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On January 16, 2024, the Company entered into a share purchase agreement with a third-party buyer to sell the Company's Brastemp-branded water filtration subscription business in the Latin America region and the transaction closed on July 1, 2024. The Company received proceeds of approximately 294 million Brazilian reais (approximately $ 52 million at the date of transaction) and recorded a gain of approximately $ 34 million during the third quarter of 2024. The disposal group met the criteria of held for sale at December 31, 2023. The carrying amounts of the disposal group's assets and liabilities as of December 31, 2024 and December 31, 2023, respectively, were immaterial. The disposal group's earnings (loss) available to Whirlpool before income taxes for the twelve months ended December 31, 2024, and December 31, 2023, respectively, were also immaterial. | text | 294 | monetaryItemType | text: <entity> 294 </entity> <entity type> monetaryItemType </entity type> <context> On January 16, 2024, the Company entered into a share purchase agreement with a third-party buyer to sell the Company's Brastemp-branded water filtration subscription business in the Latin America region and the transaction closed on July 1, 2024. The Company received proceeds of approximately 294 million Brazilian reais (approximately $ 52 million at the date of transaction) and recorded a gain of approximately $ 34 million during the third quarter of 2024. The disposal group met the criteria of held for sale at December 31, 2023. The carrying amounts of the disposal group's assets and liabilities as of December 31, 2024 and December 31, 2023, respectively, were immaterial. The disposal group's earnings (loss) available to Whirlpool before income taxes for the twelve months ended December 31, 2024, and December 31, 2023, respectively, were also immaterial. </context> | us-gaap:DisposalGroupIncludingDiscontinuedOperationConsideration |
On January 16, 2024, the Company entered into a share purchase agreement with a third-party buyer to sell the Company's Brastemp-branded water filtration subscription business in the Latin America region and the transaction closed on July 1, 2024. The Company received proceeds of approximately 294 million Brazilian reais (approximately $ 52 million at the date of transaction) and recorded a gain of approximately $ 34 million during the third quarter of 2024. The disposal group met the criteria of held for sale at December 31, 2023. The carrying amounts of the disposal group's assets and liabilities as of December 31, 2024 and December 31, 2023, respectively, were immaterial. The disposal group's earnings (loss) available to Whirlpool before income taxes for the twelve months ended December 31, 2024, and December 31, 2023, respectively, were also immaterial. | text | 52 | monetaryItemType | text: <entity> 52 </entity> <entity type> monetaryItemType </entity type> <context> On January 16, 2024, the Company entered into a share purchase agreement with a third-party buyer to sell the Company's Brastemp-branded water filtration subscription business in the Latin America region and the transaction closed on July 1, 2024. The Company received proceeds of approximately 294 million Brazilian reais (approximately $ 52 million at the date of transaction) and recorded a gain of approximately $ 34 million during the third quarter of 2024. The disposal group met the criteria of held for sale at December 31, 2023. The carrying amounts of the disposal group's assets and liabilities as of December 31, 2024 and December 31, 2023, respectively, were immaterial. The disposal group's earnings (loss) available to Whirlpool before income taxes for the twelve months ended December 31, 2024, and December 31, 2023, respectively, were also immaterial. </context> | us-gaap:DisposalGroupIncludingDiscontinuedOperationConsideration |
On January 16, 2024, the Company entered into a share purchase agreement with a third-party buyer to sell the Company's Brastemp-branded water filtration subscription business in the Latin America region and the transaction closed on July 1, 2024. The Company received proceeds of approximately 294 million Brazilian reais (approximately $ 52 million at the date of transaction) and recorded a gain of approximately $ 34 million during the third quarter of 2024. The disposal group met the criteria of held for sale at December 31, 2023. The carrying amounts of the disposal group's assets and liabilities as of December 31, 2024 and December 31, 2023, respectively, were immaterial. The disposal group's earnings (loss) available to Whirlpool before income taxes for the twelve months ended December 31, 2024, and December 31, 2023, respectively, were also immaterial. | text | 34 | monetaryItemType | text: <entity> 34 </entity> <entity type> monetaryItemType </entity type> <context> On January 16, 2024, the Company entered into a share purchase agreement with a third-party buyer to sell the Company's Brastemp-branded water filtration subscription business in the Latin America region and the transaction closed on July 1, 2024. The Company received proceeds of approximately 294 million Brazilian reais (approximately $ 52 million at the date of transaction) and recorded a gain of approximately $ 34 million during the third quarter of 2024. The disposal group met the criteria of held for sale at December 31, 2023. The carrying amounts of the disposal group's assets and liabilities as of December 31, 2024 and December 31, 2023, respectively, were immaterial. The disposal group's earnings (loss) available to Whirlpool before income taxes for the twelve months ended December 31, 2024, and December 31, 2023, respectively, were also immaterial. </context> | us-gaap:GainLossOnSaleOfBusiness |
On February 20, 2024, the Company's wholly-owned subsidiary, Whirlpool Mauritius Limited ("Seller"), executed the sale of 30.4 million equity shares of Whirlpool India via an on-market trade. The sale, which was accounted for as an equity transaction, reduced Seller's ownership in Whirlpool India from 75 % to 51 %, and generated proceeds of $ 462 million on settlement. | text | 75 | percentItemType | text: <entity> 75 </entity> <entity type> percentItemType </entity type> <context> On February 20, 2024, the Company's wholly-owned subsidiary, Whirlpool Mauritius Limited ("Seller"), executed the sale of 30.4 million equity shares of Whirlpool India via an on-market trade. The sale, which was accounted for as an equity transaction, reduced Seller's ownership in Whirlpool India from 75 % to 51 %, and generated proceeds of $ 462 million on settlement. </context> | us-gaap:MinorityInterestOwnershipPercentageByParent |
On February 20, 2024, the Company's wholly-owned subsidiary, Whirlpool Mauritius Limited ("Seller"), executed the sale of 30.4 million equity shares of Whirlpool India via an on-market trade. The sale, which was accounted for as an equity transaction, reduced Seller's ownership in Whirlpool India from 75 % to 51 %, and generated proceeds of $ 462 million on settlement. | text | 51 | percentItemType | text: <entity> 51 </entity> <entity type> percentItemType </entity type> <context> On February 20, 2024, the Company's wholly-owned subsidiary, Whirlpool Mauritius Limited ("Seller"), executed the sale of 30.4 million equity shares of Whirlpool India via an on-market trade. The sale, which was accounted for as an equity transaction, reduced Seller's ownership in Whirlpool India from 75 % to 51 %, and generated proceeds of $ 462 million on settlement. </context> | us-gaap:MinorityInterestOwnershipPercentageByParent |
On February 20, 2024, the Company's wholly-owned subsidiary, Whirlpool Mauritius Limited ("Seller"), executed the sale of 30.4 million equity shares of Whirlpool India via an on-market trade. The sale, which was accounted for as an equity transaction, reduced Seller's ownership in Whirlpool India from 75 % to 51 %, and generated proceeds of $ 462 million on settlement. | text | 462 | monetaryItemType | text: <entity> 462 </entity> <entity type> monetaryItemType </entity type> <context> On February 20, 2024, the Company's wholly-owned subsidiary, Whirlpool Mauritius Limited ("Seller"), executed the sale of 30.4 million equity shares of Whirlpool India via an on-market trade. The sale, which was accounted for as an equity transaction, reduced Seller's ownership in Whirlpool India from 75 % to 51 %, and generated proceeds of $ 462 million on settlement. </context> | us-gaap:ProceedsFromMinorityShareholders |
On August 7, 2022, the Company entered into an Asset and Stock Purchase Agreement (the “Purchase Agreement”) with Emerson Electric Co. (“Emerson”) to purchase Emerson’s InSinkErator business, a manufacturer of food waste disposers and instant hot water dispensers for home and commercial use, for a purchase price of $ 3 billion in cash, subject to customary adjustments. | text | 3 | monetaryItemType | text: <entity> 3 </entity> <entity type> monetaryItemType </entity type> <context> On August 7, 2022, the Company entered into an Asset and Stock Purchase Agreement (the “Purchase Agreement”) with Emerson Electric Co. (“Emerson”) to purchase Emerson’s InSinkErator business, a manufacturer of food waste disposers and instant hot water dispensers for home and commercial use, for a purchase price of $ 3 billion in cash, subject to customary adjustments. </context> | us-gaap:PaymentsToAcquireBusinessesGross |
On October 31, 2022, we completed the acquisition of the InSinkErator business pursuant to the terms of the Purchase Agreement. We used the net proceeds from a $ 2.5 billion borrowing under our delayed draw term loan facility and $ 500 million of cash on hand to fund the acquisition. See Note 6 to the Consolidated Financial Statements for additional information about the term loan facility. | text | 2.5 | monetaryItemType | text: <entity> 2.5 </entity> <entity type> monetaryItemType </entity type> <context> On October 31, 2022, we completed the acquisition of the InSinkErator business pursuant to the terms of the Purchase Agreement. We used the net proceeds from a $ 2.5 billion borrowing under our delayed draw term loan facility and $ 500 million of cash on hand to fund the acquisition. See Note 6 to the Consolidated Financial Statements for additional information about the term loan facility. </context> | us-gaap:ProceedsFromIssuanceOfLongTermDebt |
Goodwill of $ 1.1 billion which is not deductible for tax purposes, arose from this transaction and is allocated to the MDA North America reportable segment, and consists of expected future economic benefits arising from expected future product sales, value creation opportunities, operating efficiencies and other synergies that might result from the acquisition. The allocation has been made on the basis that the anticipated synergies identified will primarily benefit this reportable segment. | text | 1.1 | monetaryItemType | text: <entity> 1.1 </entity> <entity type> monetaryItemType </entity type> <context> Goodwill of $ 1.1 billion which is not deductible for tax purposes, arose from this transaction and is allocated to the MDA North America reportable segment, and consists of expected future economic benefits arising from expected future product sales, value creation opportunities, operating efficiencies and other synergies that might result from the acquisition. The allocation has been made on the basis that the anticipated synergies identified will primarily benefit this reportable segment. </context> | us-gaap:Goodwill |
