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On June 9, 2006, shareholders approved the Superconductive Components, Inc. 2006 Stock Incentive Plan (the “2006 Plan”). The Company adopted the 2006 Plan as incentive to key employees, directors, and consultants under which options to purchase up to 600,000 shares of the Company’s common stock may be granted, subject to the execution of stock option agreements. Incentive stock options may be granted to key employees of the Company and non-statutory options may be granted to directors who are not employees and to consultants and advisors who render services to the Company. Options may be exercised for periods up to 10 years from the date of grant at prices not less than 100 % of fair market value on the date of grant. The 2006 Plan expired in 2016 and no additional stock options may be granted. As of December 31, 2023, there were 20,243 stock options outstanding from the 2006 Plan which expire in November 2024. | text | 20243 | sharesItemType | text: <entity> 20243 </entity> <entity type> sharesItemType </entity type> <context> On June 9, 2006, shareholders approved the Superconductive Components, Inc. 2006 Stock Incentive Plan (the “2006 Plan”). The Company adopted the 2006 Plan as incentive to key employees, directors, and consultants under which options to purchase up to 600,000 shares of the Company’s common stock may be granted, subject to the execution of stock option agreements. Incentive stock options may be granted to key employees of the Company and non-statutory options may be granted to directors who are not employees and to consultants and advisors who render services to the Company. Options may be exercised for periods up to 10 years from the date of grant at prices not less than 100 % of fair market value on the date of grant. The 2006 Plan expired in 2016 and no additional stock options may be granted. As of December 31, 2023, there were 20,243 stock options outstanding from the 2006 Plan which expire in November 2024. </context> | us-gaap:ShareBasedCompensationArrangementByShareBasedPaymentAwardOptionsOutstandingNumber |
No valuation allowance was recorded against the realizability of the net deferred tax asset of $ 151,164 at December 31, 2022. | text | 151164 | monetaryItemType | text: <entity> 151164 </entity> <entity type> monetaryItemType </entity type> <context> No valuation allowance was recorded against the realizability of the net deferred tax asset of $ 151,164 at December 31, 2022. </context> | us-gaap:DeferredTaxAssetsNet |
As of each reporting date, management considers new evidence, both positive and negative, that could affect its view of the future realization of deferred tax assets. As of December 31, 2022, management determined that there was sufficient positive evidence to conclude that it was more likely than not that deferred taxes of $ 151,164 were realizable in part because we achieved six consecutive years of pretax income, expected profits to continue for the foreseeable future and implemented new efficiencies in the Company's manufacturing process. Accordingly, we determined that no valuation allowance was necessary at December 31, 2022. | text | 151164 | monetaryItemType | text: <entity> 151164 </entity> <entity type> monetaryItemType </entity type> <context> As of each reporting date, management considers new evidence, both positive and negative, that could affect its view of the future realization of deferred tax assets. As of December 31, 2022, management determined that there was sufficient positive evidence to conclude that it was more likely than not that deferred taxes of $ 151,164 were realizable in part because we achieved six consecutive years of pretax income, expected profits to continue for the foreseeable future and implemented new efficiencies in the Company's manufacturing process. Accordingly, we determined that no valuation allowance was necessary at December 31, 2022. </context> | us-gaap:DeferredTaxAssetsNet |
The Company had net operating loss carryforwards available for federal and state tax purposes of approximately $ 42,000 at December 31, 2022. | text | 42000 | monetaryItemType | text: <entity> 42000 </entity> <entity type> monetaryItemType </entity type> <context> The Company had net operating loss carryforwards available for federal and state tax purposes of approximately $ 42,000 at December 31, 2022. </context> | us-gaap:DeferredTaxAssetsOperatingLossCarryforwardsStateAndLocal |
(a) Cash dividends declared per AEP common share were $ 3.37 , $ 3.17 and $ 3.00 for the years ended December 31, 2023, 2022 and 2021, respectively. | text | 3.37 | perShareItemType | text: <entity> 3.37 </entity> <entity type> perShareItemType </entity type> <context> (a) Cash dividends declared per AEP common share were $ 3.37 , $ 3.17 and $ 3.00 for the years ended December 31, 2023, 2022 and 2021, respectively. </context> | us-gaap:CommonStockDividendsPerShareDeclared |
(a) Cash dividends declared per AEP common share were $ 3.37 , $ 3.17 and $ 3.00 for the years ended December 31, 2023, 2022 and 2021, respectively. | text | 3.17 | perShareItemType | text: <entity> 3.17 </entity> <entity type> perShareItemType </entity type> <context> (a) Cash dividends declared per AEP common share were $ 3.37 , $ 3.17 and $ 3.00 for the years ended December 31, 2023, 2022 and 2021, respectively. </context> | us-gaap:CommonStockDividendsPerShareDeclared |
(a) Cash dividends declared per AEP common share were $ 3.37 , $ 3.17 and $ 3.00 for the years ended December 31, 2023, 2022 and 2021, respectively. | text | 3.00 | perShareItemType | text: <entity> 3.00 </entity> <entity type> perShareItemType </entity type> <context> (a) Cash dividends declared per AEP common share were $ 3.37 , $ 3.17 and $ 3.00 for the years ended December 31, 2023, 2022 and 2021, respectively. </context> | us-gaap:CommonStockDividendsPerShareDeclared |
