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In August 2023, AEP completed the sale of the entire portfolio to the nonaffiliated party and received cash proceeds of approximately $ 1.2 billion, net of taxes and transaction costs. AEP recorded a pretax loss of $ 93 million ($ 73 million after-tax) for the year ended December 31, 2023 related to the sale. | text | 1.2 | monetaryItemType | text: <entity> 1.2 </entity> <entity type> monetaryItemType </entity type> <context> In August 2023, AEP completed the sale of the entire portfolio to the nonaffiliated party and received cash proceeds of approximately $ 1.2 billion, net of taxes and transaction costs. AEP recorded a pretax loss of $ 93 million ($ 73 million after-tax) for the year ended December 31, 2023 related to the sale. </context> | us-gaap:ProceedsFromDivestitureOfBusinesses |
In August 2023, AEP completed the sale of the entire portfolio to the nonaffiliated party and received cash proceeds of approximately $ 1.2 billion, net of taxes and transaction costs. AEP recorded a pretax loss of $ 93 million ($ 73 million after-tax) for the year ended December 31, 2023 related to the sale. | text | 93 | monetaryItemType | text: <entity> 93 </entity> <entity type> monetaryItemType </entity type> <context> In August 2023, AEP completed the sale of the entire portfolio to the nonaffiliated party and received cash proceeds of approximately $ 1.2 billion, net of taxes and transaction costs. AEP recorded a pretax loss of $ 93 million ($ 73 million after-tax) for the year ended December 31, 2023 related to the sale. </context> | us-gaap:GainLossOnSaleOfBusiness |
In June 2022, AEP closed on the sale of certain mineral rights to a nonaffiliated third-party and received $ 120 million of proceeds. The sale resulted in a pretax gain of $ 116 million in the second quarter of 2022. | text | 120 | monetaryItemType | text: <entity> 120 </entity> <entity type> monetaryItemType </entity type> <context> In June 2022, AEP closed on the sale of certain mineral rights to a nonaffiliated third-party and received $ 120 million of proceeds. The sale resulted in a pretax gain of $ 116 million in the second quarter of 2022. </context> | us-gaap:ProceedsFromSaleOfPropertyPlantAndEquipment |
In June 2022, AEP closed on the sale of certain mineral rights to a nonaffiliated third-party and received $ 120 million of proceeds. The sale resulted in a pretax gain of $ 116 million in the second quarter of 2022. | text | 116 | monetaryItemType | text: <entity> 116 </entity> <entity type> monetaryItemType </entity type> <context> In June 2022, AEP closed on the sale of certain mineral rights to a nonaffiliated third-party and received $ 120 million of proceeds. The sale resulted in a pretax gain of $ 116 million in the second quarter of 2022. </context> | us-gaap:GainLossOnSaleOfOtherAssets |
In December 2023, SWEPCo recorded a pretax, non-cash disallowance of $ 86 million in Asset Impairments and Other Related Charges on the statements of income due to regulatory disallowance of recovery of AFUDC on Turk Plant in the 2012 Texas Base Rate case. See the “2012 Texas Base Rate Case” section of Note 4 for additional information. | text | 86 | monetaryItemType | text: <entity> 86 </entity> <entity type> monetaryItemType </entity type> <context> In December 2023, SWEPCo recorded a pretax, non-cash disallowance of $ 86 million in Asset Impairments and Other Related Charges on the statements of income due to regulatory disallowance of recovery of AFUDC on Turk Plant in the 2012 Texas Base Rate case. See the “2012 Texas Base Rate Case” section of Note 4 for additional information. </context> | us-gaap:OtherAssetImpairmentCharges |
In December 2023, as a result of sale negotiations AEP determined a decline in the fair value of AEP’s investment in NMRD was other than temporary. In accordance with the accounting guidance for “Investment - Equity Method and Joint Ventures”, in the fourth quarter of 2023 AEP recorded a pretax other than temporary impairment charge of $ 19 million which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s statement of income. AEP’s determination of fair value utilized the accounting guidance for Fair Value Measurement market approach to valuation and was based on negotiations to sell the investment to a nonaffiliated third-party. The carrying value of the investment in NMRD was not material to AEP as of December 31, 2023. | text | 19 | monetaryItemType | text: <entity> 19 </entity> <entity type> monetaryItemType </entity type> <context> In December 2023, as a result of sale negotiations AEP determined a decline in the fair value of AEP’s investment in NMRD was other than temporary. In accordance with the accounting guidance for “Investment - Equity Method and Joint Ventures”, in the fourth quarter of 2023 AEP recorded a pretax other than temporary impairment charge of $ 19 million which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s statement of income. AEP’s determination of fair value utilized the accounting guidance for Fair Value Measurement market approach to valuation and was based on negotiations to sell the investment to a nonaffiliated third-party. The carrying value of the investment in NMRD was not material to AEP as of December 31, 2023. </context> | us-gaap:EquityMethodInvestmentOtherThanTemporaryImpairment |
In 2019, AEP acquired a 50 % ownership interest in five non-consolidated joint ventures, including Flat Ridge 2 Wind LLC (Flat Ridge 2), and two tax equity partnerships. The five non-consolidated joint ventures are jointly owned and operated by BP Wind Energy. Flat Ridge 2 sells electricity to three counterparties through long-term PPAs. | text | 50 | percentItemType | text: <entity> 50 </entity> <entity type> percentItemType </entity type> <context> In 2019, AEP acquired a 50 % ownership interest in five non-consolidated joint ventures, including Flat Ridge 2 Wind LLC (Flat Ridge 2), and two tax equity partnerships. The five non-consolidated joint ventures are jointly owned and operated by BP Wind Energy. Flat Ridge 2 sells electricity to three counterparties through long-term PPAs. </context> | us-gaap:EquityMethodInvestmentOwnershipPercentage |
Regarding AEP’s investment in Flat Ridge 2, in June 2022, as a result of Flat Ridge 2’s deteriorating financial performance, sale negotiations and AEP’s ongoing evaluation and ultimate decision to exit the investment in the near term, AEP determined a decline in the fair value of AEP’s investment in Flat Ridge 2 was other than temporary. In accordance with the accounting guidance for “Investments - Equity Method and Joint Ventures”, in the second quarter of 2022 AEP recorded a pretax other than temporary impairment charge of $ 186 million which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s statement of income. AEP’s determination of fair value utilized the accounting guidance for Fair Value Measurement market approach to valuation and was based on negotiations to sell the investment to a nonaffiliated third-party. In the third quarter of 2022, AEP recorded an additional $ 2 million pretax other than temporary impairment charge which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s statement of income. In September 2022, AEP signed a Purchase and Sale Agreement with a nonaffiliate third-party for AEP’s interest in Flat Ridge 2. The transaction closed in the fourth quarter of 2022 and had an immaterial impact on the financial statements. | text | 186 | monetaryItemType | text: <entity> 186 </entity> <entity type> monetaryItemType </entity type> <context> Regarding AEP’s investment in Flat Ridge 2, in June 2022, as a result of Flat Ridge 2’s deteriorating financial performance, sale negotiations and AEP’s ongoing evaluation and ultimate decision to exit the investment in the near term, AEP determined a decline in the fair value of AEP’s investment in Flat Ridge 2 was other than temporary. In accordance with the accounting guidance for “Investments - Equity Method and Joint Ventures”, in the second quarter of 2022 AEP recorded a pretax other than temporary impairment charge of $ 186 million which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s statement of income. AEP’s determination of fair value utilized the accounting guidance for Fair Value Measurement market approach to valuation and was based on negotiations to sell the investment to a nonaffiliated third-party. In the third quarter of 2022, AEP recorded an additional $ 2 million pretax other than temporary impairment charge which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s statement of income. In September 2022, AEP signed a Purchase and Sale Agreement with a nonaffiliate third-party for AEP’s interest in Flat Ridge 2. The transaction closed in the fourth quarter of 2022 and had an immaterial impact on the financial statements. </context> | us-gaap:EquityMethodInvestmentOtherThanTemporaryImpairment |
Regarding AEP’s investment in Flat Ridge 2, in June 2022, as a result of Flat Ridge 2’s deteriorating financial performance, sale negotiations and AEP’s ongoing evaluation and ultimate decision to exit the investment in the near term, AEP determined a decline in the fair value of AEP’s investment in Flat Ridge 2 was other than temporary. In accordance with the accounting guidance for “Investments - Equity Method and Joint Ventures”, in the second quarter of 2022 AEP recorded a pretax other than temporary impairment charge of $ 186 million which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s statement of income. AEP’s determination of fair value utilized the accounting guidance for Fair Value Measurement market approach to valuation and was based on negotiations to sell the investment to a nonaffiliated third-party. In the third quarter of 2022, AEP recorded an additional $ 2 million pretax other than temporary impairment charge which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s statement of income. In September 2022, AEP signed a Purchase and Sale Agreement with a nonaffiliate third-party for AEP’s interest in Flat Ridge 2. The transaction closed in the fourth quarter of 2022 and had an immaterial impact on the financial statements. | text | 2 | monetaryItemType | text: <entity> 2 </entity> <entity type> monetaryItemType </entity type> <context> Regarding AEP’s investment in Flat Ridge 2, in June 2022, as a result of Flat Ridge 2’s deteriorating financial performance, sale negotiations and AEP’s ongoing evaluation and ultimate decision to exit the investment in the near term, AEP determined a decline in the fair value of AEP’s investment in Flat Ridge 2 was other than temporary. In accordance with the accounting guidance for “Investments - Equity Method and Joint Ventures”, in the second quarter of 2022 AEP recorded a pretax other than temporary impairment charge of $ 186 million which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s statement of income. AEP’s determination of fair value utilized the accounting guidance for Fair Value Measurement market approach to valuation and was based on negotiations to sell the investment to a nonaffiliated third-party. In the third quarter of 2022, AEP recorded an additional $ 2 million pretax other than temporary impairment charge which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s statement of income. In September 2022, AEP signed a Purchase and Sale Agreement with a nonaffiliate third-party for AEP’s interest in Flat Ridge 2. The transaction closed in the fourth quarter of 2022 and had an immaterial impact on the financial statements. </context> | us-gaap:EquityMethodInvestmentOtherThanTemporaryImpairment |
In January 2022, the PUCT issued a final order which included a return of investment only for the recovery of the Dolet Hills Power Station. As a result of the final order, SWEPCo recorded a disallowance of $ 12 million associated with the lack of return on the Dolet Hills Power Station. In February 2022, SWEPCo filed a motion for rehearing with the PUCT challenging denial of a reasonable return or carrying costs on the Dolet Hills Power Station among other items. In April 2022, the PUCT denied the motion for rehearing. In May 2022, SWEPCo filed a petition for review with the Texas District Court seeking a judicial review of the several errors challenged in the PUCT’s final order. See “2020 Texas Base Rate Case” section of Note 4 for additional information. | text | 12 | monetaryItemType | text: <entity> 12 </entity> <entity type> monetaryItemType </entity type> <context> In January 2022, the PUCT issued a final order which included a return of investment only for the recovery of the Dolet Hills Power Station. As a result of the final order, SWEPCo recorded a disallowance of $ 12 million associated with the lack of return on the Dolet Hills Power Station. In February 2022, SWEPCo filed a motion for rehearing with the PUCT challenging denial of a reasonable return or carrying costs on the Dolet Hills Power Station among other items. In April 2022, the PUCT denied the motion for rehearing. In May 2022, SWEPCo filed a petition for review with the Texas District Court seeking a judicial review of the several errors challenged in the PUCT’s final order. See “2020 Texas Base Rate Case” section of Note 4 for additional information. </context> | us-gaap:OtherAssetImpairmentCharges |
No contributions were made to the qualified pension plan for the years ended December 31, 2024 and 2023, respectively. Contributions to the non-qualified pension plans were $ 14 million and $ 8 million for the years ended December 31, 2024 and 2023, respectively. | text | 14 | monetaryItemType | text: <entity> 14 </entity> <entity type> monetaryItemType </entity type> <context> No contributions were made to the qualified pension plan for the years ended December 31, 2024 and 2023, respectively. Contributions to the non-qualified pension plans were $ 14 million and $ 8 million for the years ended December 31, 2024 and 2023, respectively. </context> | us-gaap:DefinedBenefitPlanContributionsByEmployer |
No contributions were made to the qualified pension plan for the years ended December 31, 2024 and 2023, respectively. Contributions to the non-qualified pension plans were $ 14 million and $ 8 million for the years ended December 31, 2024 and 2023, respectively. | text | 8 | monetaryItemType | text: <entity> 8 </entity> <entity type> monetaryItemType </entity type> <context> No contributions were made to the qualified pension plan for the years ended December 31, 2024 and 2023, respectively. Contributions to the non-qualified pension plans were $ 14 million and $ 8 million for the years ended December 31, 2024 and 2023, respectively. </context> | us-gaap:DefinedBenefitPlanContributionsByEmployer |
AEP affiliates contributed $ 379 thousand, $ 396 thousand and $ 329 thousand to the United Mine Workers of America 1974 Pension Plan for the years ended December 31, 2024, 2023 and 2022, respectively. The contributions did not include surcharges. An AEP affiliate, Cook Coal Terminal (CCT), was listed in the plan’s 2022 Form 5500 as providing more than 5 percent of the total contributions for the plan year ending June 30, 2023. The plan’s 2022 Form 5500 was filed in the second quarter of 2024. | text | 379 | monetaryItemType | text: <entity> 379 </entity> <entity type> monetaryItemType </entity type> <context> AEP affiliates contributed $ 379 thousand, $ 396 thousand and $ 329 thousand to the United Mine Workers of America 1974 Pension Plan for the years ended December 31, 2024, 2023 and 2022, respectively. The contributions did not include surcharges. An AEP affiliate, Cook Coal Terminal (CCT), was listed in the plan’s 2022 Form 5500 as providing more than 5 percent of the total contributions for the plan year ending June 30, 2023. The plan’s 2022 Form 5500 was filed in the second quarter of 2024. </context> | us-gaap:MultiemployerPlanEmployerContributionCost |
