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We have a number of ground leases which are classified as operating leases. As of December 31, 2024, our ROU assets and lease liabilities were $ 678,804,000 and $ 749,759,000 , respectively. As of December 31, 2023, our ROU assets and lease liabilities were $ 680,044,000 and $ 732,859,000 , respectively. | text | 678804000 | monetaryItemType | text: <entity> 678804000 </entity> <entity type> monetaryItemType </entity type> <context> We have a number of ground leases which are classified as operating leases. As of December 31, 2024, our ROU assets and lease liabilities were $ 678,804,000 and $ 749,759,000 , respectively. As of December 31, 2023, our ROU assets and lease liabilities were $ 680,044,000 and $ 732,859,000 , respectively. </context> | us-gaap:OperatingLeaseRightOfUseAsset |
We have a number of ground leases which are classified as operating leases. As of December 31, 2024, our ROU assets and lease liabilities were $ 678,804,000 and $ 749,759,000 , respectively. As of December 31, 2023, our ROU assets and lease liabilities were $ 680,044,000 and $ 732,859,000 , respectively. | text | 749759000 | monetaryItemType | text: <entity> 749759000 </entity> <entity type> monetaryItemType </entity type> <context> We have a number of ground leases which are classified as operating leases. As of December 31, 2024, our ROU assets and lease liabilities were $ 678,804,000 and $ 749,759,000 , respectively. As of December 31, 2023, our ROU assets and lease liabilities were $ 680,044,000 and $ 732,859,000 , respectively. </context> | us-gaap:OperatingLeaseLiability |
We have a number of ground leases which are classified as operating leases. As of December 31, 2024, our ROU assets and lease liabilities were $ 678,804,000 and $ 749,759,000 , respectively. As of December 31, 2023, our ROU assets and lease liabilities were $ 680,044,000 and $ 732,859,000 , respectively. | text | 680044000 | monetaryItemType | text: <entity> 680044000 </entity> <entity type> monetaryItemType </entity type> <context> We have a number of ground leases which are classified as operating leases. As of December 31, 2024, our ROU assets and lease liabilities were $ 678,804,000 and $ 749,759,000 , respectively. As of December 31, 2023, our ROU assets and lease liabilities were $ 680,044,000 and $ 732,859,000 , respectively. </context> | us-gaap:OperatingLeaseRightOfUseAsset |
We have a number of ground leases which are classified as operating leases. As of December 31, 2024, our ROU assets and lease liabilities were $ 678,804,000 and $ 749,759,000 , respectively. As of December 31, 2023, our ROU assets and lease liabilities were $ 680,044,000 and $ 732,859,000 , respectively. | text | 732859000 | monetaryItemType | text: <entity> 732859000 </entity> <entity type> monetaryItemType </entity type> <context> We have a number of ground leases which are classified as operating leases. As of December 31, 2024, our ROU assets and lease liabilities were $ 678,804,000 and $ 749,759,000 , respectively. As of December 31, 2023, our ROU assets and lease liabilities were $ 680,044,000 and $ 732,859,000 , respectively. </context> | us-gaap:OperatingLeaseLiability |
The future lease payments detailed above exclude the ground and building lease at the Farley Building. The consolidated joint venture, in which we own a 95 % controlling interest, has a 99 -year triple-net lease with Empire State Development ("ESD") for 846,000 rentable square feet of commercial space at the property, comprised of approximately 730,000 square feet of office space and approximately 116,000 square feet of restaurant and retail space. Our lease of the commercial space at the property is accounted for as a “failed sale-leaseback” as a result of us being deemed the "accounting owner" during development of the property in accordance with ASC 842-40-55 and the lease subsequently meeting "finance lease" classification pursuant to ASC 842-40-25 upon substantial completion. The lease calls for annual rent payments and fixed payments in lieu of real estate taxes ("PILOT") through June 2030. Following the fixed PILOT payment period, the PILOT is calculated in a manner consistent with buildings subject to New York City real estate taxes and assessments. As of December 31, 2024, future rent and fixed PILOT payments are $ 519,049,000 . | text | 95 | percentItemType | text: <entity> 95 </entity> <entity type> percentItemType </entity type> <context> The future lease payments detailed above exclude the ground and building lease at the Farley Building. The consolidated joint venture, in which we own a 95 % controlling interest, has a 99 -year triple-net lease with Empire State Development ("ESD") for 846,000 rentable square feet of commercial space at the property, comprised of approximately 730,000 square feet of office space and approximately 116,000 square feet of restaurant and retail space. Our lease of the commercial space at the property is accounted for as a “failed sale-leaseback” as a result of us being deemed the "accounting owner" during development of the property in accordance with ASC 842-40-55 and the lease subsequently meeting "finance lease" classification pursuant to ASC 842-40-25 upon substantial completion. The lease calls for annual rent payments and fixed payments in lieu of real estate taxes ("PILOT") through June 2030. Following the fixed PILOT payment period, the PILOT is calculated in a manner consistent with buildings subject to New York City real estate taxes and assessments. As of December 31, 2024, future rent and fixed PILOT payments are $ 519,049,000 . </context> | us-gaap:EquityMethodInvestmentOwnershipPercentage |
During the years ended December 31, 2024, 2023 and 2022, we contributed $ 8,059,000 , $ 7,913,000 and $ 7,761,000 , respectively, towards Multiemployer Pension Plans, which is included as a component of “operating” expenses on our consolidated statements of income. Our subsidiaries’ contributions did not represent more than 5% of total employer contributions in any of these plans for the years ended December 31, 2024, 2023 and 2022. | text | 8059000 | monetaryItemType | text: <entity> 8059000 </entity> <entity type> monetaryItemType </entity type> <context> During the years ended December 31, 2024, 2023 and 2022, we contributed $ 8,059,000 , $ 7,913,000 and $ 7,761,000 , respectively, towards Multiemployer Pension Plans, which is included as a component of “operating” expenses on our consolidated statements of income. Our subsidiaries’ contributions did not represent more than 5% of total employer contributions in any of these plans for the years ended December 31, 2024, 2023 and 2022. </context> | us-gaap:MultiemployerPlanEmployerContributionCost |
During the years ended December 31, 2024, 2023 and 2022, we contributed $ 8,059,000 , $ 7,913,000 and $ 7,761,000 , respectively, towards Multiemployer Pension Plans, which is included as a component of “operating” expenses on our consolidated statements of income. Our subsidiaries’ contributions did not represent more than 5% of total employer contributions in any of these plans for the years ended December 31, 2024, 2023 and 2022. | text | 7913000 | monetaryItemType | text: <entity> 7913000 </entity> <entity type> monetaryItemType </entity type> <context> During the years ended December 31, 2024, 2023 and 2022, we contributed $ 8,059,000 , $ 7,913,000 and $ 7,761,000 , respectively, towards Multiemployer Pension Plans, which is included as a component of “operating” expenses on our consolidated statements of income. Our subsidiaries’ contributions did not represent more than 5% of total employer contributions in any of these plans for the years ended December 31, 2024, 2023 and 2022. </context> | us-gaap:MultiemployerPlanEmployerContributionCost |
During the years ended December 31, 2024, 2023 and 2022, we contributed $ 8,059,000 , $ 7,913,000 and $ 7,761,000 , respectively, towards Multiemployer Pension Plans, which is included as a component of “operating” expenses on our consolidated statements of income. Our subsidiaries’ contributions did not represent more than 5% of total employer contributions in any of these plans for the years ended December 31, 2024, 2023 and 2022. | text | 7761000 | monetaryItemType | text: <entity> 7761000 </entity> <entity type> monetaryItemType </entity type> <context> During the years ended December 31, 2024, 2023 and 2022, we contributed $ 8,059,000 , $ 7,913,000 and $ 7,761,000 , respectively, towards Multiemployer Pension Plans, which is included as a component of “operating” expenses on our consolidated statements of income. Our subsidiaries’ contributions did not represent more than 5% of total employer contributions in any of these plans for the years ended December 31, 2024, 2023 and 2022. </context> | us-gaap:MultiemployerPlanEmployerContributionCost |
Multiemployer Health Plans in which our subsidiaries participate provide health benefits to eligible active and retired employees. During the years ended December 31, 2024, 2023 and 2022, our subsidiaries contributed $ 29,555,000 , $ 28,764,000 and $ 26,514,000 , respectively, towards these plans, which is included as a component of “operating” expenses on our consolidated statements of income. | text | 29555000 | monetaryItemType | text: <entity> 29555000 </entity> <entity type> monetaryItemType </entity type> <context> Multiemployer Health Plans in which our subsidiaries participate provide health benefits to eligible active and retired employees. During the years ended December 31, 2024, 2023 and 2022, our subsidiaries contributed $ 29,555,000 , $ 28,764,000 and $ 26,514,000 , respectively, towards these plans, which is included as a component of “operating” expenses on our consolidated statements of income. </context> | us-gaap:MultiemployerPlanEmployerContributionCost |
Multiemployer Health Plans in which our subsidiaries participate provide health benefits to eligible active and retired employees. During the years ended December 31, 2024, 2023 and 2022, our subsidiaries contributed $ 29,555,000 , $ 28,764,000 and $ 26,514,000 , respectively, towards these plans, which is included as a component of “operating” expenses on our consolidated statements of income. | text | 28764000 | monetaryItemType | text: <entity> 28764000 </entity> <entity type> monetaryItemType </entity type> <context> Multiemployer Health Plans in which our subsidiaries participate provide health benefits to eligible active and retired employees. During the years ended December 31, 2024, 2023 and 2022, our subsidiaries contributed $ 29,555,000 , $ 28,764,000 and $ 26,514,000 , respectively, towards these plans, which is included as a component of “operating” expenses on our consolidated statements of income. </context> | us-gaap:MultiemployerPlanEmployerContributionCost |
Multiemployer Health Plans in which our subsidiaries participate provide health benefits to eligible active and retired employees. During the years ended December 31, 2024, 2023 and 2022, our subsidiaries contributed $ 29,555,000 , $ 28,764,000 and $ 26,514,000 , respectively, towards these plans, which is included as a component of “operating” expenses on our consolidated statements of income. | text | 26514000 | monetaryItemType | text: <entity> 26514000 </entity> <entity type> monetaryItemType </entity type> <context> Multiemployer Health Plans in which our subsidiaries participate provide health benefits to eligible active and retired employees. During the years ended December 31, 2024, 2023 and 2022, our subsidiaries contributed $ 29,555,000 , $ 28,764,000 and $ 26,514,000 , respectively, towards these plans, which is included as a component of “operating” expenses on our consolidated statements of income. </context> | us-gaap:MultiemployerPlanEmployerContributionCost |
As of December 31, 2024, $ 57,643,000 of letters of credit were outstanding under our unsecured revolving credit facilities. Our unsecured revolving credit facilities contain financial covenants that require us to maintain minimum interest coverage and maximum debt to market capitalization ratios, and provide for increased interest rates in the event of a decline in the credit rating assigned to our senior unsecured notes. Our unsecured revolving credit facilities also contain customary conditions precedent to borrowing, including representations and warranties, and also contain customary events of default that could give rise to accelerated repayment, including such items as failure to pay interest or principal. | text | 57643000 | monetaryItemType | text: <entity> 57643000 </entity> <entity type> monetaryItemType </entity type> <context> As of December 31, 2024, $ 57,643,000 of letters of credit were outstanding under our unsecured revolving credit facilities. Our unsecured revolving credit facilities contain financial covenants that require us to maintain minimum interest coverage and maximum debt to market capitalization ratios, and provide for increased interest rates in the event of a decline in the credit rating assigned to our senior unsecured notes. Our unsecured revolving credit facilities also contain customary conditions precedent to borrowing, including representations and warranties, and also contain customary events of default that could give rise to accelerated repayment, including such items as failure to pay interest or principal. </context> | us-gaap:LettersOfCreditOutstandingAmount |
Our 95 % consolidated joint venture ( 5 % is owned by Related Companies ("Related")) developed and owns the Farley Building. In connection with the development of the property, the joint venture admitted a historic Tax Credit Investor partner. Under the terms of the historic tax credit arrangement, the joint venture is required to comply with various laws, regulations, and contractual provisions. Non-compliance with applicable requirements could result in projected tax benefits not being realized and, therefore, may require a refund or reduction of the Tax Credit Investor’s capital contributions. As of December 31, 2024, the Tax Credit Investor has made $ 208,407,000 in capital contributions. Vornado and Related have guaranteed certain of the joint venture’s obligations to the Tax Credit Investor. | text | 95 | percentItemType | text: <entity> 95 </entity> <entity type> percentItemType </entity type> <context> Our 95 % consolidated joint venture ( 5 % is owned by Related Companies ("Related")) developed and owns the Farley Building. In connection with the development of the property, the joint venture admitted a historic Tax Credit Investor partner. Under the terms of the historic tax credit arrangement, the joint venture is required to comply with various laws, regulations, and contractual provisions. Non-compliance with applicable requirements could result in projected tax benefits not being realized and, therefore, may require a refund or reduction of the Tax Credit Investor’s capital contributions. As of December 31, 2024, the Tax Credit Investor has made $ 208,407,000 in capital contributions. Vornado and Related have guaranteed certain of the joint venture’s obligations to the Tax Credit Investor. </context> | us-gaap:EquityMethodInvestmentOwnershipPercentage |
Our 95 % consolidated joint venture ( 5 % is owned by Related Companies ("Related")) developed and owns the Farley Building. In connection with the development of the property, the joint venture admitted a historic Tax Credit Investor partner. Under the terms of the historic tax credit arrangement, the joint venture is required to comply with various laws, regulations, and contractual provisions. Non-compliance with applicable requirements could result in projected tax benefits not being realized and, therefore, may require a refund or reduction of the Tax Credit Investor’s capital contributions. As of December 31, 2024, the Tax Credit Investor has made $ 208,407,000 in capital contributions. Vornado and Related have guaranteed certain of the joint venture’s obligations to the Tax Credit Investor. | text | 5 | percentItemType | text: <entity> 5 </entity> <entity type> percentItemType </entity type> <context> Our 95 % consolidated joint venture ( 5 % is owned by Related Companies ("Related")) developed and owns the Farley Building. In connection with the development of the property, the joint venture admitted a historic Tax Credit Investor partner. Under the terms of the historic tax credit arrangement, the joint venture is required to comply with various laws, regulations, and contractual provisions. Non-compliance with applicable requirements could result in projected tax benefits not being realized and, therefore, may require a refund or reduction of the Tax Credit Investor’s capital contributions. As of December 31, 2024, the Tax Credit Investor has made $ 208,407,000 in capital contributions. Vornado and Related have guaranteed certain of the joint venture’s obligations to the Tax Credit Investor. </context> | us-gaap:EquityMethodInvestmentOwnershipPercentage |
Our 95 % consolidated joint venture ( 5 % is owned by Related Companies ("Related")) developed and owns the Farley Building. In connection with the development of the property, the joint venture admitted a historic Tax Credit Investor partner. Under the terms of the historic tax credit arrangement, the joint venture is required to comply with various laws, regulations, and contractual provisions. Non-compliance with applicable requirements could result in projected tax benefits not being realized and, therefore, may require a refund or reduction of the Tax Credit Investor’s capital contributions. As of December 31, 2024, the Tax Credit Investor has made $ 208,407,000 in capital contributions. Vornado and Related have guaranteed certain of the joint venture’s obligations to the Tax Credit Investor. | text | 208407000 | monetaryItemType | text: <entity> 208407000 </entity> <entity type> monetaryItemType </entity type> <context> Our 95 % consolidated joint venture ( 5 % is owned by Related Companies ("Related")) developed and owns the Farley Building. In connection with the development of the property, the joint venture admitted a historic Tax Credit Investor partner. Under the terms of the historic tax credit arrangement, the joint venture is required to comply with various laws, regulations, and contractual provisions. Non-compliance with applicable requirements could result in projected tax benefits not being realized and, therefore, may require a refund or reduction of the Tax Credit Investor’s capital contributions. As of December 31, 2024, the Tax Credit Investor has made $ 208,407,000 in capital contributions. Vornado and Related have guaranteed certain of the joint venture’s obligations to the Tax Credit Investor. </context> | us-gaap:OtherOwnershipInterestsValue |
As of December 31, 2024, we had construction commitments aggregating approximately $ 61,016,000 . | text | 61016000 | monetaryItemType | text: <entity> 61016000 </entity> <entity type> monetaryItemType </entity type> <context> As of December 31, 2024, we had construction commitments aggregating approximately $ 61,016,000 . </context> | us-gaap:OtherCommitment |
We manage and lease the real estate assets of Interstate pursuant to a management agreement for which we receive an annual fee equal to 4 % of annual base rent and percentage rent. The management agreement has a term of one year and is automatically renewable unless terminated by either of the parties on 60 days’ notice at the end of the term. We believe, based upon comparable fees charged by other real estate companies, that the management agreement terms are consistent with the market. We earned $ 208,000 , $ 206,000 , and $ 204,000 of management fees under the agreement for the years ended December 31, 2024, 2023 and 2022, respectively. | text | 4 | percentItemType | text: <entity> 4 </entity> <entity type> percentItemType </entity type> <context> We manage and lease the real estate assets of Interstate pursuant to a management agreement for which we receive an annual fee equal to 4 % of annual base rent and percentage rent. The management agreement has a term of one year and is automatically renewable unless terminated by either of the parties on 60 days’ notice at the end of the term. We believe, based upon comparable fees charged by other real estate companies, that the management agreement terms are consistent with the market. We earned $ 208,000 , $ 206,000 , and $ 204,000 of management fees under the agreement for the years ended December 31, 2024, 2023 and 2022, respectively. </context> | us-gaap:PropertyManagementFeePercentFee |