In March 2023, APCo submitted its 2020-2022 Virginia triennial review filing and base rate case with the Virginia SCC as required by state law. APCo requested a $ 213 million annual increase in Virginia base rates based upon a proposed 10.6 % return on common equity. The requested annual increase includes $ 47 million related to vegetation management and a $ 35 million increase in depreciation expense. The requested increase in depreciation expense reflects, among other things, the impacts of incremental investments made since APCo’s last depreciation study using property balances as of December 31, 2022. Effective January 1, 2023 and in accordance with past Virginia SCC directives, APCo implemented updated Virginia depreciation rates. APCo’s proposed revenue requirement also includes the recovery of certain costs incurred that partially contributed to APCo’s calculated earnings shortfall for the 2020-2022 triennial period. For triennial review periods in which a Virginia utility earns below its authorized ROE band, the utility may file to recover expenses incurred, up to the bottom of the authorized ROE band, related to certain categories of costs, including system restoration costs for severe weather events. | text | 10.6 | percentItemType | text: <entity> 10.6 </entity> <entity type> percentItemType </entity type> <context> In March 2023, APCo submitted its 2020-2022 Virginia triennial review filing and base rate case with the Virginia SCC as required by state law. APCo requested a $ 213 million annual increase in Virginia base rates based upon a proposed 10.6 % return on common equity. The requested annual increase includes $ 47 million related to vegetation management and a $ 35 million increase in depreciation expense. The requested increase in depreciation expense reflects, among other things, the impacts of incremental investments made since APCo’s last depreciation study using property balances as of December 31, 2022. Effective January 1, 2023 and in accordance with past Virginia SCC directives, APCo implemented updated Virginia depreciation rates. APCo’s proposed revenue requirement also includes the recovery of certain costs incurred that partially contributed to APCo’s calculated earnings shortfall for the 2020-2022 triennial period. For triennial review periods in which a Virginia utility earns below its authorized ROE band, the utility may file to recover expenses incurred, up to the bottom of the authorized ROE band, related to certain categories of costs, including system restoration costs for severe weather events. </context> | us-gaap:PublicUtilitiesRequestedReturnOnEquityPercentage |
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 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 requests recovery of certain historical period regulatory asset balances and proposes deferral accounting for certain future investments and tax related issues, including corporate alternative minimum tax 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 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 requests recovery of certain historical period regulatory asset balances and proposes deferral accounting for certain future investments and tax related issues, including corporate alternative minimum tax expense and PTCs related to the Cook Plant. </context> | us-gaap:PublicUtilitiesRequestedReturnOnEquityPercentage |
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 corporate alternative minimum tax 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 corporate alternative minimum tax expense and PTCs related to the Cook Plant. </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. The filing proposes no changes in depreciation rates and an annual level of storm restoration expense in base rates of approximately $ 1 million. KPCo also proposed to discontinue tracking of PJM transmission costs through a rider, and to instead collect an annual level of costs through base rates. In addition, KPCo has proposed a rider to recover certain distribution reliability investments and related incremental operation and maintenance expenses. KPCo also requested a prudency determination and recovery mechanism for approximately $ 16 million of purchased power costs not recoverable through its FAC since its last base case. KPCo’s proposal did not address the disposition of its 50 % interest in Mitchell Plant, which will be addressed in the future. | 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. The filing proposes no changes in depreciation rates and an annual level of storm restoration expense in base rates of approximately $ 1 million. KPCo also proposed to discontinue tracking of PJM transmission costs through a rider, and to instead collect an annual level of costs through base rates. In addition, KPCo has proposed a rider to recover certain distribution reliability investments and related incremental operation and maintenance expenses. KPCo also requested a prudency determination and recovery mechanism for approximately $ 16 million of purchased power costs not recoverable through its FAC since its last base case. KPCo’s proposal did not address the disposition of its 50 % interest in Mitchell Plant, which will be addressed in the future. </context> | us-gaap:PublicUtilitiesRequestedReturnOnEquityPercentage |