AEP affiliates contributed $ 379 thousand, $ 396 thousand and $ 329 thousand to the United Mine Workers of America 1974 Pension Plan for the years ended December 31, 2024, 2023 and 2022, respectively. The contributions did not include surcharges. An AEP affiliate, Cook Coal Terminal (CCT), was listed in the plan’s 2022 Form 5500 as providing more than 5 percent of the total contributions for the plan year ending June 30, 2023. The plan’s 2022 Form 5500 was filed in the second quarter of 2024. | text | 396 | monetaryItemType | text: <entity> 396 </entity> <entity type> monetaryItemType </entity type> <context> AEP affiliates contributed $ 379 thousand, $ 396 thousand and $ 329 thousand to the United Mine Workers of America 1974 Pension Plan for the years ended December 31, 2024, 2023 and 2022, respectively. The contributions did not include surcharges. An AEP affiliate, Cook Coal Terminal (CCT), was listed in the plan’s 2022 Form 5500 as providing more than 5 percent of the total contributions for the plan year ending June 30, 2023. The plan’s 2022 Form 5500 was filed in the second quarter of 2024. </context> | us-gaap:MultiemployerPlanEmployerContributionCost |
AEP affiliates contributed $ 379 thousand, $ 396 thousand and $ 329 thousand to the United Mine Workers of America 1974 Pension Plan for the years ended December 31, 2024, 2023 and 2022, respectively. The contributions did not include surcharges. An AEP affiliate, Cook Coal Terminal (CCT), was listed in the plan’s 2022 Form 5500 as providing more than 5 percent of the total contributions for the plan year ending June 30, 2023. The plan’s 2022 Form 5500 was filed in the second quarter of 2024. | text | 329 | monetaryItemType | text: <entity> 329 </entity> <entity type> monetaryItemType </entity type> <context> AEP affiliates contributed $ 379 thousand, $ 396 thousand and $ 329 thousand to the United Mine Workers of America 1974 Pension Plan for the years ended December 31, 2024, 2023 and 2022, respectively. The contributions did not include surcharges. An AEP affiliate, Cook Coal Terminal (CCT), was listed in the plan’s 2022 Form 5500 as providing more than 5 percent of the total contributions for the plan year ending June 30, 2023. The plan’s 2022 Form 5500 was filed in the second quarter of 2024. </context> | us-gaap:MultiemployerPlanEmployerContributionCost |
AEPTCo Parent is the holding company of seven FERC-regulated transmission-only electric utilities. The seven State Transcos have been identified as operating segments of AEPTCo under the accounting guidance for “Segment Reporting.” The State Transcos business consists of developing, constructing and operating transmission facilities at the request of the RTOs in which they operate and in replacing and upgrading facilities, assets and components of the existing AEP transmission system as needed to maintain reliability standards and provide service to AEP’s wholesale and retail customers. The State Transcos are regulated for rate-making purposes exclusively by the FERC and earn revenues through tariff rates charged for the use of their electric transmission systems. | text | seven | integerItemType | text: <entity> seven </entity> <entity type> integerItemType </entity type> <context> AEPTCo Parent is the holding company of seven FERC-regulated transmission-only electric utilities. The seven State Transcos have been identified as operating segments of AEPTCo under the accounting guidance for “Segment Reporting.” The State Transcos business consists of developing, constructing and operating transmission facilities at the request of the RTOs in which they operate and in replacing and upgrading facilities, assets and components of the existing AEP transmission system as needed to maintain reliability standards and provide service to AEP’s wholesale and retail customers. The State Transcos are regulated for rate-making purposes exclusively by the FERC and earn revenues through tariff rates charged for the use of their electric transmission systems. </context> | us-gaap:NumberOfOperatingSegments |
who makes operating decisions, allocates resources to and assesses performance based on these operating segments. The State Transcos operating segments all have similar economic characteristics and meet all of the criteria under the accounting guidance for “Segment Reporting” to be aggregated into one reportable segment. As a result, AEPTCo has one reportable segment. The remainder of AEPTCo’s activity is presented in AEPTCo Parent. While not considered a reportable segment, AEPTCo Parent represents the activity of the holding company which primarily relates to debt financing activity and general corporate activities. | text | one | integerItemType | text: <entity> one </entity> <entity type> integerItemType </entity type> <context> who makes operating decisions, allocates resources to and assesses performance based on these operating segments. The State Transcos operating segments all have similar economic characteristics and meet all of the criteria under the accounting guidance for “Segment Reporting” to be aggregated into one reportable segment. As a result, AEPTCo has one reportable segment. The remainder of AEPTCo’s activity is presented in AEPTCo Parent. While not considered a reportable segment, AEPTCo Parent represents the activity of the holding company which primarily relates to debt financing activity and general corporate activities. </context> | us-gaap:NumberOfReportableSegments |
According to the accounting guidance for “Derivatives and Hedging,” the Registrants reflect the fair values of derivative instruments subject to netting agreements with the same counterparty net of related cash collateral. For certain risk management contracts, the Registrants are required to post or receive cash collateral based on third-party contractual agreements and risk profiles. AEP netted cash collateral received from third-parties against short-term and long-term risk management assets in the amounts of $ 87 million and $ 46 million as of December 31, 2024 and 2023, respectively. There was no cash collateral received from third-parties netted against short-term and long-term risk management assets for the Registrant Subsidiaries as of December 31, 2024 and 2023. The amount of cash collateral paid to third-parties netted against short-term and long-term risk management liabilities was not material for the Registrants as of December 31, 2024 and 2023. | text | 87 | monetaryItemType | text: <entity> 87 </entity> <entity type> monetaryItemType </entity type> <context> According to the accounting guidance for “Derivatives and Hedging,” the Registrants reflect the fair values of derivative instruments subject to netting agreements with the same counterparty net of related cash collateral. For certain risk management contracts, the Registrants are required to post or receive cash collateral based on third-party contractual agreements and risk profiles. AEP netted cash collateral received from third-parties against short-term and long-term risk management assets in the amounts of $ 87 million and $ 46 million as of December 31, 2024 and 2023, respectively. There was no cash collateral received from third-parties netted against short-term and long-term risk management assets for the Registrant Subsidiaries as of December 31, 2024 and 2023. The amount of cash collateral paid to third-parties netted against short-term and long-term risk management liabilities was not material for the Registrants as of December 31, 2024 and 2023. </context> | us-gaap:SecuritiesReceivedAsCollateral |
According to the accounting guidance for “Derivatives and Hedging,” the Registrants reflect the fair values of derivative instruments subject to netting agreements with the same counterparty net of related cash collateral. For certain risk management contracts, the Registrants are required to post or receive cash collateral based on third-party contractual agreements and risk profiles. AEP netted cash collateral received from third-parties against short-term and long-term risk management assets in the amounts of $ 87 million and $ 46 million as of December 31, 2024 and 2023, respectively. There was no cash collateral received from third-parties netted against short-term and long-term risk management assets for the Registrant Subsidiaries as of December 31, 2024 and 2023. The amount of cash collateral paid to third-parties netted against short-term and long-term risk management liabilities was not material for the Registrants as of December 31, 2024 and 2023. | text | 46 | monetaryItemType | text: <entity> 46 </entity> <entity type> monetaryItemType </entity type> <context> According to the accounting guidance for “Derivatives and Hedging,” the Registrants reflect the fair values of derivative instruments subject to netting agreements with the same counterparty net of related cash collateral. For certain risk management contracts, the Registrants are required to post or receive cash collateral based on third-party contractual agreements and risk profiles. AEP netted cash collateral received from third-parties against short-term and long-term risk management assets in the amounts of $ 87 million and $ 46 million as of December 31, 2024 and 2023, respectively. There was no cash collateral received from third-parties netted against short-term and long-term risk management assets for the Registrant Subsidiaries as of December 31, 2024 and 2023. The amount of cash collateral paid to third-parties netted against short-term and long-term risk management liabilities was not material for the Registrants as of December 31, 2024 and 2023. </context> | us-gaap:SecuritiesReceivedAsCollateral |
Amounts include $( 22 ) million and $( 30 ) million as of December 31, 2024 and 2023, respectively, for the fair value hedge adjustment of hedged debt obligations for which hedge accounting has been discontinued. | text | 22 | monetaryItemType | text: <entity> 22 </entity> <entity type> monetaryItemType </entity type> <context> Amounts include $( 22 ) million and $( 30 ) million as of December 31, 2024 and 2023, respectively, for the fair value hedge adjustment of hedged debt obligations for which hedge accounting has been discontinued. </context> | us-gaap:HedgedLiabilityDiscontinuedFairValueHedgeCumulativeIncreaseDecrease |
Amounts include $( 22 ) million and $( 30 ) million as of December 31, 2024 and 2023, respectively, for the fair value hedge adjustment of hedged debt obligations for which hedge accounting has been discontinued. | text | 30 | monetaryItemType | text: <entity> 30 </entity> <entity type> monetaryItemType </entity type> <context> Amounts include $( 22 ) million and $( 30 ) million as of December 31, 2024 and 2023, respectively, for the fair value hedge adjustment of hedged debt obligations for which hedge accounting has been discontinued. </context> | us-gaap:HedgedLiabilityDiscontinuedFairValueHedgeCumulativeIncreaseDecrease |
As of December 31, 2024, AEP, OPCo, PSO, and SWEPCo have pretax state NOLC as indicated in the table below. Net of tax, the NOLCs for AEP and subsidiaries amount to $ 110.3 million of future tax benefit. Additionally, the amounts presented below for OPCo, PSO, and SWEPCo amount to $ 2.7 million, $ 27.8 million, and $ 36.1 million, respectively.: | text | 110.3 | monetaryItemType | text: <entity> 110.3 </entity> <entity type> monetaryItemType </entity type> <context> As of December 31, 2024, AEP, OPCo, PSO, and SWEPCo have pretax state NOLC as indicated in the table below. Net of tax, the NOLCs for AEP and subsidiaries amount to $ 110.3 million of future tax benefit. Additionally, the amounts presented below for OPCo, PSO, and SWEPCo amount to $ 2.7 million, $ 27.8 million, and $ 36.1 million, respectively.: </context> | us-gaap:OperatingLossCarryforwards |
As of December 31, 2024, AEP, OPCo, PSO, and SWEPCo have pretax state NOLC as indicated in the table below. Net of tax, the NOLCs for AEP and subsidiaries amount to $ 110.3 million of future tax benefit. Additionally, the amounts presented below for OPCo, PSO, and SWEPCo amount to $ 2.7 million, $ 27.8 million, and $ 36.1 million, respectively.: | text | 2.7 | monetaryItemType | text: <entity> 2.7 </entity> <entity type> monetaryItemType </entity type> <context> As of December 31, 2024, AEP, OPCo, PSO, and SWEPCo have pretax state NOLC as indicated in the table below. Net of tax, the NOLCs for AEP and subsidiaries amount to $ 110.3 million of future tax benefit. Additionally, the amounts presented below for OPCo, PSO, and SWEPCo amount to $ 2.7 million, $ 27.8 million, and $ 36.1 million, respectively.: </context> | us-gaap:OperatingLossCarryforwards |
As of December 31, 2024, AEP, OPCo, PSO, and SWEPCo have pretax state NOLC as indicated in the table below. Net of tax, the NOLCs for AEP and subsidiaries amount to $ 110.3 million of future tax benefit. Additionally, the amounts presented below for OPCo, PSO, and SWEPCo amount to $ 2.7 million, $ 27.8 million, and $ 36.1 million, respectively.: | text | 27.8 | monetaryItemType | text: <entity> 27.8 </entity> <entity type> monetaryItemType </entity type> <context> As of December 31, 2024, AEP, OPCo, PSO, and SWEPCo have pretax state NOLC as indicated in the table below. Net of tax, the NOLCs for AEP and subsidiaries amount to $ 110.3 million of future tax benefit. Additionally, the amounts presented below for OPCo, PSO, and SWEPCo amount to $ 2.7 million, $ 27.8 million, and $ 36.1 million, respectively.: </context> | us-gaap:OperatingLossCarryforwards |
As of December 31, 2024, AEP, OPCo, PSO, and SWEPCo have pretax state NOLC as indicated in the table below. Net of tax, the NOLCs for AEP and subsidiaries amount to $ 110.3 million of future tax benefit. Additionally, the amounts presented below for OPCo, PSO, and SWEPCo amount to $ 2.7 million, $ 27.8 million, and $ 36.1 million, respectively.: | text | 36.1 | monetaryItemType | text: <entity> 36.1 </entity> <entity type> monetaryItemType </entity type> <context> As of December 31, 2024, AEP, OPCo, PSO, and SWEPCo have pretax state NOLC as indicated in the table below. Net of tax, the NOLCs for AEP and subsidiaries amount to $ 110.3 million of future tax benefit. Additionally, the amounts presented below for OPCo, PSO, and SWEPCo amount to $ 2.7 million, $ 27.8 million, and $ 36.1 million, respectively.: </context> | us-gaap:OperatingLossCarryforwards |
, $ 13 million, and $ 23 million, respectively. | text | 13 | monetaryItemType | text: <entity> 13 </entity> <entity type> monetaryItemType </entity type> <context> , $ 13 million, and $ 23 million, respectively. </context> | us-gaap:UnrecognizedTaxBenefitsThatWouldImpactEffectiveTaxRate |
, $ 13 million, and $ 23 million, respectively. | text | 23 | monetaryItemType | text: <entity> 23 </entity> <entity type> monetaryItemType </entity type> <context> , $ 13 million, and $ 23 million, respectively. </context> | us-gaap:UnrecognizedTaxBenefitsThatWouldImpactEffectiveTaxRate |