We manage and lease the real estate assets of Interstate pursuant to a management agreement for which we receive an annual fee equal to 4 % of annual base rent and percentage rent. The management agreement has a term of one year and is automatically renewable unless terminated by either of the parties on 60 days’ notice at the end of the term. We believe, based upon comparable fees charged by other real estate companies, that the management agreement terms are consistent with the market. We earned $ 208,000 , $ 206,000 , and $ 204,000 of management fees under the agreement for the years ended December 31, 2024, 2023 and 2022, respectively. | text | 208000 | monetaryItemType | text: <entity> 208000 </entity> <entity type> monetaryItemType </entity type> <context> We manage and lease the real estate assets of Interstate pursuant to a management agreement for which we receive an annual fee equal to 4 % of annual base rent and percentage rent. The management agreement has a term of one year and is automatically renewable unless terminated by either of the parties on 60 days’ notice at the end of the term. We believe, based upon comparable fees charged by other real estate companies, that the management agreement terms are consistent with the market. We earned $ 208,000 , $ 206,000 , and $ 204,000 of management fees under the agreement for the years ended December 31, 2024, 2023 and 2022, respectively. </context> | us-gaap:PropertyManagementFeeRevenue |
We manage and lease the real estate assets of Interstate pursuant to a management agreement for which we receive an annual fee equal to 4 % of annual base rent and percentage rent. The management agreement has a term of one year and is automatically renewable unless terminated by either of the parties on 60 days’ notice at the end of the term. We believe, based upon comparable fees charged by other real estate companies, that the management agreement terms are consistent with the market. We earned $ 208,000 , $ 206,000 , and $ 204,000 of management fees under the agreement for the years ended December 31, 2024, 2023 and 2022, respectively. | text | 206000 | monetaryItemType | text: <entity> 206000 </entity> <entity type> monetaryItemType </entity type> <context> We manage and lease the real estate assets of Interstate pursuant to a management agreement for which we receive an annual fee equal to 4 % of annual base rent and percentage rent. The management agreement has a term of one year and is automatically renewable unless terminated by either of the parties on 60 days’ notice at the end of the term. We believe, based upon comparable fees charged by other real estate companies, that the management agreement terms are consistent with the market. We earned $ 208,000 , $ 206,000 , and $ 204,000 of management fees under the agreement for the years ended December 31, 2024, 2023 and 2022, respectively. </context> | us-gaap:PropertyManagementFeeRevenue |
We manage and lease the real estate assets of Interstate pursuant to a management agreement for which we receive an annual fee equal to 4 % of annual base rent and percentage rent. The management agreement has a term of one year and is automatically renewable unless terminated by either of the parties on 60 days’ notice at the end of the term. We believe, based upon comparable fees charged by other real estate companies, that the management agreement terms are consistent with the market. We earned $ 208,000 , $ 206,000 , and $ 204,000 of management fees under the agreement for the years ended December 31, 2024, 2023 and 2022, respectively. | text | 204000 | monetaryItemType | text: <entity> 204000 </entity> <entity type> monetaryItemType </entity type> <context> We manage and lease the real estate assets of Interstate pursuant to a management agreement for which we receive an annual fee equal to 4 % of annual base rent and percentage rent. The management agreement has a term of one year and is automatically renewable unless terminated by either of the parties on 60 days’ notice at the end of the term. We believe, based upon comparable fees charged by other real estate companies, that the management agreement terms are consistent with the market. We earned $ 208,000 , $ 206,000 , and $ 204,000 of management fees under the agreement for the years ended December 31, 2024, 2023 and 2022, respectively. </context> | us-gaap:PropertyManagementFeeRevenue |
We aggregate these operating segments into two reportable segments, New York and Other, which is based on similar economic characteristics. | text | two | integerItemType | text: <entity> two </entity> <entity type> integerItemType </entity type> <context> We aggregate these operating segments into two reportable segments, New York and Other, which is based on similar economic characteristics. </context> | us-gaap:NumberOfReportableSegments |
On January 8, 2025, the Fifth Avenue and Times Square JV completed the sale to UNIQLO of the portion of its U.S. flagship store at 666 Fifth Avenue owned by the retail joint venture for $ 350,000,000 . The joint venture continues to own 23,832 square feet of retail space ( 7,416 square feet at grade) at 666 Fifth Avenue consisting of the Abercrombie & Fitch and Tissot stores. The $ 342,000,000 of net proceeds from the sale were used to partially redeem Vornado’s $ 390,000,000 of preferred equity on the asset. The financial statement gain, which will be recognized in the first quarter of 2025, will be approximately $ 76,000,000 . | text | 350000000 | monetaryItemType | text: <entity> 350000000 </entity> <entity type> monetaryItemType </entity type> <context> On January 8, 2025, the Fifth Avenue and Times Square JV completed the sale to UNIQLO of the portion of its U.S. flagship store at 666 Fifth Avenue owned by the retail joint venture for $ 350,000,000 . The joint venture continues to own 23,832 square feet of retail space ( 7,416 square feet at grade) at 666 Fifth Avenue consisting of the Abercrombie & Fitch and Tissot stores. The $ 342,000,000 of net proceeds from the sale were used to partially redeem Vornado’s $ 390,000,000 of preferred equity on the asset. The financial statement gain, which will be recognized in the first quarter of 2025, will be approximately $ 76,000,000 . </context> | us-gaap:ProceedsFromSaleOfRealEstateHeldforinvestment |
On January 8, 2025, the Fifth Avenue and Times Square JV completed the sale to UNIQLO of the portion of its U.S. flagship store at 666 Fifth Avenue owned by the retail joint venture for $ 350,000,000 . The joint venture continues to own 23,832 square feet of retail space ( 7,416 square feet at grade) at 666 Fifth Avenue consisting of the Abercrombie & Fitch and Tissot stores. The $ 342,000,000 of net proceeds from the sale were used to partially redeem Vornado’s $ 390,000,000 of preferred equity on the asset. The financial statement gain, which will be recognized in the first quarter of 2025, will be approximately $ 76,000,000 . | text | 76000000 | monetaryItemType | text: <entity> 76000000 </entity> <entity type> monetaryItemType </entity type> <context> On January 8, 2025, the Fifth Avenue and Times Square JV completed the sale to UNIQLO of the portion of its U.S. flagship store at 666 Fifth Avenue owned by the retail joint venture for $ 350,000,000 . The joint venture continues to own 23,832 square feet of retail space ( 7,416 square feet at grade) at 666 Fifth Avenue consisting of the Abercrombie & Fitch and Tissot stores. The $ 342,000,000 of net proceeds from the sale were used to partially redeem Vornado’s $ 390,000,000 of preferred equity on the asset. The financial statement gain, which will be recognized in the first quarter of 2025, will be approximately $ 76,000,000 . </context> | us-gaap:GainsLossesOnSalesOfInvestmentRealEstate |
We repaid our $ 450,000,000 3.50 % senior unsecured notes on their January 15, 2025 maturity date. | text | 450000000 | monetaryItemType | text: <entity> 450000000 </entity> <entity type> monetaryItemType </entity type> <context> We repaid our $ 450,000,000 3.50 % senior unsecured notes on their January 15, 2025 maturity date. </context> | us-gaap:RepaymentsOfDebt |
We repaid our $ 450,000,000 3.50 % senior unsecured notes on their January 15, 2025 maturity date. | text | 3.50 | percentItemType | text: <entity> 3.50 </entity> <entity type> percentItemType </entity type> <context> We repaid our $ 450,000,000 3.50 % senior unsecured notes on their January 15, 2025 maturity date. </context> | us-gaap:DebtInstrumentInterestRateStatedPercentage |
On January 17, 2025, we closed on the sale of a condominium unit at 220 CPS for net proceeds of $ 11,695,000 ; three units remain unsold. | text | 11695000 | monetaryItemType | text: <entity> 11695000 </entity> <entity type> monetaryItemType </entity type> <context> On January 17, 2025, we closed on the sale of a condominium unit at 220 CPS for net proceeds of $ 11,695,000 ; three units remain unsold. </context> | us-gaap:ProceedsFromSaleOfRealEstate |
AEP’s public utility subsidiaries’ rates are regulated by the FERC and state regulatory commissions in the eleven state operating territories in which they operate. The FERC also regulates the Registrants’ affiliated transactions, including AEPSC intercompany service billings which are generally at cost, under the 2005 Public Utility Holding Company Act and the Federal Power Act. The FERC also has jurisdiction over certain issuances and acquisitions of securities of the public utility subsidiaries, the acquisition or sale of certain utility assets and mergers with another electric utility or holding company. The state regulatory commissions also regulate certain intercompany transactions under various orders and affiliate statutes. Both the FERC and state regulatory commissions are permitted to review and audit the relevant books and records of companies within a public utility holding company system. | text | eleven | integerItemType | text: <entity> eleven </entity> <entity type> integerItemType </entity type> <context> AEP’s public utility subsidiaries’ rates are regulated by the FERC and state regulatory commissions in the eleven state operating territories in which they operate. The FERC also regulates the Registrants’ affiliated transactions, including AEPSC intercompany service billings which are generally at cost, under the 2005 Public Utility Holding Company Act and the Federal Power Act. The FERC also has jurisdiction over certain issuances and acquisitions of securities of the public utility subsidiaries, the acquisition or sale of certain utility assets and mergers with another electric utility or holding company. The state regulatory commissions also regulate certain intercompany transactions under various orders and affiliate statutes. Both the FERC and state regulatory commissions are permitted to review and audit the relevant books and records of companies within a public utility holding company system. </context> | us-gaap:NumberOfStatesInWhichEntityOperates |
In February 2024, AEP Texas filed a request with the PUCT for a $ 164 million annual base rate increase over its adjusted test year revenues which include interim transmission and distribution rate updates. AEP Texas’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case sought a prudence determination on all capital additions placed in service during the period January 1, 2019 through September 30, 2023. In July 2024, AEP Texas filed an unopposed settlement agreement with the PUCT. The settlement agreement included a proposed annual revenue increase of $ 70 million based upon a 9.76 % ROE with a capital structure of 57.5 % debt and 42.5 % common equity. In addition, the settlement agreement approved the prudency of capital investments placed in service for the period January 1, 2019 through September 30, 2023 and the associated interim revenues collected on those capital investments. In October 2024, the PUCT issued a final order approving the settlement agreement without modification. | text | 164 | monetaryItemType | text: <entity> 164 </entity> <entity type> monetaryItemType </entity type> <context> In February 2024, AEP Texas filed a request with the PUCT for a $ 164 million annual base rate increase over its adjusted test year revenues which include interim transmission and distribution rate updates. AEP Texas’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case sought a prudence determination on all capital additions placed in service during the period January 1, 2019 through September 30, 2023. In July 2024, AEP Texas filed an unopposed settlement agreement with the PUCT. The settlement agreement included a proposed annual revenue increase of $ 70 million based upon a 9.76 % ROE with a capital structure of 57.5 % debt and 42.5 % common equity. In addition, the settlement agreement approved the prudency of capital investments placed in service for the period January 1, 2019 through September 30, 2023 and the associated interim revenues collected on those capital investments. In October 2024, the PUCT issued a final order approving the settlement agreement without modification. </context> | us-gaap:PublicUtilitiesRequestedRateIncreaseDecreaseAmount |
In February 2024, AEP Texas filed a request with the PUCT for a $ 164 million annual base rate increase over its adjusted test year revenues which include interim transmission and distribution rate updates. AEP Texas’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case sought a prudence determination on all capital additions placed in service during the period January 1, 2019 through September 30, 2023. In July 2024, AEP Texas filed an unopposed settlement agreement with the PUCT. The settlement agreement included a proposed annual revenue increase of $ 70 million based upon a 9.76 % ROE with a capital structure of 57.5 % debt and 42.5 % common equity. In addition, the settlement agreement approved the prudency of capital investments placed in service for the period January 1, 2019 through September 30, 2023 and the associated interim revenues collected on those capital investments. In October 2024, the PUCT issued a final order approving the settlement agreement without modification. | text | 10.6 | percentItemType | text: <entity> 10.6 </entity> <entity type> percentItemType </entity type> <context> In February 2024, AEP Texas filed a request with the PUCT for a $ 164 million annual base rate increase over its adjusted test year revenues which include interim transmission and distribution rate updates. AEP Texas’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case sought a prudence determination on all capital additions placed in service during the period January 1, 2019 through September 30, 2023. In July 2024, AEP Texas filed an unopposed settlement agreement with the PUCT. The settlement agreement included a proposed annual revenue increase of $ 70 million based upon a 9.76 % ROE with a capital structure of 57.5 % debt and 42.5 % common equity. In addition, the settlement agreement approved the prudency of capital investments placed in service for the period January 1, 2019 through September 30, 2023 and the associated interim revenues collected on those capital investments. In October 2024, the PUCT issued a final order approving the settlement agreement without modification. </context> | us-gaap:PublicUtilitiesRequestedReturnOnEquityPercentage |
In February 2024, AEP Texas filed a request with the PUCT for a $ 164 million annual base rate increase over its adjusted test year revenues which include interim transmission and distribution rate updates. AEP Texas’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case sought a prudence determination on all capital additions placed in service during the period January 1, 2019 through September 30, 2023. In July 2024, AEP Texas filed an unopposed settlement agreement with the PUCT. The settlement agreement included a proposed annual revenue increase of $ 70 million based upon a 9.76 % ROE with a capital structure of 57.5 % debt and 42.5 % common equity. In addition, the settlement agreement approved the prudency of capital investments placed in service for the period January 1, 2019 through September 30, 2023 and the associated interim revenues collected on those capital investments. In October 2024, the PUCT issued a final order approving the settlement agreement without modification. | text | 55 | percentItemType | text: <entity> 55 </entity> <entity type> percentItemType </entity type> <context> In February 2024, AEP Texas filed a request with the PUCT for a $ 164 million annual base rate increase over its adjusted test year revenues which include interim transmission and distribution rate updates. AEP Texas’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case sought a prudence determination on all capital additions placed in service during the period January 1, 2019 through September 30, 2023. In July 2024, AEP Texas filed an unopposed settlement agreement with the PUCT. The settlement agreement included a proposed annual revenue increase of $ 70 million based upon a 9.76 % ROE with a capital structure of 57.5 % debt and 42.5 % common equity. In addition, the settlement agreement approved the prudency of capital investments placed in service for the period January 1, 2019 through September 30, 2023 and the associated interim revenues collected on those capital investments. In October 2024, the PUCT issued a final order approving the settlement agreement without modification. </context> | us-gaap:PublicUtilitiesRequestedDebtCapitalStructurePercentage |
In February 2024, AEP Texas filed a request with the PUCT for a $ 164 million annual base rate increase over its adjusted test year revenues which include interim transmission and distribution rate updates. AEP Texas’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case sought a prudence determination on all capital additions placed in service during the period January 1, 2019 through September 30, 2023. In July 2024, AEP Texas filed an unopposed settlement agreement with the PUCT. The settlement agreement included a proposed annual revenue increase of $ 70 million based upon a 9.76 % ROE with a capital structure of 57.5 % debt and 42.5 % common equity. In addition, the settlement agreement approved the prudency of capital investments placed in service for the period January 1, 2019 through September 30, 2023 and the associated interim revenues collected on those capital investments. In October 2024, the PUCT issued a final order approving the settlement agreement without modification. | text | 45 | percentItemType | text: <entity> 45 </entity> <entity type> percentItemType </entity type> <context> In February 2024, AEP Texas filed a request with the PUCT for a $ 164 million annual base rate increase over its adjusted test year revenues which include interim transmission and distribution rate updates. AEP Texas’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case sought a prudence determination on all capital additions placed in service during the period January 1, 2019 through September 30, 2023. In July 2024, AEP Texas filed an unopposed settlement agreement with the PUCT. The settlement agreement included a proposed annual revenue increase of $ 70 million based upon a 9.76 % ROE with a capital structure of 57.5 % debt and 42.5 % common equity. In addition, the settlement agreement approved the prudency of capital investments placed in service for the period January 1, 2019 through September 30, 2023 and the associated interim revenues collected on those capital investments. In October 2024, the PUCT issued a final order approving the settlement agreement without modification. </context> | us-gaap:PublicUtilitiesRequestedEquityCapitalStructurePercentage |