During the year ended December 31, 2022, we incurred transaction and other costs in connection with the acquisition of approximately $ 44 million which are included in Selling, general and administrative expense in our Consolidated Statements of Income (Loss). | text | 44 | monetaryItemType | text: <entity> 44 </entity> <entity type> monetaryItemType </entity type> <context> During the year ended December 31, 2022, we incurred transaction and other costs in connection with the acquisition of approximately $ 44 million which are included in Selling, general and administrative expense in our Consolidated Statements of Income (Loss). </context> | us-gaap:BusinessCombinationAcquisitionRelatedCosts |
On August 31, 2022, we completed the sale to Arcelik. The consideration includes contingent consideration based on future business and other conditions of the Russian operations. We will recognize the benefit of the contingent consideration when received due to the uncertainty in the Russian marketplace. Additionally, the contingent consideration is subject to a cap based on the agreed net asset value of the Russia business of € 261 million at closing (approximately $ 262 million at August 31, 2022). | text | 261 | monetaryItemType | text: <entity> 261 </entity> <entity type> monetaryItemType </entity type> <context> On August 31, 2022, we completed the sale to Arcelik. The consideration includes contingent consideration based on future business and other conditions of the Russian operations. We will recognize the benefit of the contingent consideration when received due to the uncertainty in the Russian marketplace. Additionally, the contingent consideration is subject to a cap based on the agreed net asset value of the Russia business of € 261 million at closing (approximately $ 262 million at August 31, 2022). </context> | us-gaap:ContingentConsiderationClassifiedAsEquityFairValueDisclosure |
On August 31, 2022, we completed the sale to Arcelik. The consideration includes contingent consideration based on future business and other conditions of the Russian operations. We will recognize the benefit of the contingent consideration when received due to the uncertainty in the Russian marketplace. Additionally, the contingent consideration is subject to a cap based on the agreed net asset value of the Russia business of € 261 million at closing (approximately $ 262 million at August 31, 2022). | text | 262 | monetaryItemType | text: <entity> 262 </entity> <entity type> monetaryItemType </entity type> <context> On August 31, 2022, we completed the sale to Arcelik. The consideration includes contingent consideration based on future business and other conditions of the Russian operations. We will recognize the benefit of the contingent consideration when received due to the uncertainty in the Russian marketplace. Additionally, the contingent consideration is subject to a cap based on the agreed net asset value of the Russia business of € 261 million at closing (approximately $ 262 million at August 31, 2022). </context> | us-gaap:ContingentConsiderationClassifiedAsEquityFairValueDisclosure |
In connection with the sale, we recorded a loss on disposal of $ 346 million in the second quarter of 2022. The loss included a charge of $ 333 million for the write-down of the net assets of the disposal group to fair value and $ 13 million of cumulative currency translation adjustments. On the closing date of August 31, 2022, we recorded an immaterial adjustment to the final loss amount, resulting in a total loss of $ 348 million for the nine months ended September 30, 2022. | text | 346 | monetaryItemType | text: <entity> 346 </entity> <entity type> monetaryItemType </entity type> <context> In connection with the sale, we recorded a loss on disposal of $ 346 million in the second quarter of 2022. The loss included a charge of $ 333 million for the write-down of the net assets of the disposal group to fair value and $ 13 million of cumulative currency translation adjustments. On the closing date of August 31, 2022, we recorded an immaterial adjustment to the final loss amount, resulting in a total loss of $ 348 million for the nine months ended September 30, 2022. </context> | us-gaap:GainLossOnSaleOfBusiness |
In connection with the sale, we recorded a loss on disposal of $ 346 million in the second quarter of 2022. The loss included a charge of $ 333 million for the write-down of the net assets of the disposal group to fair value and $ 13 million of cumulative currency translation adjustments. On the closing date of August 31, 2022, we recorded an immaterial adjustment to the final loss amount, resulting in a total loss of $ 348 million for the nine months ended September 30, 2022. | text | 333 | monetaryItemType | text: <entity> 333 </entity> <entity type> monetaryItemType </entity type> <context> In connection with the sale, we recorded a loss on disposal of $ 346 million in the second quarter of 2022. The loss included a charge of $ 333 million for the write-down of the net assets of the disposal group to fair value and $ 13 million of cumulative currency translation adjustments. On the closing date of August 31, 2022, we recorded an immaterial adjustment to the final loss amount, resulting in a total loss of $ 348 million for the nine months ended September 30, 2022. </context> | us-gaap:DisposalGroupNotDiscontinuedOperationLossGainOnWriteDown |
In connection with the sale, we recorded a loss on disposal of $ 346 million in the second quarter of 2022. The loss included a charge of $ 333 million for the write-down of the net assets of the disposal group to fair value and $ 13 million of cumulative currency translation adjustments. On the closing date of August 31, 2022, we recorded an immaterial adjustment to the final loss amount, resulting in a total loss of $ 348 million for the nine months ended September 30, 2022. | text | 13 | monetaryItemType | text: <entity> 13 </entity> <entity type> monetaryItemType </entity type> <context> In connection with the sale, we recorded a loss on disposal of $ 346 million in the second quarter of 2022. The loss included a charge of $ 333 million for the write-down of the net assets of the disposal group to fair value and $ 13 million of cumulative currency translation adjustments. On the closing date of August 31, 2022, we recorded an immaterial adjustment to the final loss amount, resulting in a total loss of $ 348 million for the nine months ended September 30, 2022. </context> | us-gaap:DisposalGroupIncludingDiscontinuedOperationForeignCurrencyTranslationGainsLosses |
In connection with the sale, we recorded a loss on disposal of $ 346 million in the second quarter of 2022. The loss included a charge of $ 333 million for the write-down of the net assets of the disposal group to fair value and $ 13 million of cumulative currency translation adjustments. On the closing date of August 31, 2022, we recorded an immaterial adjustment to the final loss amount, resulting in a total loss of $ 348 million for the nine months ended September 30, 2022. | text | 348 | monetaryItemType | text: <entity> 348 </entity> <entity type> monetaryItemType </entity type> <context> In connection with the sale, we recorded a loss on disposal of $ 346 million in the second quarter of 2022. The loss included a charge of $ 333 million for the write-down of the net assets of the disposal group to fair value and $ 13 million of cumulative currency translation adjustments. On the closing date of August 31, 2022, we recorded an immaterial adjustment to the final loss amount, resulting in a total loss of $ 348 million for the nine months ended September 30, 2022. </context> | us-gaap:GainLossOnSaleOfBusiness |
We present two reportable segments: Regulated Operations and ALLETE Clean Energy. Our segments were determined in accordance with the guidance on segment reporting. We measure performance of our operations through budgeting and monitoring of contributions to consolidated net income by each business segment. | text | two | integerItemType | text: <entity> two </entity> <entity type> integerItemType </entity type> <context> We present two reportable segments: Regulated Operations and ALLETE Clean Energy. Our segments were determined in accordance with the guidance on segment reporting. We measure performance of our operations through budgeting and monitoring of contributions to consolidated net income by each business segment. </context> | us-gaap:NumberOfReportableSegments |
Our investment in Nobles 2 represents a 49 percent equity interest in Nobles 2, the entity that owns and operates a 250 MW wind energy facility in southwestern Minnesota pursuant to a 20 -year PPA with Minnesota Power. | text | 49 | percentItemType | text: <entity> 49 </entity> <entity type> percentItemType </entity type> <context> Our investment in Nobles 2 represents a 49 percent equity interest in Nobles 2, the entity that owns and operates a 250 MW wind energy facility in southwestern Minnesota pursuant to a 20 -year PPA with Minnesota Power. </context> | us-gaap:EquityMethodInvestmentOwnershipPercentage |
BNI Energy mines and sells lignite coal to two North Dakota mine-mouth generating units, one of which is Square Butte. In 2024, Square Butte supplied 50 percent ( 227.5 MW) of its output to Minnesota Power under long-term contracts. (See Note 9. Commitments, Guarantees and Contingencies.) | text | 50 | percentItemType | text: <entity> 50 </entity> <entity type> percentItemType </entity type> <context> BNI Energy mines and sells lignite coal to two North Dakota mine-mouth generating units, one of which is Square Butte. In 2024, Square Butte supplied 50 percent ( 227.5 MW) of its output to Minnesota Power under long-term contracts. (See Note 9. Commitments, Guarantees and Contingencies.) </context> | us-gaap:LongTermContractForPurchaseOfElectricPowerShareOfPlantOutputBeingPurchased |