These expenses were primarily included in Other Operation and Maintenance on the statements of income and Other Current Liabilities on the balance sheets. Settlement accounting was triggered for the qualified pension plan in November 2024 under the accounting guidance for “Compensation - Retirement Benefits”. A settlement charge of $ 90 million was recorded. AEP will seek recovery for the portion of the expense related to regulated operations. See Note 8 - Benefit Plans for additional information associated with the plan. | text | 90 | monetaryItemType | text: <entity> 90 </entity> <entity type> monetaryItemType </entity type> <context> These expenses were primarily included in Other Operation and Maintenance on the statements of income and Other Current Liabilities on the balance sheets. Settlement accounting was triggered for the qualified pension plan in November 2024 under the accounting guidance for “Compensation - Retirement Benefits”. A settlement charge of $ 90 million was recorded. AEP will seek recovery for the portion of the expense related to regulated operations. See Note 8 - Benefit Plans for additional information associated with the plan. </context> | us-gaap:PostemploymentBenefitsPeriodExpense |
In 2023, AEP filed a prospectus supplement and executed an Equity Distribution Agreement, pursuant to which AEP may sell, from time to time, up to an aggregate of $ 1.7 billion of its common stock through an ATM offering program, including an equity forward sales component. The compensation paid to the selling agents by AEP may be up to 2 % of the gross offering proceeds of the shares. For the year ended 2024, AEP issued 4,437,136 shares of common stock and received net cash proceeds of $ 397 million under the ATM program. As of December 31, 2024, approximately $ 1.3 billion of equity is available for issuance under the ATM program. | text | 4437136 | sharesItemType | text: <entity> 4437136 </entity> <entity type> sharesItemType </entity type> <context> In 2023, AEP filed a prospectus supplement and executed an Equity Distribution Agreement, pursuant to which AEP may sell, from time to time, up to an aggregate of $ 1.7 billion of its common stock through an ATM offering program, including an equity forward sales component. The compensation paid to the selling agents by AEP may be up to 2 % of the gross offering proceeds of the shares. For the year ended 2024, AEP issued 4,437,136 shares of common stock and received net cash proceeds of $ 397 million under the ATM program. As of December 31, 2024, approximately $ 1.3 billion of equity is available for issuance under the ATM program. </context> | us-gaap:StockIssuedDuringPeriodSharesNewIssues |
In 2023, AEP filed a prospectus supplement and executed an Equity Distribution Agreement, pursuant to which AEP may sell, from time to time, up to an aggregate of $ 1.7 billion of its common stock through an ATM offering program, including an equity forward sales component. The compensation paid to the selling agents by AEP may be up to 2 % of the gross offering proceeds of the shares. For the year ended 2024, AEP issued 4,437,136 shares of common stock and received net cash proceeds of $ 397 million under the ATM program. As of December 31, 2024, approximately $ 1.3 billion of equity is available for issuance under the ATM program. | text | 397 | monetaryItemType | text: <entity> 397 </entity> <entity type> monetaryItemType </entity type> <context> In 2023, AEP filed a prospectus supplement and executed an Equity Distribution Agreement, pursuant to which AEP may sell, from time to time, up to an aggregate of $ 1.7 billion of its common stock through an ATM offering program, including an equity forward sales component. The compensation paid to the selling agents by AEP may be up to 2 % of the gross offering proceeds of the shares. For the year ended 2024, AEP issued 4,437,136 shares of common stock and received net cash proceeds of $ 397 million under the ATM program. As of December 31, 2024, approximately $ 1.3 billion of equity is available for issuance under the ATM program. </context> | us-gaap:ProceedsFromIssuanceOfCommonStock |
In 2023, AEP filed a prospectus supplement and executed an Equity Distribution Agreement, pursuant to which AEP may sell, from time to time, up to an aggregate of $ 1.7 billion of its common stock through an ATM offering program, including an equity forward sales component. The compensation paid to the selling agents by AEP may be up to 2 % of the gross offering proceeds of the shares. For the year ended 2024, AEP issued 4,437,136 shares of common stock and received net cash proceeds of $ 397 million under the ATM program. As of December 31, 2024, approximately $ 1.3 billion of equity is available for issuance under the ATM program. | text | 1.3 | sharesItemType | text: <entity> 1.3 </entity> <entity type> sharesItemType </entity type> <context> In 2023, AEP filed a prospectus supplement and executed an Equity Distribution Agreement, pursuant to which AEP may sell, from time to time, up to an aggregate of $ 1.7 billion of its common stock through an ATM offering program, including an equity forward sales component. The compensation paid to the selling agents by AEP may be up to 2 % of the gross offering proceeds of the shares. For the year ended 2024, AEP issued 4,437,136 shares of common stock and received net cash proceeds of $ 397 million under the ATM program. As of December 31, 2024, approximately $ 1.3 billion of equity is available for issuance under the ATM program. </context> | us-gaap:CommonStockCapitalSharesReservedForFutureIssuance |
In January and February 2025, I&M retired $ 9 million and $ 4 million, respectively, of Notes Payable related to DCC Fuel. | text | 9 | monetaryItemType | text: <entity> 9 </entity> <entity type> monetaryItemType </entity type> <context> In January and February 2025, I&M retired $ 9 million and $ 4 million, respectively, of Notes Payable related to DCC Fuel. </context> | us-gaap:RepaymentsOfDebt |
In January and February 2025, I&M retired $ 9 million and $ 4 million, respectively, of Notes Payable related to DCC Fuel. | text | 4 | monetaryItemType | text: <entity> 4 </entity> <entity type> monetaryItemType </entity type> <context> In January and February 2025, I&M retired $ 9 million and $ 4 million, respectively, of Notes Payable related to DCC Fuel. </context> | us-gaap:RepaymentsOfDebt |
In January 2025, Transource Energy issued $ 2 million of variable rate Other Long-term Debt due in 2025. | text | 2 | monetaryItemType | text: <entity> 2 </entity> <entity type> monetaryItemType </entity type> <context> In January 2025, Transource Energy issued $ 2 million of variable rate Other Long-term Debt due in 2025. </context> | us-gaap:DebtInstrumentFaceAmount |
In January 2025, KPCo entered into a $ 150 million term loan due in February 2026. | text | 150 | monetaryItemType | text: <entity> 150 </entity> <entity type> monetaryItemType </entity type> <context> In January 2025, KPCo entered into a $ 150 million term loan due in February 2026. </context> | us-gaap:DebtInstrumentFaceAmount |
In February 2025, APCo retired $ 14 million of Securitization Bonds. | text | 14 | monetaryItemType | text: <entity> 14 </entity> <entity type> monetaryItemType </entity type> <context> In February 2025, APCo retired $ 14 million of Securitization Bonds. </context> | us-gaap:RepaymentsOfDebt |
In February 2025, AEP Texas retired $ 12 million of Securitization Bonds. | text | 12 | monetaryItemType | text: <entity> 12 </entity> <entity type> monetaryItemType </entity type> <context> In February 2025, AEP Texas retired $ 12 million of Securitization Bonds. </context> | us-gaap:RepaymentsOfDebt |
Pursuant to the leverage restrictions in credit agreements, AEP must maintain a percentage of debt-to-total capitalization at a level that does not exceed 67.5 %. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. AEP may not declare or pay any cash dividend or distribution on its common stock during any period when AEP defers interest on its junior subordinated notes. As of December 31, 2024, AEP had $ 8.6 billion of available retained earnings to pay dividends to common shareholders. AEP paid $ 1.9 billion, $ 1.8 billion and $ 1.6 billion of dividends to common shareholders for the years ended December 31, 2024, 2023 and 2022, respectively. | text | 8.6 | monetaryItemType | text: <entity> 8.6 </entity> <entity type> monetaryItemType </entity type> <context> Pursuant to the leverage restrictions in credit agreements, AEP must maintain a percentage of debt-to-total capitalization at a level that does not exceed 67.5 %. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. AEP may not declare or pay any cash dividend or distribution on its common stock during any period when AEP defers interest on its junior subordinated notes. As of December 31, 2024, AEP had $ 8.6 billion of available retained earnings to pay dividends to common shareholders. AEP paid $ 1.9 billion, $ 1.8 billion and $ 1.6 billion of dividends to common shareholders for the years ended December 31, 2024, 2023 and 2022, respectively. </context> | us-gaap:RetainedEarningsUnappropriated |
Pursuant to the leverage restrictions in credit agreements, AEP must maintain a percentage of debt-to-total capitalization at a level that does not exceed 67.5 %. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. AEP may not declare or pay any cash dividend or distribution on its common stock during any period when AEP defers interest on its junior subordinated notes. As of December 31, 2024, AEP had $ 8.6 billion of available retained earnings to pay dividends to common shareholders. AEP paid $ 1.9 billion, $ 1.8 billion and $ 1.6 billion of dividends to common shareholders for the years ended December 31, 2024, 2023 and 2022, respectively. | text | 1.9 | monetaryItemType | text: <entity> 1.9 </entity> <entity type> monetaryItemType </entity type> <context> Pursuant to the leverage restrictions in credit agreements, AEP must maintain a percentage of debt-to-total capitalization at a level that does not exceed 67.5 %. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. AEP may not declare or pay any cash dividend or distribution on its common stock during any period when AEP defers interest on its junior subordinated notes. As of December 31, 2024, AEP had $ 8.6 billion of available retained earnings to pay dividends to common shareholders. AEP paid $ 1.9 billion, $ 1.8 billion and $ 1.6 billion of dividends to common shareholders for the years ended December 31, 2024, 2023 and 2022, respectively. </context> | us-gaap:PaymentsOfDividendsCommonStock |
Pursuant to the leverage restrictions in credit agreements, AEP must maintain a percentage of debt-to-total capitalization at a level that does not exceed 67.5 %. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. AEP may not declare or pay any cash dividend or distribution on its common stock during any period when AEP defers interest on its junior subordinated notes. As of December 31, 2024, AEP had $ 8.6 billion of available retained earnings to pay dividends to common shareholders. AEP paid $ 1.9 billion, $ 1.8 billion and $ 1.6 billion of dividends to common shareholders for the years ended December 31, 2024, 2023 and 2022, respectively. | text | 1.8 | monetaryItemType | text: <entity> 1.8 </entity> <entity type> monetaryItemType </entity type> <context> Pursuant to the leverage restrictions in credit agreements, AEP must maintain a percentage of debt-to-total capitalization at a level that does not exceed 67.5 %. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. AEP may not declare or pay any cash dividend or distribution on its common stock during any period when AEP defers interest on its junior subordinated notes. As of December 31, 2024, AEP had $ 8.6 billion of available retained earnings to pay dividends to common shareholders. AEP paid $ 1.9 billion, $ 1.8 billion and $ 1.6 billion of dividends to common shareholders for the years ended December 31, 2024, 2023 and 2022, respectively. </context> | us-gaap:PaymentsOfDividendsCommonStock |
Pursuant to the leverage restrictions in credit agreements, AEP must maintain a percentage of debt-to-total capitalization at a level that does not exceed 67.5 %. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. AEP may not declare or pay any cash dividend or distribution on its common stock during any period when AEP defers interest on its junior subordinated notes. As of December 31, 2024, AEP had $ 8.6 billion of available retained earnings to pay dividends to common shareholders. AEP paid $ 1.9 billion, $ 1.8 billion and $ 1.6 billion of dividends to common shareholders for the years ended December 31, 2024, 2023 and 2022, respectively. | text | 1.6 | monetaryItemType | text: <entity> 1.6 </entity> <entity type> monetaryItemType </entity type> <context> Pursuant to the leverage restrictions in credit agreements, AEP must maintain a percentage of debt-to-total capitalization at a level that does not exceed 67.5 %. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. AEP may not declare or pay any cash dividend or distribution on its common stock during any period when AEP defers interest on its junior subordinated notes. As of December 31, 2024, AEP had $ 8.6 billion of available retained earnings to pay dividends to common shareholders. AEP paid $ 1.9 billion, $ 1.8 billion and $ 1.6 billion of dividends to common shareholders for the years ended December 31, 2024, 2023 and 2022, respectively. </context> | us-gaap:PaymentsOfDividendsCommonStock |
Securitized Debt for Receivables, for the year ended 2024, had a weighted-average interest rate of 5.39 % and a maximum amount outstanding of $ 900 million. The commercial paper program, for the year ended 2024, had a weighted-average yield of 5.39 % and a maximum amount outstanding of $ 2.9 billion. AEP’s outstanding short-term debt was as follows: | text | 5.39 | percentItemType | text: <entity> 5.39 </entity> <entity type> percentItemType </entity type> <context> Securitized Debt for Receivables, for the year ended 2024, had a weighted-average interest rate of 5.39 % and a maximum amount outstanding of $ 900 million. The commercial paper program, for the year ended 2024, had a weighted-average yield of 5.39 % and a maximum amount outstanding of $ 2.9 billion. AEP’s outstanding short-term debt was as follows: </context> | us-gaap:DebtInstrumentInterestRateDuringPeriod |
Securitized Debt for Receivables, for the year ended 2024, had a weighted-average interest rate of 5.39 % and a maximum amount outstanding of $ 900 million. The commercial paper program, for the year ended 2024, had a weighted-average yield of 5.39 % and a maximum amount outstanding of $ 2.9 billion. AEP’s outstanding short-term debt was as follows: | text | 900 | monetaryItemType | text: <entity> 900 </entity> <entity type> monetaryItemType </entity type> <context> Securitized Debt for Receivables, for the year ended 2024, had a weighted-average interest rate of 5.39 % and a maximum amount outstanding of $ 900 million. The commercial paper program, for the year ended 2024, had a weighted-average yield of 5.39 % and a maximum amount outstanding of $ 2.9 billion. AEP’s outstanding short-term debt was as follows: </context> | us-gaap:TransfersAccountedForAsSecuredBorrowingsAssociatedLiabilitiesCarryingAmount |