In February 2024, AEP Texas filed a request with the PUCT for a $ 164 million annual base rate increase over its adjusted test year revenues which include interim transmission and distribution rate updates. AEP Texas’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case sought a prudence determination on all capital additions placed in service during the period January 1, 2019 through September 30, 2023. In July 2024, AEP Texas filed an unopposed settlement agreement with the PUCT. The settlement agreement included a proposed annual revenue increase of $ 70 million based upon a 9.76 % ROE with a capital structure of 57.5 % debt and 42.5 % common equity. In addition, the settlement agreement approved the prudency of capital investments placed in service for the period January 1, 2019 through September 30, 2023 and the associated interim revenues collected on those capital investments. In October 2024, the PUCT issued a final order approving the settlement agreement without modification. | text | 70 | monetaryItemType | text: <entity> 70 </entity> <entity type> monetaryItemType </entity type> <context> In February 2024, AEP Texas filed a request with the PUCT for a $ 164 million annual base rate increase over its adjusted test year revenues which include interim transmission and distribution rate updates. AEP Texas’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case sought a prudence determination on all capital additions placed in service during the period January 1, 2019 through September 30, 2023. In July 2024, AEP Texas filed an unopposed settlement agreement with the PUCT. The settlement agreement included a proposed annual revenue increase of $ 70 million based upon a 9.76 % ROE with a capital structure of 57.5 % debt and 42.5 % common equity. In addition, the settlement agreement approved the prudency of capital investments placed in service for the period January 1, 2019 through September 30, 2023 and the associated interim revenues collected on those capital investments. In October 2024, the PUCT issued a final order approving the settlement agreement without modification. </context> | us-gaap:PublicUtilitiesApprovedRateIncreaseDecreaseAmount |
In February 2024, AEP Texas filed a request with the PUCT for a $ 164 million annual base rate increase over its adjusted test year revenues which include interim transmission and distribution rate updates. AEP Texas’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case sought a prudence determination on all capital additions placed in service during the period January 1, 2019 through September 30, 2023. In July 2024, AEP Texas filed an unopposed settlement agreement with the PUCT. The settlement agreement included a proposed annual revenue increase of $ 70 million based upon a 9.76 % ROE with a capital structure of 57.5 % debt and 42.5 % common equity. In addition, the settlement agreement approved the prudency of capital investments placed in service for the period January 1, 2019 through September 30, 2023 and the associated interim revenues collected on those capital investments. In October 2024, the PUCT issued a final order approving the settlement agreement without modification. | text | 9.76 | percentItemType | text: <entity> 9.76 </entity> <entity type> percentItemType </entity type> <context> In February 2024, AEP Texas filed a request with the PUCT for a $ 164 million annual base rate increase over its adjusted test year revenues which include interim transmission and distribution rate updates. AEP Texas’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case sought a prudence determination on all capital additions placed in service during the period January 1, 2019 through September 30, 2023. In July 2024, AEP Texas filed an unopposed settlement agreement with the PUCT. The settlement agreement included a proposed annual revenue increase of $ 70 million based upon a 9.76 % ROE with a capital structure of 57.5 % debt and 42.5 % common equity. In addition, the settlement agreement approved the prudency of capital investments placed in service for the period January 1, 2019 through September 30, 2023 and the associated interim revenues collected on those capital investments. In October 2024, the PUCT issued a final order approving the settlement agreement without modification. </context> | us-gaap:PublicUtilitiesApprovedReturnOnEquityPercentage |
In February 2024, AEP Texas filed a request with the PUCT for a $ 164 million annual base rate increase over its adjusted test year revenues which include interim transmission and distribution rate updates. AEP Texas’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case sought a prudence determination on all capital additions placed in service during the period January 1, 2019 through September 30, 2023. In July 2024, AEP Texas filed an unopposed settlement agreement with the PUCT. The settlement agreement included a proposed annual revenue increase of $ 70 million based upon a 9.76 % ROE with a capital structure of 57.5 % debt and 42.5 % common equity. In addition, the settlement agreement approved the prudency of capital investments placed in service for the period January 1, 2019 through September 30, 2023 and the associated interim revenues collected on those capital investments. In October 2024, the PUCT issued a final order approving the settlement agreement without modification. | text | 57.5 | percentItemType | text: <entity> 57.5 </entity> <entity type> percentItemType </entity type> <context> In February 2024, AEP Texas filed a request with the PUCT for a $ 164 million annual base rate increase over its adjusted test year revenues which include interim transmission and distribution rate updates. AEP Texas’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case sought a prudence determination on all capital additions placed in service during the period January 1, 2019 through September 30, 2023. In July 2024, AEP Texas filed an unopposed settlement agreement with the PUCT. The settlement agreement included a proposed annual revenue increase of $ 70 million based upon a 9.76 % ROE with a capital structure of 57.5 % debt and 42.5 % common equity. In addition, the settlement agreement approved the prudency of capital investments placed in service for the period January 1, 2019 through September 30, 2023 and the associated interim revenues collected on those capital investments. In October 2024, the PUCT issued a final order approving the settlement agreement without modification. </context> | us-gaap:PublicUtilitiesApprovedDebtCapitalStructurePercentage |
In February 2024, AEP Texas filed a request with the PUCT for a $ 164 million annual base rate increase over its adjusted test year revenues which include interim transmission and distribution rate updates. AEP Texas’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case sought a prudence determination on all capital additions placed in service during the period January 1, 2019 through September 30, 2023. In July 2024, AEP Texas filed an unopposed settlement agreement with the PUCT. The settlement agreement included a proposed annual revenue increase of $ 70 million based upon a 9.76 % ROE with a capital structure of 57.5 % debt and 42.5 % common equity. In addition, the settlement agreement approved the prudency of capital investments placed in service for the period January 1, 2019 through September 30, 2023 and the associated interim revenues collected on those capital investments. In October 2024, the PUCT issued a final order approving the settlement agreement without modification. | text | 42.5 | percentItemType | text: <entity> 42.5 </entity> <entity type> percentItemType </entity type> <context> In February 2024, AEP Texas filed a request with the PUCT for a $ 164 million annual base rate increase over its adjusted test year revenues which include interim transmission and distribution rate updates. AEP Texas’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case sought a prudence determination on all capital additions placed in service during the period January 1, 2019 through September 30, 2023. In July 2024, AEP Texas filed an unopposed settlement agreement with the PUCT. The settlement agreement included a proposed annual revenue increase of $ 70 million based upon a 9.76 % ROE with a capital structure of 57.5 % debt and 42.5 % common equity. In addition, the settlement agreement approved the prudency of capital investments placed in service for the period January 1, 2019 through September 30, 2023 and the associated interim revenues collected on those capital investments. In October 2024, the PUCT issued a final order approving the settlement agreement without modification. </context> | us-gaap:PublicUtilitiesApprovedEquityCapitalStructurePercentage |
In April 2024, the Companies submitted their annual ENEC update filing with the WVPSC proposing a $ 58 million annual increase in ENEC rates when compared to existing ENEC rates. The Companies proposed that this ENEC rate change would: (a) become effective September 1, 2024, (b) include a $ 20 million annual increase in ENEC rates related to the period ending February 29, 2024 and the forecast period September 2024 through August 2025 and (c) include a $ 38 million annual increase in ENEC rates for the recovery of $ 321 million of ENEC under-recovered costs as of February 28, 2023 over a ten-year period, plus a 4 % debt carrying charge rate. In July 2024, intervenors and staff filed testimony with the WVPSC, which did not recommend any disallowances. | text | 58 | monetaryItemType | text: <entity> 58 </entity> <entity type> monetaryItemType </entity type> <context> In April 2024, the Companies submitted their annual ENEC update filing with the WVPSC proposing a $ 58 million annual increase in ENEC rates when compared to existing ENEC rates. The Companies proposed that this ENEC rate change would: (a) become effective September 1, 2024, (b) include a $ 20 million annual increase in ENEC rates related to the period ending February 29, 2024 and the forecast period September 2024 through August 2025 and (c) include a $ 38 million annual increase in ENEC rates for the recovery of $ 321 million of ENEC under-recovered costs as of February 28, 2023 over a ten-year period, plus a 4 % debt carrying charge rate. In July 2024, intervenors and staff filed testimony with the WVPSC, which did not recommend any disallowances. </context> | us-gaap:PublicUtilitiesRequestedRateIncreaseDecreaseAmount |
In April 2024, the Companies submitted their annual ENEC update filing with the WVPSC proposing a $ 58 million annual increase in ENEC rates when compared to existing ENEC rates. The Companies proposed that this ENEC rate change would: (a) become effective September 1, 2024, (b) include a $ 20 million annual increase in ENEC rates related to the period ending February 29, 2024 and the forecast period September 2024 through August 2025 and (c) include a $ 38 million annual increase in ENEC rates for the recovery of $ 321 million of ENEC under-recovered costs as of February 28, 2023 over a ten-year period, plus a 4 % debt carrying charge rate. In July 2024, intervenors and staff filed testimony with the WVPSC, which did not recommend any disallowances. | text | 20 | monetaryItemType | text: <entity> 20 </entity> <entity type> monetaryItemType </entity type> <context> In April 2024, the Companies submitted their annual ENEC update filing with the WVPSC proposing a $ 58 million annual increase in ENEC rates when compared to existing ENEC rates. The Companies proposed that this ENEC rate change would: (a) become effective September 1, 2024, (b) include a $ 20 million annual increase in ENEC rates related to the period ending February 29, 2024 and the forecast period September 2024 through August 2025 and (c) include a $ 38 million annual increase in ENEC rates for the recovery of $ 321 million of ENEC under-recovered costs as of February 28, 2023 over a ten-year period, plus a 4 % debt carrying charge rate. In July 2024, intervenors and staff filed testimony with the WVPSC, which did not recommend any disallowances. </context> | us-gaap:PublicUtilitiesRequestedRateIncreaseDecreaseAmount |
In April 2024, the Companies submitted their annual ENEC update filing with the WVPSC proposing a $ 58 million annual increase in ENEC rates when compared to existing ENEC rates. The Companies proposed that this ENEC rate change would: (a) become effective September 1, 2024, (b) include a $ 20 million annual increase in ENEC rates related to the period ending February 29, 2024 and the forecast period September 2024 through August 2025 and (c) include a $ 38 million annual increase in ENEC rates for the recovery of $ 321 million of ENEC under-recovered costs as of February 28, 2023 over a ten-year period, plus a 4 % debt carrying charge rate. In July 2024, intervenors and staff filed testimony with the WVPSC, which did not recommend any disallowances. | text | 38 | monetaryItemType | text: <entity> 38 </entity> <entity type> monetaryItemType </entity type> <context> In April 2024, the Companies submitted their annual ENEC update filing with the WVPSC proposing a $ 58 million annual increase in ENEC rates when compared to existing ENEC rates. The Companies proposed that this ENEC rate change would: (a) become effective September 1, 2024, (b) include a $ 20 million annual increase in ENEC rates related to the period ending February 29, 2024 and the forecast period September 2024 through August 2025 and (c) include a $ 38 million annual increase in ENEC rates for the recovery of $ 321 million of ENEC under-recovered costs as of February 28, 2023 over a ten-year period, plus a 4 % debt carrying charge rate. In July 2024, intervenors and staff filed testimony with the WVPSC, which did not recommend any disallowances. </context> | us-gaap:PublicUtilitiesRequestedRateIncreaseDecreaseAmount |
In August 2024, the WVPSC issued an order approving the requested $ 38 million annual increase effective September 1, 2024. The WVPSC will address the proposed additional $ 20 million annual increase in ENEC rates in a future order. If any costs included in the future filing are not approved for recovery, it could reduce future net income and cash flows and impact financial condition. | text | 38 | monetaryItemType | text: <entity> 38 </entity> <entity type> monetaryItemType </entity type> <context> In August 2024, the WVPSC issued an order approving the requested $ 38 million annual increase effective September 1, 2024. The WVPSC will address the proposed additional $ 20 million annual increase in ENEC rates in a future order. If any costs included in the future filing are not approved for recovery, it could reduce future net income and cash flows and impact financial condition. </context> | us-gaap:PublicUtilitiesApprovedRateIncreaseDecreaseAmount |
In August 2024, the WVPSC issued an order approving the requested $ 38 million annual increase effective September 1, 2024. The WVPSC will address the proposed additional $ 20 million annual increase in ENEC rates in a future order. If any costs included in the future filing are not approved for recovery, it could reduce future net income and cash flows and impact financial condition. | text | 20 | monetaryItemType | text: <entity> 20 </entity> <entity type> monetaryItemType </entity type> <context> In August 2024, the WVPSC issued an order approving the requested $ 38 million annual increase effective September 1, 2024. The WVPSC will address the proposed additional $ 20 million annual increase in ENEC rates in a future order. If any costs included in the future filing are not approved for recovery, it could reduce future net income and cash flows and impact financial condition. </context> | us-gaap:PublicUtilitiesApprovedRateIncreaseDecreaseAmount |
In March 2024, APCo filed a request with the Virginia SCC for a $ 95 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 51 % debt and 49 % common equity. The requested increase in base rates is primarily due to incremental rate base, proposed capital structure changes including an increase in ROE and proposed increases in distribution and generation operation and maintenance expenses. In September 2024, a hearing was held where APCo updated its requested increase in base rates to $ 64 million consistent with its rebuttal positions or, alternatively, an increase of $ 45 million if annual environmental compliance consumable expenses are moved from base rates to recovery through APCo’s environmental rate adjustment clause. | text | 95 | monetaryItemType | text: <entity> 95 </entity> <entity type> monetaryItemType </entity type> <context> In March 2024, APCo filed a request with the Virginia SCC for a $ 95 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 51 % debt and 49 % common equity. The requested increase in base rates is primarily due to incremental rate base, proposed capital structure changes including an increase in ROE and proposed increases in distribution and generation operation and maintenance expenses. In September 2024, a hearing was held where APCo updated its requested increase in base rates to $ 64 million consistent with its rebuttal positions or, alternatively, an increase of $ 45 million if annual environmental compliance consumable expenses are moved from base rates to recovery through APCo’s environmental rate adjustment clause. </context> | us-gaap:PublicUtilitiesRequestedRateIncreaseDecreaseAmount |
In March 2024, APCo filed a request with the Virginia SCC for a $ 95 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 51 % debt and 49 % common equity. The requested increase in base rates is primarily due to incremental rate base, proposed capital structure changes including an increase in ROE and proposed increases in distribution and generation operation and maintenance expenses. In September 2024, a hearing was held where APCo updated its requested increase in base rates to $ 64 million consistent with its rebuttal positions or, alternatively, an increase of $ 45 million if annual environmental compliance consumable expenses are moved from base rates to recovery through APCo’s environmental rate adjustment clause. | text | 10.8 | percentItemType | text: <entity> 10.8 </entity> <entity type> percentItemType </entity type> <context> In March 2024, APCo filed a request with the Virginia SCC for a $ 95 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 51 % debt and 49 % common equity. The requested increase in base rates is primarily due to incremental rate base, proposed capital structure changes including an increase in ROE and proposed increases in distribution and generation operation and maintenance expenses. In September 2024, a hearing was held where APCo updated its requested increase in base rates to $ 64 million consistent with its rebuttal positions or, alternatively, an increase of $ 45 million if annual environmental compliance consumable expenses are moved from base rates to recovery through APCo’s environmental rate adjustment clause. </context> | us-gaap:PublicUtilitiesRequestedReturnOnEquityPercentage |
In March 2024, APCo filed a request with the Virginia SCC for a $ 95 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 51 % debt and 49 % common equity. The requested increase in base rates is primarily due to incremental rate base, proposed capital structure changes including an increase in ROE and proposed increases in distribution and generation operation and maintenance expenses. In September 2024, a hearing was held where APCo updated its requested increase in base rates to $ 64 million consistent with its rebuttal positions or, alternatively, an increase of $ 45 million if annual environmental compliance consumable expenses are moved from base rates to recovery through APCo’s environmental rate adjustment clause. | text | 51 | percentItemType | text: <entity> 51 </entity> <entity type> percentItemType </entity type> <context> In March 2024, APCo filed a request with the Virginia SCC for a $ 95 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 51 % debt and 49 % common equity. The requested increase in base rates is primarily due to incremental rate base, proposed capital structure changes including an increase in ROE and proposed increases in distribution and generation operation and maintenance expenses. In September 2024, a hearing was held where APCo updated its requested increase in base rates to $ 64 million consistent with its rebuttal positions or, alternatively, an increase of $ 45 million if annual environmental compliance consumable expenses are moved from base rates to recovery through APCo’s environmental rate adjustment clause. </context> | us-gaap:PublicUtilitiesRequestedDebtCapitalStructurePercentage |