We are subject to concentration of credit risk primarily as a result of accounts receivable. Minnesota Power sells electricity to eight Large Power Customers. Receivables from these customers totaled $ 13.3 million as of December 31, 2024 ($ 11.2 million as of December 31, 2023). Minnesota Power does not obtain collateral to support utility receivables, but monitors the credit standing of major customers. In addition, Minnesota Power, as permitted by the MPUC, requires its taconite-producing Large Power Customers to pay weekly for electric usage based on monthly energy usage estimates, which allows us to closely manage collection of amounts due. Minnesota Power’s taconite customers, which are currently owned by two entities at the end of 2024, accounted for 33 percent of Regulated Operations operating revenue and 27 percent of consolidated operating revenue in 2024 ( 32 percent of Regulated Operations operating revenue and 21 percent of consolidated operating revenue in 2023 and 32 percent of Regulated Operations operating revenue and 26 percent of consolidated operating revenue in 2022). | text | 13.3 | monetaryItemType | text: <entity> 13.3 </entity> <entity type> monetaryItemType </entity type> <context> We are subject to concentration of credit risk primarily as a result of accounts receivable. Minnesota Power sells electricity to eight Large Power Customers. Receivables from these customers totaled $ 13.3 million as of December 31, 2024 ($ 11.2 million as of December 31, 2023). Minnesota Power does not obtain collateral to support utility receivables, but monitors the credit standing of major customers. In addition, Minnesota Power, as permitted by the MPUC, requires its taconite-producing Large Power Customers to pay weekly for electric usage based on monthly energy usage estimates, which allows us to closely manage collection of amounts due. Minnesota Power’s taconite customers, which are currently owned by two entities at the end of 2024, accounted for 33 percent of Regulated Operations operating revenue and 27 percent of consolidated operating revenue in 2024 ( 32 percent of Regulated Operations operating revenue and 21 percent of consolidated operating revenue in 2023 and 32 percent of Regulated Operations operating revenue and 26 percent of consolidated operating revenue in 2022). </context> | us-gaap:AccountsReceivableGross |
We are subject to concentration of credit risk primarily as a result of accounts receivable. Minnesota Power sells electricity to eight Large Power Customers. Receivables from these customers totaled $ 13.3 million as of December 31, 2024 ($ 11.2 million as of December 31, 2023). Minnesota Power does not obtain collateral to support utility receivables, but monitors the credit standing of major customers. In addition, Minnesota Power, as permitted by the MPUC, requires its taconite-producing Large Power Customers to pay weekly for electric usage based on monthly energy usage estimates, which allows us to closely manage collection of amounts due. Minnesota Power’s taconite customers, which are currently owned by two entities at the end of 2024, accounted for 33 percent of Regulated Operations operating revenue and 27 percent of consolidated operating revenue in 2024 ( 32 percent of Regulated Operations operating revenue and 21 percent of consolidated operating revenue in 2023 and 32 percent of Regulated Operations operating revenue and 26 percent of consolidated operating revenue in 2022). | text | 11.2 | monetaryItemType | text: <entity> 11.2 </entity> <entity type> monetaryItemType </entity type> <context> We are subject to concentration of credit risk primarily as a result of accounts receivable. Minnesota Power sells electricity to eight Large Power Customers. Receivables from these customers totaled $ 13.3 million as of December 31, 2024 ($ 11.2 million as of December 31, 2023). Minnesota Power does not obtain collateral to support utility receivables, but monitors the credit standing of major customers. In addition, Minnesota Power, as permitted by the MPUC, requires its taconite-producing Large Power Customers to pay weekly for electric usage based on monthly energy usage estimates, which allows us to closely manage collection of amounts due. Minnesota Power’s taconite customers, which are currently owned by two entities at the end of 2024, accounted for 33 percent of Regulated Operations operating revenue and 27 percent of consolidated operating revenue in 2024 ( 32 percent of Regulated Operations operating revenue and 21 percent of consolidated operating revenue in 2023 and 32 percent of Regulated Operations operating revenue and 26 percent of consolidated operating revenue in 2022). </context> | us-gaap:AccountsReceivableGross |
We are subject to concentration of credit risk primarily as a result of accounts receivable. Minnesota Power sells electricity to eight Large Power Customers. Receivables from these customers totaled $ 13.3 million as of December 31, 2024 ($ 11.2 million as of December 31, 2023). Minnesota Power does not obtain collateral to support utility receivables, but monitors the credit standing of major customers. In addition, Minnesota Power, as permitted by the MPUC, requires its taconite-producing Large Power Customers to pay weekly for electric usage based on monthly energy usage estimates, which allows us to closely manage collection of amounts due. Minnesota Power’s taconite customers, which are currently owned by two entities at the end of 2024, accounted for 33 percent of Regulated Operations operating revenue and 27 percent of consolidated operating revenue in 2024 ( 32 percent of Regulated Operations operating revenue and 21 percent of consolidated operating revenue in 2023 and 32 percent of Regulated Operations operating revenue and 26 percent of consolidated operating revenue in 2022). | text | 33 | percentItemType | text: <entity> 33 </entity> <entity type> percentItemType </entity type> <context> We are subject to concentration of credit risk primarily as a result of accounts receivable. Minnesota Power sells electricity to eight Large Power Customers. Receivables from these customers totaled $ 13.3 million as of December 31, 2024 ($ 11.2 million as of December 31, 2023). Minnesota Power does not obtain collateral to support utility receivables, but monitors the credit standing of major customers. In addition, Minnesota Power, as permitted by the MPUC, requires its taconite-producing Large Power Customers to pay weekly for electric usage based on monthly energy usage estimates, which allows us to closely manage collection of amounts due. Minnesota Power’s taconite customers, which are currently owned by two entities at the end of 2024, accounted for 33 percent of Regulated Operations operating revenue and 27 percent of consolidated operating revenue in 2024 ( 32 percent of Regulated Operations operating revenue and 21 percent of consolidated operating revenue in 2023 and 32 percent of Regulated Operations operating revenue and 26 percent of consolidated operating revenue in 2022). </context> | us-gaap:ConcentrationRiskPercentage1 |
We are subject to concentration of credit risk primarily as a result of accounts receivable. Minnesota Power sells electricity to eight Large Power Customers. Receivables from these customers totaled $ 13.3 million as of December 31, 2024 ($ 11.2 million as of December 31, 2023). Minnesota Power does not obtain collateral to support utility receivables, but monitors the credit standing of major customers. In addition, Minnesota Power, as permitted by the MPUC, requires its taconite-producing Large Power Customers to pay weekly for electric usage based on monthly energy usage estimates, which allows us to closely manage collection of amounts due. Minnesota Power’s taconite customers, which are currently owned by two entities at the end of 2024, accounted for 33 percent of Regulated Operations operating revenue and 27 percent of consolidated operating revenue in 2024 ( 32 percent of Regulated Operations operating revenue and 21 percent of consolidated operating revenue in 2023 and 32 percent of Regulated Operations operating revenue and 26 percent of consolidated operating revenue in 2022). | text | 27 | percentItemType | text: <entity> 27 </entity> <entity type> percentItemType </entity type> <context> We are subject to concentration of credit risk primarily as a result of accounts receivable. Minnesota Power sells electricity to eight Large Power Customers. Receivables from these customers totaled $ 13.3 million as of December 31, 2024 ($ 11.2 million as of December 31, 2023). Minnesota Power does not obtain collateral to support utility receivables, but monitors the credit standing of major customers. In addition, Minnesota Power, as permitted by the MPUC, requires its taconite-producing Large Power Customers to pay weekly for electric usage based on monthly energy usage estimates, which allows us to closely manage collection of amounts due. Minnesota Power’s taconite customers, which are currently owned by two entities at the end of 2024, accounted for 33 percent of Regulated Operations operating revenue and 27 percent of consolidated operating revenue in 2024 ( 32 percent of Regulated Operations operating revenue and 21 percent of consolidated operating revenue in 2023 and 32 percent of Regulated Operations operating revenue and 26 percent of consolidated operating revenue in 2022). </context> | us-gaap:ConcentrationRiskPercentage1 |
We are subject to concentration of credit risk primarily as a result of accounts receivable. Minnesota Power sells electricity to eight Large Power Customers. Receivables from these customers totaled $ 13.3 million as of December 31, 2024 ($ 11.2 million as of December 31, 2023). Minnesota Power does not obtain collateral to support utility receivables, but monitors the credit standing of major customers. In addition, Minnesota Power, as permitted by the MPUC, requires its taconite-producing Large Power Customers to pay weekly for electric usage based on monthly energy usage estimates, which allows us to closely manage collection of amounts due. Minnesota Power’s taconite customers, which are currently owned by two entities at the end of 2024, accounted for 33 percent of Regulated Operations operating revenue and 27 percent of consolidated operating revenue in 2024 ( 32 percent of Regulated Operations operating revenue and 21 percent of consolidated operating revenue in 2023 and 32 percent of Regulated Operations operating revenue and 26 percent of consolidated operating revenue in 2022). | text | 32 | percentItemType | text: <entity> 32 </entity> <entity type> percentItemType </entity type> <context> We are subject to concentration of credit risk primarily as a result of accounts receivable. Minnesota Power sells electricity to eight Large Power Customers. Receivables from these customers totaled $ 13.3 million as of December 31, 2024 ($ 11.2 million as of December 31, 2023). Minnesota Power does not obtain collateral to support utility receivables, but monitors the credit standing of major customers. In addition, Minnesota Power, as permitted by the MPUC, requires its taconite-producing Large Power Customers to pay weekly for electric usage based on monthly energy usage estimates, which allows us to closely manage collection of amounts due. Minnesota Power’s taconite customers, which are currently owned by two entities at the end of 2024, accounted for 33 percent of Regulated Operations operating revenue and 27 percent of consolidated operating revenue in 2024 ( 32 percent of Regulated Operations operating revenue and 21 percent of consolidated operating revenue in 2023 and 32 percent of Regulated Operations operating revenue and 26 percent of consolidated operating revenue in 2022). </context> | us-gaap:ConcentrationRiskPercentage1 |