Securitized Debt for Receivables, for the year ended 2024, had a weighted-average interest rate of 5.39 % and a maximum amount outstanding of $ 900 million. The commercial paper program, for the year ended 2024, had a weighted-average yield of 5.39 % and a maximum amount outstanding of $ 2.9 billion. AEP’s outstanding short-term debt was as follows: | text | 2.9 | monetaryItemType | text: <entity> 2.9 </entity> <entity type> monetaryItemType </entity type> <context> Securitized Debt for Receivables, for the year ended 2024, had a weighted-average interest rate of 5.39 % and a maximum amount outstanding of $ 900 million. The commercial paper program, for the year ended 2024, had a weighted-average yield of 5.39 % and a maximum amount outstanding of $ 2.9 billion. AEP’s outstanding short-term debt was as follows: </context> | us-gaap:ShorttermDebtMaximumAmountOutstandingDuringPeriod |
AEP’s long-term incentive plan available for eligible employees and directors, the American Electric Power System 2015 Long-Term Incentive Plan (2015 LTIP), was replaced prospectively for new grants by the American Electric Power System 2024 Long-Term Incentive Plan (2024 LTIP) effective in April 2024. The 2024 LTIP provides for a maximum of 10 million AEP common shares to be available for grant to eligible employees and directors. As of December 31, 2024, 9,806,016 shares remained available for issuance under the 2024 LTIP. No new awards may be granted under the 2015 LTIP. To the extent the issuance of a share is subject to an outstanding award under the 2015 LTIP, the issuance of that share will take place under the 2015 LTIP. Awards granted under the 2024 LTIP may be made in the form of stock options, stock appreciation rights, restricted stock, restricted stock units, performance shares, performance units, cash-based awards and other stock-based awards. All types of shares issued under the 2024 LTIP including stock options, stock appreciation rights, restricted stock units and performance shares reduce the shares remaining available for grants at a rate of 1 to 1. Cash settled awards do not reduce the number of shares remaining available under the 2024 LTIP. The following sections provide further information regarding each type of stock-based compensation award granted under these plans. | text | 10 | sharesItemType | text: <entity> 10 </entity> <entity type> sharesItemType </entity type> <context> AEP’s long-term incentive plan available for eligible employees and directors, the American Electric Power System 2015 Long-Term Incentive Plan (2015 LTIP), was replaced prospectively for new grants by the American Electric Power System 2024 Long-Term Incentive Plan (2024 LTIP) effective in April 2024. The 2024 LTIP provides for a maximum of 10 million AEP common shares to be available for grant to eligible employees and directors. As of December 31, 2024, 9,806,016 shares remained available for issuance under the 2024 LTIP. No new awards may be granted under the 2015 LTIP. To the extent the issuance of a share is subject to an outstanding award under the 2015 LTIP, the issuance of that share will take place under the 2015 LTIP. Awards granted under the 2024 LTIP may be made in the form of stock options, stock appreciation rights, restricted stock, restricted stock units, performance shares, performance units, cash-based awards and other stock-based awards. All types of shares issued under the 2024 LTIP including stock options, stock appreciation rights, restricted stock units and performance shares reduce the shares remaining available for grants at a rate of 1 to 1. Cash settled awards do not reduce the number of shares remaining available under the 2024 LTIP. The following sections provide further information regarding each type of stock-based compensation award granted under these plans. </context> | us-gaap:ShareBasedCompensationArrangementByShareBasedPaymentAwardNumberOfSharesAvailableForGrant |
AEP’s long-term incentive plan available for eligible employees and directors, the American Electric Power System 2015 Long-Term Incentive Plan (2015 LTIP), was replaced prospectively for new grants by the American Electric Power System 2024 Long-Term Incentive Plan (2024 LTIP) effective in April 2024. The 2024 LTIP provides for a maximum of 10 million AEP common shares to be available for grant to eligible employees and directors. As of December 31, 2024, 9,806,016 shares remained available for issuance under the 2024 LTIP. No new awards may be granted under the 2015 LTIP. To the extent the issuance of a share is subject to an outstanding award under the 2015 LTIP, the issuance of that share will take place under the 2015 LTIP. Awards granted under the 2024 LTIP may be made in the form of stock options, stock appreciation rights, restricted stock, restricted stock units, performance shares, performance units, cash-based awards and other stock-based awards. All types of shares issued under the 2024 LTIP including stock options, stock appreciation rights, restricted stock units and performance shares reduce the shares remaining available for grants at a rate of 1 to 1. Cash settled awards do not reduce the number of shares remaining available under the 2024 LTIP. The following sections provide further information regarding each type of stock-based compensation award granted under these plans. | text | 9806016 | sharesItemType | text: <entity> 9806016 </entity> <entity type> sharesItemType </entity type> <context> AEP’s long-term incentive plan available for eligible employees and directors, the American Electric Power System 2015 Long-Term Incentive Plan (2015 LTIP), was replaced prospectively for new grants by the American Electric Power System 2024 Long-Term Incentive Plan (2024 LTIP) effective in April 2024. The 2024 LTIP provides for a maximum of 10 million AEP common shares to be available for grant to eligible employees and directors. As of December 31, 2024, 9,806,016 shares remained available for issuance under the 2024 LTIP. No new awards may be granted under the 2015 LTIP. To the extent the issuance of a share is subject to an outstanding award under the 2015 LTIP, the issuance of that share will take place under the 2015 LTIP. Awards granted under the 2024 LTIP may be made in the form of stock options, stock appreciation rights, restricted stock, restricted stock units, performance shares, performance units, cash-based awards and other stock-based awards. All types of shares issued under the 2024 LTIP including stock options, stock appreciation rights, restricted stock units and performance shares reduce the shares remaining available for grants at a rate of 1 to 1. Cash settled awards do not reduce the number of shares remaining available under the 2024 LTIP. The following sections provide further information regarding each type of stock-based compensation award granted under these plans. </context> | us-gaap:CommonStockCapitalSharesReservedForFutureIssuance |
The total aggregate intrinsic value of nonvested RSUs as of December 31, 2024 was $ 44 million and the weighted-average remaining contractual life was 1.5 years. | text | 44 | monetaryItemType | text: <entity> 44 </entity> <entity type> monetaryItemType </entity type> <context> The total aggregate intrinsic value of nonvested RSUs as of December 31, 2024 was $ 44 million and the weighted-average remaining contractual life was 1.5 years. </context> | us-gaap:SharebasedCompensationArrangementBySharebasedPaymentAwardEquityInstrumentsOtherThanOptionsAggregateIntrinsicValueNonvested |
As of December 31, 2024, there was $ 59 million of total unrecognized compensation cost related to unvested share-based compensation arrangements granted under the 2015 LTIP and the 2024 LTIP. Unrecognized compensation cost related to unvested share-based arrangements will change as the fair value of performance shares is adjusted each period and as forfeitures for all award types are realized. AEP’s unrecognized compensation cost will be recognized over a weighted-average period of 1.5 years. | text | 59 | monetaryItemType | text: <entity> 59 </entity> <entity type> monetaryItemType </entity type> <context> As of December 31, 2024, there was $ 59 million of total unrecognized compensation cost related to unvested share-based compensation arrangements granted under the 2015 LTIP and the 2024 LTIP. Unrecognized compensation cost related to unvested share-based arrangements will change as the fair value of performance shares is adjusted each period and as forfeitures for all award types are realized. AEP’s unrecognized compensation cost will be recognized over a weighted-average period of 1.5 years. </context> | us-gaap:EmployeeServiceShareBasedCompensationNonvestedAwardsTotalCompensationCostNotYetRecognized |
A UPA between AEGCo and I&M (the I&M Power Agreement) provides for the sale by AEGCo to I&M of all the energy and capacity available to AEGCo at the Rockport Plant unless it is sold to another utility. I&M is obligated, whether or not power is available from AEGCo, to pay as a demand charge for the right to receive such power (and as an energy charge for any associated energy taken by I&M) net of amounts received by AEGCo from any other sources, sufficient to enable AEGCo to pay all of its operating and other expenses, including a rate of return on the common equity of AEGCo as approved by the FERC. The UPA will continue in effect until the debt obligations of AEGCo secured by the Rockport Plant have been satisfied and discharged (currently expected to be December 2028). I&M’s direct purchases from AEGCo were $ 209 million, $ 181 million and $ 242 million for the years ended December 31, 2024, 2023 and 2022, respectively. These direct purchases are presented as Purchased Electricity from AEP Affiliates on I&M’s statements of income. | text | 209 | monetaryItemType | text: <entity> 209 </entity> <entity type> monetaryItemType </entity type> <context> A UPA between AEGCo and I&M (the I&M Power Agreement) provides for the sale by AEGCo to I&M of all the energy and capacity available to AEGCo at the Rockport Plant unless it is sold to another utility. I&M is obligated, whether or not power is available from AEGCo, to pay as a demand charge for the right to receive such power (and as an energy charge for any associated energy taken by I&M) net of amounts received by AEGCo from any other sources, sufficient to enable AEGCo to pay all of its operating and other expenses, including a rate of return on the common equity of AEGCo as approved by the FERC. The UPA will continue in effect until the debt obligations of AEGCo secured by the Rockport Plant have been satisfied and discharged (currently expected to be December 2028). I&M’s direct purchases from AEGCo were $ 209 million, $ 181 million and $ 242 million for the years ended December 31, 2024, 2023 and 2022, respectively. These direct purchases are presented as Purchased Electricity from AEP Affiliates on I&M’s statements of income. </context> | us-gaap:RelatedPartyTransactionPurchasesFromRelatedParty |
A UPA between AEGCo and I&M (the I&M Power Agreement) provides for the sale by AEGCo to I&M of all the energy and capacity available to AEGCo at the Rockport Plant unless it is sold to another utility. I&M is obligated, whether or not power is available from AEGCo, to pay as a demand charge for the right to receive such power (and as an energy charge for any associated energy taken by I&M) net of amounts received by AEGCo from any other sources, sufficient to enable AEGCo to pay all of its operating and other expenses, including a rate of return on the common equity of AEGCo as approved by the FERC. The UPA will continue in effect until the debt obligations of AEGCo secured by the Rockport Plant have been satisfied and discharged (currently expected to be December 2028). I&M’s direct purchases from AEGCo were $ 209 million, $ 181 million and $ 242 million for the years ended December 31, 2024, 2023 and 2022, respectively. These direct purchases are presented as Purchased Electricity from AEP Affiliates on I&M’s statements of income. | text | 181 | monetaryItemType | text: <entity> 181 </entity> <entity type> monetaryItemType </entity type> <context> A UPA between AEGCo and I&M (the I&M Power Agreement) provides for the sale by AEGCo to I&M of all the energy and capacity available to AEGCo at the Rockport Plant unless it is sold to another utility. I&M is obligated, whether or not power is available from AEGCo, to pay as a demand charge for the right to receive such power (and as an energy charge for any associated energy taken by I&M) net of amounts received by AEGCo from any other sources, sufficient to enable AEGCo to pay all of its operating and other expenses, including a rate of return on the common equity of AEGCo as approved by the FERC. The UPA will continue in effect until the debt obligations of AEGCo secured by the Rockport Plant have been satisfied and discharged (currently expected to be December 2028). I&M’s direct purchases from AEGCo were $ 209 million, $ 181 million and $ 242 million for the years ended December 31, 2024, 2023 and 2022, respectively. These direct purchases are presented as Purchased Electricity from AEP Affiliates on I&M’s statements of income. </context> | us-gaap:RelatedPartyTransactionPurchasesFromRelatedParty |
A UPA between AEGCo and I&M (the I&M Power Agreement) provides for the sale by AEGCo to I&M of all the energy and capacity available to AEGCo at the Rockport Plant unless it is sold to another utility. I&M is obligated, whether or not power is available from AEGCo, to pay as a demand charge for the right to receive such power (and as an energy charge for any associated energy taken by I&M) net of amounts received by AEGCo from any other sources, sufficient to enable AEGCo to pay all of its operating and other expenses, including a rate of return on the common equity of AEGCo as approved by the FERC. The UPA will continue in effect until the debt obligations of AEGCo secured by the Rockport Plant have been satisfied and discharged (currently expected to be December 2028). I&M’s direct purchases from AEGCo were $ 209 million, $ 181 million and $ 242 million for the years ended December 31, 2024, 2023 and 2022, respectively. These direct purchases are presented as Purchased Electricity from AEP Affiliates on I&M’s statements of income. | text | 242 | monetaryItemType | text: <entity> 242 </entity> <entity type> monetaryItemType </entity type> <context> A UPA between AEGCo and I&M (the I&M Power Agreement) provides for the sale by AEGCo to I&M of all the energy and capacity available to AEGCo at the Rockport Plant unless it is sold to another utility. I&M is obligated, whether or not power is available from AEGCo, to pay as a demand charge for the right to receive such power (and as an energy charge for any associated energy taken by I&M) net of amounts received by AEGCo from any other sources, sufficient to enable AEGCo to pay all of its operating and other expenses, including a rate of return on the common equity of AEGCo as approved by the FERC. The UPA will continue in effect until the debt obligations of AEGCo secured by the Rockport Plant have been satisfied and discharged (currently expected to be December 2028). I&M’s direct purchases from AEGCo were $ 209 million, $ 181 million and $ 242 million for the years ended December 31, 2024, 2023 and 2022, respectively. These direct purchases are presented as Purchased Electricity from AEP Affiliates on I&M’s statements of income. </context> | us-gaap:RelatedPartyTransactionPurchasesFromRelatedParty |