As of December 31, 2023, the net book value of KPCo’s share of the Mitchell Plant, before cost of removal including CWIP and inventory, was $ 553 million. | text | 553 | monetaryItemType | text: <entity> 553 </entity> <entity type> monetaryItemType </entity type> <context> As of December 31, 2023, the net book value of KPCo’s share of the Mitchell Plant, before cost of removal including CWIP and inventory, was $ 553 million. </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. The KPSC denied implementation of a rider to recover certain distribution reliability investments. 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. | 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. The KPSC denied implementation of a rider to recover certain distribution reliability investments. 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. </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. An order from the PUCO is expected in the first quarter of 2024. If OPCo is ultimately not permitted to fully collect its ESP rates it could reduce future net income and cash flows and impact financial condition. | 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. An order from the PUCO is expected in the first quarter of 2024. If OPCo is ultimately not permitted to fully collect its ESP rates it could reduce future net income and cash flows and impact financial condition. </context> | us-gaap:PublicUtilitiesApprovedReturnOnEquityPercentage |
In November 2023, the OCC issued a final order approving an annual base rate increase of $ 131 million based upon a 9.3 % ROE. As a result of the final order, PSO is required to exclude Rock Falls Wind Facility from recovery through base rates until a future base case since the facility was placed into service for PSO customers after the conclusion of the customary six-month post-test year period for ratemaking adjustments. In addition, PSO must provide Rock Falls Wind Facility benefits in excess of $ 21 million on an annual basis to customers through a rider. | text | 9.3 | percentItemType | text: <entity> 9.3 </entity> <entity type> percentItemType </entity type> <context> In November 2023, the OCC issued a final order approving an annual base rate increase of $ 131 million based upon a 9.3 % ROE. As a result of the final order, PSO is required to exclude Rock Falls Wind Facility from recovery through base rates until a future base case since the facility was placed into service for PSO customers after the conclusion of the customary six-month post-test year period for ratemaking adjustments. In addition, PSO must provide Rock Falls Wind Facility benefits in excess of $ 21 million on an annual basis to customers through a rider. </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 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 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 ROE of 9.6 %, 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 ROE of 9.6 %, 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 | 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 </context> | us-gaap:PublicUtilitiesApprovedReturnOnEquityPercentage |
In December 2020, SWEPCo filed a request with the LPSC for a $ 134 million annual increase in Louisiana base rates based upon a proposed 10.35 % ROE. SWEPCo’s requested annual increase includes accelerated depreciation related to the Dolet Hills Power Station, Pirkey Power Plant and Welsh Plant, all of which were or are expected to be retired early. SWEPCo also included recovery of Welsh Plant, Unit 2 over the blended useful life of Welsh Plant, Units 1 and 3. SWEPCo subsequently revised the requested annual increase to $ 95 million to reflect removing hurricane storm restoration costs from the base case filing, to modify the proposed recovery of the Dolet Hills Power Station and revisions to various proposed amortizations. The hurricane costs have been requested in a separate storm filing. See “2021 Louisiana Storm Cost Filing” below for more information. | text | 10.35 | percentItemType | text: <entity> 10.35 </entity> <entity type> percentItemType </entity type> <context> In December 2020, SWEPCo filed a request with the LPSC for a $ 134 million annual increase in Louisiana base rates based upon a proposed 10.35 % ROE. SWEPCo’s requested annual increase includes accelerated depreciation related to the Dolet Hills Power Station, Pirkey Power Plant and Welsh Plant, all of which were or are expected to be retired early. SWEPCo also included recovery of Welsh Plant, Unit 2 over the blended useful life of Welsh Plant, Units 1 and 3. SWEPCo subsequently revised the requested annual increase to $ 95 million to reflect removing hurricane storm restoration costs from the base case filing, to modify the proposed recovery of the Dolet Hills Power Station and revisions to various proposed amortizations. The hurricane costs have been requested in a separate storm filing. See “2021 Louisiana Storm Cost Filing” below for more information. </context> | us-gaap:PublicUtilitiesRequestedReturnOnEquityPercentage |
In January 2023, the LPSC approved a settlement which provides for an annual revenue increase of $ 27 million based upon a 9.5 % ROE and includes: (a) a $ 21 million increase in base rates effective February 2023, (b) a $ 14 million rider to recover costs of the Dolet Hills Power Station and Pirkey Plant including a return, (c) an $ 8 million reduction in fuel rates, (d) adoption of a 3-year formula rate term subject to an earnings band and (e) the recovery of certain incremental SPP charges net of associated revenue and the Louisiana jurisdictional share of the return on and of projected transmission capital investment outside of the earnings band. The settlement agreement did not rule on the prudency of the early retirement of the Dolet Hills Power Station, which is being addressed in a separate proceeding. | text | 9.5 | percentItemType | text: <entity> 9.5 </entity> <entity type> percentItemType </entity type> <context> In January 2023, the LPSC approved a settlement which provides for an annual revenue increase of $ 27 million based upon a 9.5 % ROE and includes: (a) a $ 21 million increase in base rates effective February 2023, (b) a $ 14 million rider to recover costs of the Dolet Hills Power Station and Pirkey Plant including a return, (c) an $ 8 million reduction in fuel rates, (d) adoption of a 3-year formula rate term subject to an earnings band and (e) the recovery of certain incremental SPP charges net of associated revenue and the Louisiana jurisdictional share of the return on and of projected transmission capital investment outside of the earnings band. The settlement agreement did not rule on the prudency of the early retirement of the Dolet Hills Power Station, which is being addressed in a separate proceeding. </context> | us-gaap:PublicUtilitiesApprovedReturnOnEquityPercentage |