We are subject to concentration of credit risk primarily as a result of accounts receivable. Minnesota Power sells electricity to eight Large Power Customers. Receivables from these customers totaled $ 13.3 million as of December 31, 2024 ($ 11.2 million as of December 31, 2023). Minnesota Power does not obtain collateral to support utility receivables, but monitors the credit standing of major customers. In addition, Minnesota Power, as permitted by the MPUC, requires its taconite-producing Large Power Customers to pay weekly for electric usage based on monthly energy usage estimates, which allows us to closely manage collection of amounts due. Minnesota Power’s taconite customers, which are currently owned by two entities at the end of 2024, accounted for 33 percent of Regulated Operations operating revenue and 27 percent of consolidated operating revenue in 2024 ( 32 percent of Regulated Operations operating revenue and 21 percent of consolidated operating revenue in 2023 and 32 percent of Regulated Operations operating revenue and 26 percent of consolidated operating revenue in 2022). | text | 21 | percentItemType | text: <entity> 21 </entity> <entity type> percentItemType </entity type> <context> We are subject to concentration of credit risk primarily as a result of accounts receivable. Minnesota Power sells electricity to eight Large Power Customers. Receivables from these customers totaled $ 13.3 million as of December 31, 2024 ($ 11.2 million as of December 31, 2023). Minnesota Power does not obtain collateral to support utility receivables, but monitors the credit standing of major customers. In addition, Minnesota Power, as permitted by the MPUC, requires its taconite-producing Large Power Customers to pay weekly for electric usage based on monthly energy usage estimates, which allows us to closely manage collection of amounts due. Minnesota Power’s taconite customers, which are currently owned by two entities at the end of 2024, accounted for 33 percent of Regulated Operations operating revenue and 27 percent of consolidated operating revenue in 2024 ( 32 percent of Regulated Operations operating revenue and 21 percent of consolidated operating revenue in 2023 and 32 percent of Regulated Operations operating revenue and 26 percent of consolidated operating revenue in 2022). </context> | us-gaap:ConcentrationRiskPercentage1 |
We are subject to concentration of credit risk primarily as a result of accounts receivable. Minnesota Power sells electricity to eight Large Power Customers. Receivables from these customers totaled $ 13.3 million as of December 31, 2024 ($ 11.2 million as of December 31, 2023). Minnesota Power does not obtain collateral to support utility receivables, but monitors the credit standing of major customers. In addition, Minnesota Power, as permitted by the MPUC, requires its taconite-producing Large Power Customers to pay weekly for electric usage based on monthly energy usage estimates, which allows us to closely manage collection of amounts due. Minnesota Power’s taconite customers, which are currently owned by two entities at the end of 2024, accounted for 33 percent of Regulated Operations operating revenue and 27 percent of consolidated operating revenue in 2024 ( 32 percent of Regulated Operations operating revenue and 21 percent of consolidated operating revenue in 2023 and 32 percent of Regulated Operations operating revenue and 26 percent of consolidated operating revenue in 2022). | text | 26 | percentItemType | text: <entity> 26 </entity> <entity type> percentItemType </entity type> <context> We are subject to concentration of credit risk primarily as a result of accounts receivable. Minnesota Power sells electricity to eight Large Power Customers. Receivables from these customers totaled $ 13.3 million as of December 31, 2024 ($ 11.2 million as of December 31, 2023). Minnesota Power does not obtain collateral to support utility receivables, but monitors the credit standing of major customers. In addition, Minnesota Power, as permitted by the MPUC, requires its taconite-producing Large Power Customers to pay weekly for electric usage based on monthly energy usage estimates, which allows us to closely manage collection of amounts due. Minnesota Power’s taconite customers, which are currently owned by two entities at the end of 2024, accounted for 33 percent of Regulated Operations operating revenue and 27 percent of consolidated operating revenue in 2024 ( 32 percent of Regulated Operations operating revenue and 21 percent of consolidated operating revenue in 2023 and 32 percent of Regulated Operations operating revenue and 26 percent of consolidated operating revenue in 2022). </context> | us-gaap:ConcentrationRiskPercentage1 |
Prepayments and Other on the Consolidated Balance Sheet included $ 32.4 million of costs in excess of billings at New Energy as of December 31, 2024 ($ 21.5 million as of December 31, 2023). | text | 32.4 | monetaryItemType | text: <entity> 32.4 </entity> <entity type> monetaryItemType </entity type> <context> Prepayments and Other on the Consolidated Balance Sheet included $ 32.4 million of costs in excess of billings at New Energy as of December 31, 2024 ($ 21.5 million as of December 31, 2023). </context> | us-gaap:OtherAssetsCurrent |
Prepayments and Other on the Consolidated Balance Sheet included $ 32.4 million of costs in excess of billings at New Energy as of December 31, 2024 ($ 21.5 million as of December 31, 2023). | text | 21.5 | monetaryItemType | text: <entity> 21.5 </entity> <entity type> monetaryItemType </entity type> <context> Prepayments and Other on the Consolidated Balance Sheet included $ 32.4 million of costs in excess of billings at New Energy as of December 31, 2024 ($ 21.5 million as of December 31, 2023). </context> | us-gaap:OtherAssetsCurrent |
(a) The asset retirement obligation is primarily related to our Regulated Operations and is funded through customer rates over the life of the related assets. Additionally, BNI Energy funds its obligation through its cost-plus coal supply agreements for which BNI Energy has recorded a receivable of $ 42.3 million in Other Non-Current Assets on the Consolidated Balance Sheet as of December 31, 2024 ($ 37.2 million as of December 31, 2023). | text | 42.3 | monetaryItemType | text: <entity> 42.3 </entity> <entity type> monetaryItemType </entity type> <context> (a) The asset retirement obligation is primarily related to our Regulated Operations and is funded through customer rates over the life of the related assets. Additionally, BNI Energy funds its obligation through its cost-plus coal supply agreements for which BNI Energy has recorded a receivable of $ 42.3 million in Other Non-Current Assets on the Consolidated Balance Sheet as of December 31, 2024 ($ 37.2 million as of December 31, 2023). </context> | us-gaap:OtherReceivables |
(a) The asset retirement obligation is primarily related to our Regulated Operations and is funded through customer rates over the life of the related assets. Additionally, BNI Energy funds its obligation through its cost-plus coal supply agreements for which BNI Energy has recorded a receivable of $ 42.3 million in Other Non-Current Assets on the Consolidated Balance Sheet as of December 31, 2024 ($ 37.2 million as of December 31, 2023). | text | 37.2 | monetaryItemType | text: <entity> 37.2 </entity> <entity type> monetaryItemType </entity type> <context> (a) The asset retirement obligation is primarily related to our Regulated Operations and is funded through customer rates over the life of the related assets. Additionally, BNI Energy funds its obligation through its cost-plus coal supply agreements for which BNI Energy has recorded a receivable of $ 42.3 million in Other Non-Current Assets on the Consolidated Balance Sheet as of December 31, 2024 ($ 37.2 million as of December 31, 2023). </context> | us-gaap:OtherReceivables |
The majority of our operating leases are for heavy equipment, vehicles and land with fixed monthly payments which we group into two categories: Vehicles and Equipment; and Land and Other. Our largest operating lease is for the drag line at BNI Energy which includes a termination payment at the end of the lease term if we do not exercise our purchase option. The amount of this payment is $ 3 million and is included in our calculation of the right-of-use asset and lease liability recorded. None of our other leases contain residual value guarantees. We have one finance lease for heavy equipment which includes a purchase option we are reasonably certain to exercise when the lease terminates. | text | 3 | monetaryItemType | text: <entity> 3 </entity> <entity type> monetaryItemType </entity type> <context> The majority of our operating leases are for heavy equipment, vehicles and land with fixed monthly payments which we group into two categories: Vehicles and Equipment; and Land and Other. Our largest operating lease is for the drag line at BNI Energy which includes a termination payment at the end of the lease term if we do not exercise our purchase option. The amount of this payment is $ 3 million and is included in our calculation of the right-of-use asset and lease liability recorded. None of our other leases contain residual value guarantees. We have one finance lease for heavy equipment which includes a purchase option we are reasonably certain to exercise when the lease terminates. </context> | us-gaap:ResidualValueOfLeasedAsset |
includes sales recognized from contracts with customers in the taconite mining, paper, pulp and secondary wood products, pipeline and other industries. Industrial sales accounted for approximately 56 percent of total regulated utility kWh sales for the year ended December 31, 2024. Within industrial revenue, Minnesota Power had eight Large Power Customer contracts, each serving requirements of 10 MW or more of customer load as of December 31, 2024. These contracts automatically renew past the contract term unless a four-year written notice is given. Large Power Customer contracts have earliest termination dates ranging from 2028 through 2029. We satisfy our performance obligations for these customers at the time energy is delivered to an agreed upon customer substation. Revenue is accrued for energy provided but not yet billed at period end. Based on current contracts with industrial customers, we expect to recognize minimum revenue for the fixed contract components of approximately $ 60 million per annum through 2028 and approximately $ 10 million in 2029, which reflects the termination notice period in these contracts. When determining minimum revenue, we assume that customer contracts will continue under the contract renewal provision; however, if long-term contracts are renegotiated and subsequently approved by the MPUC or there are changes within our industrial customer class, these amounts may be impacted. Contracts with customers that contain variable pricing or quantity components are excluded from the expected minimum revenue amounts. | text | 60 | monetaryItemType | text: <entity> 60 </entity> <entity type> monetaryItemType </entity type> <context> includes sales recognized from contracts with customers in the taconite mining, paper, pulp and secondary wood products, pipeline and other industries. Industrial sales accounted for approximately 56 percent of total regulated utility kWh sales for the year ended December 31, 2024. Within industrial revenue, Minnesota Power had eight Large Power Customer contracts, each serving requirements of 10 MW or more of customer load as of December 31, 2024. These contracts automatically renew past the contract term unless a four-year written notice is given. Large Power Customer contracts have earliest termination dates ranging from 2028 through 2029. We satisfy our performance obligations for these customers at the time energy is delivered to an agreed upon customer substation. Revenue is accrued for energy provided but not yet billed at period end. Based on current contracts with industrial customers, we expect to recognize minimum revenue for the fixed contract components of approximately $ 60 million per annum through 2028 and approximately $ 10 million in 2029, which reflects the termination notice period in these contracts. When determining minimum revenue, we assume that customer contracts will continue under the contract renewal provision; however, if long-term contracts are renegotiated and subsequently approved by the MPUC or there are changes within our industrial customer class, these amounts may be impacted. Contracts with customers that contain variable pricing or quantity components are excluded from the expected minimum revenue amounts. </context> | us-gaap:RevenueRemainingPerformanceObligation |