In connection with OPCo’s June 2012 - May 2015 ESP, the PUCO ordered OPCo to conduct energy and capacity auctions for its entire SSO load for delivery beginning in June 2015. AEP Energy and AEPEP participate in the auction process and have been awarded tranches of OPCo’s SSO load. OPCo’s auction purchases were $ 98 million, $ 87 million and $ 10 million for the years ended December 31, 2024, 2023 and 2022, respectively. These direct purchases are presented as Purchased Electricity from AEP Affiliates on OPCo’s statements of income. | text | 98 | monetaryItemType | text: <entity> 98 </entity> <entity type> monetaryItemType </entity type> <context> In connection with OPCo’s June 2012 - May 2015 ESP, the PUCO ordered OPCo to conduct energy and capacity auctions for its entire SSO load for delivery beginning in June 2015. AEP Energy and AEPEP participate in the auction process and have been awarded tranches of OPCo’s SSO load. OPCo’s auction purchases were $ 98 million, $ 87 million and $ 10 million for the years ended December 31, 2024, 2023 and 2022, respectively. These direct purchases are presented as Purchased Electricity from AEP Affiliates on OPCo’s statements of income. </context> | us-gaap:RelatedPartyTransactionPurchasesFromRelatedParty |
In connection with OPCo’s June 2012 - May 2015 ESP, the PUCO ordered OPCo to conduct energy and capacity auctions for its entire SSO load for delivery beginning in June 2015. AEP Energy and AEPEP participate in the auction process and have been awarded tranches of OPCo’s SSO load. OPCo’s auction purchases were $ 98 million, $ 87 million and $ 10 million for the years ended December 31, 2024, 2023 and 2022, respectively. These direct purchases are presented as Purchased Electricity from AEP Affiliates on OPCo’s statements of income. | text | 87 | monetaryItemType | text: <entity> 87 </entity> <entity type> monetaryItemType </entity type> <context> In connection with OPCo’s June 2012 - May 2015 ESP, the PUCO ordered OPCo to conduct energy and capacity auctions for its entire SSO load for delivery beginning in June 2015. AEP Energy and AEPEP participate in the auction process and have been awarded tranches of OPCo’s SSO load. OPCo’s auction purchases were $ 98 million, $ 87 million and $ 10 million for the years ended December 31, 2024, 2023 and 2022, respectively. These direct purchases are presented as Purchased Electricity from AEP Affiliates on OPCo’s statements of income. </context> | us-gaap:RelatedPartyTransactionPurchasesFromRelatedParty |
In connection with OPCo’s June 2012 - May 2015 ESP, the PUCO ordered OPCo to conduct energy and capacity auctions for its entire SSO load for delivery beginning in June 2015. AEP Energy and AEPEP participate in the auction process and have been awarded tranches of OPCo’s SSO load. OPCo’s auction purchases were $ 98 million, $ 87 million and $ 10 million for the years ended December 31, 2024, 2023 and 2022, respectively. These direct purchases are presented as Purchased Electricity from AEP Affiliates on OPCo’s statements of income. | text | 10 | monetaryItemType | text: <entity> 10 </entity> <entity type> monetaryItemType </entity type> <context> In connection with OPCo’s June 2012 - May 2015 ESP, the PUCO ordered OPCo to conduct energy and capacity auctions for its entire SSO load for delivery beginning in June 2015. AEP Energy and AEPEP participate in the auction process and have been awarded tranches of OPCo’s SSO load. OPCo’s auction purchases were $ 98 million, $ 87 million and $ 10 million for the years ended December 31, 2024, 2023 and 2022, respectively. These direct purchases are presented as Purchased Electricity from AEP Affiliates on OPCo’s statements of income. </context> | us-gaap:RelatedPartyTransactionPurchasesFromRelatedParty |
Certain AEP subsidiaries had affiliated sales and purchases of electric property individually amounting to $ 100 thousand or more, sales and purchases of meters and transformers, and sales and purchases of transmission property. There were no gains or losses recorded on the transactions and the net book value of all sales and purchases for the years ended December 31, 2024, 2023 and 2022 were not material. These sales and purchases are recorded in Property, Plant and Equipment on the balance sheets. | text | 100 | monetaryItemType | text: <entity> 100 </entity> <entity type> monetaryItemType </entity type> <context> Certain AEP subsidiaries had affiliated sales and purchases of electric property individually amounting to $ 100 thousand or more, sales and purchases of meters and transformers, and sales and purchases of transmission property. There were no gains or losses recorded on the transactions and the net book value of all sales and purchases for the years ended December 31, 2024, 2023 and 2022 were not material. These sales and purchases are recorded in Property, Plant and Equipment on the balance sheets. </context> | us-gaap:RelatedPartyTransactionPurchasesFromRelatedParty |
For the years ended December 31, 2023 and 2022, AEP made contributions of $ 0.1 million and $ 0.2 million, respectively, to Clean Affordable Reliable Coalition (CARE), a 501(c)(6) organization established to encourage communication, discussion and concerted action related to tax policy associated with clean, affordable and reliable power initiatives. These contributions were made in the ordinary course of business. AEP was a member of CARE and provided the organization its primary financial support. In addition, an employee of AEP served as a board member of the organization during 2023 and 2022. AEP management has determined these contributions are Related Party transactions under ASC 850 based on AEP’s ability to significantly influence the management and operating policies of CARE. AEP made no contributions to CARE in 2024. | text | 0.1 | monetaryItemType | text: <entity> 0.1 </entity> <entity type> monetaryItemType </entity type> <context> For the years ended December 31, 2023 and 2022, AEP made contributions of $ 0.1 million and $ 0.2 million, respectively, to Clean Affordable Reliable Coalition (CARE), a 501(c)(6) organization established to encourage communication, discussion and concerted action related to tax policy associated with clean, affordable and reliable power initiatives. These contributions were made in the ordinary course of business. AEP was a member of CARE and provided the organization its primary financial support. In addition, an employee of AEP served as a board member of the organization during 2023 and 2022. AEP management has determined these contributions are Related Party transactions under ASC 850 based on AEP’s ability to significantly influence the management and operating policies of CARE. AEP made no contributions to CARE in 2024. </context> | us-gaap:RelatedPartyTransactionAmountsOfTransaction |
For the years ended December 31, 2023 and 2022, AEP made contributions of $ 0.1 million and $ 0.2 million, respectively, to Clean Affordable Reliable Coalition (CARE), a 501(c)(6) organization established to encourage communication, discussion and concerted action related to tax policy associated with clean, affordable and reliable power initiatives. These contributions were made in the ordinary course of business. AEP was a member of CARE and provided the organization its primary financial support. In addition, an employee of AEP served as a board member of the organization during 2023 and 2022. AEP management has determined these contributions are Related Party transactions under ASC 850 based on AEP’s ability to significantly influence the management and operating policies of CARE. AEP made no contributions to CARE in 2024. | text | 0.2 | monetaryItemType | text: <entity> 0.2 </entity> <entity type> monetaryItemType </entity type> <context> For the years ended December 31, 2023 and 2022, AEP made contributions of $ 0.1 million and $ 0.2 million, respectively, to Clean Affordable Reliable Coalition (CARE), a 501(c)(6) organization established to encourage communication, discussion and concerted action related to tax policy associated with clean, affordable and reliable power initiatives. These contributions were made in the ordinary course of business. AEP was a member of CARE and provided the organization its primary financial support. In addition, an employee of AEP served as a board member of the organization during 2023 and 2022. AEP management has determined these contributions are Related Party transactions under ASC 850 based on AEP’s ability to significantly influence the management and operating policies of CARE. AEP made no contributions to CARE in 2024. </context> | us-gaap:RelatedPartyTransactionAmountsOfTransaction |
For the years ended December 31, 2023 and 2022, AEP made contributions of $ 0.1 million and $ 0.2 million, respectively, to Clean Affordable Reliable Coalition (CARE), a 501(c)(6) organization established to encourage communication, discussion and concerted action related to tax policy associated with clean, affordable and reliable power initiatives. These contributions were made in the ordinary course of business. AEP was a member of CARE and provided the organization its primary financial support. In addition, an employee of AEP served as a board member of the organization during 2023 and 2022. AEP management has determined these contributions are Related Party transactions under ASC 850 based on AEP’s ability to significantly influence the management and operating policies of CARE. AEP made no contributions to CARE in 2024. | text | no | monetaryItemType | text: <entity> no </entity> <entity type> monetaryItemType </entity type> <context> For the years ended December 31, 2023 and 2022, AEP made contributions of $ 0.1 million and $ 0.2 million, respectively, to Clean Affordable Reliable Coalition (CARE), a 501(c)(6) organization established to encourage communication, discussion and concerted action related to tax policy associated with clean, affordable and reliable power initiatives. These contributions were made in the ordinary course of business. AEP was a member of CARE and provided the organization its primary financial support. In addition, an employee of AEP served as a board member of the organization during 2023 and 2022. AEP management has determined these contributions are Related Party transactions under ASC 850 based on AEP’s ability to significantly influence the management and operating policies of CARE. AEP made no contributions to CARE in 2024. </context> | us-gaap:RelatedPartyTransactionAmountsOfTransaction |
Beginning in August 2024, an officer of AEP also served as a member of the board of directors of a company that is a vendor of certain AEP subsidiaries. From August 2024 through December 2024, AEP purchased $ 44 million of distribution and transmission infrastructure services from the related party vendor in the ordinary course of business. Of this amount, $ 25 million was incurred by AEP Texas and $ 13 million was incurred by PSO. The amounts incurred by the remaining Registrant Subsidiaries were not significant. | text | 44 | monetaryItemType | text: <entity> 44 </entity> <entity type> monetaryItemType </entity type> <context> Beginning in August 2024, an officer of AEP also served as a member of the board of directors of a company that is a vendor of certain AEP subsidiaries. From August 2024 through December 2024, AEP purchased $ 44 million of distribution and transmission infrastructure services from the related party vendor in the ordinary course of business. Of this amount, $ 25 million was incurred by AEP Texas and $ 13 million was incurred by PSO. The amounts incurred by the remaining Registrant Subsidiaries were not significant. </context> | us-gaap:RelatedPartyTransactionAmountsOfTransaction |
Beginning in August 2024, an officer of AEP also served as a member of the board of directors of a company that is a vendor of certain AEP subsidiaries. From August 2024 through December 2024, AEP purchased $ 44 million of distribution and transmission infrastructure services from the related party vendor in the ordinary course of business. Of this amount, $ 25 million was incurred by AEP Texas and $ 13 million was incurred by PSO. The amounts incurred by the remaining Registrant Subsidiaries were not significant. | text | 25 | monetaryItemType | text: <entity> 25 </entity> <entity type> monetaryItemType </entity type> <context> Beginning in August 2024, an officer of AEP also served as a member of the board of directors of a company that is a vendor of certain AEP subsidiaries. From August 2024 through December 2024, AEP purchased $ 44 million of distribution and transmission infrastructure services from the related party vendor in the ordinary course of business. Of this amount, $ 25 million was incurred by AEP Texas and $ 13 million was incurred by PSO. The amounts incurred by the remaining Registrant Subsidiaries were not significant. </context> | us-gaap:RelatedPartyTransactionAmountsOfTransaction |
Beginning in August 2024, an officer of AEP also served as a member of the board of directors of a company that is a vendor of certain AEP subsidiaries. From August 2024 through December 2024, AEP purchased $ 44 million of distribution and transmission infrastructure services from the related party vendor in the ordinary course of business. Of this amount, $ 25 million was incurred by AEP Texas and $ 13 million was incurred by PSO. The amounts incurred by the remaining Registrant Subsidiaries were not significant. | text | 13 | monetaryItemType | text: <entity> 13 </entity> <entity type> monetaryItemType </entity type> <context> Beginning in August 2024, an officer of AEP also served as a member of the board of directors of a company that is a vendor of certain AEP subsidiaries. From August 2024 through December 2024, AEP purchased $ 44 million of distribution and transmission infrastructure services from the related party vendor in the ordinary course of business. Of this amount, $ 25 million was incurred by AEP Texas and $ 13 million was incurred by PSO. The amounts incurred by the remaining Registrant Subsidiaries were not significant. </context> | us-gaap:RelatedPartyTransactionAmountsOfTransaction |
See Note 7 - Acquisitions, Dispositions and Impairments for additional information related to the disposal of the 50 % interests in Fowler Ridge 2 which was included in the August 2023 sale of the Competitive Contracted Renewables Portfolio and Flat Ridge 2 which was sold in November 2022. | text | 50 | percentItemType | text: <entity> 50 </entity> <entity type> percentItemType </entity type> <context> See Note 7 - Acquisitions, Dispositions and Impairments for additional information related to the disposal of the 50 % interests in Fowler Ridge 2 which was included in the August 2023 sale of the Competitive Contracted Renewables Portfolio and Flat Ridge 2 which was sold in November 2022. </context> | us-gaap:EquityMethodInvestmentOwnershipPercentage |
$ 100 million. Actual costs may vary due to inflation and changes in reclamation scope. SWEPCo recovers these costs through its fuel clauses. As of December 31, 2024, SWEPCo has recorded an ARO of $ 96 million and has paid or accrued $ 77 million for reclamation costs billed by Sabine. To date, SWEPCo has collected $ 97 million from customers for reclamation costs and expects to collect an additional $ 76 million recorded in Deferred Charges and Other Noncurrent Assets on SWEPCo’s balance sheets. | text | 100 | monetaryItemType | text: <entity> 100 </entity> <entity type> monetaryItemType </entity type> <context> $ 100 million. Actual costs may vary due to inflation and changes in reclamation scope. SWEPCo recovers these costs through its fuel clauses. As of December 31, 2024, SWEPCo has recorded an ARO of $ 96 million and has paid or accrued $ 77 million for reclamation costs billed by Sabine. To date, SWEPCo has collected $ 97 million from customers for reclamation costs and expects to collect an additional $ 76 million recorded in Deferred Charges and Other Noncurrent Assets on SWEPCo’s balance sheets. </context> | us-gaap:MineReclamationAndClosingLiabilityNoncurrent |
