regulatory assets and liabilities meet the criteria for probability of future recovery or deferral. With the exception of the regulatory asset for Boswell Units 1 and 2 net plant and equipment, no other regulatory assets are currently earning a return. The recovery, refund or credit to rates for these regulatory assets and liabilities will occur over the periods either specified by the applicable regulatory authority or over the corresponding period related to the asset or liability. NOTE 4. REGULATORY MATTERS (Continued)
Regulatory Assets and Liabilities |  |
As of December 31 | 2024 | 2023
Millions |  |
Current Regulatory Assets (a) |  |
Fuel Adjustment Clause (b) | — |  | $8.7 |
Other | $1.6 |  | 0.6 |
Total Current Regulatory Assets | $1.6 |  | $9.3 |
Non-Current Regulatory Assets |  |
Defined Benefit Pension and Other Postretirement Benefit Plans (c) | $200.3 |  | $218.6 |
Income Taxes (d) | 84.9 |  | 88.1 |
Asset Retirement Obligations (e) | 41.0 |  | 37.7 |
Taconite Harbor (g) | 17.3 |  | 20.9 |
Manufactured Gas Plant (h) | 11.6 |  | 13.2 |
Cost Recovery Riders (f) | 5.5 |  | 33.8 |
Fuel Adjustment Clause (b) | 4.5 |  | 5.0 |
PPACA Income Tax Deferral | 3.7 |  | 3.9 |
Other | 2.9 |  | 4.2 |
Total Non-Current Regulatory Assets | $371.7 |  | $425.4 |
Current Regulatory Liabilities (i) |  |
Provision for Interim Rate Refund | $23.0 |  | — |
Fuel Adjustment Clause (b) | 7.2 |  | — |
Other | 1.3 |  | $3.9 |
Total Current Regulatory Liabilities | $31.5 |  | $3.9 |
Non-Current Regulatory Liabilities |  |
Income Taxes (d) | $292.7 |  | $310.0 |
Wholesale and Retail Contra AFUDC (j) | 77.6 |  | 78.0 |
Plant Removal Obligations (k) | 74.2 |  | 67.0 |
Defined Benefit Pension and Other Postretirement Benefit Plans (c) | 40.7 |  | 48.6 |
Non-Jurisdictional Land Sales (l) | 59.7 |  | 30.2 |
Investment Tax Credits (m) | 17.8 |  | 13.6 |
Boswell Units 1 and 2 Net Plant and Equipment (n) | 6.7 |  | 6.7 |
Fuel Adjustment Clause (b) | 0.6 |  | 15.5 |
Other | 0.5 |  | 4.4 |
Total Non-Current Regulatory Liabilities | $570.5 |  | $574.0 |
(a)Current regulatory assets are presented within Prepayments and Other on the Consolidated Balance Sheet. (b)Fuel adjustment clause regulatory assets and liabilities represent the amount expected to be recovered from or refunded to customers for the under- or over-collection of fuel adjustment clause recoveries. (See Fuel Adjustment Clause.) (c)Defined benefit pension and other postretirement items included in our Regulated Operations, which are otherwise required to be recognized in accumulated other comprehensive income, are recognized as regulatory assets or regulatory liabilities on the Consolidated Balance Sheet. The asset or liability will decrease as the deferred items are amortized and recognized as components of net periodic benefit cost. (See Note 12. Pension and Other Postretirement Benefit Plans.) (d)These costs represent the difference between deferred income taxes recognized for financial reporting purposes and amounts previously billed to our customers. The balances will primarily decrease over the remaining life of the related temporary differences. (e)Asset retirement obligations will accrete and be amortized over the lives of the related property with asset retirement obligations. (f)The cost recovery rider regulatory assets and liabilities are revenue not yet collected from our customers and cash collections from our customers in excess of the revenue recognized, respectively, primarily due to capital expenditures related to Bison and the GNTL as well as differences between production tax credits recognized and those assumed in Minnesota Power’s base rates. The cost recovery rider regulatory assets as of December 31, 2024, will be recovered within the next two years. (g)In the first quarter of 2023, Minnesota Power retired Taconite Harbor Units 1 and 2. The remaining net book value was reclassified from property, plant and equipment to a regulatory asset on the Consolidated Balance Sheet when the units were retired. Minnesota Power expects to receive recovery of the remaining net book value from customers. (h)This regulatory asset represents costs of remediation for a former manufactured gas plant site located in Superior, Wisconsin, and formerly operated by SWL&P. We expect recovery of these remediation costs to be allowed by the PSCW in rates over time. (i)Current regulatory liabilities are presented within Other Current Liabilities on the Consolidated Balance Sheet. (j)Wholesale and retail contra AFUDC represents amortization to offset AFUDC Equity and Debt recorded during the construction period of our cost recovery rider projects prior to placing the projects in service. The regulatory liability will decrease over the remaining depreciable life of the related asset. (k)Non-legal plant removal obligations included in retail customer rates that have not yet been incurred. (l)This regulatory liability represents the net proceeds from the sale of certain land by Minnesota Power that is expected to be refunded to ratepayers through a future rate case or through its renewable resources rider. (m)North Dakota and federal investment tax credits expected to be realized from Minnesota Power’s Bison facility and SWL&P’s community solar facility that will be credited to retail customers primarily through future renewable cost recovery rider and rate filings as the tax credits are utilized. (n)In 2018, Minnesota Power retired Boswell Units 1 and 2 and reclassified the remaining net book value from property, plant and equipment to a regulatory asset on the Consolidated Balance Sheet. The remaining net book value is currently included in Minnesota Power’s rate base and Minnesota Power is earning a return on the outstanding balance.

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