includes sales recognized from contracts with customers in the taconite mining, paper, pulp and secondary wood products, pipeline and other industries. Industrial sales accounted for approximately 56 percent of total regulated utility kWh sales for the year ended December 31, 2024. Within industrial revenue, Minnesota Power had eight Large Power Customer contracts, each serving requirements of 10 MW or more of customer load as of December 31, 2024. These contracts automatically renew past the contract term unless a four-year written notice is given. Large Power Customer contracts have earliest termination dates ranging from 2028 through 2029. We satisfy our performance obligations for these customers at the time energy is delivered to an agreed upon customer substation. Revenue is accrued for energy provided but not yet billed at period end. Based on current contracts with industrial customers, we expect to recognize minimum revenue for the fixed contract components of approximately $ 60 million per annum through 2028 and approximately $ 10 million in 2029, which reflects the termination notice period in these contracts. When determining minimum revenue, we assume that customer contracts will continue under the contract renewal provision; however, if long-term contracts are renegotiated and subsequently approved by the MPUC or there are changes within our industrial customer class, these amounts may be impacted. Contracts with customers that contain variable pricing or quantity components are excluded from the expected minimum revenue amounts. | text | 10 | monetaryItemType | text: <entity> 10 </entity> <entity type> monetaryItemType </entity type> <context> includes sales recognized from contracts with customers in the taconite mining, paper, pulp and secondary wood products, pipeline and other industries. Industrial sales accounted for approximately 56 percent of total regulated utility kWh sales for the year ended December 31, 2024. Within industrial revenue, Minnesota Power had eight Large Power Customer contracts, each serving requirements of 10 MW or more of customer load as of December 31, 2024. These contracts automatically renew past the contract term unless a four-year written notice is given. Large Power Customer contracts have earliest termination dates ranging from 2028 through 2029. We satisfy our performance obligations for these customers at the time energy is delivered to an agreed upon customer substation. Revenue is accrued for energy provided but not yet billed at period end. Based on current contracts with industrial customers, we expect to recognize minimum revenue for the fixed contract components of approximately $ 60 million per annum through 2028 and approximately $ 10 million in 2029, which reflects the termination notice period in these contracts. When determining minimum revenue, we assume that customer contracts will continue under the contract renewal provision; however, if long-term contracts are renegotiated and subsequently approved by the MPUC or there are changes within our industrial customer class, these amounts may be impacted. Contracts with customers that contain variable pricing or quantity components are excluded from the expected minimum revenue amounts. </context> | us-gaap:RevenueRemainingPerformanceObligation |
We recognize as an asset the incremental costs of obtaining a contract with a customer if we expect the benefit of those costs to be longer than one year. We expense incremental costs when the asset that would have resulted from capitalizing these costs would have been amortized in one year or less. As of December 31, 2024, we have $ 15.9 million of assets recognized for costs incurred to obtain contracts with our customers ($ 18.5 million as of December 31, 2023). Management determined the amount of costs to be recognized as assets based on actual costs incurred and paid to obtain and fulfill these contracts to provide goods and services to our customers. Assets recognized to obtain contracts are amortized on a straight-line basis over the contract term as a non-cash reduction to revenue. We recognized $ 2.4 million of non-cash amortization for the year ended December 31, 2024 ($ 2.4 million for the year ended December 31, 2023). | text | 15.9 | monetaryItemType | text: <entity> 15.9 </entity> <entity type> monetaryItemType </entity type> <context> We recognize as an asset the incremental costs of obtaining a contract with a customer if we expect the benefit of those costs to be longer than one year. We expense incremental costs when the asset that would have resulted from capitalizing these costs would have been amortized in one year or less. As of December 31, 2024, we have $ 15.9 million of assets recognized for costs incurred to obtain contracts with our customers ($ 18.5 million as of December 31, 2023). Management determined the amount of costs to be recognized as assets based on actual costs incurred and paid to obtain and fulfill these contracts to provide goods and services to our customers. Assets recognized to obtain contracts are amortized on a straight-line basis over the contract term as a non-cash reduction to revenue. We recognized $ 2.4 million of non-cash amortization for the year ended December 31, 2024 ($ 2.4 million for the year ended December 31, 2023). </context> | us-gaap:ContractWithCustomerAssetNetNoncurrent |
We recognize as an asset the incremental costs of obtaining a contract with a customer if we expect the benefit of those costs to be longer than one year. We expense incremental costs when the asset that would have resulted from capitalizing these costs would have been amortized in one year or less. As of December 31, 2024, we have $ 15.9 million of assets recognized for costs incurred to obtain contracts with our customers ($ 18.5 million as of December 31, 2023). Management determined the amount of costs to be recognized as assets based on actual costs incurred and paid to obtain and fulfill these contracts to provide goods and services to our customers. Assets recognized to obtain contracts are amortized on a straight-line basis over the contract term as a non-cash reduction to revenue. We recognized $ 2.4 million of non-cash amortization for the year ended December 31, 2024 ($ 2.4 million for the year ended December 31, 2023). | text | 18.5 | monetaryItemType | text: <entity> 18.5 </entity> <entity type> monetaryItemType </entity type> <context> We recognize as an asset the incremental costs of obtaining a contract with a customer if we expect the benefit of those costs to be longer than one year. We expense incremental costs when the asset that would have resulted from capitalizing these costs would have been amortized in one year or less. As of December 31, 2024, we have $ 15.9 million of assets recognized for costs incurred to obtain contracts with our customers ($ 18.5 million as of December 31, 2023). Management determined the amount of costs to be recognized as assets based on actual costs incurred and paid to obtain and fulfill these contracts to provide goods and services to our customers. Assets recognized to obtain contracts are amortized on a straight-line basis over the contract term as a non-cash reduction to revenue. We recognized $ 2.4 million of non-cash amortization for the year ended December 31, 2024 ($ 2.4 million for the year ended December 31, 2023). </context> | us-gaap:ContractWithCustomerAssetNetNoncurrent |
We recognize as an asset the incremental costs of obtaining a contract with a customer if we expect the benefit of those costs to be longer than one year. We expense incremental costs when the asset that would have resulted from capitalizing these costs would have been amortized in one year or less. As of December 31, 2024, we have $ 15.9 million of assets recognized for costs incurred to obtain contracts with our customers ($ 18.5 million as of December 31, 2023). Management determined the amount of costs to be recognized as assets based on actual costs incurred and paid to obtain and fulfill these contracts to provide goods and services to our customers. Assets recognized to obtain contracts are amortized on a straight-line basis over the contract term as a non-cash reduction to revenue. We recognized $ 2.4 million of non-cash amortization for the year ended December 31, 2024 ($ 2.4 million for the year ended December 31, 2023). | text | 2.4 | monetaryItemType | text: <entity> 2.4 </entity> <entity type> monetaryItemType </entity type> <context> We recognize as an asset the incremental costs of obtaining a contract with a customer if we expect the benefit of those costs to be longer than one year. We expense incremental costs when the asset that would have resulted from capitalizing these costs would have been amortized in one year or less. As of December 31, 2024, we have $ 15.9 million of assets recognized for costs incurred to obtain contracts with our customers ($ 18.5 million as of December 31, 2023). Management determined the amount of costs to be recognized as assets based on actual costs incurred and paid to obtain and fulfill these contracts to provide goods and services to our customers. Assets recognized to obtain contracts are amortized on a straight-line basis over the contract term as a non-cash reduction to revenue. We recognized $ 2.4 million of non-cash amortization for the year ended December 31, 2024 ($ 2.4 million for the year ended December 31, 2023). </context> | us-gaap:CapitalizedContractCostAmortization |