$ 100 million. Actual costs may vary due to inflation and changes in reclamation scope. SWEPCo recovers these costs through its fuel clauses. As of December 31, 2024, SWEPCo has recorded an ARO of $ 96 million and has paid or accrued $ 77 million for reclamation costs billed by Sabine. To date, SWEPCo has collected $ 97 million from customers for reclamation costs and expects to collect an additional $ 76 million recorded in Deferred Charges and Other Noncurrent Assets on SWEPCo’s balance sheets. | text | 77 | monetaryItemType | text: <entity> 77 </entity> <entity type> monetaryItemType </entity type> <context> $ 100 million. Actual costs may vary due to inflation and changes in reclamation scope. SWEPCo recovers these costs through its fuel clauses. As of December 31, 2024, SWEPCo has recorded an ARO of $ 96 million and has paid or accrued $ 77 million for reclamation costs billed by Sabine. To date, SWEPCo has collected $ 97 million from customers for reclamation costs and expects to collect an additional $ 76 million recorded in Deferred Charges and Other Noncurrent Assets on SWEPCo’s balance sheets. </context> | us-gaap:AccountsPayableCurrent |
Transition Funding was formed for the sole purpose of issuing and servicing securitization bonds related to restructuring legislation in Texas. Management concluded that AEP Texas is the primary beneficiary of Transition Funding because AEP Texas has the power to direct the most significant activities of the VIE and AEP Texas’ equity interest could potentially be significant. Therefore, AEP Texas is required to consolidate Transition Funding. In December 2024, the final AEP Texas Central Transition Funding III LLC securitization bond matured. As of December 31, 2023, the securitized bond included in Long-term Debt Due Within One Year - Nonaffiliated was $ 72 million and the securitized bond included in Long-term Debt - Nonaffiliated was immaterial on the balance sheet. Transition Funding’s securitized transition assets were $ 64 million as of December 31, 2023, which was presented separately on the face of the balance sheet. | text | 72 | monetaryItemType | text: <entity> 72 </entity> <entity type> monetaryItemType </entity type> <context> Transition Funding was formed for the sole purpose of issuing and servicing securitization bonds related to restructuring legislation in Texas. Management concluded that AEP Texas is the primary beneficiary of Transition Funding because AEP Texas has the power to direct the most significant activities of the VIE and AEP Texas’ equity interest could potentially be significant. Therefore, AEP Texas is required to consolidate Transition Funding. In December 2024, the final AEP Texas Central Transition Funding III LLC securitization bond matured. As of December 31, 2023, the securitized bond included in Long-term Debt Due Within One Year - Nonaffiliated was $ 72 million and the securitized bond included in Long-term Debt - Nonaffiliated was immaterial on the balance sheet. Transition Funding’s securitized transition assets were $ 64 million as of December 31, 2023, which was presented separately on the face of the balance sheet. </context> | us-gaap:SecuredDebt |
Transition Funding was formed for the sole purpose of issuing and servicing securitization bonds related to restructuring legislation in Texas. Management concluded that AEP Texas is the primary beneficiary of Transition Funding because AEP Texas has the power to direct the most significant activities of the VIE and AEP Texas’ equity interest could potentially be significant. Therefore, AEP Texas is required to consolidate Transition Funding. In December 2024, the final AEP Texas Central Transition Funding III LLC securitization bond matured. As of December 31, 2023, the securitized bond included in Long-term Debt Due Within One Year - Nonaffiliated was $ 72 million and the securitized bond included in Long-term Debt - Nonaffiliated was immaterial on the balance sheet. Transition Funding’s securitized transition assets were $ 64 million as of December 31, 2023, which was presented separately on the face of the balance sheet. | text | 64 | monetaryItemType | text: <entity> 64 </entity> <entity type> monetaryItemType </entity type> <context> Transition Funding was formed for the sole purpose of issuing and servicing securitization bonds related to restructuring legislation in Texas. Management concluded that AEP Texas is the primary beneficiary of Transition Funding because AEP Texas has the power to direct the most significant activities of the VIE and AEP Texas’ equity interest could potentially be significant. Therefore, AEP Texas is required to consolidate Transition Funding. In December 2024, the final AEP Texas Central Transition Funding III LLC securitization bond matured. As of December 31, 2023, the securitized bond included in Long-term Debt Due Within One Year - Nonaffiliated was $ 72 million and the securitized bond included in Long-term Debt - Nonaffiliated was immaterial on the balance sheet. Transition Funding’s securitized transition assets were $ 64 million as of December 31, 2023, which was presented separately on the face of the balance sheet. </context> | us-gaap:SecuritizedRegulatoryTransitionAssetsNoncurrent |
Restoration Funding was formed for the sole purpose of issuing and servicing securitization bonds related to storm restoration of AEP Texas’ distribution system primarily due to damage caused by Hurricane Harvey. Management concluded that AEP Texas is the primary beneficiary of Restoration Funding because AEP Texas has the power to direct the most significant activities of the VIE and AEP Texas’ equity interest could potentially be significant. Therefore, AEP Texas is required to consolidate Restoration Funding. As of December 31, 2024 and 2023, $ 24 million and $ 24 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and | text | 24 | monetaryItemType | text: <entity> 24 </entity> <entity type> monetaryItemType </entity type> <context> Restoration Funding was formed for the sole purpose of issuing and servicing securitization bonds related to storm restoration of AEP Texas’ distribution system primarily due to damage caused by Hurricane Harvey. Management concluded that AEP Texas is the primary beneficiary of Restoration Funding because AEP Texas has the power to direct the most significant activities of the VIE and AEP Texas’ equity interest could potentially be significant. Therefore, AEP Texas is required to consolidate Restoration Funding. As of December 31, 2024 and 2023, $ 24 million and $ 24 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and </context> | us-gaap:SecuredDebt |
$ 102 million and $ 126 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Restoration Funding’s securitized assets were $ 117 million and $ 139 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. | text | 102 | monetaryItemType | text: <entity> 102 </entity> <entity type> monetaryItemType </entity type> <context> $ 102 million and $ 126 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Restoration Funding’s securitized assets were $ 117 million and $ 139 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. </context> | us-gaap:SecuredDebt |
$ 102 million and $ 126 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Restoration Funding’s securitized assets were $ 117 million and $ 139 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. | text | 126 | monetaryItemType | text: <entity> 126 </entity> <entity type> monetaryItemType </entity type> <context> $ 102 million and $ 126 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Restoration Funding’s securitized assets were $ 117 million and $ 139 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. </context> | us-gaap:SecuredDebt |
$ 102 million and $ 126 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Restoration Funding’s securitized assets were $ 117 million and $ 139 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. | text | 117 | monetaryItemType | text: <entity> 117 </entity> <entity type> monetaryItemType </entity type> <context> $ 102 million and $ 126 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Restoration Funding’s securitized assets were $ 117 million and $ 139 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. </context> | us-gaap:SecuritizedRegulatoryTransitionAssetsNoncurrent |
$ 102 million and $ 126 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Restoration Funding’s securitized assets were $ 117 million and $ 139 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. | text | 139 | monetaryItemType | text: <entity> 139 </entity> <entity type> monetaryItemType </entity type> <context> $ 102 million and $ 126 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Restoration Funding’s securitized assets were $ 117 million and $ 139 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. </context> | us-gaap:SecuritizedRegulatoryTransitionAssetsNoncurrent |
Appalachian Consumer Rate Relief Funding was formed for the sole purpose of issuing and servicing securitization bonds related to APCo’s under-recovered ENEC deferral balance. Management concluded that APCo is the primary beneficiary of Appalachian Consumer Rate Relief Funding because APCo has the power to direct the most significant activities of the VIE and APCo’s equity interest could potentially be significant. Therefore, APCo is required to consolidate Appalachian Consumer Rate Relief Funding. As of December 31, 2024 and 2023, $ 28 million and $ 27 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and $ 91 million and $ 120 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Appalachian Consumer Rate Relief Funding’s securitized assets were $ 106 million and $ 133 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. | text | 28 | monetaryItemType | text: <entity> 28 </entity> <entity type> monetaryItemType </entity type> <context> Appalachian Consumer Rate Relief Funding was formed for the sole purpose of issuing and servicing securitization bonds related to APCo’s under-recovered ENEC deferral balance. Management concluded that APCo is the primary beneficiary of Appalachian Consumer Rate Relief Funding because APCo has the power to direct the most significant activities of the VIE and APCo’s equity interest could potentially be significant. Therefore, APCo is required to consolidate Appalachian Consumer Rate Relief Funding. As of December 31, 2024 and 2023, $ 28 million and $ 27 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and $ 91 million and $ 120 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Appalachian Consumer Rate Relief Funding’s securitized assets were $ 106 million and $ 133 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. </context> | us-gaap:SecuredDebt |
Appalachian Consumer Rate Relief Funding was formed for the sole purpose of issuing and servicing securitization bonds related to APCo’s under-recovered ENEC deferral balance. Management concluded that APCo is the primary beneficiary of Appalachian Consumer Rate Relief Funding because APCo has the power to direct the most significant activities of the VIE and APCo’s equity interest could potentially be significant. Therefore, APCo is required to consolidate Appalachian Consumer Rate Relief Funding. As of December 31, 2024 and 2023, $ 28 million and $ 27 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and $ 91 million and $ 120 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Appalachian Consumer Rate Relief Funding’s securitized assets were $ 106 million and $ 133 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. | text | 27 | monetaryItemType | text: <entity> 27 </entity> <entity type> monetaryItemType </entity type> <context> Appalachian Consumer Rate Relief Funding was formed for the sole purpose of issuing and servicing securitization bonds related to APCo’s under-recovered ENEC deferral balance. Management concluded that APCo is the primary beneficiary of Appalachian Consumer Rate Relief Funding because APCo has the power to direct the most significant activities of the VIE and APCo’s equity interest could potentially be significant. Therefore, APCo is required to consolidate Appalachian Consumer Rate Relief Funding. As of December 31, 2024 and 2023, $ 28 million and $ 27 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and $ 91 million and $ 120 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Appalachian Consumer Rate Relief Funding’s securitized assets were $ 106 million and $ 133 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. </context> | us-gaap:SecuredDebt |
Appalachian Consumer Rate Relief Funding was formed for the sole purpose of issuing and servicing securitization bonds related to APCo’s under-recovered ENEC deferral balance. Management concluded that APCo is the primary beneficiary of Appalachian Consumer Rate Relief Funding because APCo has the power to direct the most significant activities of the VIE and APCo’s equity interest could potentially be significant. Therefore, APCo is required to consolidate Appalachian Consumer Rate Relief Funding. As of December 31, 2024 and 2023, $ 28 million and $ 27 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and $ 91 million and $ 120 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Appalachian Consumer Rate Relief Funding’s securitized assets were $ 106 million and $ 133 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. | text | 91 | monetaryItemType | text: <entity> 91 </entity> <entity type> monetaryItemType </entity type> <context> Appalachian Consumer Rate Relief Funding was formed for the sole purpose of issuing and servicing securitization bonds related to APCo’s under-recovered ENEC deferral balance. Management concluded that APCo is the primary beneficiary of Appalachian Consumer Rate Relief Funding because APCo has the power to direct the most significant activities of the VIE and APCo’s equity interest could potentially be significant. Therefore, APCo is required to consolidate Appalachian Consumer Rate Relief Funding. As of December 31, 2024 and 2023, $ 28 million and $ 27 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and $ 91 million and $ 120 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Appalachian Consumer Rate Relief Funding’s securitized assets were $ 106 million and $ 133 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. </context> | us-gaap:SecuredDebt |