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. 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. See “2020 Texas Base Rate Case” and “2020 Louisiana Base Rate Case” sections of Note 4 for additional information. | 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. 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. See “2020 Texas Base Rate Case” and “2020 Louisiana Base Rate Case” sections of Note 4 for additional information. </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. 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. See “2020 Texas Base Rate Case” and “2020 Louisiana Base Rate Case” sections of Note 4 for additional information. | 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. 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. See “2020 Texas Base Rate Case” and “2020 Louisiana Base Rate Case” sections of Note 4 for additional information. </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 proposal for decision that concluded the decision to retire the Pirkey Plant was prudent. In September 2023, the PUCT rejected the ALJs proposal for decision concluding the retirement of the Pirkey Plant was prudent. 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, 2023, the Texas jurisdictional share of the net book value of the Pirkey Plant was $ 67 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 | 67 | monetaryItemType | text: <entity> 67 </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 proposal for decision that concluded the decision to retire the Pirkey Plant was prudent. In September 2023, the PUCT rejected the ALJs proposal for decision concluding the retirement of the Pirkey Plant was prudent. 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, 2023, the Texas jurisdictional share of the net book value of the Pirkey Plant was $ 67 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:PropertyPlantAndEquipmentNet |
Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 228 million and $ 277 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 5 years. | text | 228 | monetaryItemType | text: <entity> 228 </entity> <entity type> monetaryItemType </entity type> <context> Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 228 million and $ 277 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 5 years. </context> | us-gaap:RegulatoryLiabilityNoncurrent |
Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 228 million and $ 277 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 5 years. | text | 277 | monetaryItemType | text: <entity> 277 </entity> <entity type> monetaryItemType </entity type> <context> Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 228 million and $ 277 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 5 years. </context> | us-gaap:RegulatoryLiabilityNoncurrent |
Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 13 million and $ 16 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 5 years. | text | 13 | monetaryItemType | text: <entity> 13 </entity> <entity type> monetaryItemType </entity type> <context> Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 13 million and $ 16 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 5 years. </context> | us-gaap:RegulatoryLiabilityNoncurrent |
Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 13 million and $ 16 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 5 years. | text | 16 | monetaryItemType | text: <entity> 16 </entity> <entity type> monetaryItemType </entity type> <context> Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 13 million and $ 16 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 5 years. </context> | us-gaap:RegulatoryLiabilityNoncurrent |
Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 35 million and $ 19 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 5 years. | text | 35 | monetaryItemType | text: <entity> 35 </entity> <entity type> monetaryItemType </entity type> <context> Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 35 million and $ 19 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 5 years. </context> | us-gaap:RegulatoryLiabilityNoncurrent |
Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 35 million and $ 19 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 5 years. | text | 19 | monetaryItemType | text: <entity> 19 </entity> <entity type> monetaryItemType </entity type> <context> Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 35 million and $ 19 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 5 years. </context> | us-gaap:RegulatoryLiabilityNoncurrent |
Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 25 million and $ 42 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 5 years. | text | 25 | monetaryItemType | text: <entity> 25 </entity> <entity type> monetaryItemType </entity type> <context> Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 25 million and $ 42 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 5 years. </context> | us-gaap:RegulatoryLiabilityNoncurrent |
Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 25 million and $ 42 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 5 years. | text | 42 | monetaryItemType | text: <entity> 42 </entity> <entity type> monetaryItemType </entity type> <context> Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 25 million and $ 42 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 5 years. </context> | us-gaap:RegulatoryLiabilityNoncurrent |
Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 132 million and $ 162 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 5 years. | text | 132 | monetaryItemType | text: <entity> 132 </entity> <entity type> monetaryItemType </entity type> <context> Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 132 million and $ 162 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 5 years. </context> | us-gaap:RegulatoryLiabilityNoncurrent |
Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 132 million and $ 162 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 5 years. | text | 162 | monetaryItemType | text: <entity> 162 </entity> <entity type> monetaryItemType </entity type> <context> Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 132 million and $ 162 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 5 years. </context> | us-gaap:RegulatoryLiabilityNoncurrent |
Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 51 million and $ 21 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 1 year. | text | 51 | monetaryItemType | text: <entity> 51 </entity> <entity type> monetaryItemType </entity type> <context> Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 51 million and $ 21 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 1 year. </context> | us-gaap:RegulatoryLiabilityNoncurrent |
Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 51 million and $ 21 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 1 year. | text | 21 | monetaryItemType | text: <entity> 21 </entity> <entity type> monetaryItemType </entity type> <context> Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $ 51 million and $ 21 million for the years ended December 31, 2023 and 2022, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2023 is to be refunded over 1 year. </context> | us-gaap:RegulatoryLiabilityNoncurrent |
AEP has $ 4 billion and $ 1 billion revolving credit facilities due in March 2027 and 2025, respectively, under which up to $ 1.2 billion may be issued as letters of credit on behalf of subsidiaries. As of December 31, 2023, 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> AEP has $ 4 billion and $ 1 billion revolving credit facilities due in March 2027 and 2025, respectively, under which up to $ 1.2 billion may be issued as letters of credit on behalf of subsidiaries. As of December 31, 2023, no letters of credit were issued under the revolving credit facility. </context> | us-gaap:LineOfCreditFacilityMaximumBorrowingCapacity |
In March 2021, AEP acquired a 75 % ownership interest in the Dry Lake Solar Project located in southern Nevada for approximately $ 114 million and the project was placed in-service in May 2021. In August 2023, Dry Lake was included in the sale of the competitive contracted renewables portfolio. See the “Disposition of the Competitive Contracted Renewables Portfolio” section below and Note 17 - Variable Interest Entities and Equity Method Investments for additional information. | text | 114 | monetaryItemType | text: <entity> 114 </entity> <entity type> monetaryItemType </entity type> <context> In March 2021, AEP acquired a 75 % ownership interest in the Dry Lake Solar Project located in southern Nevada for approximately $ 114 million and the project was placed in-service in May 2021. In August 2023, Dry Lake was included in the sale of the competitive contracted renewables portfolio. See the “Disposition of the Competitive Contracted Renewables Portfolio” section below and Note 17 - Variable Interest Entities and Equity Method Investments for additional information. </context> | us-gaap:PaymentsToAcquirePropertyPlantAndEquipment |
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 April 2021, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Sundance during its development and construction for $ 270 million. Sundance was placed in-service in April 2021. In September 2021, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Maverick during its development and construction for $ 383 million. Maverick was placed in-service in September 2021. In March 2022, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Traverse during its development and construction for $ 1.2 billion. Traverse was placed in-service in March 2022. Immediately following the acquisitions, PSO and SWEPCo liquidated the entities 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 | 270 | monetaryItemType | text: <entity> 270 </entity> <entity type> monetaryItemType </entity type> <context> In April 2021, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Sundance during its development and construction for $ 270 million. Sundance was placed in-service in April 2021. In September 2021, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Maverick during its development and construction for $ 383 million. Maverick was placed in-service in September 2021. In March 2022, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Traverse during its development and construction for $ 1.2 billion. Traverse was placed in-service in March 2022. Immediately following the acquisitions, PSO and SWEPCo liquidated the entities 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 April 2021, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Sundance during its development and construction for $ 270 million. Sundance was placed in-service in April 2021. In September 2021, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Maverick during its development and construction for $ 383 million. Maverick was placed in-service in September 2021. In