In March 2024, APCo filed a request with the Virginia SCC for a $ 95 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 51 % debt and 49 % common equity. The requested increase in base rates is primarily due to incremental rate base, proposed capital structure changes including an increase in ROE and proposed increases in distribution and generation operation and maintenance expenses. In September 2024, a hearing was held where APCo updated its requested increase in base rates to $ 64 million consistent with its rebuttal positions or, alternatively, an increase of $ 45 million if annual environmental compliance consumable expenses are moved from base rates to recovery through APCo’s environmental rate adjustment clause. | text | 49 | percentItemType | text: <entity> 49 </entity> <entity type> percentItemType </entity type> <context> In March 2024, APCo filed a request with the Virginia SCC for a $ 95 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 51 % debt and 49 % common equity. The requested increase in base rates is primarily due to incremental rate base, proposed capital structure changes including an increase in ROE and proposed increases in distribution and generation operation and maintenance expenses. In September 2024, a hearing was held where APCo updated its requested increase in base rates to $ 64 million consistent with its rebuttal positions or, alternatively, an increase of $ 45 million if annual environmental compliance consumable expenses are moved from base rates to recovery through APCo’s environmental rate adjustment clause. </context> | us-gaap:PublicUtilitiesRequestedEquityCapitalStructurePercentage |
In March 2024, APCo filed a request with the Virginia SCC for a $ 95 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 51 % debt and 49 % common equity. The requested increase in base rates is primarily due to incremental rate base, proposed capital structure changes including an increase in ROE and proposed increases in distribution and generation operation and maintenance expenses. In September 2024, a hearing was held where APCo updated its requested increase in base rates to $ 64 million consistent with its rebuttal positions or, alternatively, an increase of $ 45 million if annual environmental compliance consumable expenses are moved from base rates to recovery through APCo’s environmental rate adjustment clause. | text | 64 | monetaryItemType | text: <entity> 64 </entity> <entity type> monetaryItemType </entity type> <context> In March 2024, APCo filed a request with the Virginia SCC for a $ 95 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 51 % debt and 49 % common equity. The requested increase in base rates is primarily due to incremental rate base, proposed capital structure changes including an increase in ROE and proposed increases in distribution and generation operation and maintenance expenses. In September 2024, a hearing was held where APCo updated its requested increase in base rates to $ 64 million consistent with its rebuttal positions or, alternatively, an increase of $ 45 million if annual environmental compliance consumable expenses are moved from base rates to recovery through APCo’s environmental rate adjustment clause. </context> | us-gaap:PublicUtilitiesRequestedRateIncreaseDecreaseAmount |
In March 2024, APCo filed a request with the Virginia SCC for a $ 95 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 51 % debt and 49 % common equity. The requested increase in base rates is primarily due to incremental rate base, proposed capital structure changes including an increase in ROE and proposed increases in distribution and generation operation and maintenance expenses. In September 2024, a hearing was held where APCo updated its requested increase in base rates to $ 64 million consistent with its rebuttal positions or, alternatively, an increase of $ 45 million if annual environmental compliance consumable expenses are moved from base rates to recovery through APCo’s environmental rate adjustment clause. | text | 45 | monetaryItemType | text: <entity> 45 </entity> <entity type> monetaryItemType </entity type> <context> In March 2024, APCo filed a request with the Virginia SCC for a $ 95 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 51 % debt and 49 % common equity. The requested increase in base rates is primarily due to incremental rate base, proposed capital structure changes including an increase in ROE and proposed increases in distribution and generation operation and maintenance expenses. In September 2024, a hearing was held where APCo updated its requested increase in base rates to $ 64 million consistent with its rebuttal positions or, alternatively, an increase of $ 45 million if annual environmental compliance consumable expenses are moved from base rates to recovery through APCo’s environmental rate adjustment clause. </context> | us-gaap:PublicUtilitiesRequestedRateIncreaseDecreaseAmount |
In November 2024, the Virginia SCC issued a final order approving an annual base rate increase of $ 10 million, effective January 2025, based on a 9.75 % ROE. | text | 10 | monetaryItemType | text: <entity> 10 </entity> <entity type> monetaryItemType </entity type> <context> In November 2024, the Virginia SCC issued a final order approving an annual base rate increase of $ 10 million, effective January 2025, based on a 9.75 % ROE. </context> | us-gaap:PublicUtilitiesApprovedRateIncreaseDecreaseAmount |
In November 2024, the Virginia SCC issued a final order approving an annual base rate increase of $ 10 million, effective January 2025, based on a 9.75 % ROE. | text | 9.75 | percentItemType | text: <entity> 9.75 </entity> <entity type> percentItemType </entity type> <context> In November 2024, the Virginia SCC issued a final order approving an annual base rate increase of $ 10 million, effective January 2025, based on a 9.75 % ROE. </context> | us-gaap:PublicUtilitiesApprovedReturnOnEquityPercentage |
In November 2024, APCo and WPCo (the Companies) filed a request with the WVPSC for a net $ 251 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 52 % debt and 48 % common equity. The requested net annual increase in base rates excludes the Companies’ proposed $ 94 million annual Modified Rate Base Cost (MRBC) surcharge update proposed to be effective in a separate proceeding and the existing $ 21 million annual Mitchell Base Rate Surcharge that are both proposed to be rolled into base rates upon the Companies’ anticipated 2025 change in base rates. The Companies’ proposed base rate increase includes recovery of approximately $ 118 million in previously deferred major storm expense over a three-year period, capital structure changes including an increase in ROE, an increase in depreciation expense related to proposed changes in depreciation rates and increased capital investments and increases in distribution and generation operation and maintenance expenses. | text | 251 | monetaryItemType | text: <entity> 251 </entity> <entity type> monetaryItemType </entity type> <context> In November 2024, APCo and WPCo (the Companies) filed a request with the WVPSC for a net $ 251 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 52 % debt and 48 % common equity. The requested net annual increase in base rates excludes the Companies’ proposed $ 94 million annual Modified Rate Base Cost (MRBC) surcharge update proposed to be effective in a separate proceeding and the existing $ 21 million annual Mitchell Base Rate Surcharge that are both proposed to be rolled into base rates upon the Companies’ anticipated 2025 change in base rates. The Companies’ proposed base rate increase includes recovery of approximately $ 118 million in previously deferred major storm expense over a three-year period, capital structure changes including an increase in ROE, an increase in depreciation expense related to proposed changes in depreciation rates and increased capital investments and increases in distribution and generation operation and maintenance expenses. </context> | us-gaap:PublicUtilitiesRequestedRateIncreaseDecreaseAmount |
In November 2024, APCo and WPCo (the Companies) filed a request with the WVPSC for a net $ 251 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 52 % debt and 48 % common equity. The requested net annual increase in base rates excludes the Companies’ proposed $ 94 million annual Modified Rate Base Cost (MRBC) surcharge update proposed to be effective in a separate proceeding and the existing $ 21 million annual Mitchell Base Rate Surcharge that are both proposed to be rolled into base rates upon the Companies’ anticipated 2025 change in base rates. The Companies’ proposed base rate increase includes recovery of approximately $ 118 million in previously deferred major storm expense over a three-year period, capital structure changes including an increase in ROE, an increase in depreciation expense related to proposed changes in depreciation rates and increased capital investments and increases in distribution and generation operation and maintenance expenses. | text | 10.8 | percentItemType | text: <entity> 10.8 </entity> <entity type> percentItemType </entity type> <context> In November 2024, APCo and WPCo (the Companies) filed a request with the WVPSC for a net $ 251 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 52 % debt and 48 % common equity. The requested net annual increase in base rates excludes the Companies’ proposed $ 94 million annual Modified Rate Base Cost (MRBC) surcharge update proposed to be effective in a separate proceeding and the existing $ 21 million annual Mitchell Base Rate Surcharge that are both proposed to be rolled into base rates upon the Companies’ anticipated 2025 change in base rates. The Companies’ proposed base rate increase includes recovery of approximately $ 118 million in previously deferred major storm expense over a three-year period, capital structure changes including an increase in ROE, an increase in depreciation expense related to proposed changes in depreciation rates and increased capital investments and increases in distribution and generation operation and maintenance expenses. </context> | us-gaap:PublicUtilitiesRequestedReturnOnEquityPercentage |
In November 2024, APCo and WPCo (the Companies) filed a request with the WVPSC for a net $ 251 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 52 % debt and 48 % common equity. The requested net annual increase in base rates excludes the Companies’ proposed $ 94 million annual Modified Rate Base Cost (MRBC) surcharge update proposed to be effective in a separate proceeding and the existing $ 21 million annual Mitchell Base Rate Surcharge that are both proposed to be rolled into base rates upon the Companies’ anticipated 2025 change in base rates. The Companies’ proposed base rate increase includes recovery of approximately $ 118 million in previously deferred major storm expense over a three-year period, capital structure changes including an increase in ROE, an increase in depreciation expense related to proposed changes in depreciation rates and increased capital investments and increases in distribution and generation operation and maintenance expenses. | text | 52 | percentItemType | text: <entity> 52 </entity> <entity type> percentItemType </entity type> <context> In November 2024, APCo and WPCo (the Companies) filed a request with the WVPSC for a net $ 251 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 52 % debt and 48 % common equity. The requested net annual increase in base rates excludes the Companies’ proposed $ 94 million annual Modified Rate Base Cost (MRBC) surcharge update proposed to be effective in a separate proceeding and the existing $ 21 million annual Mitchell Base Rate Surcharge that are both proposed to be rolled into base rates upon the Companies’ anticipated 2025 change in base rates. The Companies’ proposed base rate increase includes recovery of approximately $ 118 million in previously deferred major storm expense over a three-year period, capital structure changes including an increase in ROE, an increase in depreciation expense related to proposed changes in depreciation rates and increased capital investments and increases in distribution and generation operation and maintenance expenses. </context> | us-gaap:PublicUtilitiesRequestedDebtCapitalStructurePercentage |
In November 2024, APCo and WPCo (the Companies) filed a request with the WVPSC for a net $ 251 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 52 % debt and 48 % common equity. The requested net annual increase in base rates excludes the Companies’ proposed $ 94 million annual Modified Rate Base Cost (MRBC) surcharge update proposed to be effective in a separate proceeding and the existing $ 21 million annual Mitchell Base Rate Surcharge that are both proposed to be rolled into base rates upon the Companies’ anticipated 2025 change in base rates. The Companies’ proposed base rate increase includes recovery of approximately $ 118 million in previously deferred major storm expense over a three-year period, capital structure changes including an increase in ROE, an increase in depreciation expense related to proposed changes in depreciation rates and increased capital investments and increases in distribution and generation operation and maintenance expenses. | text | 48 | percentItemType | text: <entity> 48 </entity> <entity type> percentItemType </entity type> <context> In November 2024, APCo and WPCo (the Companies) filed a request with the WVPSC for a net $ 251 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 52 % debt and 48 % common equity. The requested net annual increase in base rates excludes the Companies’ proposed $ 94 million annual Modified Rate Base Cost (MRBC) surcharge update proposed to be effective in a separate proceeding and the existing $ 21 million annual Mitchell Base Rate Surcharge that are both proposed to be rolled into base rates upon the Companies’ anticipated 2025 change in base rates. The Companies’ proposed base rate increase includes recovery of approximately $ 118 million in previously deferred major storm expense over a three-year period, capital structure changes including an increase in ROE, an increase in depreciation expense related to proposed changes in depreciation rates and increased capital investments and increases in distribution and generation operation and maintenance expenses. </context> | us-gaap:PublicUtilitiesRequestedEquityCapitalStructurePercentage |
In November 2024, APCo and WPCo (the Companies) filed a request with the WVPSC for a net $ 251 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 52 % debt and 48 % common equity. The requested net annual increase in base rates excludes the Companies’ proposed $ 94 million annual Modified Rate Base Cost (MRBC) surcharge update proposed to be effective in a separate proceeding and the existing $ 21 million annual Mitchell Base Rate Surcharge that are both proposed to be rolled into base rates upon the Companies’ anticipated 2025 change in base rates. The Companies’ proposed base rate increase includes recovery of approximately $ 118 million in previously deferred major storm expense over a three-year period, capital structure changes including an increase in ROE, an increase in depreciation expense related to proposed changes in depreciation rates and increased capital investments and increases in distribution and generation operation and maintenance expenses. | text | 94 | monetaryItemType | text: <entity> 94 </entity> <entity type> monetaryItemType </entity type> <context> In November 2024, APCo and WPCo (the Companies) filed a request with the WVPSC for a net $ 251 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 52 % debt and 48 % common equity. The requested net annual increase in base rates excludes the Companies’ proposed $ 94 million annual Modified Rate Base Cost (MRBC) surcharge update proposed to be effective in a separate proceeding and the existing $ 21 million annual Mitchell Base Rate Surcharge that are both proposed to be rolled into base rates upon the Companies’ anticipated 2025 change in base rates. The Companies’ proposed base rate increase includes recovery of approximately $ 118 million in previously deferred major storm expense over a three-year period, capital structure changes including an increase in ROE, an increase in depreciation expense related to proposed changes in depreciation rates and increased capital investments and increases in distribution and generation operation and maintenance expenses. </context> | us-gaap:PublicUtilitiesRequestedRateIncreaseDecreaseAmount |
In November 2024, APCo and WPCo (the Companies) filed a request with the WVPSC for a net $ 251 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 52 % debt and 48 % common equity. The requested net annual increase in base rates excludes the Companies’ proposed $ 94 million annual Modified Rate Base Cost (MRBC) surcharge update proposed to be effective in a separate proceeding and the existing $ 21 million annual Mitchell Base Rate Surcharge that are both proposed to be rolled into base rates upon the Companies’ anticipated 2025 change in base rates. The Companies’ proposed base rate increase includes recovery of approximately $ 118 million in previously deferred major storm expense over a three-year period, capital structure changes including an increase in ROE, an increase in depreciation expense related to proposed changes in depreciation rates and increased capital investments and increases in distribution and generation operation and maintenance expenses. | text | 21 | monetaryItemType | text: <entity> 21 </entity> <entity type> monetaryItemType </entity type> <context> In November 2024, APCo and WPCo (the Companies) filed a request with the WVPSC for a net $ 251 million annual increase in base rates based upon a proposed 10.8 % ROE and a proposed capital structure of 52 % debt and 48 % common equity. The requested net annual increase in base rates excludes the Companies’ proposed $ 94 million annual Modified Rate Base Cost (MRBC) surcharge update proposed to be effective in a separate proceeding and the existing $ 21 million annual Mitchell Base Rate Surcharge that are both proposed to be rolled into base rates upon the Companies’ anticipated 2025 change in base rates. The Companies’ proposed base rate increase includes recovery of approximately $ 118 million in previously deferred major storm expense over a three-year period, capital structure changes including an increase in ROE, an increase in depreciation expense related to proposed changes in depreciation rates and increased capital investments and increases in distribution and generation operation and maintenance expenses. </context> | us-gaap:PublicUtilitiesRequestedRateIncreaseDecreaseAmount |
In March 2024, APCo and WPCo (the Companies) submitted an annual MRBC surcharge update filing with the WVPSC requesting a $ 32 million annual increase in the Companies’ combined MRBC rates. The MRBC is an infrastructure investment tracker that allows limited cost recovery related to capital investments between the Companies’ West Virginia jurisdictional base rate cases. WVPSC staff and an intervening party recommended revenue requirement disallowances in written and verbal testimony and briefs for certain ratemaking issues used to develop the Companies’ proposed MRBC rates, including the West Virginia jurisdictional effect of state deferred income taxes, NOLC and AROs. If any refund liabilities are imposed by the WVPSC, it could reduce future net income and cash flows and impact financial condition. | text | 32 | monetaryItemType | text: <entity> 32 </entity> <entity type> monetaryItemType </entity type> <context> In March 2024, APCo and WPCo (the Companies) submitted an annual MRBC surcharge update filing with the WVPSC requesting a $ 32 million annual increase in the Companies’ combined MRBC rates. The MRBC is an infrastructure investment tracker that allows limited cost recovery related to capital investments between the Companies’ West Virginia jurisdictional base rate cases. WVPSC staff and an intervening party recommended revenue requirement disallowances in written and verbal testimony and briefs for certain ratemaking issues used to develop the Companies’ proposed MRBC rates, including the West Virginia jurisdictional effect of state deferred income taxes, NOLC and AROs. If any refund liabilities are imposed by the WVPSC, it could reduce future net income and cash flows and impact financial condition. </context> | us-gaap:PublicUtilitiesRequestedRateIncreaseDecreaseAmount |
In January 2025, ETT filed a request with the PUCT for a $ 57 million annual base rate increase over its adjusted test year revenues which includes interim transmission rate updates. ETT’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case seeks a prudence review determination on cumulative capital additions included in interim rates. A procedural schedule for the case is pending. If any of the costs in the case are not recoverable or refunds collected under interim transmission rates are ordered to be returned, it could reduce future net income and cash flows and impact financial condition. | text | 57 | monetaryItemType | text: <entity> 57 </entity> <entity type> monetaryItemType </entity type> <context> In January 2025, ETT filed a request with the PUCT for a $ 57 million annual base rate increase over its adjusted test year revenues which includes interim transmission rate updates. ETT’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case seeks a prudence review determination on cumulative capital additions included in interim rates. A procedural schedule for the case is pending. If any of the costs in the case are not recoverable or refunds collected under interim transmission rates are ordered to be returned, it could reduce future net income and cash flows and impact financial condition. </context> | us-gaap:PublicUtilitiesRequestedRateIncreaseDecreaseAmount |