Appalachian Consumer Rate Relief Funding was formed for the sole purpose of issuing and servicing securitization bonds related to APCo’s under-recovered ENEC deferral balance. Management concluded that APCo is the primary beneficiary of Appalachian Consumer Rate Relief Funding because APCo has the power to direct the most significant activities of the VIE and APCo’s equity interest could potentially be significant. Therefore, APCo is required to consolidate Appalachian Consumer Rate Relief Funding. As of December 31, 2024 and 2023, $ 28 million and $ 27 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and $ 91 million and $ 120 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Appalachian Consumer Rate Relief Funding’s securitized assets were $ 106 million and $ 133 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. | text | 120 | monetaryItemType | text: <entity> 120 </entity> <entity type> monetaryItemType </entity type> <context> Appalachian Consumer Rate Relief Funding was formed for the sole purpose of issuing and servicing securitization bonds related to APCo’s under-recovered ENEC deferral balance. Management concluded that APCo is the primary beneficiary of Appalachian Consumer Rate Relief Funding because APCo has the power to direct the most significant activities of the VIE and APCo’s equity interest could potentially be significant. Therefore, APCo is required to consolidate Appalachian Consumer Rate Relief Funding. As of December 31, 2024 and 2023, $ 28 million and $ 27 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and $ 91 million and $ 120 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Appalachian Consumer Rate Relief Funding’s securitized assets were $ 106 million and $ 133 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. </context> | us-gaap:SecuredDebt |
Appalachian Consumer Rate Relief Funding was formed for the sole purpose of issuing and servicing securitization bonds related to APCo’s under-recovered ENEC deferral balance. Management concluded that APCo is the primary beneficiary of Appalachian Consumer Rate Relief Funding because APCo has the power to direct the most significant activities of the VIE and APCo’s equity interest could potentially be significant. Therefore, APCo is required to consolidate Appalachian Consumer Rate Relief Funding. As of December 31, 2024 and 2023, $ 28 million and $ 27 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and $ 91 million and $ 120 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Appalachian Consumer Rate Relief Funding’s securitized assets were $ 106 million and $ 133 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. | text | 106 | monetaryItemType | text: <entity> 106 </entity> <entity type> monetaryItemType </entity type> <context> Appalachian Consumer Rate Relief Funding was formed for the sole purpose of issuing and servicing securitization bonds related to APCo’s under-recovered ENEC deferral balance. Management concluded that APCo is the primary beneficiary of Appalachian Consumer Rate Relief Funding because APCo has the power to direct the most significant activities of the VIE and APCo’s equity interest could potentially be significant. Therefore, APCo is required to consolidate Appalachian Consumer Rate Relief Funding. As of December 31, 2024 and 2023, $ 28 million and $ 27 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and $ 91 million and $ 120 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Appalachian Consumer Rate Relief Funding’s securitized assets were $ 106 million and $ 133 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. </context> | us-gaap:SecuritizedRegulatoryTransitionAssetsNoncurrent |
Appalachian Consumer Rate Relief Funding was formed for the sole purpose of issuing and servicing securitization bonds related to APCo’s under-recovered ENEC deferral balance. Management concluded that APCo is the primary beneficiary of Appalachian Consumer Rate Relief Funding because APCo has the power to direct the most significant activities of the VIE and APCo’s equity interest could potentially be significant. Therefore, APCo is required to consolidate Appalachian Consumer Rate Relief Funding. As of December 31, 2024 and 2023, $ 28 million and $ 27 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and $ 91 million and $ 120 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Appalachian Consumer Rate Relief Funding’s securitized assets were $ 106 million and $ 133 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. | text | 133 | monetaryItemType | text: <entity> 133 </entity> <entity type> monetaryItemType </entity type> <context> Appalachian Consumer Rate Relief Funding was formed for the sole purpose of issuing and servicing securitization bonds related to APCo’s under-recovered ENEC deferral balance. Management concluded that APCo is the primary beneficiary of Appalachian Consumer Rate Relief Funding because APCo has the power to direct the most significant activities of the VIE and APCo’s equity interest could potentially be significant. Therefore, APCo is required to consolidate Appalachian Consumer Rate Relief Funding. As of December 31, 2024 and 2023, $ 28 million and $ 27 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and $ 91 million and $ 120 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Appalachian Consumer Rate Relief Funding’s securitized assets were $ 106 million and $ 133 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. </context> | us-gaap:SecuritizedRegulatoryTransitionAssetsNoncurrent |
In August 2024, Storm Recovery Funding was formed for the sole purpose of issuing and servicing securitization bonds related to storm recovery primarily related to SWEPCo’s distribution system. Management concluded that SWEPCo is the primary beneficiary of Storm Recovery Funding because SWEPCo has the power to direct the most significant activities of the VIE and SWEPCo’s equity interest could potentially be significant. Therefore, SWEPCo is required to consolidate Storm Recovery Funding. As of December 31, 2024, $ 23 million of the securitized bonds was included in Long-term Debt Due Within One Year - Nonaffiliated and | text | 23 | monetaryItemType | text: <entity> 23 </entity> <entity type> monetaryItemType </entity type> <context> In August 2024, Storm Recovery Funding was formed for the sole purpose of issuing and servicing securitization bonds related to storm recovery primarily related to SWEPCo’s distribution system. Management concluded that SWEPCo is the primary beneficiary of Storm Recovery Funding because SWEPCo has the power to direct the most significant activities of the VIE and SWEPCo’s equity interest could potentially be significant. Therefore, SWEPCo is required to consolidate Storm Recovery Funding. As of December 31, 2024, $ 23 million of the securitized bonds was included in Long-term Debt Due Within One Year - Nonaffiliated and </context> | us-gaap:SecuredDebt |
AEGCo, a wholly-owned subsidiary of Parent, is consolidated by AEP. AEGCo owns a 50 % ownership interest in Rockport Plant, Units 1 and 2. AEGCo sells its portion of the output from the Rockport Plant to I&M. AEP has agreed to provide AEGCo with the funds necessary to satisfy all the debt obligations of AEGCo. I&M is considered to have a significant variable interest in AEGCo due to these transactions. I&M is exposed to losses to the extent it cannot recover the costs of AEGCo through its normal business operations. In the event AEGCo requires financing or other support outside the billings to I&M, it would be provided by AEP. AEGCo’s billings to I&M for the years ended December 31, 2024, 2023 and 2022 were $ 209 million, $ 181 million and $ 242 million, respectively. The carrying amounts of I&M’s liabilities associated with AEGCo as of December 31, 2024 and 2023 were | text | 50 | percentItemType | text: <entity> 50 </entity> <entity type> percentItemType </entity type> <context> AEGCo, a wholly-owned subsidiary of Parent, is consolidated by AEP. AEGCo owns a 50 % ownership interest in Rockport Plant, Units 1 and 2. AEGCo sells its portion of the output from the Rockport Plant to I&M. AEP has agreed to provide AEGCo with the funds necessary to satisfy all the debt obligations of AEGCo. I&M is considered to have a significant variable interest in AEGCo due to these transactions. I&M is exposed to losses to the extent it cannot recover the costs of AEGCo through its normal business operations. In the event AEGCo requires financing or other support outside the billings to I&M, it would be provided by AEP. AEGCo’s billings to I&M for the years ended December 31, 2024, 2023 and 2022 were $ 209 million, $ 181 million and $ 242 million, respectively. The carrying amounts of I&M’s liabilities associated with AEGCo as of December 31, 2024 and 2023 were </context> | us-gaap:JointlyOwnedUtilityPlantProportionateOwnershipShare |
$ 14 million and $ 15 million, respectively. Management estimates the maximum exposure of loss to be equal to the amount of such liabilities. | text | 14 | monetaryItemType | text: <entity> 14 </entity> <entity type> monetaryItemType </entity type> <context> $ 14 million and $ 15 million, respectively. Management estimates the maximum exposure of loss to be equal to the amount of such liabilities. </context> | us-gaap:InvestmentsInAffiliatesSubsidiariesAssociatesAndJointVentures |
$ 14 million and $ 15 million, respectively. Management estimates the maximum exposure of loss to be equal to the amount of such liabilities. | text | 15 | monetaryItemType | text: <entity> 15 </entity> <entity type> monetaryItemType </entity type> <context> $ 14 million and $ 15 million, respectively. Management estimates the maximum exposure of loss to be equal to the amount of such liabilities. </context> | us-gaap:InvestmentsInAffiliatesSubsidiariesAssociatesAndJointVentures |
Devco is a VIE because its operations and activities, including the initial 100 MWs purchase of fuel cells from Bloom Energy, are entirely financed by Parent through borrowings from the Nonutility Money Pool. Parent controls the significant activities of Devco and is exposed to its potential losses to the extent sales of completed fuel cell generation facilities to OPCo are insufficient to cover its costs of operations. AEP intends to recover its investment through the fulfillment of contractual commitments to deploy and install fuel cells to provide electricity service to customers. Based on AEP’s control of Devco, management concluded that AEP is the primary beneficiary and is required to consolidate Devco. In addition, OPCo has a noncontrolling variable interest in Devco because of the pricing structure for the sales of fuel cell generation facilities. As of December 31, 2024, the amounts of CWIP and borrowings from the Nonutility Money Pool were $ 457 million and $ 456 million, respectively. | text | 457 | monetaryItemType | text: <entity> 457 </entity> <entity type> monetaryItemType </entity type> <context> Devco is a VIE because its operations and activities, including the initial 100 MWs purchase of fuel cells from Bloom Energy, are entirely financed by Parent through borrowings from the Nonutility Money Pool. Parent controls the significant activities of Devco and is exposed to its potential losses to the extent sales of completed fuel cell generation facilities to OPCo are insufficient to cover its costs of operations. AEP intends to recover its investment through the fulfillment of contractual commitments to deploy and install fuel cells to provide electricity service to customers. Based on AEP’s control of Devco, management concluded that AEP is the primary beneficiary and is required to consolidate Devco. In addition, OPCo has a noncontrolling variable interest in Devco because of the pricing structure for the sales of fuel cell generation facilities. As of December 31, 2024, the amounts of CWIP and borrowings from the Nonutility Money Pool were $ 457 million and $ 456 million, respectively. </context> | us-gaap:ConstructionInProgressGross |
DHLC is a mining operator which previously sold 50 % of the lignite produced to SWEPCo and 50 % to CLECO. The operations of DHLC are governed by the lignite mining agreement among SWEPCo, CLECO and DHLC. SWEPCo and CLECO share the executive board seats and voting rights equally. In accordance with the lignite mining agreement, each entity is responsible for 50 % of DHLC’s obligations, including debt. SWEPCo and CLECO equally approve DHLC’s annual budget. The creditors of DHLC have no recourse to any AEP entity other than SWEPCo. As SWEPCo is the sole equity owner of DHLC, it receives 100 % of the management fee earned by DHLC. In April 2020, SWEPCo and CLECO jointly filed a notification letter to the LPSC providing notice of the cessation of lignite mining. SWEPCo’s total billings from DHLC for the years ended December 31, 2024, 2023, and 2022 were not material. DHLC paid dividends of $ 1 million, $ 1 million, and $ 25 million to SWEPCo for the years ended December 31, 2024, 2023 and 2022, respectively. SWEPCo does not have the power to control decision making that significantly impacts the economic performance of DHLC because such power is shared with CLECO. As a result, SWEPCo is not required to consolidate DHLC as it is not the primary beneficiary, although it holds a significant variable interest in DHLC. SWEPCo’s equity investment in DHLC is included in Deferred Charges and Other Noncurrent Assets on SWEPCo’s balance sheets. | text | 1 | monetaryItemType | text: <entity> 1 </entity> <entity type> monetaryItemType </entity type> <context> DHLC is a mining operator which previously sold 50 % of the lignite produced to SWEPCo and 50 % to CLECO. The operations of DHLC are governed by the lignite mining agreement among SWEPCo, CLECO and DHLC. SWEPCo and CLECO share the executive board seats and voting rights equally. In accordance with the lignite mining agreement, each entity is responsible for 50 % of DHLC’s obligations, including debt. SWEPCo and CLECO equally approve DHLC’s annual budget. The creditors of DHLC have no recourse to any AEP entity other than SWEPCo. As SWEPCo is the sole equity owner of DHLC, it receives 100 % of the management fee earned by DHLC. In April 2020, SWEPCo and CLECO jointly filed a notification letter to the LPSC providing notice of the cessation of lignite mining. SWEPCo’s total billings from DHLC for the years ended December 31, 2024, 2023, and 2022 were not material. DHLC paid dividends of $ 1 million, $ 1 million, and $ 25 million to SWEPCo for the years ended December 31, 2024, 2023 and 2022, respectively. SWEPCo does not have the power to control decision making that significantly impacts the economic performance of DHLC because such power is shared with CLECO. As a result, SWEPCo is not required to consolidate DHLC as it is not the primary beneficiary, although it holds a significant variable interest in DHLC. SWEPCo’s equity investment in DHLC is included in Deferred Charges and Other Noncurrent Assets on SWEPCo’s balance sheets. </context> | us-gaap:Dividends |