March 2022, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Traverse during its development and construction for $ 1.2 billion. Traverse was placed in-service in March 2022. Immediately following the acquisitions, PSO and SWEPCo liquidated the entities 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 | 383 | monetaryItemType | text: <entity> 383 </entity> <entity type> monetaryItemType </entity type> <context> In April 2021, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Sundance during its development and construction for $ 270 million. Sundance was placed in-service in April 2021. In September 2021, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Maverick during its development and construction for $ 383 million. Maverick was placed in-service in September 2021. In March 2022, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Traverse during its development and construction for $ 1.2 billion. Traverse was placed in-service in March 2022. Immediately following the acquisitions, PSO and SWEPCo liquidated the entities 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 April 2021, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Sundance during its development and construction for $ 270 million. Sundance was placed in-service in April 2021. In September 2021, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Maverick during its development and construction for $ 383 million. Maverick was placed in-service in September 2021. In March 2022, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Traverse during its development and construction for $ 1.2 billion. Traverse was placed in-service in March 2022. Immediately following the acquisitions, PSO and SWEPCo liquidated the entities 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 April 2021, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Sundance during its development and construction for $ 270 million. Sundance was placed in-service in April 2021. In September 2021, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Maverick during its development and construction for $ 383 million. Maverick was placed in-service in September 2021. In March 2022, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Traverse during its development and construction for $ 1.2 billion. Traverse was placed in-service in March 2022. Immediately following the acquisitions, PSO and SWEPCo liquidated the entities 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. See the “2022 Oklahoma Base Rate Case” section of Note 4 for additional information. | 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. See the “2022 Oklahoma Base Rate Case” section of Note 4 for additional information. </context> | us-gaap:PaymentsToAcquirePropertyPlantAndEquipment |
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. | 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. </context> | us-gaap:OtherAssetImpairmentCharges |
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 | 28 | monetaryItemType | text: <entity> 28 </entity> <entity type> monetaryItemType </entity type> <context> 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:BusinessAcquisitionCostOfAcquiredEntityTransactionCosts |
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> 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 |
In August 2023, AEP completed the sale of the entire portfolio to the nonaffiliated party and received cash proceeds of approximately $ 1.2 billion, net of taxes and transaction costs. AEP recorded a pretax loss of $ 93 million ($ 73 million after-tax) for the year ended December 31, 2023 related to the sale. | text | 1.2 | monetaryItemType | text: <entity> 1.2 </entity> <entity type> monetaryItemType </entity type> <context> In August 2023, AEP completed the sale of the entire portfolio to the nonaffiliated party and received cash proceeds of approximately $ 1.2 billion, net of taxes and transaction costs. AEP recorded a pretax loss of $ 93 million ($ 73 million after-tax) for the year ended December 31, 2023 related to the sale. </context> | us-gaap:ProceedsFromSaleOfProductiveAssets |
In August 2023, AEP completed the sale of the entire portfolio to the nonaffiliated party and received cash proceeds of approximately $ 1.2 billion, net of taxes and transaction costs. AEP recorded a pretax loss of $ 93 million ($ 73 million after-tax) for the year ended December 31, 2023 related to the sale. | text | 93 | monetaryItemType | text: <entity> 93 </entity> <entity type> monetaryItemType </entity type> <context> In August 2023, AEP completed the sale of the entire portfolio to the nonaffiliated party and received cash proceeds of approximately $ 1.2 billion, net of taxes and transaction costs. AEP recorded a pretax loss of $ 93 million ($ 73 million after-tax) for the year ended December 31, 2023 related to the sale. </context> | us-gaap:GainLossOnSaleOfBusiness |
In June 2022, AEP closed on the sale of certain mineral rights to a nonaffiliated third-party and received $ 120 million of proceeds. The sale resulted in a pretax gain of $ 116 million in the second quarter of 2022. | text | 120 | monetaryItemType | text: <entity> 120 </entity> <entity type> monetaryItemType </entity type> <context> In June 2022, AEP closed on the sale of certain mineral rights to a nonaffiliated third-party and received $ 120 million of proceeds. The sale resulted in a pretax gain of $ 116 million in the second quarter of 2022. </context> | us-gaap:ProceedsFromSaleOfPropertyPlantAndEquipment |
In June 2022, AEP closed on the sale of certain mineral rights to a nonaffiliated third-party and received $ 120 million of proceeds. The sale resulted in a pretax gain of $ 116 million in the second quarter of 2022. | text | 116 | monetaryItemType | text: <entity> 116 </entity> <entity type> monetaryItemType </entity type> <context> In June 2022, AEP closed on the sale of certain mineral rights to a nonaffiliated third-party and received $ 120 million of proceeds. The sale resulted in a pretax gain of $ 116 million in the second quarter of 2022. </context> | us-gaap:GainLossOnSaleOfOtherAssets |