In January 2025, ETT filed a request with the PUCT for a $ 57 million annual base rate increase over its adjusted test year revenues which includes interim transmission rate updates. ETT’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case seeks a prudence review determination on cumulative capital additions included in interim rates. A procedural schedule for the case is pending. If any of the costs in the case are not recoverable or refunds collected under interim transmission rates are ordered to be returned, it could reduce future net income and cash flows and impact financial condition. | text | 10.6 | percentItemType | text: <entity> 10.6 </entity> <entity type> percentItemType </entity type> <context> In January 2025, ETT filed a request with the PUCT for a $ 57 million annual base rate increase over its adjusted test year revenues which includes interim transmission rate updates. ETT’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case seeks a prudence review determination on cumulative capital additions included in interim rates. A procedural schedule for the case is pending. If any of the costs in the case are not recoverable or refunds collected under interim transmission rates are ordered to be returned, it could reduce future net income and cash flows and impact financial condition. </context> | us-gaap:PublicUtilitiesRequestedReturnOnEquityPercentage |
In January 2025, ETT filed a request with the PUCT for a $ 57 million annual base rate increase over its adjusted test year revenues which includes interim transmission rate updates. ETT’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case seeks a prudence review determination on cumulative capital additions included in interim rates. A procedural schedule for the case is pending. If any of the costs in the case are not recoverable or refunds collected under interim transmission rates are ordered to be returned, it could reduce future net income and cash flows and impact financial condition. | text | 55 | percentItemType | text: <entity> 55 </entity> <entity type> percentItemType </entity type> <context> In January 2025, ETT filed a request with the PUCT for a $ 57 million annual base rate increase over its adjusted test year revenues which includes interim transmission rate updates. ETT’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case seeks a prudence review determination on cumulative capital additions included in interim rates. A procedural schedule for the case is pending. If any of the costs in the case are not recoverable or refunds collected under interim transmission rates are ordered to be returned, it could reduce future net income and cash flows and impact financial condition. </context> | us-gaap:PublicUtilitiesRequestedDebtCapitalStructurePercentage |
In January 2025, ETT filed a request with the PUCT for a $ 57 million annual base rate increase over its adjusted test year revenues which includes interim transmission rate updates. ETT’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case seeks a prudence review determination on cumulative capital additions included in interim rates. A procedural schedule for the case is pending. If any of the costs in the case are not recoverable or refunds collected under interim transmission rates are ordered to be returned, it could reduce future net income and cash flows and impact financial condition. | text | 45 | percentItemType | text: <entity> 45 </entity> <entity type> percentItemType </entity type> <context> In January 2025, ETT filed a request with the PUCT for a $ 57 million annual base rate increase over its adjusted test year revenues which includes interim transmission rate updates. ETT’s request is based upon a proposed 10.6 % ROE with a capital structure of 55 % debt and 45 % common equity. The rate case seeks a prudence review determination on cumulative capital additions included in interim rates. A procedural schedule for the case is pending. If any of the costs in the case are not recoverable or refunds collected under interim transmission rates are ordered to be returned, it could reduce future net income and cash flows and impact financial condition. </context> | us-gaap:PublicUtilitiesRequestedEquityCapitalStructurePercentage |
In August 2023, I&M filed a request with the IURC for a $ 116 million annual increase in Indiana base rates based upon a 2024 forecasted test year, a proposed 10.5 % ROE and a proposed capital structure of 48.8 % debt and 51.2 % common equity. I&M proposed that the annual increase in base rates be implemented in two steps, with the first increase effective in mid-2024, following an IURC order, and the second increase effective in January 2025. The proposed annual increase includes, but is not limited to, a $ 41 million increase related to depreciation expense, driven by increased depreciation rates and increased capital investments, and a $ 15 million increase related to storm expenses. I&M’s Indiana base case filing requested recovery of certain historical period regulatory asset balances and proposed deferral accounting for certain future investments and tax-related issues, including CAMT expense and PTCs related to the Cook Plant. | text | 10.5 | percentItemType | text: <entity> 10.5 </entity> <entity type> percentItemType </entity type> <context> In August 2023, I&M filed a request with the IURC for a $ 116 million annual increase in Indiana base rates based upon a 2024 forecasted test year, a proposed 10.5 % ROE and a proposed capital structure of 48.8 % debt and 51.2 % common equity. I&M proposed that the annual increase in base rates be implemented in two steps, with the first increase effective in mid-2024, following an IURC order, and the second increase effective in January 2025. The proposed annual increase includes, but is not limited to, a $ 41 million increase related to depreciation expense, driven by increased depreciation rates and increased capital investments, and a $ 15 million increase related to storm expenses. I&M’s Indiana base case filing requested recovery of certain historical period regulatory asset balances and proposed deferral accounting for certain future investments and tax-related issues, including CAMT expense and PTCs related to the Cook Plant. </context> | us-gaap:PublicUtilitiesRequestedReturnOnEquityPercentage |
In May 2024, the IURC issued an order approving the settlement agreement with minor modifications. In January 2025, in accordance with the IURC’s order on I&M’s 2023 Indiana base case filing, I&M submitted a filing with the IURC reflecting December 31, 2024 balances of electric plant in service in comparison to I&M’s 2024 forecasted test year, resulting in a $ 15 million annual increase in I&M Indiana base rates effective January 2025. | text | 15 | monetaryItemType | text: <entity> 15 </entity> <entity type> monetaryItemType </entity type> <context> In May 2024, the IURC issued an order approving the settlement agreement with minor modifications. In January 2025, in accordance with the IURC’s order on I&M’s 2023 Indiana base case filing, I&M submitted a filing with the IURC reflecting December 31, 2024 balances of electric plant in service in comparison to I&M’s 2024 forecasted test year, resulting in a $ 15 million annual increase in I&M Indiana base rates effective January 2025. </context> | us-gaap:PublicUtilitiesApprovedRateIncreaseDecreaseAmount |
In September 2023, I&M filed a request with the MPSC for a $ 34 million annual increase in Michigan base rates based upon a 2024 forecasted test year, a proposed 10.5 % ROE and a capital structure of 49.4 % debt and 50.6 % common equity. The proposed annual increase includes an $ 11 million annual increase in depreciation expense driven by increased capital investment. I&M’s Michigan base case filing requests recovery of certain historical period regulatory asset balances and proposes deferral accounting for certain future investments and tax-related issues, including CAMT expense and PTCs related to the Cook Plant. | text | 10.5 | percentItemType | text: <entity> 10.5 </entity> <entity type> percentItemType </entity type> <context> In September 2023, I&M filed a request with the MPSC for a $ 34 million annual increase in Michigan base rates based upon a 2024 forecasted test year, a proposed 10.5 % ROE and a capital structure of 49.4 % debt and 50.6 % common equity. The proposed annual increase includes an $ 11 million annual increase in depreciation expense driven by increased capital investment. I&M’s Michigan base case filing requests recovery of certain historical period regulatory asset balances and proposes deferral accounting for certain future investments and tax-related issues, including CAMT expense and PTCs related to the Cook Plant. </context> | us-gaap:PublicUtilitiesRequestedReturnOnEquityPercentage |
In July 2024, the MPSC issued a final order approving an annual base rate increase of $ 17 million based on a 9.86 % ROE and a capital structure of 52 % debt and 48 % common equity. The MPSC also ordered that Michigan jurisdictional Cook Plant PTCs will be reflected as a deferral in I&M’s PSCR reconciliation and rejected I&M’s request to defer Michigan jurisdictional CAMT. | text | 17 | monetaryItemType | text: <entity> 17 </entity> <entity type> monetaryItemType </entity type> <context> In July 2024, the MPSC issued a final order approving an annual base rate increase of $ 17 million based on a 9.86 % ROE and a capital structure of 52 % debt and 48 % common equity. The MPSC also ordered that Michigan jurisdictional Cook Plant PTCs will be reflected as a deferral in I&M’s PSCR reconciliation and rejected I&M’s request to defer Michigan jurisdictional CAMT. </context> | us-gaap:PublicUtilitiesApprovedRateIncreaseDecreaseAmount |
In July 2024, the MPSC issued a final order approving an annual base rate increase of $ 17 million based on a 9.86 % ROE and a capital structure of 52 % debt and 48 % common equity. The MPSC also ordered that Michigan jurisdictional Cook Plant PTCs will be reflected as a deferral in I&M’s PSCR reconciliation and rejected I&M’s request to defer Michigan jurisdictional CAMT. | text | 9.86 | percentItemType | text: <entity> 9.86 </entity> <entity type> percentItemType </entity type> <context> In July 2024, the MPSC issued a final order approving an annual base rate increase of $ 17 million based on a 9.86 % ROE and a capital structure of 52 % debt and 48 % common equity. The MPSC also ordered that Michigan jurisdictional Cook Plant PTCs will be reflected as a deferral in I&M’s PSCR reconciliation and rejected I&M’s request to defer Michigan jurisdictional CAMT. </context> | us-gaap:PublicUtilitiesApprovedReturnOnEquityPercentage |
In July 2024, the MPSC issued a final order approving an annual base rate increase of $ 17 million based on a 9.86 % ROE and a capital structure of 52 % debt and 48 % common equity. The MPSC also ordered that Michigan jurisdictional Cook Plant PTCs will be reflected as a deferral in I&M’s PSCR reconciliation and rejected I&M’s request to defer Michigan jurisdictional CAMT. | text | 52 | percentItemType | text: <entity> 52 </entity> <entity type> percentItemType </entity type> <context> In July 2024, the MPSC issued a final order approving an annual base rate increase of $ 17 million based on a 9.86 % ROE and a capital structure of 52 % debt and 48 % common equity. The MPSC also ordered that Michigan jurisdictional Cook Plant PTCs will be reflected as a deferral in I&M’s PSCR reconciliation and rejected I&M’s request to defer Michigan jurisdictional CAMT. </context> | us-gaap:PublicUtilitiesApprovedDebtCapitalStructurePercentage |
In July 2024, the MPSC issued a final order approving an annual base rate increase of $ 17 million based on a 9.86 % ROE and a capital structure of 52 % debt and 48 % common equity. The MPSC also ordered that Michigan jurisdictional Cook Plant PTCs will be reflected as a deferral in I&M’s PSCR reconciliation and rejected I&M’s request to defer Michigan jurisdictional CAMT. | text | 48 | percentItemType | text: <entity> 48 </entity> <entity type> percentItemType </entity type> <context> In July 2024, the MPSC issued a final order approving an annual base rate increase of $ 17 million based on a 9.86 % ROE and a capital structure of 52 % debt and 48 % common equity. The MPSC also ordered that Michigan jurisdictional Cook Plant PTCs will be reflected as a deferral in I&M’s PSCR reconciliation and rejected I&M’s request to defer Michigan jurisdictional CAMT. </context> | us-gaap:PublicUtilitiesApprovedEquityCapitalStructurePercentage |
In June 2023, KPCo filed a request with the KPSC for a $ 94 million net annual increase in base rates based upon a proposed 9.9 % ROE with the increase to be implemented no earlier than January 2024. In conjunction with its June 2023 filing, KPCo further requested to finance through the issuance of securitization bonds, approximately $ 471 million of regulatory assets. KPCo’s proposal did not address the disposition of its 50 % interest in Mitchell Plant, which will be addressed in the future. As of December 31, 2024, the net book value of KPCo’s share of the Mitchell Plant, before cost of removal including CWIP and inventory, was $ 547 million. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. | text | 9.9 | percentItemType | text: <entity> 9.9 </entity> <entity type> percentItemType </entity type> <context> In June 2023, KPCo filed a request with the KPSC for a $ 94 million net annual increase in base rates based upon a proposed 9.9 % ROE with the increase to be implemented no earlier than January 2024. In conjunction with its June 2023 filing, KPCo further requested to finance through the issuance of securitization bonds, approximately $ 471 million of regulatory assets. KPCo’s proposal did not address the disposition of its 50 % interest in Mitchell Plant, which will be addressed in the future. As of December 31, 2024, the net book value of KPCo’s share of the Mitchell Plant, before cost of removal including CWIP and inventory, was $ 547 million. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. </context> | us-gaap:PublicUtilitiesRequestedReturnOnEquityPercentage |
In June 2023, KPCo filed a request with the KPSC for a $ 94 million net annual increase in base rates based upon a proposed 9.9 % ROE with the increase to be implemented no earlier than January 2024. In conjunction with its June 2023 filing, KPCo further requested to finance through the issuance of securitization bonds, approximately $ 471 million of regulatory assets. KPCo’s proposal did not address the disposition of its 50 % interest in Mitchell Plant, which will be addressed in the future. As of December 31, 2024, the net book value of KPCo’s share of the Mitchell Plant, before cost of removal including CWIP and inventory, was $ 547 million. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. | text | 547 | monetaryItemType | text: <entity> 547 </entity> <entity type> monetaryItemType </entity type> <context> In June 2023, KPCo filed a request with the KPSC for a $ 94 million net annual increase in base rates based upon a proposed 9.9 % ROE with the increase to be implemented no earlier than January 2024. In conjunction with its June 2023 filing, KPCo further requested to finance through the issuance of securitization bonds, approximately $ 471 million of regulatory assets. KPCo’s proposal did not address the disposition of its 50 % interest in Mitchell Plant, which will be addressed in the future. As of December 31, 2024, the net book value of KPCo’s share of the Mitchell Plant, before cost of removal including CWIP and inventory, was $ 547 million. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. </context> | us-gaap:PropertyPlantAndEquipmentNet |
In January 2024, the KPSC issued an order modifying the November 2023 uncontested settlement agreement and approving an annual base rate increase of $ 60 million based upon a 9.75 % ROE effective with billing cycles mid-January 2024. The order reduced KPCo’s base rate revenue requirement by $ 14 million to allow recovery of actual test year PJM transmission costs instead of KPCo’s requested annual level of costs based on PJM 2023 projected transmission revenue requirements. In February 2024, KPCo filed an appeal with the Commonwealth of Kentucky Franklin Circuit Court, challenging among other aspects of the order, the $ 14 million base rate revenue requirement reduction. In January 2025, the Commonwealth of Kentucky Franklin Circuit Court issued an order agreeing with KPCo’s appeal and remanded this issue back to the KPSC with instructions to enter an order, within 30 days, which includes setting rates to allow KPCo to recover the $ 14 million of annual PJM transmission costs effective upon KPCo's January 2024 implementation of updated base rates. | text | 9.75 | percentItemType | text: <entity> 9.75 </entity> <entity type> percentItemType </entity type> <context> In January 2024, the KPSC issued an order modifying the November 2023 uncontested settlement agreement and approving an annual base rate increase of $ 60 million based upon a 9.75 % ROE effective with billing cycles mid-January 2024. The order reduced KPCo’s base rate revenue requirement by $ 14 million to allow recovery of actual test year PJM transmission costs instead of KPCo’s requested annual level of costs based on PJM 2023 projected transmission revenue requirements. In February 2024, KPCo filed an appeal with the Commonwealth of Kentucky Franklin Circuit Court, challenging among other aspects of the order, the $ 14 million base rate revenue requirement reduction. In January 2025, the Commonwealth of Kentucky Franklin Circuit Court issued an order agreeing with KPCo’s appeal and remanded this issue back to the KPSC with instructions to enter an order, within 30 days, which includes setting rates to allow KPCo to recover the $ 14 million of annual PJM transmission costs effective upon KPCo's January 2024 implementation of updated base rates. </context> | us-gaap:PublicUtilitiesApprovedReturnOnEquityPercentage |
In January 2023, OPCo filed an application with the PUCO to approve an ESP that included proposed rate adjustments, proposed new riders and the continuation and modification of certain existing riders, including the DIR, effective June 2024 through May 2030. The proposal includes a return on common equity of 10.65 % on capital costs for certain riders. In June 2023, intervenors filed testimony opposing OPCo’s plan for various new riders and modifications to existing riders, including the DIR. In September 2023, OPCo and certain intervenors filed a settlement agreement with the PUCO addressing the ESP application. The settlement included a four year term from June 2024 through May 2028, an ROE of 9.7 % and continuation of a number of riders including the DIR subject to revenue caps. In April 2024, the PUCO issued an order approving the settlement agreement. In May 2024, intervenors filed an application for rehearing with the PUCO on the approved settlement agreement and the PUCO denied the intervenors’ application for rehearing in June 2024. | text | 9.7 | percentItemType | text: <entity> 9.7 </entity> <entity type> percentItemType </entity type> <context> In January 2023, OPCo filed an application with the PUCO to approve an ESP that included proposed rate adjustments, proposed new riders and the continuation and modification of certain existing riders, including the DIR, effective June 2024 through May 2030. The proposal includes a return on common equity of 10.65 % on capital costs for certain riders. In June 2023, intervenors filed testimony opposing OPCo’s plan for various new riders and modifications to existing riders, including the DIR. In September 2023, OPCo and certain intervenors filed a settlement agreement with the PUCO addressing the ESP application. The settlement included a four year term from June 2024 through May 2028, an ROE of 9.7 % and continuation of a number of riders including the DIR subject to revenue caps. In April 2024, the PUCO issued an order approving the settlement agreement. In May 2024, intervenors filed an application for rehearing with the PUCO on the approved settlement agreement and the PUCO denied the intervenors’ application for rehearing in June 2024. </context> | us-gaap:PublicUtilitiesApprovedReturnOnEquityPercentage |