Interest and Investment Income for the year ended December 31, 2023, reflects $ 5.1 million of interest income related to interest awarded as part of an arbitration ruling involving a subsidiary of ALLETE Clean Energy. (See Note 9. Commitments, Guarantees and Contingencies.) | text | 5.1 | monetaryItemType | text: <entity> 5.1 </entity> <entity type> monetaryItemType </entity type> <context> Interest and Investment Income for the year ended December 31, 2023, reflects $ 5.1 million of interest income related to interest awarded as part of an arbitration ruling involving a subsidiary of ALLETE Clean Energy. (See Note 9. Commitments, Guarantees and Contingencies.) </context> | us-gaap:OtherNonoperatingIncomeExpense |
Minnesota Power owns 80 percent of the 585 MW Boswell Unit 4. While Minnesota Power operates the plant, certain decisions about the operations of Boswell Unit 4 are subject to the oversight of a committee on which it and WPPI Energy, the owner of the remaining 20 percent, have equal representation and voting rights. Each owner must provide its own financing and is obligated to its ownership share of operating costs. Minnesota Power’s share of operating expenses for Boswell Unit 4 is included in Operating Expenses on the Consolidated Statement of Income. | text | 80 | percentItemType | text: <entity> 80 </entity> <entity type> percentItemType </entity type> <context> Minnesota Power owns 80 percent of the 585 MW Boswell Unit 4. While Minnesota Power operates the plant, certain decisions about the operations of Boswell Unit 4 are subject to the oversight of a committee on which it and WPPI Energy, the owner of the remaining 20 percent, have equal representation and voting rights. Each owner must provide its own financing and is obligated to its ownership share of operating costs. Minnesota Power’s share of operating expenses for Boswell Unit 4 is included in Operating Expenses on the Consolidated Statement of Income. </context> | us-gaap:JointlyOwnedUtilityPlantProportionateOwnershipShare |
South Shore Energy, ALLETE’s non-rate regulated, Wisconsin subsidiary, is developing NTEC, an approximately 600 MW proposed combined-cycle natural gas-fired generating facility to be built in Superior, Wisconsin, which will be jointly owned by Dairyland Power Cooperative, Basin and South Shore Energy. Minnesota Power is expected to purchase approximately 20 percent of the facility's output starting upon completion of the facility pursuant to a capacity dedication agreement. Construction of NTEC is subject to obtaining additional permits from local, state and federal authorities. The total project cost is estimated to be approximately $ 700 million, of which South Shore Energy will be responsible for approximately 20 percent. South Shore Energy’s portion of NTEC project costs incurred through December 31, 2024, is approximately $ 10 million. | text | 20 | percentItemType | text: <entity> 20 </entity> <entity type> percentItemType </entity type> <context> South Shore Energy, ALLETE’s non-rate regulated, Wisconsin subsidiary, is developing NTEC, an approximately 600 MW proposed combined-cycle natural gas-fired generating facility to be built in Superior, Wisconsin, which will be jointly owned by Dairyland Power Cooperative, Basin and South Shore Energy. Minnesota Power is expected to purchase approximately 20 percent of the facility's output starting upon completion of the facility pursuant to a capacity dedication agreement. Construction of NTEC is subject to obtaining additional permits from local, state and federal authorities. The total project cost is estimated to be approximately $ 700 million, of which South Shore Energy will be responsible for approximately 20 percent. South Shore Energy’s portion of NTEC project costs incurred through December 31, 2024, is approximately $ 10 million. </context> | us-gaap:LongTermContractForPurchaseOfElectricPowerShareOfPlantOutputBeingPurchased |
.) Revenue from cost recovery riders was $ 20.0 million in 2024 ($ 57.0 million in 2023; $ 38.8 million in 2022). | text | 20.0 | monetaryItemType | text: <entity> 20.0 </entity> <entity type> monetaryItemType </entity type> <context> .) Revenue from cost recovery riders was $ 20.0 million in 2024 ($ 57.0 million in 2023; $ 38.8 million in 2022). </context> | us-gaap:RegulatedOperatingRevenueOther |
.) Revenue from cost recovery riders was $ 20.0 million in 2024 ($ 57.0 million in 2023; $ 38.8 million in 2022). | text | 57.0 | monetaryItemType | text: <entity> 57.0 </entity> <entity type> monetaryItemType </entity type> <context> .) Revenue from cost recovery riders was $ 20.0 million in 2024 ($ 57.0 million in 2023; $ 38.8 million in 2022). </context> | us-gaap:RegulatedOperatingRevenueOther |
.) Revenue from cost recovery riders was $ 20.0 million in 2024 ($ 57.0 million in 2023; $ 38.8 million in 2022). | text | 38.8 | monetaryItemType | text: <entity> 38.8 </entity> <entity type> monetaryItemType </entity type> <context> .) Revenue from cost recovery riders was $ 20.0 million in 2024 ($ 57.0 million in 2023; $ 38.8 million in 2022). </context> | us-gaap:RegulatedOperatingRevenueOther |
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 | text | 9.25 | percentItemType | text: <entity> 9.25 </entity> <entity type> percentItemType </entity type> <context> 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 </context> | us-gaap:PublicUtilitiesApprovedReturnOnEquityPercentage |
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 | text | 53.81 | percentItemType | text: <entity> 53.81 </entity> <entity type> percentItemType </entity type> <context> 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 </context> | us-gaap:PublicUtilitiesApprovedEquityCapitalStructurePercentage |
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 | text | 9.65 | percentItemType | text: <entity> 9.65 </entity> <entity type> percentItemType </entity type> <context> 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 </context> | us-gaap:PublicUtilitiesApprovedReturnOnEquityPercentage |
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 | text | 52.50 | percentItemType | text: <entity> 52.50 </entity> <entity type> percentItemType </entity type> <context> 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 </context> | us-gaap:PublicUtilitiesApprovedEquityCapitalStructurePercentage |
.) 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. | text | 9.78 | percentItemType | text: <entity> 9.78 </entity> <entity type> percentItemType </entity type> <context> .) 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. </context> | us-gaap:PublicUtilitiesRequestedReturnOnEquityPercentage |
.) 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. | text | 53.00 | percentItemType | text: <entity> 53.00 </entity> <entity type> percentItemType </entity type> <context> .) 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. </context> | us-gaap:PublicUtilitiesRequestedEquityCapitalStructurePercentage |
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. | text | 12.00 | percentItemType | text: <entity> 12.00 </entity> <entity type> percentItemType </entity type> <context> 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. </context> | us-gaap:PublicUtilitiesRequestedRateIncreaseDecreasePercentage |
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. | text | 10.30 | percentItemType | text: <entity> 10.30 </entity> <entity type> percentItemType </entity type> <context> 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. </context> | us-gaap:PublicUtilitiesRequestedReturnOnEquityPercentage |
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. | text | 53.00 | percentItemType | text: <entity> 53.00 </entity> <entity type> percentItemType </entity type> <context> 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. </context> | us-gaap:PublicUtilitiesRequestedEquityCapitalStructurePercentage |
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. | text | 89 | monetaryItemType | text: <entity> 89 </entity> <entity type> monetaryItemType </entity type> <context> 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. </context> | us-gaap:PublicUtilitiesRequestedRateIncreaseDecreaseAmount |
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. | text | 64 | monetaryItemType | text: <entity> 64 </entity> <entity type> monetaryItemType </entity type> <context> 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. </context> | us-gaap:PublicUtilitiesRequestedRateIncreaseDecreaseAmount |
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. | text | 33.97 | monetaryItemType | text: <entity> 33.97 </entity> <entity type> monetaryItemType </entity type> <context> 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. </context> | us-gaap:PublicUtilitiesRequestedRateIncreaseDecreaseAmount |
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. | text | 9.78 | percentItemType | text: <entity> 9.78 </entity> <entity type> percentItemType </entity type> <context> 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. </context> | us-gaap:PublicUtilitiesRequestedReturnOnEquityPercentage |
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. | text | 53.00 | percentItemType | text: <entity> 53.00 </entity> <entity type> percentItemType </entity type> <context> 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. </context> | us-gaap:PublicUtilitiesRequestedEquityCapitalStructurePercentage |
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. | text | 23.0 | monetaryItemType | text: <entity> 23.0 </entity> <entity type> monetaryItemType </entity type> <context> 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. </context> | us-gaap:RegulatoryLiabilities |
. 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. | text | 9.65 | percentItemType | text: <entity> 9.65 </entity> <entity type> percentItemType </entity type> <context> . 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. </context> | us-gaap:PublicUtilitiesApprovedReturnOnEquityPercentage |
. 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. | text | 52.50 | percentItemType | text: <entity> 52.50 </entity> <entity type> percentItemType </entity type> <context> . 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. </context> | us-gaap:PublicUtilitiesApprovedEquityCapitalStructurePercentage |
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. | text | 39 | monetaryItemType | text: <entity> 39 </entity> <entity type> monetaryItemType </entity type> <context> 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. </context> | us-gaap:CustomerRefundLiabilityCurrent |
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. | text | 18 | monetaryItemType | text: <entity> 18 </entity> <entity type> monetaryItemType </entity type> <context> 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. </context> | us-gaap:CustomerRefundLiabilityCurrent |
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. | text | 13 | monetaryItemType | text: <entity> 13 </entity> <entity type> monetaryItemType </entity type> <context> 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. </context> | us-gaap:RegulatoryAssetsNoncurrent |