In December 2023, SWEPCo recorded a pretax, non-cash disallowance of $ 86 million in Asset Impairments and Other Related Charges on the statements of income due to regulatory disallowance of recovery of AFUDC on Turk Plant in the 2012 Texas Base Rate case. See the “2012 Texas Base Rate Case” section of Note 4 for additional information. | text | 86 | monetaryItemType | text: <entity> 86 </entity> <entity type> monetaryItemType </entity type> <context> In December 2023, SWEPCo recorded a pretax, non-cash disallowance of $ 86 million in Asset Impairments and Other Related Charges on the statements of income due to regulatory disallowance of recovery of AFUDC on Turk Plant in the 2012 Texas Base Rate case. See the “2012 Texas Base Rate Case” section of Note 4 for additional information. </context> | us-gaap:OtherAssetImpairmentCharges |
In December 2023, as a result of sale negotiations AEP determined a decline in the fair value of AEP’s investment in New Mexico Renewable Development (NMRD) was other than temporary. In accordance with the accounting guidance for “Investment - Equity Method and Joint Ventures”, in the fourth quarter of 2023 AEP recorded a pretax other than temporary impairment charge of $ 19 million which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s Statement of Income. AEP’s determination of fair value utilized the accounting guidance for Fair Value Measurement market approach to valuation and was based on negotiations to sell the investment to a non-affiliate. The carrying value of the investment in NMRD was not material to AEP as of December 31, 2023. | text | 19 | monetaryItemType | text: <entity> 19 </entity> <entity type> monetaryItemType </entity type> <context> In December 2023, as a result of sale negotiations AEP determined a decline in the fair value of AEP’s investment in New Mexico Renewable Development (NMRD) was other than temporary. In accordance with the accounting guidance for “Investment - Equity Method and Joint Ventures”, in the fourth quarter of 2023 AEP recorded a pretax other than temporary impairment charge of $ 19 million which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s Statement of Income. AEP’s determination of fair value utilized the accounting guidance for Fair Value Measurement market approach to valuation and was based on negotiations to sell the investment to a non-affiliate. The carrying value of the investment in NMRD was not material to AEP as of December 31, 2023. </context> | us-gaap:EquityMethodInvestmentOtherThanTemporaryImpairment |
In 2019, AEP acquired a 50 % ownership interest in five non-consolidated joint ventures, including Flat Ridge 2 Wind LLC (Flat Ridge 2), and two tax equity partnerships. The five non-consolidated joint ventures are jointly owned and operated by BP Wind Energy. Flat Ridge 2 sells electricity to three counterparties through long-term PPAs. | text | 50 | percentItemType | text: <entity> 50 </entity> <entity type> percentItemType </entity type> <context> In 2019, AEP acquired a 50 % ownership interest in five non-consolidated joint ventures, including Flat Ridge 2 Wind LLC (Flat Ridge 2), and two tax equity partnerships. The five non-consolidated joint ventures are jointly owned and operated by BP Wind Energy. Flat Ridge 2 sells electricity to three counterparties through long-term PPAs. </context> | us-gaap:EquityMethodInvestmentOwnershipPercentage |
Regarding AEP’s investment in Flat Ridge 2, in June 2022, as a result of Flat Ridge 2’s deteriorating financial performance, sale negotiations and AEP’s ongoing evaluation and ultimate decision to exit the investment in the near term, AEP determined a decline in the fair value of AEP’s investment in Flat Ridge 2 was other than temporary. In accordance with the accounting guidance for “Investments - Equity Method and Joint Ventures”, in the second quarter of 2022 AEP recorded a pretax other than temporary impairment charge of $ 186 million which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s Statement of Income. AEP’s determination of fair value utilized the accounting guidance for Fair Value Measurement market approach to valuation and was based on negotiations to sell the investment to a non-affiliate. In the third quarter of 2022, AEP recorded an additional $ 2 million pretax other than temporary impairment charge which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s Statement of Income. In September 2022, AEP signed a Purchase and Sale Agreement with a nonaffiliate for AEP’s interest in Flat Ridge 2. The transaction closed in the fourth quarter of 2022 and had an immaterial impact on the financial statements at closing. | text | 186 | monetaryItemType | text: <entity> 186 </entity> <entity type> monetaryItemType </entity type> <context> Regarding AEP’s investment in Flat Ridge 2, in June 2022, as a result of Flat Ridge 2’s deteriorating financial performance, sale negotiations and AEP’s ongoing evaluation and ultimate decision to exit the investment in the near term, AEP determined a decline in the fair value of AEP’s investment in Flat Ridge 2 was other than temporary. In accordance with the accounting guidance for “Investments - Equity Method and Joint Ventures”, in the second quarter of 2022 AEP recorded a pretax other than temporary impairment charge of $ 186 million which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s Statement of Income. AEP’s determination of fair value utilized the accounting guidance for Fair Value Measurement market approach to valuation and was based on negotiations to sell the investment to a non-affiliate. In the third quarter of 2022, AEP recorded an additional $ 2 million pretax other than temporary impairment charge which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s Statement of Income. In September 2022, AEP signed a Purchase and Sale Agreement with a nonaffiliate for AEP’s interest in Flat Ridge 2. The transaction closed in the fourth quarter of 2022 and had an immaterial impact on the financial statements at closing. </context> | us-gaap:EquityMethodInvestmentOtherThanTemporaryImpairment |