In January 2024, PSO filed a request with the OCC for a $ 218 million annual base rate increase based upon a 10.8 % ROE with a capital structure of 48.9 % debt and 51.1 % common equity. PSO requested an expanded transmission cost recovery rider and a mechanism to recover generation costs necessary to comply with SPP’s 2023 increased capacity planning reserve margin requirements. PSO’s request includes the 155 MW Rock Falls Wind Facility and reflects recovery of Northeastern Plant, Unit 3 through 2040. | text | 10.8 | percentItemType | text: <entity> 10.8 </entity> <entity type> percentItemType </entity type> <context> In January 2024, PSO filed a request with the OCC for a $ 218 million annual base rate increase based upon a 10.8 % ROE with a capital structure of 48.9 % debt and 51.1 % common equity. PSO requested an expanded transmission cost recovery rider and a mechanism to recover generation costs necessary to comply with SPP’s 2023 increased capacity planning reserve margin requirements. PSO’s request includes the 155 MW Rock Falls Wind Facility and reflects recovery of Northeastern Plant, Unit 3 through 2040. </context> | us-gaap:PublicUtilitiesRequestedReturnOnEquityPercentage |
In 2016, SWEPCo filed a request with the PUCT for a net increase in Texas annual revenues of $ 69 million based upon a 10 % ROE. In January 2018, the PUCT issued a final order approving a net increase in Texas annual revenues of $ 50 million based upon a 9.6 % ROE, effective May 2017. The final order also included: (a) approval to recover the Texas jurisdictional share of environmental investments placed in-service, as of June 30, 2016, at various plants, including Welsh Plant, Units 1 and 3, (b) approval of recovery of, but no return on, the Texas jurisdictional share of the net book value of Welsh Plant, Unit 2, (c) approval of $ 2 million in additional vegetation management expenses and (d) the rejection of SWEPCo’s proposed transmission cost recovery mechanism. | text | 9.6 | percentItemType | text: <entity> 9.6 </entity> <entity type> percentItemType </entity type> <context> In 2016, SWEPCo filed a request with the PUCT for a net increase in Texas annual revenues of $ 69 million based upon a 10 % ROE. In January 2018, the PUCT issued a final order approving a net increase in Texas annual revenues of $ 50 million based upon a 9.6 % ROE, effective May 2017. The final order also included: (a) approval to recover the Texas jurisdictional share of environmental investments placed in-service, as of June 30, 2016, at various plants, including Welsh Plant, Units 1 and 3, (b) approval of recovery of, but no return on, the Texas jurisdictional share of the net book value of Welsh Plant, Unit 2, (c) approval of $ 2 million in additional vegetation management expenses and (d) the rejection of SWEPCo’s proposed transmission cost recovery mechanism. </context> | us-gaap:PublicUtilitiesApprovedReturnOnEquityPercentage |
In October 2020, SWEPCo filed a request with the PUCT for a $ 105 million annual increase in Texas base rates based upon a proposed 10.35 % ROE. The request would move transmission and distribution interim revenues recovered through riders into base rates. Eliminating these riders would result in a net annual requested base rate increase of $ 90 million primarily due to increased investments. SWEPCo subsequently filed a request with the PUCT lowering the requested annual increase in Texas base rates to $ 100 million which would result in an $ 85 million net annual base rate increase after moving the proposed riders to rate base. | text | 10.35 | percentItemType | text: <entity> 10.35 </entity> <entity type> percentItemType </entity type> <context> In October 2020, SWEPCo filed a request with the PUCT for a $ 105 million annual increase in Texas base rates based upon a proposed 10.35 % ROE. The request would move transmission and distribution interim revenues recovered through riders into base rates. Eliminating these riders would result in a net annual requested base rate increase of $ 90 million primarily due to increased investments. SWEPCo subsequently filed a request with the PUCT lowering the requested annual increase in Texas base rates to $ 100 million which would result in an $ 85 million net annual base rate increase after moving the proposed riders to rate base. </context> | us-gaap:PublicUtilitiesRequestedReturnOnEquityPercentage |
In January 2022, the PUCT issued a final order approving an annual revenue increase of $ 39 million based upon a 9.25 % ROE. The order also includes: (a) rates implemented retroactively back to March 18, 2021, (b) $ 5 million of the proposed increase related to vegetation management, (c) $ 2 million annually to establish a storm catastrophe reserve and (d) the creation of a rider to recover the Dolet Hills Power Station as if it were in rate base until its retirement at the end of 2021 and starting in 2022 the remaining net book value to be recovered as a regulatory asset through 2046. As a result of the final order, SWEPCo recorded a disallowance of $ 12 million in 2021 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 several errors in the order, which include challenges of the approved ROE, the denial of a reasonable return or carrying costs on the Dolet Hills Power Station and the calculation of the Texas jurisdictional share of the storm catastrophe reserve. 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. | text | 9.25 | percentItemType | text: <entity> 9.25 </entity> <entity type> percentItemType </entity type> <context> In January 2022, the PUCT issued a final order approving an annual revenue increase of $ 39 million based upon a 9.25 % ROE. The order also includes: (a) rates implemented retroactively back to March 18, 2021, (b) $ 5 million of the proposed increase related to vegetation management, (c) $ 2 million annually to establish a storm catastrophe reserve and (d) the creation of a rider to recover the Dolet Hills Power Station as if it were in rate base until its retirement at the end of 2021 and starting in 2022 the remaining net book value to be recovered as a regulatory asset through 2046. As a result of the final order, SWEPCo recorded a disallowance of $ 12 million in 2021 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 several errors in the order, which include challenges of the approved ROE, the denial of a reasonable return or carrying costs on the Dolet Hills Power Station and the calculation of the Texas jurisdictional share of the storm catastrophe reserve. 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. </context> | us-gaap:PublicUtilitiesApprovedReturnOnEquityPercentage |
In 2020, Hurricanes Laura and Delta caused power outages and extensive damage to the SWEPCo service territories, primarily impacting the Louisiana jurisdiction. Following both hurricanes, the LPSC issued orders allowing Louisiana utilities, including SWEPCo, to establish regulatory assets to track and defer expenses associated with these storms. In February 2021, severe winter weather impacted the Louisiana jurisdiction and in March 2021, the LPSC approved the deferral of incremental storm restoration expenses related to the winter storm. In March 2023, SWEPCo and the LPSC staff filed a joint stipulation and settlement agreement with the LPSC which confirmed the prudency of $ 150 million of deferred incremental storm restoration expenses. The agreement also authorized an interim carrying charge at a rate of 3.125 % through March 2024. In April 2023, the LPSC issued an order approving the stipulation and settlement agreement. In July 2023, SWEPCo submitted additional information in phase two of this proceeding to obtain a financing order and prudency review of capital investment. In April 2024, SWEPCo and the LPSC staff filed a joint uncontested stipulation and settlement agreement with the LPSC requesting securitization of storm costs, including a storm reserve. In July 2024, the LPSC issued an order approving the joint uncontested stipulation and settlement agreement. In December 2024, SWEPCo issued $ 337 million of securitization bonds. The securitization bonds included $ 180 million for storm costs related to Hurricanes Laura and Delta and $ 150 million related to a storm reserve. In June 2023, SWEPCo incurred approximately $ 44 million in storm costs impacting the Louisiana jurisdiction. As authorized by the LPSC, the June 2023 storm costs were applied against the $ 150 million storm reserve. Any costs applied against the remaining storm reserve are subject to audit and prudency reviews. SWEPCo is required to accrue carrying charges on the remaining storm reserve liability. The securitization bonds also included $ 7 million related to estimated financing costs and carrying charges. | text | 337 | monetaryItemType | text: <entity> 337 </entity> <entity type> monetaryItemType </entity type> <context> In 2020, Hurricanes Laura and Delta caused power outages and extensive damage to the SWEPCo service territories, primarily impacting the Louisiana jurisdiction. Following both hurricanes, the LPSC issued orders allowing Louisiana utilities, including SWEPCo, to establish regulatory assets to track and defer expenses associated with these storms. In February 2021, severe winter weather impacted the Louisiana jurisdiction and in March 2021, the LPSC approved the deferral of incremental storm restoration expenses related to the winter storm. In March 2023, SWEPCo and the LPSC staff filed a joint stipulation and settlement agreement with the LPSC which confirmed the prudency of $ 150 million of deferred incremental storm restoration expenses. The agreement also authorized an interim carrying charge at a rate of 3.125 % through March 2024. In April 2023, the LPSC issued an order approving the stipulation and settlement agreement. In July 2023, SWEPCo submitted additional information in phase two of this proceeding to obtain a financing order and prudency review of capital investment. In April 2024, SWEPCo and the LPSC staff filed a joint uncontested stipulation and settlement agreement with the LPSC requesting securitization of storm costs, including a storm reserve. In July 2024, the LPSC issued an order approving the joint uncontested stipulation and settlement agreement. In December 2024, SWEPCo issued $ 337 million of securitization bonds. The securitization bonds included $ 180 million for storm costs related to Hurricanes Laura and Delta and $ 150 million related to a storm reserve. In June 2023, SWEPCo incurred approximately $ 44 million in storm costs impacting the Louisiana jurisdiction. As authorized by the LPSC, the June 2023 storm costs were applied against the $ 150 million storm reserve. Any costs applied against the remaining storm reserve are subject to audit and prudency reviews. SWEPCo is required to accrue carrying charges on the remaining storm reserve liability. The securitization bonds also included $ 7 million related to estimated financing costs and carrying charges. </context> | us-gaap:SecuredDebt |
In 2020, Hurricanes Laura and Delta caused power outages and extensive damage to the SWEPCo service territories, primarily impacting the Louisiana jurisdiction. Following both hurricanes, the LPSC issued orders allowing Louisiana utilities, including SWEPCo, to establish regulatory assets to track and defer expenses associated with these storms. In February 2021, severe winter weather impacted the Louisiana jurisdiction and in March 2021, the LPSC approved the deferral of incremental storm restoration expenses related to the winter storm. In March 2023, SWEPCo and the LPSC staff filed a joint stipulation and settlement agreement with the LPSC which confirmed the prudency of $ 150 million of deferred incremental storm restoration expenses. The agreement also authorized an interim carrying charge at a rate of 3.125 % through March 2024. In April 2023, the LPSC issued an order approving the stipulation and settlement agreement. In July 2023, SWEPCo submitted additional information in phase two of this proceeding to obtain a financing order and prudency review of capital investment. In April 2024, SWEPCo and the LPSC staff filed a joint uncontested stipulation and settlement agreement with the LPSC requesting securitization of storm costs, including a storm reserve. In July 2024, the LPSC issued an order approving the joint uncontested stipulation and settlement agreement. In December 2024, SWEPCo issued $ 337 million of securitization bonds. The securitization bonds included $ 180 million for storm costs related to Hurricanes Laura and Delta and $ 150 million related to a storm reserve. In June 2023, SWEPCo incurred approximately $ 44 million in storm costs impacting the Louisiana jurisdiction. As authorized by the LPSC, the June 2023 storm costs were applied against the $ 150 million storm reserve. Any costs applied against the remaining storm reserve are subject to audit and prudency reviews. SWEPCo is required to accrue carrying charges on the remaining storm reserve liability. The securitization bonds also included $ 7 million related to estimated financing costs and carrying charges. | text | 180 | monetaryItemType | text: <entity> 180 </entity> <entity type> monetaryItemType </entity type> <context> In 2020, Hurricanes Laura and Delta caused power outages and extensive damage to the SWEPCo service territories, primarily impacting the Louisiana jurisdiction. Following both hurricanes, the LPSC issued orders allowing Louisiana utilities, including SWEPCo, to establish regulatory assets to track and defer expenses associated with these storms. In February 2021, severe winter weather impacted the Louisiana jurisdiction and in March 2021, the LPSC approved the deferral of incremental storm restoration expenses related to the winter storm. In March 2023, SWEPCo and the LPSC staff filed a joint stipulation and settlement agreement with the LPSC which confirmed the prudency of $ 150 million of deferred incremental storm restoration expenses. The agreement also authorized an interim carrying charge at a rate of 3.125 % through March 2024. In April 2023, the LPSC issued an order approving the stipulation and settlement agreement. In July 2023, SWEPCo submitted additional information in phase two of this proceeding to obtain a financing order and prudency review of capital investment. In April 2024, SWEPCo and the LPSC staff filed a joint uncontested stipulation and settlement agreement with the LPSC requesting securitization of storm costs, including a storm reserve. In July 2024, the LPSC issued an order approving the joint uncontested stipulation and settlement agreement. In December 2024, SWEPCo issued $ 337 million of securitization bonds. The securitization bonds included $ 180 million for storm costs related to Hurricanes Laura and Delta and $ 150 million related to a storm reserve. In June 2023, SWEPCo incurred approximately $ 44 million in storm costs impacting the Louisiana jurisdiction. As authorized by the LPSC, the June 2023 storm costs were applied against the $ 150 million storm reserve. Any costs applied against the remaining storm reserve are subject to audit and prudency reviews. SWEPCo is required to accrue carrying charges on the remaining storm reserve liability. The securitization bonds also included $ 7 million related to estimated financing costs and carrying charges. </context> | us-gaap:SecuredDebt |
In 2020, Hurricanes Laura and Delta caused power outages and extensive damage to the SWEPCo service territories, primarily impacting the Louisiana jurisdiction. Following both hurricanes, the LPSC issued orders allowing Louisiana utilities, including SWEPCo, to establish regulatory assets to track and defer expenses associated with these storms. In February 2021, severe winter weather impacted the Louisiana jurisdiction and in March 2021, the LPSC approved the deferral of incremental storm restoration expenses related to the winter storm. In March 2023, SWEPCo and the LPSC staff filed a joint stipulation and settlement agreement with the LPSC which confirmed the prudency of $ 150 million of deferred incremental storm restoration expenses. The agreement also authorized an interim carrying charge at a rate of 3.125 % through March 2024. In April 2023, the LPSC issued an order approving the stipulation and settlement agreement. In July 2023, SWEPCo submitted additional information in phase two of this proceeding to obtain a financing order and prudency review of capital investment. In April 2024, SWEPCo and the LPSC staff filed a joint uncontested stipulation and settlement agreement with the LPSC requesting securitization of storm costs, including a storm reserve. In July 2024, the LPSC issued an order approving the joint uncontested stipulation and settlement agreement. In December 2024, SWEPCo issued $ 337 million of securitization bonds. The securitization bonds included $ 180 million for storm costs related to Hurricanes Laura and Delta and $ 150 million related to a storm reserve. In June 2023, SWEPCo incurred approximately $ 44 million in storm costs impacting the Louisiana jurisdiction. As authorized by the LPSC, the June 2023 storm costs were applied against the $ 150 million storm reserve. Any costs applied against the remaining storm reserve are subject to audit and prudency reviews. SWEPCo is required to accrue carrying charges on the remaining storm reserve liability. The securitization bonds also included $ 7 million related to estimated financing costs and carrying charges. | text | 150 | monetaryItemType | text: <entity> 150 </entity> <entity type> monetaryItemType </entity type> <context> In 2020, Hurricanes Laura and Delta caused power outages and extensive damage to the SWEPCo service territories, primarily impacting the Louisiana jurisdiction. Following both hurricanes, the LPSC issued orders allowing Louisiana utilities, including SWEPCo, to establish regulatory assets to track and defer expenses associated with these storms. In February 2021, severe winter weather impacted the Louisiana jurisdiction and in March 2021, the LPSC approved the deferral of incremental storm restoration expenses related to the winter storm. In March 2023, SWEPCo and the LPSC staff filed a joint stipulation and settlement agreement with the LPSC which confirmed the prudency of $ 150 million of deferred incremental storm restoration expenses. The agreement also authorized an interim carrying charge at a rate of 3.125 % through March 2024. In April 2023, the LPSC issued an order approving the stipulation and settlement agreement. In July 2023, SWEPCo submitted additional information in phase two of this proceeding to obtain a financing order and prudency review of capital investment. In April 2024, SWEPCo and the LPSC staff filed a joint uncontested stipulation and settlement agreement with the LPSC requesting securitization of storm costs, including a storm reserve. In July 2024, the LPSC issued an order approving the joint uncontested stipulation and settlement agreement. In December 2024, SWEPCo issued $ 337 million of securitization bonds. The securitization bonds included $ 180 million for storm costs related to Hurricanes Laura and Delta and $ 150 million related to a storm reserve. In June 2023, SWEPCo incurred approximately $ 44 million in storm costs impacting the Louisiana jurisdiction. As authorized by the LPSC, the June 2023 storm costs were applied against the $ 150 million storm reserve. Any costs applied against the remaining storm reserve are subject to audit and prudency reviews. SWEPCo is required to accrue carrying charges on the remaining storm reserve liability. The securitization bonds also included $ 7 million related to estimated financing costs and carrying charges. </context> | us-gaap:SecuredDebt |