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. | text | 15.5 | monetaryItemType | text: <entity> 15.5 </entity> <entity type> monetaryItemType </entity type> <context> 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. </context> | us-gaap:RegulatoryLiabilityNoncurrent |
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. | text | 4.5 | monetaryItemType | text: <entity> 4.5 </entity> <entity type> monetaryItemType </entity type> <context> 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. </context> | us-gaap:RegulatoryLiabilityNoncurrent |
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. | text | 4.2 | monetaryItemType | text: <entity> 4.2 </entity> <entity type> monetaryItemType </entity type> <context> 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. </context> | us-gaap:Depreciation |
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 | text | 10.40 | percentItemType | text: <entity> 10.40 </entity> <entity type> percentItemType </entity type> <context> 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 </context> | us-gaap:PublicUtilitiesRequestedReturnOnEquityPercentage |
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 | text | 55.00 | percentItemType | text: <entity> 55.00 </entity> <entity type> percentItemType </entity type> <context> 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 </context> | us-gaap:PublicUtilitiesRequestedEquityCapitalStructurePercentage |
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 | text | 10.00 | percentItemType | text: <entity> 10.00 </entity> <entity type> percentItemType </entity type> <context> 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 </context> | us-gaap:PublicUtilitiesApprovedReturnOnEquityPercentage |
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 | text | 55.00 | percentItemType | text: <entity> 55.00 </entity> <entity type> percentItemType </entity type> <context> 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 </context> | us-gaap:PublicUtilitiesApprovedEquityCapitalStructurePercentage |
.) 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 | text | 9.80 | percentItemType | text: <entity> 9.80 </entity> <entity type> percentItemType </entity type> <context> .) 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 </context> | us-gaap:PublicUtilitiesApprovedReturnOnEquityPercentage |
.) 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 | text | 55.00 | percentItemType | text: <entity> 55.00 </entity> <entity type> percentItemType </entity type> <context> .) 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 </context> | us-gaap:PublicUtilitiesApprovedEquityCapitalStructurePercentage |
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. | text | 10.00 | percentItemType | text: <entity> 10.00 </entity> <entity type> percentItemType </entity type> <context> 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. </context> | us-gaap:PublicUtilitiesRequestedReturnOnEquityPercentage |
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. | text | 55.00 | percentItemType | text: <entity> 55.00 </entity> <entity type> percentItemType </entity type> <context> 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. </context> | us-gaap:PublicUtilitiesRequestedEquityCapitalStructurePercentage |
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. | text | 5.90 | percentItemType | text: <entity> 5.90 </entity> <entity type> percentItemType </entity type> <context> 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. </context> | us-gaap:PublicUtilitiesRequestedRateIncreaseDecreasePercentage |
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. | text | 7.3 | monetaryItemType | text: <entity> 7.3 </entity> <entity type> monetaryItemType </entity type> <context> 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. </context> | us-gaap:PublicUtilitiesRequestedRateIncreaseDecreaseAmount |
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. | text | 5.5 | monetaryItemType | text: <entity> 5.5 </entity> <entity type> monetaryItemType </entity type> <context> 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. </context> | us-gaap:PublicUtilitiesApprovedRateIncreaseDecreaseAmount |
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. | text | 9.80 | percentItemType | text: <entity> 9.80 </entity> <entity type> percentItemType </entity type> <context> 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. </context> | us-gaap:PublicUtilitiesApprovedReturnOnEquityPercentage |
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. | text | 55.00 | percentItemType | text: <entity> 55.00 </entity> <entity type> percentItemType </entity type> <context> 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. </context> | us-gaap:PublicUtilitiesApprovedEquityCapitalStructurePercentage |
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. | text | 3.3 | monetaryItemType | text: <entity> 3.3 </entity> <entity type> monetaryItemType </entity type> <context> 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. </context> | us-gaap:PublicUtilitiesApprovedRateIncreaseDecreaseAmount |
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. | text | 10.00 | percentItemType | text: <entity> 10.00 </entity> <entity type> percentItemType </entity type> <context> 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. </context> | us-gaap:PublicUtilitiesApprovedReturnOnEquityPercentage |
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. | text | 55.00 | percentItemType | text: <entity> 55.00 </entity> <entity type> percentItemType </entity type> <context> 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. </context> | us-gaap:PublicUtilitiesApprovedEquityCapitalStructurePercentage |
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. | text | 2.2 | monetaryItemType | text: <entity> 2.2 </entity> <entity type> monetaryItemType </entity type> <context> 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. </context> | us-gaap:RegulatedOperatingRevenueOther |
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. | text | 1.9 | monetaryItemType | text: <entity> 1.9 </entity> <entity type> monetaryItemType </entity type> <context> 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. </context> | us-gaap:RegulatedOperatingRevenueOther |
On April 15, 2022, a wholly-owned subsidiary of ALLETE acquired 100 percent of the membership interests of New Energy for a purchase price of $ 165.5 million. Total consideration of approximately $ 158.8 million was paid in cash on the acquisition date, which is net of cash acquired and debt assumed. New Energy, which is headquartered in Annapolis, Maryland, is a renewable energy development company with a primary focus on solar and storage facilities while also offering comprehensive operations, maintenance and asset management services. The acquisition of New Energy is consistent with ALLETE’s stated strategy of additional investment in renewable energy and related infrastructure across North America to support the Company’s sustainability-in-action strategy while providing potential long-term earnings growth. | text | 100 | percentItemType | text: <entity> 100 </entity> <entity type> percentItemType </entity type> <context> On April 15, 2022, a wholly-owned subsidiary of ALLETE acquired 100 percent of the membership interests of New Energy for a purchase price of $ 165.5 million. Total consideration of approximately $ 158.8 million was paid in cash on the acquisition date, which is net of cash acquired and debt assumed. New Energy, which is headquartered in Annapolis, Maryland, is a renewable energy development company with a primary focus on solar and storage facilities while also offering comprehensive operations, maintenance and asset management services. The acquisition of New Energy is consistent with ALLETE’s stated strategy of additional investment in renewable energy and related infrastructure across North America to support the Company’s sustainability-in-action strategy while providing potential long-term earnings growth. </context> | us-gaap:BusinessAcquisitionPercentageOfVotingInterestsAcquired |
On April 15, 2022, a wholly-owned subsidiary of ALLETE acquired 100 percent of the membership interests of New Energy for a purchase price of $ 165.5 million. Total consideration of approximately $ 158.8 million was paid in cash on the acquisition date, which is net of cash acquired and debt assumed. New Energy, which is headquartered in Annapolis, Maryland, is a renewable energy development company with a primary focus on solar and storage facilities while also offering comprehensive operations, maintenance and asset management services. The acquisition of New Energy is consistent with ALLETE’s stated strategy of additional investment in renewable energy and related infrastructure across North America to support the Company’s sustainability-in-action strategy while providing potential long-term earnings growth. | text | 158.8 | monetaryItemType | text: <entity> 158.8 </entity> <entity type> monetaryItemType </entity type> <context> On April 15, 2022, a wholly-owned subsidiary of ALLETE acquired 100 percent of the membership interests of New Energy for a purchase price of $ 165.5 million. Total consideration of approximately $ 158.8 million was paid in cash on the acquisition date, which is net of cash acquired and debt assumed. New Energy, which is headquartered in Annapolis, Maryland, is a renewable energy development company with a primary focus on solar and storage facilities while also offering comprehensive operations, maintenance and asset management services. The acquisition of New Energy is consistent with ALLETE’s stated strategy of additional investment in renewable energy and related infrastructure across North America to support the Company’s sustainability-in-action strategy while providing potential long-term earnings growth. </context> | us-gaap:BusinessCombinationConsiderationTransferred1 |
For tax purpose, the purchase price allocation resulted in $ 154.9 million of deductible goodwill. | text | 154.9 | monetaryItemType | text: <entity> 154.9 </entity> <entity type> monetaryItemType </entity type> <context> For tax purpose, the purchase price allocation resulted in $ 154.9 million of deductible goodwill. </context> | us-gaap:BusinessAcquisitionPurchasePriceAllocationGoodwillExpectedTaxDeductibleAmount |
Acquisition-related costs were $ 2.7 million after-tax, expensed as incurred during 2022 and recorded in Operating and Maintenance on the Consolidated Statement of Income. | text | 2.7 | monetaryItemType | text: <entity> 2.7 </entity> <entity type> monetaryItemType </entity type> <context> Acquisition-related costs were $ 2.7 million after-tax, expensed as incurred during 2022 and recorded in Operating and Maintenance on the Consolidated Statement of Income. </context> | us-gaap:BusinessCombinationAcquisitionRelatedCosts |