DHLC is a mining operator which previously sold 50 % of the lignite produced to SWEPCo and 50 % to CLECO. The operations of DHLC are governed by the lignite mining agreement among SWEPCo, CLECO and DHLC. SWEPCo and CLECO share the executive board seats and voting rights equally. In accordance with the lignite mining agreement, each entity is responsible for 50 % of DHLC’s obligations, including debt. SWEPCo and CLECO equally approve DHLC’s annual budget. The creditors of DHLC have no recourse to any AEP entity other than SWEPCo. As SWEPCo is the sole equity owner of DHLC, it receives 100 % of the management fee earned by DHLC. In April 2020, SWEPCo and CLECO jointly filed a notification letter to the LPSC providing notice of the cessation of lignite mining. SWEPCo’s total billings from DHLC for the years ended December 31, 2024, 2023, and 2022 were not material. DHLC paid dividends of $ 1 million, $ 1 million, and $ 25 million to SWEPCo for the years ended December 31, 2024, 2023 and 2022, respectively. SWEPCo does not have the power to control decision making that significantly impacts the economic performance of DHLC because such power is shared with CLECO. As a result, SWEPCo is not required to consolidate DHLC as it is not the primary beneficiary, although it holds a significant variable interest in DHLC. SWEPCo’s equity investment in DHLC is included in Deferred Charges and Other Noncurrent Assets on SWEPCo’s balance sheets. | text | 25 | monetaryItemType | text: <entity> 25 </entity> <entity type> monetaryItemType </entity type> <context> DHLC is a mining operator which previously sold 50 % of the lignite produced to SWEPCo and 50 % to CLECO. The operations of DHLC are governed by the lignite mining agreement among SWEPCo, CLECO and DHLC. SWEPCo and CLECO share the executive board seats and voting rights equally. In accordance with the lignite mining agreement, each entity is responsible for 50 % of DHLC’s obligations, including debt. SWEPCo and CLECO equally approve DHLC’s annual budget. The creditors of DHLC have no recourse to any AEP entity other than SWEPCo. As SWEPCo is the sole equity owner of DHLC, it receives 100 % of the management fee earned by DHLC. In April 2020, SWEPCo and CLECO jointly filed a notification letter to the LPSC providing notice of the cessation of lignite mining. SWEPCo’s total billings from DHLC for the years ended December 31, 2024, 2023, and 2022 were not material. DHLC paid dividends of $ 1 million, $ 1 million, and $ 25 million to SWEPCo for the years ended December 31, 2024, 2023 and 2022, respectively. SWEPCo does not have the power to control decision making that significantly impacts the economic performance of DHLC because such power is shared with CLECO. As a result, SWEPCo is not required to consolidate DHLC as it is not the primary beneficiary, although it holds a significant variable interest in DHLC. SWEPCo’s equity investment in DHLC is included in Deferred Charges and Other Noncurrent Assets on SWEPCo’s balance sheets. </context> | us-gaap:Dividends |
ETT designs, acquires, constructs, owns and operates certain transmission facilities in ERCOT. BHE, a nonaffiliated entity, holds a 50 % membership interest in ETT and AEP Transmission Holdco holds a 50 % membership interest in ETT. As a result, AEP, through its wholly-owned subsidiary, holds a 50 % membership interest in ETT. As of December 31, 2024 and 2023, AEP’s investment in ETT was | text | 50 | percentItemType | text: <entity> 50 </entity> <entity type> percentItemType </entity type> <context> ETT designs, acquires, constructs, owns and operates certain transmission facilities in ERCOT. BHE, a nonaffiliated entity, holds a 50 % membership interest in ETT and AEP Transmission Holdco holds a 50 % membership interest in ETT. As a result, AEP, through its wholly-owned subsidiary, holds a 50 % membership interest in ETT. As of December 31, 2024 and 2023, AEP’s investment in ETT was </context> | us-gaap:EquityMethodInvestmentOwnershipPercentage |
and $ 811 million, respectively. AEP’s equity earnings associated with ET | text | 811 | monetaryItemType | text: <entity> 811 </entity> <entity type> monetaryItemType </entity type> <context> and $ 811 million, respectively. AEP’s equity earnings associated with ET </context> | us-gaap:EquityMethodInvestments |
$ 86 million, $ 74 million and $ 74 million for the years ended December 31, 2024, 2023 and 2022, respectively. | text | 86 | monetaryItemType | text: <entity> 86 </entity> <entity type> monetaryItemType </entity type> <context> $ 86 million, $ 74 million and $ 74 million for the years ended December 31, 2024, 2023 and 2022, respectively. </context> | us-gaap:IncomeLossFromEquityMethodInvestments |
$ 86 million, $ 74 million and $ 74 million for the years ended December 31, 2024, 2023 and 2022, respectively. | text | 74 | monetaryItemType | text: <entity> 74 </entity> <entity type> monetaryItemType </entity type> <context> $ 86 million, $ 74 million and $ 74 million for the years ended December 31, 2024, 2023 and 2022, respectively. </context> | us-gaap:IncomeLossFromEquityMethodInvestments |
(a) I&M's annual composite depreciation rate for Generation property is 1.8 % and the depreciable life is 39 years. | text | 1.8 | percentItemType | text: <entity> 1.8 </entity> <entity type> percentItemType </entity type> <context> (a) I&M's annual composite depreciation rate for Generation property is 1.8 % and the depreciable life is 39 years. </context> | us-gaap:PublicUtilitiesPropertyPlantAndEquipmentDisclosureOfCompositeDepreciationRateForPlantsInService |
In April 2024, the Federal EPA finalized revisions to the CCR Rule to expand the scope of the rule to include inactive impoundments at inactive facilities as well as to establish requirements for currently exempt solid waste management units that involve the direct placement of CCR on the land. In the second quarter of 2024, AEP evaluated the applicability of the rule to current and former plant sites and incurred ARO liabilities of $ 602 million and revised cash flow estimates by an additional $ 72 million based on initial cost estimates. See the “Federal EPA’s Revised CCR Rule” section of Note 6 for additional information. | text | 602 | monetaryItemType | text: <entity> 602 </entity> <entity type> monetaryItemType </entity type> <context> In April 2024, the Federal EPA finalized revisions to the CCR Rule to expand the scope of the rule to include inactive impoundments at inactive facilities as well as to establish requirements for currently exempt solid waste management units that involve the direct placement of CCR on the land. In the second quarter of 2024, AEP evaluated the applicability of the rule to current and former plant sites and incurred ARO liabilities of $ 602 million and revised cash flow estimates by an additional $ 72 million based on initial cost estimates. See the “Federal EPA’s Revised CCR Rule” section of Note 6 for additional information. </context> | us-gaap:AssetRetirementObligationLiabilitiesIncurred |
In April 2024, the Federal EPA finalized revisions to the CCR Rule to expand the scope of the rule to include inactive impoundments at inactive facilities as well as to establish requirements for currently exempt solid waste management units that involve the direct placement of CCR on the land. In the second quarter of 2024, AEP evaluated the applicability of the rule to current and former plant sites and incurred ARO liabilities of $ 602 million and revised cash flow estimates by an additional $ 72 million based on initial cost estimates. See the “Federal EPA’s Revised CCR Rule” section of Note 6 for additional information. | text | 72 | monetaryItemType | text: <entity> 72 </entity> <entity type> monetaryItemType </entity type> <context> In April 2024, the Federal EPA finalized revisions to the CCR Rule to expand the scope of the rule to include inactive impoundments at inactive facilities as well as to establish requirements for currently exempt solid waste management units that involve the direct placement of CCR on the land. In the second quarter of 2024, AEP evaluated the applicability of the rule to current and former plant sites and incurred ARO liabilities of $ 602 million and revised cash flow estimates by an additional $ 72 million based on initial cost estimates. See the “Federal EPA’s Revised CCR Rule” section of Note 6 for additional information. </context> | us-gaap:AssetRetirementObligationRevisionOfEstimate |
In December 2024, I&M recorded a $ 176 million revision as a result of the completion of the latest Cook Plant nuclear decommissioning study. I&M's ARO related to nuclear decommissioning costs for the Cook Plant was $ 1.97 billion and $ 2.11 billion as of December 31, 2024 and 2023. As of December 31, 2024 and 2023, the fair value of I&M’s assets that are legally restricted for purposes of settling decommissioning liabilities totaled $ 4.03 billion and $ 3.51 billion, respectively. These assets are included in Spent Nuclear Fuel and Decommissioning Trusts on I&M’s balance sheets. | text | 1.97 | monetaryItemType | text: <entity> 1.97 </entity> <entity type> monetaryItemType </entity type> <context> In December 2024, I&M recorded a $ 176 million revision as a result of the completion of the latest Cook Plant nuclear decommissioning study. I&M's ARO related to nuclear decommissioning costs for the Cook Plant was $ 1.97 billion and $ 2.11 billion as of December 31, 2024 and 2023. As of December 31, 2024 and 2023, the fair value of I&M’s assets that are legally restricted for purposes of settling decommissioning liabilities totaled $ 4.03 billion and $ 3.51 billion, respectively. These assets are included in Spent Nuclear Fuel and Decommissioning Trusts on I&M’s balance sheets. </context> | us-gaap:DecommissioningLiabilityNoncurrent |
In December 2024, I&M recorded a $ 176 million revision as a result of the completion of the latest Cook Plant nuclear decommissioning study. I&M's ARO related to nuclear decommissioning costs for the Cook Plant was $ 1.97 billion and $ 2.11 billion as of December 31, 2024 and 2023. As of December 31, 2024 and 2023, the fair value of I&M’s assets that are legally restricted for purposes of settling decommissioning liabilities totaled $ 4.03 billion and $ 3.51 billion, respectively. These assets are included in Spent Nuclear Fuel and Decommissioning Trusts on I&M’s balance sheets. | text | 2.11 | monetaryItemType | text: <entity> 2.11 </entity> <entity type> monetaryItemType </entity type> <context> In December 2024, I&M recorded a $ 176 million revision as a result of the completion of the latest Cook Plant nuclear decommissioning study. I&M's ARO related to nuclear decommissioning costs for the Cook Plant was $ 1.97 billion and $ 2.11 billion as of December 31, 2024 and 2023. As of December 31, 2024 and 2023, the fair value of I&M’s assets that are legally restricted for purposes of settling decommissioning liabilities totaled $ 4.03 billion and $ 3.51 billion, respectively. These assets are included in Spent Nuclear Fuel and Decommissioning Trusts on I&M’s balance sheets. </context> | us-gaap:DecommissioningLiabilityNoncurrent |
In December 2024, I&M recorded a $ 176 million revision as a result of the completion of the latest Cook Plant nuclear decommissioning study. I&M's ARO related to nuclear decommissioning costs for the Cook Plant was $ 1.97 billion and $ 2.11 billion as of December 31, 2024 and 2023. As of December 31, 2024 and 2023, the fair value of I&M’s assets that are legally restricted for purposes of settling decommissioning liabilities totaled $ 4.03 billion and $ 3.51 billion, respectively. These assets are included in Spent Nuclear Fuel and Decommissioning Trusts on I&M’s balance sheets. | text | 4.03 | monetaryItemType | text: <entity> 4.03 </entity> <entity type> monetaryItemType </entity type> <context> In December 2024, I&M recorded a $ 176 million revision as a result of the completion of the latest Cook Plant nuclear decommissioning study. I&M's ARO related to nuclear decommissioning costs for the Cook Plant was $ 1.97 billion and $ 2.11 billion as of December 31, 2024 and 2023. As of December 31, 2024 and 2023, the fair value of I&M’s assets that are legally restricted for purposes of settling decommissioning liabilities totaled $ 4.03 billion and $ 3.51 billion, respectively. These assets are included in Spent Nuclear Fuel and Decommissioning Trusts on I&M’s balance sheets. </context> | us-gaap:AssetRetirementObligationLegallyRestrictedAssetsFairValue |
In December 2024, I&M recorded a $ 176 million revision as a result of the completion of the latest Cook Plant nuclear decommissioning study. I&M's ARO related to nuclear decommissioning costs for the Cook Plant was $ 1.97 billion and $ 2.11 billion as of December 31, 2024 and 2023. As of December 31, 2024 and 2023, the fair value of I&M’s assets that are legally restricted for purposes of settling decommissioning liabilities totaled $ 4.03 billion and $ 3.51 billion, respectively. These assets are included in Spent Nuclear Fuel and Decommissioning Trusts on I&M’s balance sheets. | text | 3.51 | monetaryItemType | text: <entity> 3.51 </entity> <entity type> monetaryItemType </entity type> <context> In December 2024, I&M recorded a $ 176 million revision as a result of the completion of the latest Cook Plant nuclear decommissioning study. I&M's ARO related to nuclear decommissioning costs for the Cook Plant was $ 1.97 billion and $ 2.11 billion as of December 31, 2024 and 2023. As of December 31, 2024 and 2023, the fair value of I&M’s assets that are legally restricted for purposes of settling decommissioning liabilities totaled $ 4.03 billion and $ 3.51 billion, respectively. These assets are included in Spent Nuclear Fuel and Decommissioning Trusts on I&M’s balance sheets. </context> | us-gaap:AssetRetirementObligationLegallyRestrictedAssetsFairValue |
Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $ 1.6 billion and Vertically Integrated Utilities was $ 177 million. The remaining affiliated amounts were immaterial. | text | 1.6 | monetaryItemType | text: <entity> 1.6 </entity> <entity type> monetaryItemType </entity type> <context> Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $ 1.6 billion and Vertically Integrated Utilities was $ 177 million. The remaining affiliated amounts were immaterial. </context> | us-gaap:RevenueFromContractWithCustomerExcludingAssessedTax |
Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $ 1.6 billion and Vertically Integrated Utilities was $ 177 million. The remaining affiliated amounts were immaterial. | text | 177 | monetaryItemType | text: <entity> 177 </entity> <entity type> monetaryItemType </entity type> <context> Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $ 1.6 billion and Vertically Integrated Utilities was $ 177 million. The remaining affiliated amounts were immaterial. </context> | us-gaap:RevenueFromContractWithCustomerExcludingAssessedTax |
Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $ 96 million. The remaining affiliated amounts were immaterial. | text | 96 | monetaryItemType | text: <entity> 96 </entity> <entity type> monetaryItemType </entity type> <context> Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $ 96 million. The remaining affiliated amounts were immaterial. </context> | us-gaap:RevenueFromContractWithCustomerExcludingAssessedTax |
Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $ 137 million. The remaining affiliated amounts were immaterial. | text | 137 | monetaryItemType | text: <entity> 137 </entity> <entity type> monetaryItemType </entity type> <context> Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $ 137 million. The remaining affiliated amounts were immaterial. </context> | us-gaap:RevenueFromContractWithCustomerExcludingAssessedTax |
Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $ 1.5 billion and Vertically Integrated Utilities was $ 205 million. The remaining affiliated amounts were immaterial. | text | 1.5 | monetaryItemType | text: <entity> 1.5 </entity> <entity type> monetaryItemType </entity type> <context> Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $ 1.5 billion and Vertically Integrated Utilities was $ 205 million. The remaining affiliated amounts were immaterial. </context> | us-gaap:RevenueFromContractWithCustomerExcludingAssessedTax |
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