In 2020, Hurricanes Laura and Delta caused power outages and extensive damage to the SWEPCo service territories, primarily impacting the Louisiana jurisdiction. Following both hurricanes, the LPSC issued orders allowing Louisiana utilities, including SWEPCo, to establish regulatory assets to track and defer expenses associated with these storms. In February 2021, severe winter weather impacted the Louisiana jurisdiction and in March 2021, the LPSC approved the deferral of incremental storm restoration expenses related to the winter storm. In March 2023, SWEPCo and the LPSC staff filed a joint stipulation and settlement agreement with the LPSC which confirmed the prudency of $ 150 million of deferred incremental storm restoration expenses. The agreement also authorized an interim carrying charge at a rate of 3.125 % through March 2024. In April 2023, the LPSC issued an order approving the stipulation and settlement agreement. In July 2023, SWEPCo submitted additional information in phase two of this proceeding to obtain a financing order and prudency review of capital investment. In April 2024, SWEPCo and the LPSC staff filed a joint uncontested stipulation and settlement agreement with the LPSC requesting securitization of storm costs, including a storm reserve. In July 2024, the LPSC issued an order approving the joint uncontested stipulation and settlement agreement. In December 2024, SWEPCo issued $ 337 million of securitization bonds. The securitization bonds included $ 180 million for storm costs related to Hurricanes Laura and Delta and $ 150 million related to a storm reserve. In June 2023, SWEPCo incurred approximately $ 44 million in storm costs impacting the Louisiana jurisdiction. As authorized by the LPSC, the June 2023 storm costs were applied against the $ 150 million storm reserve. Any costs applied against the remaining storm reserve are subject to audit and prudency reviews. SWEPCo is required to accrue carrying charges on the remaining storm reserve liability. The securitization bonds also included $ 7 million related to estimated financing costs and carrying charges. | text | 7 | monetaryItemType | text: <entity> 7 </entity> <entity type> monetaryItemType </entity type> <context> In 2020, Hurricanes Laura and Delta caused power outages and extensive damage to the SWEPCo service territories, primarily impacting the Louisiana jurisdiction. Following both hurricanes, the LPSC issued orders allowing Louisiana utilities, including SWEPCo, to establish regulatory assets to track and defer expenses associated with these storms. In February 2021, severe winter weather impacted the Louisiana jurisdiction and in March 2021, the LPSC approved the deferral of incremental storm restoration expenses related to the winter storm. In March 2023, SWEPCo and the LPSC staff filed a joint stipulation and settlement agreement with the LPSC which confirmed the prudency of $ 150 million of deferred incremental storm restoration expenses. The agreement also authorized an interim carrying charge at a rate of 3.125 % through March 2024. In April 2023, the LPSC issued an order approving the stipulation and settlement agreement. In July 2023, SWEPCo submitted additional information in phase two of this proceeding to obtain a financing order and prudency review of capital investment. In April 2024, SWEPCo and the LPSC staff filed a joint uncontested stipulation and settlement agreement with the LPSC requesting securitization of storm costs, including a storm reserve. In July 2024, the LPSC issued an order approving the joint uncontested stipulation and settlement agreement. In December 2024, SWEPCo issued $ 337 million of securitization bonds. The securitization bonds included $ 180 million for storm costs related to Hurricanes Laura and Delta and $ 150 million related to a storm reserve. In June 2023, SWEPCo incurred approximately $ 44 million in storm costs impacting the Louisiana jurisdiction. As authorized by the LPSC, the June 2023 storm costs were applied against the $ 150 million storm reserve. Any costs applied against the remaining storm reserve are subject to audit and prudency reviews. SWEPCo is required to accrue carrying charges on the remaining storm reserve liability. The securitization bonds also included $ 7 million related to estimated financing costs and carrying charges. </context> | us-gaap:DeferredFinanceCostsGross |
In December 2021, the Dolet Hills Power Station was retired. As part of the 2020 Texas Base Rate Case, the PUCT authorized recovery of SWEPCo’s Texas jurisdictional share of the Dolet Hills Power Station through 2046, but denied SWEPCo the ability to earn a return on this investment resulting in a disallowance of $ 12 million in 2021. See “2020 Texas Base Rate Case” section of Note 4 for additional information. As part of the 2021 Arkansas Base Rate Case, the APSC authorized recovery of SWEPCo’s Arkansas jurisdictional share of the Dolet Hills Power Station through 2027, but denied SWEPCo the ability to earn a return on this investment resulting in a disallowance of $ 2 million in the second quarter of 2022. Also, the APSC did not rule on the prudency of the early retirement of the Dolet Hills Power Station, which will be addressed in a future proceeding. As part of the 2020 Louisiana Base Rate Case, the LPSC authorized the recovery of SWEPCo’s Louisiana share of the Dolet Hills Power Station, through a separate rider, through 2032, but did not rule on the prudency of the early retirement of the plant, which is being addressed in a separate proceeding. | text | 12 | monetaryItemType | text: <entity> 12 </entity> <entity type> monetaryItemType </entity type> <context> In December 2021, the Dolet Hills Power Station was retired. As part of the 2020 Texas Base Rate Case, the PUCT authorized recovery of SWEPCo’s Texas jurisdictional share of the Dolet Hills Power Station through 2046, but denied SWEPCo the ability to earn a return on this investment resulting in a disallowance of $ 12 million in 2021. See “2020 Texas Base Rate Case” section of Note 4 for additional information. As part of the 2021 Arkansas Base Rate Case, the APSC authorized recovery of SWEPCo’s Arkansas jurisdictional share of the Dolet Hills Power Station through 2027, but denied SWEPCo the ability to earn a return on this investment resulting in a disallowance of $ 2 million in the second quarter of 2022. Also, the APSC did not rule on the prudency of the early retirement of the Dolet Hills Power Station, which will be addressed in a future proceeding. As part of the 2020 Louisiana Base Rate Case, the LPSC authorized the recovery of SWEPCo’s Louisiana share of the Dolet Hills Power Station, through a separate rider, through 2032, but did not rule on the prudency of the early retirement of the plant, which is being addressed in a separate proceeding. </context> | us-gaap:OtherAssetImpairmentCharges |
In December 2021, the Dolet Hills Power Station was retired. As part of the 2020 Texas Base Rate Case, the PUCT authorized recovery of SWEPCo’s Texas jurisdictional share of the Dolet Hills Power Station through 2046, but denied SWEPCo the ability to earn a return on this investment resulting in a disallowance of $ 12 million in 2021. See “2020 Texas Base Rate Case” section of Note 4 for additional information. As part of the 2021 Arkansas Base Rate Case, the APSC authorized recovery of SWEPCo’s Arkansas jurisdictional share of the Dolet Hills Power Station through 2027, but denied SWEPCo the ability to earn a return on this investment resulting in a disallowance of $ 2 million in the second quarter of 2022. Also, the APSC did not rule on the prudency of the early retirement of the Dolet Hills Power Station, which will be addressed in a future proceeding. As part of the 2020 Louisiana Base Rate Case, the LPSC authorized the recovery of SWEPCo’s Louisiana share of the Dolet Hills Power Station, through a separate rider, through 2032, but did not rule on the prudency of the early retirement of the plant, which is being addressed in a separate proceeding. | text | 2 | monetaryItemType | text: <entity> 2 </entity> <entity type> monetaryItemType </entity type> <context> In December 2021, the Dolet Hills Power Station was retired. As part of the 2020 Texas Base Rate Case, the PUCT authorized recovery of SWEPCo’s Texas jurisdictional share of the Dolet Hills Power Station through 2046, but denied SWEPCo the ability to earn a return on this investment resulting in a disallowance of $ 12 million in 2021. See “2020 Texas Base Rate Case” section of Note 4 for additional information. As part of the 2021 Arkansas Base Rate Case, the APSC authorized recovery of SWEPCo’s Arkansas jurisdictional share of the Dolet Hills Power Station through 2027, but denied SWEPCo the ability to earn a return on this investment resulting in a disallowance of $ 2 million in the second quarter of 2022. Also, the APSC did not rule on the prudency of the early retirement of the Dolet Hills Power Station, which will be addressed in a future proceeding. As part of the 2020 Louisiana Base Rate Case, the LPSC authorized the recovery of SWEPCo’s Louisiana share of the Dolet Hills Power Station, through a separate rider, through 2032, but did not rule on the prudency of the early retirement of the plant, which is being addressed in a separate proceeding. </context> | us-gaap:OtherAssetImpairmentCharges |
In April 2024, the LPSC approved a unanimous settlement agreement filed by SWEPCo, LPSC staff and certain intervenors that resolved the prudency of the retirement of the Dolet Hills Power Station and resulted in a disallowance of $ 14 million in the first quarter of 2024. | text | 14 | monetaryItemType | text: <entity> 14 </entity> <entity type> monetaryItemType </entity type> <context> In April 2024, the LPSC approved a unanimous settlement agreement filed by SWEPCo, LPSC staff and certain intervenors that resolved the prudency of the retirement of the Dolet Hills Power Station and resulted in a disallowance of $ 14 million in the first quarter of 2024. </context> | us-gaap:OtherAssetImpairmentCharges |
In March 2023, the Pirkey Plant was retired. As part of the 2020 Louisiana Base Rate Case, the LPSC authorized the recovery of SWEPCo’s Louisiana jurisdictional share of the Pirkey Plant, through a separate rider, through 2032. As part of the 2021 Arkansas Base Rate Case, the APSC granted SWEPCo regulatory asset treatment. SWEPCo will request recovery including a weighted average cost of capital carrying charge through a future proceeding. In July 2023, Texas ALJs issued a PFD that concluded the decision to retire the Pirkey Plant was prudent. In September 2023, the PUCT rejected the ALJs’ July 2023 PFD. In the open meeting, the commissioners expressed their concerns that the analysis in support of SWEPCo’s decision to retire the Pirkey Plant was not robust enough and that SWEPCo should have re-evaluated the decision following Winter Storm Uri. The treatment of the cost of recovery of the Pirkey Plant is expected to be addressed in a future rate case. As of December 31, 2024, the Texas jurisdictional share of the net book value of the Pirkey Plant was $ 69 million. To the extent any portion of the Texas jurisdictional share of the net book value of the Pirkey Plant is not recoverable, it could reduce future net income and cash flows and impact financial condition. | text | 69 | monetaryItemType | text: <entity> 69 </entity> <entity type> monetaryItemType </entity type> <context> In March 2023, the Pirkey Plant was retired. As part of the 2020 Louisiana Base Rate Case, the LPSC authorized the recovery of SWEPCo’s Louisiana jurisdictional share of the Pirkey Plant, through a separate rider, through 2032. As part of the 2021 Arkansas Base Rate Case, the APSC granted SWEPCo regulatory asset treatment. SWEPCo will request recovery including a weighted average cost of capital carrying charge through a future proceeding. In July 2023, Texas ALJs issued a PFD that concluded the decision to retire the Pirkey Plant was prudent. In September 2023, the PUCT rejected the ALJs’ July 2023 PFD. In the open meeting, the commissioners expressed their concerns that the analysis in support of SWEPCo’s decision to retire the Pirkey Plant was not robust enough and that SWEPCo should have re-evaluated the decision following Winter Storm Uri. The treatment of the cost of recovery of the Pirkey Plant is expected to be addressed in a future rate case. As of December 31, 2024, the Texas jurisdictional share of the net book value of the Pirkey Plant was $ 69 million. To the extent any portion of the Texas jurisdictional share of the net book value of the Pirkey Plant is not recoverable, it could reduce future net income and cash flows and impact financial condition. </context> | us-gaap:NetRegulatoryAssets |
In March 2021, the LPSC issued an order allowing SWEPCo to recover up to $ 20 million of fuel costs in 2021 and defer approximately $ 35 million of additional costs with a recovery period to be determined at a later date. In August 2022, the LPSC staff filed testimony recommending fuel disallowances of up to $ 55 million, including denial of recovery of the $ 35 million deferral, with refunds to customers over five years . In February 2024, an ALJ issued a final recommendation which included a proposed $ 55 million refund to customers and the denial of recovery of the $ 35 million deferral. SWEPCo filed a motion to present oral arguments with the LPSC to dispute the ALJ’s recommendations. In April 2024, the LPSC approved a unanimous settlement agreement filed by SWEPCo, LPSC staff and certain intervenors that resolved the fuel recovery dispute and resulted in a fuel disallowance of $ 11 million. The remaining $ 24 million regulatory asset balance will be recovered over three years with interest. | text | 24 | monetaryItemType | text: <entity> 24 </entity> <entity type> monetaryItemType </entity type> <context> In March 2021, the LPSC issued an order allowing SWEPCo to recover up to $ 20 million of fuel costs in 2021 and defer approximately $ 35 million of additional costs with a recovery period to be determined at a later date. In August 2022, the LPSC staff filed testimony recommending fuel disallowances of up to $ 55 million, including denial of recovery of the $ 35 million deferral, with refunds to customers over five years . In February 2024, an ALJ issued a final recommendation which included a proposed $ 55 million refund to customers and the denial of recovery of the $ 35 million deferral. SWEPCo filed a motion to present oral arguments with the LPSC to dispute the ALJ’s recommendations. In April 2024, the LPSC approved a unanimous settlement agreement filed by SWEPCo, LPSC staff and certain intervenors that resolved the fuel recovery dispute and resulted in a fuel disallowance of $ 11 million. The remaining $ 24 million regulatory asset balance will be recovered over three years with interest. </context> | us-gaap:RegulatoryAssets |
In March 2024, AEP increased its $ 4 billion revolving credit facility to $ 5 billion and extended the due date from March 2027 to March 2029. Also, in March 2024, AEP extended the due date of its $ 1 billion revolving credit facility from March 2025 to March 2027. AEP may issue up to $ 1.2 billion as letters of credit under these revolving credit facilities on behalf of subsidiaries. As of December 31, 2024, no letters of credit were issued under the revolving credit facility. | text | 4 | monetaryItemType | text: <entity> 4 </entity> <entity type> monetaryItemType </entity type> <context> In March 2024, AEP increased its $ 4 billion revolving credit facility to $ 5 billion and extended the due date from March 2027 to March 2029. Also, in March 2024, AEP extended the due date of its $ 1 billion revolving credit facility from March 2025 to March 2027. AEP may issue up to $ 1.2 billion as letters of credit under these revolving credit facilities on behalf of subsidiaries. As of December 31, 2024, no letters of credit were issued under the revolving credit facility. </context> | us-gaap:LineOfCreditFacilityMaximumBorrowingCapacity |
In March 2024, AEP increased its $ 4 billion revolving credit facility to $ 5 billion and extended the due date from March 2027 to March 2029. Also, in March 2024, AEP extended the due date of its $ 1 billion revolving credit facility from March 2025 to March 2027. AEP may issue up to $ 1.2 billion as letters of credit under these revolving credit facilities on behalf of subsidiaries. As of December 31, 2024, no letters of credit were issued under the revolving credit facility. | text | 5 | monetaryItemType | text: <entity> 5 </entity> <entity type> monetaryItemType </entity type> <context> In March 2024, AEP increased its $ 4 billion revolving credit facility to $ 5 billion and extended the due date from March 2027 to March 2029. Also, in March 2024, AEP extended the due date of its $ 1 billion revolving credit facility from March 2025 to March 2027. AEP may issue up to $ 1.2 billion as letters of credit under these revolving credit facilities on behalf of subsidiaries. As of December 31, 2024, no letters of credit were issued under the revolving credit facility. </context> | us-gaap:LineOfCreditFacilityMaximumBorrowingCapacity |
In March 2024, AEP increased its $ 4 billion revolving credit facility to $ 5 billion and extended the due date from March 2027 to March 2029. Also, in March 2024, AEP extended the due date of its $ 1 billion revolving credit facility from March 2025 to March 2027. AEP may issue up to $ 1.2 billion as letters of credit under these revolving credit facilities on behalf of subsidiaries. As of December 31, 2024, no letters of credit were issued under the revolving credit facility. | text | 1 | monetaryItemType | text: <entity> 1 </entity> <entity type> monetaryItemType </entity type> <context> In March 2024, AEP increased its $ 4 billion revolving credit facility to $ 5 billion and extended the due date from March 2027 to March 2029. Also, in March 2024, AEP extended the due date of its $ 1 billion revolving credit facility from March 2025 to March 2027. AEP may issue up to $ 1.2 billion as letters of credit under these revolving credit facilities on behalf of subsidiaries. As of December 31, 2024, no letters of credit were issued under the revolving credit facility. </context> | us-gaap:LineOfCreditFacilityMaximumBorrowingCapacity |
In March 2024, AEP increased its $ 4 billion revolving credit facility to $ 5 billion and extended the due date from March 2027 to March 2029. Also, in March 2024, AEP extended the due date of its $ 1 billion revolving credit facility from March 2025 to March 2027. AEP may issue up to $ 1.2 billion as letters of credit under these revolving credit facilities on behalf of subsidiaries. As of December 31, 2024, no letters of credit were issued under the revolving credit facility. | text | 1.2 | monetaryItemType | text: <entity> 1.2 </entity> <entity type> monetaryItemType </entity type> <context> In March 2024, AEP increased its $ 4 billion revolving credit facility to $ 5 billion and extended the due date from March 2027 to March 2029. Also, in March 2024, AEP extended the due date of its $ 1 billion revolving credit facility from March 2025 to March 2027. AEP may issue up to $ 1.2 billion as letters of credit under these revolving credit facilities on behalf of subsidiaries. As of December 31, 2024, no letters of credit were issued under the revolving credit facility. </context> | us-gaap:LineOfCreditFacilityMaximumBorrowingCapacity |
In March 2024, AEP increased its $ 4 billion revolving credit facility to $ 5 billion and extended the due date from March 2027 to March 2029. Also, in March 2024, AEP extended the due date of its $ 1 billion revolving credit facility from March 2025 to March 2027. AEP may issue up to $ 1.2 billion as letters of credit under these revolving credit facilities on behalf of subsidiaries. As of December 31, 2024, no letters of credit were issued under the revolving credit facility. | text | no | monetaryItemType | text: <entity> no </entity> <entity type> monetaryItemType </entity type> <context> In March 2024, AEP increased its $ 4 billion revolving credit facility to $ 5 billion and extended the due date from March 2027 to March 2029. Also, in March 2024, AEP extended the due date of its $ 1 billion revolving credit facility from March 2025 to March 2027. AEP may issue up to $ 1.2 billion as letters of credit under these revolving credit facilities on behalf of subsidiaries. As of December 31, 2024, no letters of credit were issued under the revolving credit facility. </context> | us-gaap:LineOfCreditFacilityMaximumBorrowingCapacity |
An uncommitted facility gives the issuer of the facility the right to accept or decline each request made under the facility. AEP issues letters of credit on behalf of subsidiaries under six uncommitted facilities totaling $ 450 million. The Registrants’ maximum future payments for letters of credit issued under the uncommitted facilities as of December 31, 2024 were as follows: | text | 450 | monetaryItemType | text: <entity> 450 </entity> <entity type> monetaryItemType </entity type> <context> An uncommitted facility gives the issuer of the facility the right to accept or decline each request made under the facility. AEP issues letters of credit on behalf of subsidiaries under six uncommitted facilities totaling $ 450 million. The Registrants’ maximum future payments for letters of credit issued under the uncommitted facilities as of December 31, 2024 were as follows: </context> | us-gaap:DebtInstrumentFaceAmount |