Our wholly-owned subsidiary, ALLETE Transmission Holdings, owns approximately 8 percent of ATC, a Wisconsin-based utility that owns and maintains electric transmission assets in portions of Wisconsin, Michigan, Minnesota and Illinois. We account for our investment in ATC under the equity method of accounting. In 2024, we invested $ 5.8 million in ATC. In total, we expect to invest approximately $ 18.3 million in 2025. | text | 8 | percentItemType | text: <entity> 8 </entity> <entity type> percentItemType </entity type> <context> Our wholly-owned subsidiary, ALLETE Transmission Holdings, owns approximately 8 percent of ATC, a Wisconsin-based utility that owns and maintains electric transmission assets in portions of Wisconsin, Michigan, Minnesota and Illinois. We account for our investment in ATC under the equity method of accounting. In 2024, we invested $ 5.8 million in ATC. In total, we expect to invest approximately $ 18.3 million in 2025. </context> | us-gaap:EquityMethodInvestmentOwnershipPercentage |
Our wholly-owned subsidiary, ALLETE Transmission Holdings, owns approximately 8 percent of ATC, a Wisconsin-based utility that owns and maintains electric transmission assets in portions of Wisconsin, Michigan, Minnesota and Illinois. We account for our investment in ATC under the equity method of accounting. In 2024, we invested $ 5.8 million in ATC. In total, we expect to invest approximately $ 18.3 million in 2025. | text | 5.8 | monetaryItemType | text: <entity> 5.8 </entity> <entity type> monetaryItemType </entity type> <context> Our wholly-owned subsidiary, ALLETE Transmission Holdings, owns approximately 8 percent of ATC, a Wisconsin-based utility that owns and maintains electric transmission assets in portions of Wisconsin, Michigan, Minnesota and Illinois. We account for our investment in ATC under the equity method of accounting. In 2024, we invested $ 5.8 million in ATC. In total, we expect to invest approximately $ 18.3 million in 2025. </context> | us-gaap:PaymentsToAcquireEquityMethodInvestments |
Our subsidiary, ALLETE South Wind, owns a 49 percent equity interest in Nobles 2, the entity that owns and operates a 250 MW wind energy facility in southwestern Minnesota pursuant to a 20 -year PPA with Minnesota Power. We account for our investment in Nobles 2 under the equity method of accounting. | text | 49 | percentItemType | text: <entity> 49 </entity> <entity type> percentItemType </entity type> <context> Our subsidiary, ALLETE South Wind, owns a 49 percent equity interest in Nobles 2, the entity that owns and operates a 250 MW wind energy facility in southwestern Minnesota pursuant to a 20 -year PPA with Minnesota Power. We account for our investment in Nobles 2 under the equity method of accounting. </context> | us-gaap:EquityMethodInvestmentOwnershipPercentage |
The Company also recorded net loss attributable to non-controlling interest of $ 11.7 million related to its investment in Nobles 2. | text | 11.7 | monetaryItemType | text: <entity> 11.7 </entity> <entity type> monetaryItemType </entity type> <context> The Company also recorded net loss attributable to non-controlling interest of $ 11.7 million related to its investment in Nobles 2. </context> | us-gaap:NetIncomeLossAttributableToNoncontrollingInterest |
As of December 31, 2024, the aggregate amount of available-for-sale corporate and governmental debt securities maturing in one year or less was $ 2.0 million, in one year to less than three years was $ 2.8 million, in three years to less than five years was $ 1.5 million and in five or more years was $ 0.5 million. | text | 2.0 | monetaryItemType | text: <entity> 2.0 </entity> <entity type> monetaryItemType </entity type> <context> As of December 31, 2024, the aggregate amount of available-for-sale corporate and governmental debt securities maturing in one year or less was $ 2.0 million, in one year to less than three years was $ 2.8 million, in three years to less than five years was $ 1.5 million and in five or more years was $ 0.5 million. </context> | us-gaap:AvailableForSaleSecuritiesDebtMaturitiesWithinOneYearFairValue |
The aggregate carrying amount of our equity investments was $ 340.1 million as of December 31, 2024 ($ 331.2 million as of December 31, 2023). The Company assesses our equity investments in ATC and Nobles 2 for impairment whenever events or changes in circumstances indicate that the carrying amount of our investments may not be recoverable. For the years ended December 31, 2024 and 2023, there were no indicators of impairment. (See Note 6. Equity Investments.) | text | 340.1 | monetaryItemType | text: <entity> 340.1 </entity> <entity type> monetaryItemType </entity type> <context> The aggregate carrying amount of our equity investments was $ 340.1 million as of December 31, 2024 ($ 331.2 million as of December 31, 2023). The Company assesses our equity investments in ATC and Nobles 2 for impairment whenever events or changes in circumstances indicate that the carrying amount of our investments may not be recoverable. For the years ended December 31, 2024 and 2023, there were no indicators of impairment. (See Note 6. Equity Investments.) </context> | us-gaap:EquityMethodInvestments |
The aggregate carrying amount of our equity investments was $ 340.1 million as of December 31, 2024 ($ 331.2 million as of December 31, 2023). The Company assesses our equity investments in ATC and Nobles 2 for impairment whenever events or changes in circumstances indicate that the carrying amount of our investments may not be recoverable. For the years ended December 31, 2024 and 2023, there were no indicators of impairment. (See Note 6. Equity Investments.) | text | 331.2 | monetaryItemType | text: <entity> 331.2 </entity> <entity type> monetaryItemType </entity type> <context> The aggregate carrying amount of our equity investments was $ 340.1 million as of December 31, 2024 ($ 331.2 million as of December 31, 2023). The Company assesses our equity investments in ATC and Nobles 2 for impairment whenever events or changes in circumstances indicate that the carrying amount of our investments may not be recoverable. For the years ended December 31, 2024 and 2023, there were no indicators of impairment. (See Note 6. Equity Investments.) </context> | us-gaap:EquityMethodInvestments |
The Company assesses the impairment of goodwill annually in the fourth quarter and whenever an event occurs or circumstances change that would indicate that the carrying amount may be impaired. The Company’s goodwill is a result of the New Energy acquisition in 2022. (See Note 1. Operations and Significant Accounting Policies and Note 5. Acquisitions.) The aggregate carrying amount of goodwill was $ 154.9 million as of December 31, 2024. | text | 154.9 | monetaryItemType | text: <entity> 154.9 </entity> <entity type> monetaryItemType </entity type> <context> The Company assesses the impairment of goodwill annually in the fourth quarter and whenever an event occurs or circumstances change that would indicate that the carrying amount may be impaired. The Company’s goodwill is a result of the New Energy acquisition in 2022. (See Note 1. Operations and Significant Accounting Policies and Note 5. Acquisitions.) The aggregate carrying amount of goodwill was $ 154.9 million as of December 31, 2024. </context> | us-gaap:Goodwill |
As of December 31, 2024, total short-term debt outstanding was $ 94.7 million ($ 111.4 million as of December 31, 2023), and consisted of long-term debt due within one year and included no unamortized debt issuance costs. | text | 94.7 | monetaryItemType | text: <entity> 94.7 </entity> <entity type> monetaryItemType </entity type> <context> As of December 31, 2024, total short-term debt outstanding was $ 94.7 million ($ 111.4 million as of December 31, 2023), and consisted of long-term debt due within one year and included no unamortized debt issuance costs. </context> | us-gaap:DebtCurrent |
As of December 31, 2024, total short-term debt outstanding was $ 94.7 million ($ 111.4 million as of December 31, 2023), and consisted of long-term debt due within one year and included no unamortized debt issuance costs. | text | 111.4 | monetaryItemType | text: <entity> 111.4 </entity> <entity type> monetaryItemType </entity type> <context> As of December 31, 2024, total short-term debt outstanding was $ 94.7 million ($ 111.4 million as of December 31, 2023), and consisted of long-term debt due within one year and included no unamortized debt issuance costs. </context> | us-gaap:DebtCurrent |
As of December 31, 2024, total short-term debt outstanding was $ 94.7 million ($ 111.4 million as of December 31, 2023), and consisted of long-term debt due within one year and included no unamortized debt issuance costs. | text | no | monetaryItemType | text: <entity> no </entity> <entity type> monetaryItemType </entity type> <context> As of December 31, 2024, total short-term debt outstanding was $ 94.7 million ($ 111.4 million as of December 31, 2023), and consisted of long-term debt due within one year and included no unamortized debt issuance costs. </context> | us-gaap:DeferredFinanceCostsCurrentNet |
As of December 31, 2024, we had consolidated bank lines of credit aggregating to $ 362.0 million ($ 423.1 million as of December 31, 2023), most of which expire in January 2027. We had $ 16.2 million outstanding in standby letters of credit and $ 20.0 million outstanding draws under our lines of credit as of December 31, 2024 ($ 19.4 million in standby letters of credit and $ 34.1 million outstanding draws as of December 31, 2023). | text | 362.0 | monetaryItemType | text: <entity> 362.0 </entity> <entity type> monetaryItemType </entity type> <context> As of December 31, 2024, we had consolidated bank lines of credit aggregating to $ 362.0 million ($ 423.1 million as of December 31, 2023), most of which expire in January 2027. We had $ 16.2 million outstanding in standby letters of credit and $ 20.0 million outstanding draws under our lines of credit as of December 31, 2024 ($ 19.4 million in standby letters of credit and $ 34.1 million outstanding draws as of December 31, 2023). </context> | us-gaap:LineOfCreditFacilityMaximumBorrowingCapacity |
As of December 31, 2024, we had consolidated bank lines of credit aggregating to $ 362.0 million ($ 423.1 million as of December 31, 2023), most of which expire in January 2027. We had $ 16.2 million outstanding in standby letters of credit and $ 20.0 million outstanding draws under our lines of credit as of December 31, 2024 ($ 19.4 million in standby letters of credit and $ 34.1 million outstanding draws as of December 31, 2023). | text | 423.1 | monetaryItemType | text: <entity> 423.1 </entity> <entity type> monetaryItemType </entity type> <context> As of December 31, 2024, we had consolidated bank lines of credit aggregating to $ 362.0 million ($ 423.1 million as of December 31, 2023), most of which expire in January 2027. We had $ 16.2 million outstanding in standby letters of credit and $ 20.0 million outstanding draws under our lines of credit as of December 31, 2024 ($ 19.4 million in standby letters of credit and $ 34.1 million outstanding draws as of December 31, 2023). </context> | us-gaap:LineOfCreditFacilityMaximumBorrowingCapacity |
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