In April 2024, AEP reached an agreement with the four shareholders to fully and finally resolve the Derivative Actions and the Litigation Demand, and all claims asserted or that could have been asserted by any AEP shareholder based on the facts alleged, in the manner and upon the terms and conditions set forth in the settlement documents (the Settlement). In July 2024, the U.S. District Court preliminarily approved the Settlement. The Settlement includes a payment of $ 450 thousand for attorneys’ fees | text | 450 | monetaryItemType | text: <entity> 450 </entity> <entity type> monetaryItemType </entity type> <context> In April 2024, AEP reached an agreement with the four shareholders to fully and finally resolve the Derivative Actions and the Litigation Demand, and all claims asserted or that could have been asserted by any AEP shareholder based on the facts alleged, in the manner and upon the terms and conditions set forth in the settlement documents (the Settlement). In July 2024, the U.S. District Court preliminarily approved the Settlement. The Settlement includes a payment of $ 450 thousand for attorneys’ fees </context> | us-gaap:LitigationSettlementAmountAwardedToOtherParty |
In May 2021, AEP received a subpoena from the SEC’s Division of Enforcement seeking various documents, including documents relating to the passage of HB 6 and documents relating to AEP’s policies and financial processes and controls. In August 2022, AEP received a second subpoena from the SEC seeking various additional documents relating to its ongoing investigation. In January 2025, AEP and the SEC reached a settlement concluding and resolving the SEC’s investigation concerning AEP’s relationship with and statements about Empowering Ohio’s Economy, a 501(c)(4) organization and AEP’s related internal accounting and disclosure controls. Under the terms of the administrative order, in which AEP neither admits nor denies the SEC’s findings, AEP agreed to pay a civil penalty of $ 19 million and to cease and desist from committing or causing any violations and any future violations of the specified provisions of the federal securities laws. AEP recorded an accrual for the full amount of the penalty in the third quarter of 2024. The $ 19 million penalty is included in Other Operation expenses on AEP’s statements of income and in Other Current Liabilities on AEP’s balance sheet. | text | 19 | monetaryItemType | text: <entity> 19 </entity> <entity type> monetaryItemType </entity type> <context> In May 2021, AEP received a subpoena from the SEC’s Division of Enforcement seeking various documents, including documents relating to the passage of HB 6 and documents relating to AEP’s policies and financial processes and controls. In August 2022, AEP received a second subpoena from the SEC seeking various additional documents relating to its ongoing investigation. In January 2025, AEP and the SEC reached a settlement concluding and resolving the SEC’s investigation concerning AEP’s relationship with and statements about Empowering Ohio’s Economy, a 501(c)(4) organization and AEP’s related internal accounting and disclosure controls. Under the terms of the administrative order, in which AEP neither admits nor denies the SEC’s findings, AEP agreed to pay a civil penalty of $ 19 million and to cease and desist from committing or causing any violations and any future violations of the specified provisions of the federal securities laws. AEP recorded an accrual for the full amount of the penalty in the third quarter of 2024. The $ 19 million penalty is included in Other Operation expenses on AEP’s statements of income and in Other Current Liabilities on AEP’s balance sheet. </context> | us-gaap:LossContingencyLossInPeriod |
In 2020, PSO and SWEPCo received regulatory approvals to acquire the NCWF, comprised of three Oklahoma wind facilities totaling 1,484 MWs, on a fixed cost turn-key basis. PSO and SWEPCo own undivided interests of 45.5 % and 54.5 % of the NCWF, respectively. In total, the three wind facilities cost approximately $ 2 billion and consist of Traverse ( 998 MW), Maverick ( 287 MW) and Sundance ( 199 MW). Output from the NCWF serves retail load in PSO’s Oklahoma service territory and both retail and FERC wholesale load in SWEPCo’s service territories in Arkansas and Louisiana. The Oklahoma and Louisiana portions of the NCWF revenue requirement, net of PTC benefit, are recoverable through authorized riders until the amounts are reflected in base rates. Recovery of the Arkansas portion of the NCWF revenue requirement through base rates was approved by the APSC in May 2022. The NCWF are subject to various regulatory performance requirements. If these performance requirements are not met, PSO and SWEPCo would recognize a regulatory liability to refund retail customers. | text | three | integerItemType | text: <entity> three </entity> <entity type> integerItemType </entity type> <context> In 2020, PSO and SWEPCo received regulatory approvals to acquire the NCWF, comprised of three Oklahoma wind facilities totaling 1,484 MWs, on a fixed cost turn-key basis. PSO and SWEPCo own undivided interests of 45.5 % and 54.5 % of the NCWF, respectively. In total, the three wind facilities cost approximately $ 2 billion and consist of Traverse ( 998 MW), Maverick ( 287 MW) and Sundance ( 199 MW). Output from the NCWF serves retail load in PSO’s Oklahoma service territory and both retail and FERC wholesale load in SWEPCo’s service territories in Arkansas and Louisiana. The Oklahoma and Louisiana portions of the NCWF revenue requirement, net of PTC benefit, are recoverable through authorized riders until the amounts are reflected in base rates. Recovery of the Arkansas portion of the NCWF revenue requirement through base rates was approved by the APSC in May 2022. The NCWF are subject to various regulatory performance requirements. If these performance requirements are not met, PSO and SWEPCo would recognize a regulatory liability to refund retail customers. </context> | us-gaap:NumberOfRealEstateProperties |
In 2020, PSO and SWEPCo received regulatory approvals to acquire the NCWF, comprised of three Oklahoma wind facilities totaling 1,484 MWs, on a fixed cost turn-key basis. PSO and SWEPCo own undivided interests of 45.5 % and 54.5 % of the NCWF, respectively. In total, the three wind facilities cost approximately $ 2 billion and consist of Traverse ( 998 MW), Maverick ( 287 MW) and Sundance ( 199 MW). Output from the NCWF serves retail load in PSO’s Oklahoma service territory and both retail and FERC wholesale load in SWEPCo’s service territories in Arkansas and Louisiana. The Oklahoma and Louisiana portions of the NCWF revenue requirement, net of PTC benefit, are recoverable through authorized riders until the amounts are reflected in base rates. Recovery of the Arkansas portion of the NCWF revenue requirement through base rates was approved by the APSC in May 2022. The NCWF are subject to various regulatory performance requirements. If these performance requirements are not met, PSO and SWEPCo would recognize a regulatory liability to refund retail customers. | text | 45.5 | percentItemType | text: <entity> 45.5 </entity> <entity type> percentItemType </entity type> <context> In 2020, PSO and SWEPCo received regulatory approvals to acquire the NCWF, comprised of three Oklahoma wind facilities totaling 1,484 MWs, on a fixed cost turn-key basis. PSO and SWEPCo own undivided interests of 45.5 % and 54.5 % of the NCWF, respectively. In total, the three wind facilities cost approximately $ 2 billion and consist of Traverse ( 998 MW), Maverick ( 287 MW) and Sundance ( 199 MW). Output from the NCWF serves retail load in PSO’s Oklahoma service territory and both retail and FERC wholesale load in SWEPCo’s service territories in Arkansas and Louisiana. The Oklahoma and Louisiana portions of the NCWF revenue requirement, net of PTC benefit, are recoverable through authorized riders until the amounts are reflected in base rates. Recovery of the Arkansas portion of the NCWF revenue requirement through base rates was approved by the APSC in May 2022. The NCWF are subject to various regulatory performance requirements. If these performance requirements are not met, PSO and SWEPCo would recognize a regulatory liability to refund retail customers. </context> | us-gaap:BusinessAcquisitionPercentageOfVotingInterestsAcquired |
In 2020, PSO and SWEPCo received regulatory approvals to acquire the NCWF, comprised of three Oklahoma wind facilities totaling 1,484 MWs, on a fixed cost turn-key basis. PSO and SWEPCo own undivided interests of 45.5 % and 54.5 % of the NCWF, respectively. In total, the three wind facilities cost approximately $ 2 billion and consist of Traverse ( 998 MW), Maverick ( 287 MW) and Sundance ( 199 MW). Output from the NCWF serves retail load in PSO’s Oklahoma service territory and both retail and FERC wholesale load in SWEPCo’s service territories in Arkansas and Louisiana. The Oklahoma and Louisiana portions of the NCWF revenue requirement, net of PTC benefit, are recoverable through authorized riders until the amounts are reflected in base rates. Recovery of the Arkansas portion of the NCWF revenue requirement through base rates was approved by the APSC in May 2022. The NCWF are subject to various regulatory performance requirements. If these performance requirements are not met, PSO and SWEPCo would recognize a regulatory liability to refund retail customers. | text | 54.5 | percentItemType | text: <entity> 54.5 </entity> <entity type> percentItemType </entity type> <context> In 2020, PSO and SWEPCo received regulatory approvals to acquire the NCWF, comprised of three Oklahoma wind facilities totaling 1,484 MWs, on a fixed cost turn-key basis. PSO and SWEPCo own undivided interests of 45.5 % and 54.5 % of the NCWF, respectively. In total, the three wind facilities cost approximately $ 2 billion and consist of Traverse ( 998 MW), Maverick ( 287 MW) and Sundance ( 199 MW). Output from the NCWF serves retail load in PSO’s Oklahoma service territory and both retail and FERC wholesale load in SWEPCo’s service territories in Arkansas and Louisiana. The Oklahoma and Louisiana portions of the NCWF revenue requirement, net of PTC benefit, are recoverable through authorized riders until the amounts are reflected in base rates. Recovery of the Arkansas portion of the NCWF revenue requirement through base rates was approved by the APSC in May 2022. The NCWF are subject to various regulatory performance requirements. If these performance requirements are not met, PSO and SWEPCo would recognize a regulatory liability to refund retail customers. </context> | us-gaap:BusinessAcquisitionPercentageOfVotingInterestsAcquired |
In 2020, PSO and SWEPCo received regulatory approvals to acquire the NCWF, comprised of three Oklahoma wind facilities totaling 1,484 MWs, on a fixed cost turn-key basis. PSO and SWEPCo own undivided interests of 45.5 % and 54.5 % of the NCWF, respectively. In total, the three wind facilities cost approximately $ 2 billion and consist of Traverse ( 998 MW), Maverick ( 287 MW) and Sundance ( 199 MW). Output from the NCWF serves retail load in PSO’s Oklahoma service territory and both retail and FERC wholesale load in SWEPCo’s service territories in Arkansas and Louisiana. The Oklahoma and Louisiana portions of the NCWF revenue requirement, net of PTC benefit, are recoverable through authorized riders until the amounts are reflected in base rates. Recovery of the Arkansas portion of the NCWF revenue requirement through base rates was approved by the APSC in May 2022. The NCWF are subject to various regulatory performance requirements. If these performance requirements are not met, PSO and SWEPCo would recognize a regulatory liability to refund retail customers. | text | 2 | monetaryItemType | text: <entity> 2 </entity> <entity type> monetaryItemType </entity type> <context> In 2020, PSO and SWEPCo received regulatory approvals to acquire the NCWF, comprised of three Oklahoma wind facilities totaling 1,484 MWs, on a fixed cost turn-key basis. PSO and SWEPCo own undivided interests of 45.5 % and 54.5 % of the NCWF, respectively. In total, the three wind facilities cost approximately $ 2 billion and consist of Traverse ( 998 MW), Maverick ( 287 MW) and Sundance ( 199 MW). Output from the NCWF serves retail load in PSO’s Oklahoma service territory and both retail and FERC wholesale load in SWEPCo’s service territories in Arkansas and Louisiana. The Oklahoma and Louisiana portions of the NCWF revenue requirement, net of PTC benefit, are recoverable through authorized riders until the amounts are reflected in base rates. Recovery of the Arkansas portion of the NCWF revenue requirement through base rates was approved by the APSC in May 2022. The NCWF are subject to various regulatory performance requirements. If these performance requirements are not met, PSO and SWEPCo would recognize a regulatory liability to refund retail customers. </context> | us-gaap:PaymentsToAcquirePropertyPlantAndEquipment |
In March 2022, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Traverse, the final NCWF project, during its development and construction for $ 1.2 billion. Traverse was placed in-service in March 2022. Immediately following the acquisition, PSO and SWEPCo liquidated the entity and simultaneously distributed the assets in proportion to their undivided ownership interests. PSO and SWEPCo apply the joint plant accounting model to account for their respective undivided interests in the assets, liabilities, revenues and expenses of the NCWF projects. | text | 1.2 | monetaryItemType | text: <entity> 1.2 </entity> <entity type> monetaryItemType </entity type> <context> In March 2022, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Traverse, the final NCWF project, during its development and construction for $ 1.2 billion. Traverse was placed in-service in March 2022. Immediately following the acquisition, PSO and SWEPCo liquidated the entity and simultaneously distributed the assets in proportion to their undivided ownership interests. PSO and SWEPCo apply the joint plant accounting model to account for their respective undivided interests in the assets, liabilities, revenues and expenses of the NCWF projects. </context> | us-gaap:PaymentsToAcquirePropertyPlantAndEquipment |
In November 2022, PSO entered into an agreement to acquire the Rock Falls Wind Facility. In February 2023, the FERC approved PSO’s acquisition of the Rock Falls Wind Facility under Section 203 of the Federal Power Act. In March 2023, PSO acquired an ownership interest in the entity that owned Rock Falls during its development and construction for $ 146 million. In accordance with the guidance for “Business Combinations,” AEP management determined that the acquisition of the Rock Falls Wind Facility represents an asset acquisition. The lease obligations related to Rock Falls were not material at the time of acquisition. | text | 146 | monetaryItemType | text: <entity> 146 </entity> <entity type> monetaryItemType </entity type> <context> In November 2022, PSO entered into an agreement to acquire the Rock Falls Wind Facility. In February 2023, the FERC approved PSO’s acquisition of the Rock Falls Wind Facility under Section 203 of the Federal Power Act. In March 2023, PSO acquired an ownership interest in the entity that owned Rock Falls during its development and construction for $ 146 million. In accordance with the guidance for “Business Combinations,” AEP management determined that the acquisition of the Rock Falls Wind Facility represents an asset acquisition. The lease obligations related to Rock Falls were not material at the time of acquisition. </context> | us-gaap:BusinessCombinationConsiderationTransferred1 |
In April 2023, AEP initiated a sales process for its ownership in AEP OnSite Partners. AEP OnSite Partners targeted opportunities in distributed solar, combined heat and power, energy storage, waste heat recovery, energy efficiency, peaking generation and other energy solutions. In May 2024, AEP signed an agreement to sell AEP OnSite Partners to a nonaffiliated third-party. In September 2024, AEP completed the sale and received cash proceeds of approximately $ 318 million, net of taxes and transaction costs. The proceeds were used to pay down short-term debt. | text | 318 | monetaryItemType | text: <entity> 318 </entity> <entity type> monetaryItemType </entity type> <context> In April 2023, AEP initiated a sales process for its ownership in AEP OnSite Partners. AEP OnSite Partners targeted opportunities in distributed solar, combined heat and power, energy storage, waste heat recovery, energy efficiency, peaking generation and other energy solutions. In May 2024, AEP signed an agreement to sell AEP OnSite Partners to a nonaffiliated third-party. In September 2024, AEP completed the sale and received cash proceeds of approximately $ 318 million, net of taxes and transaction costs. The proceeds were used to pay down short-term debt. </context> | us-gaap:ProceedsFromDivestitureOfBusinesses |
In December 2023, AEP and the joint owner signed an agreement to sell NMRD to a nonaffiliated third party and the sale was completed in February 2024. AEP received cash proceeds of approximately $ 107 million, net of taxes and transaction costs. The transaction did not have a material impact on net income or financial condition. | text | 107 | monetaryItemType | text: <entity> 107 </entity> <entity type> monetaryItemType </entity type> <context> In December 2023, AEP and the joint owner signed an agreement to sell NMRD to a nonaffiliated third party and the sale was completed in February 2024. AEP received cash proceeds of approximately $ 107 million, net of taxes and transaction costs. The transaction did not have a material impact on net income or financial condition. </context> | us-gaap:ProceedsFromDivestitureOfBusinesses |
As a result of delays in the anticipated timing of the closing of the transaction and other factors, AEP recorded a $ 363 million pretax loss on the expected sale of the Kentucky Operations for the year ended December 31, 2022. In April 2023, AEP, AEPTCo and Liberty entered into a Mutual Termination Agreement (Termination Agreement) terminating the SPA. The parties entered into the Termination Agreement as all of the conditions precedent to closing the sale could not be satisfied prior to April 26, 2023. Upon termination of the sale and reverting to a held and used model, in the first quarter of 2023, AEP reversed $ 28 million of expected transaction costs included in the $ 363 million pretax loss and was required to present its investment in the Kentucky Operations at the lower of fair value or historical carrying value which resulted in a $ 335 million reduction recorded in Property, Plant and Equipment. The reduced investment in KPCo’s assets is being amortized over the 30-year average useful life of the KPCo assets. | text | 363 | monetaryItemType | text: <entity> 363 </entity> <entity type> monetaryItemType </entity type> <context> As a result of delays in the anticipated timing of the closing of the transaction and other factors, AEP recorded a $ 363 million pretax loss on the expected sale of the Kentucky Operations for the year ended December 31, 2022. In April 2023, AEP, AEPTCo and Liberty entered into a Mutual Termination Agreement (Termination Agreement) terminating the SPA. The parties entered into the Termination Agreement as all of the conditions precedent to closing the sale could not be satisfied prior to April 26, 2023. Upon termination of the sale and reverting to a held and used model, in the first quarter of 2023, AEP reversed $ 28 million of expected transaction costs included in the $ 363 million pretax loss and was required to present its investment in the Kentucky Operations at the lower of fair value or historical carrying value which resulted in a $ 335 million reduction recorded in Property, Plant and Equipment. The reduced investment in KPCo’s assets is being amortized over the 30-year average useful life of the KPCo assets. </context> | us-gaap:OtherAssetImpairmentCharges |
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