Regarding AEP’s investment in Flat Ridge 2, in June 2022, as a result of Flat Ridge 2’s deteriorating financial performance, sale negotiations and AEP’s ongoing evaluation and ultimate decision to exit the investment in the near term, AEP determined a decline in the fair value of AEP’s investment in Flat Ridge 2 was other than temporary. In accordance with the accounting guidance for “Investments - Equity Method and Joint Ventures”, in the second quarter of 2022 AEP recorded a pretax other than temporary impairment charge of $ 186 million which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s Statement of Income. AEP’s determination of fair value utilized the accounting guidance for Fair Value Measurement market approach to valuation and was based on negotiations to sell the investment to a non-affiliate. In the third quarter of 2022, AEP recorded an additional $ 2 million pretax other than temporary impairment charge which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s Statement of Income. In September 2022, AEP signed a Purchase and Sale Agreement with a nonaffiliate for AEP’s interest in Flat Ridge 2. The transaction closed in the fourth quarter of 2022 and had an immaterial impact on the financial statements at closing. | text | 2 | monetaryItemType | text: <entity> 2 </entity> <entity type> monetaryItemType </entity type> <context> Regarding AEP’s investment in Flat Ridge 2, in June 2022, as a result of Flat Ridge 2’s deteriorating financial performance, sale negotiations and AEP’s ongoing evaluation and ultimate decision to exit the investment in the near term, AEP determined a decline in the fair value of AEP’s investment in Flat Ridge 2 was other than temporary. In accordance with the accounting guidance for “Investments - Equity Method and Joint Ventures”, in the second quarter of 2022 AEP recorded a pretax other than temporary impairment charge of $ 186 million which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s Statement of Income. AEP’s determination of fair value utilized the accounting guidance for Fair Value Measurement market approach to valuation and was based on negotiations to sell the investment to a non-affiliate. In the third quarter of 2022, AEP recorded an additional $ 2 million pretax other than temporary impairment charge which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s Statement of Income. In September 2022, AEP signed a Purchase and Sale Agreement with a nonaffiliate for AEP’s interest in Flat Ridge 2. The transaction closed in the fourth quarter of 2022 and had an immaterial impact on the financial statements at closing. </context> | us-gaap:EquityMethodInvestmentOtherThanTemporaryImpairment |
In January 2022, the PUCT issued a final order which included a return of investment only for the recovery of the Dolet Hills Power Station. As a result of the final order, SWEPCo recorded a disallowance of $ 12 million associated with the lack of return on the Dolet Hills Power Station. In February 2022, SWEPCo filed a motion for rehearing with the PUCT challenging denial of a reasonable return or carrying costs on the Dolet Hills Power Station among other items. In April 2022, the PUCT denied the motion for rehearing. In May 2022, SWEPCo filed a petition for review with the Texas District Court seeking a judicial review of the several errors challenged in the PUCT’s final order. See “2020 Texas Base Rate Case” section of Note 4 for additional information. | text | 12 | monetaryItemType | text: <entity> 12 </entity> <entity type> monetaryItemType </entity type> <context> In January 2022, the PUCT issued a final order which included a return of investment only for the recovery of the Dolet Hills Power Station. As a result of the final order, SWEPCo recorded a disallowance of $ 12 million associated with the lack of return on the Dolet Hills Power Station. In February 2022, SWEPCo filed a motion for rehearing with the PUCT challenging denial of a reasonable return or carrying costs on the Dolet Hills Power Station among other items. In April 2022, the PUCT denied the motion for rehearing. In May 2022, SWEPCo filed a petition for review with the Texas District Court seeking a judicial review of the several errors challenged in the PUCT’s final order. See “2020 Texas Base Rate Case” section of Note 4 for additional information. </context> | us-gaap:OtherAssetImpairmentCharges |
No contributions were made to the qualified pension plan for the years ended December 31, 2023 and 2022, respectively. Contributions to the non-qualified pension plans were $ 8 million and $ 8 million for the years ended December 31, 2023 and 2022, respectively. | text | 8 | monetaryItemType | text: <entity> 8 </entity> <entity type> monetaryItemType </entity type> <context> No contributions were made to the qualified pension plan for the years ended December 31, 2023 and 2022, respectively. Contributions to the non-qualified pension plans were $ 8 million and $ 8 million for the years ended December 31, 2023 and 2022, respectively. </context> | us-gaap:DefinedBenefitPlanContributionsByEmployer |
AEP affiliates contributed $ 396 thousand, $ 329 thousand and $ 339 thousand to the United Mine Workers of America 1974 Pension Plan for the years ended December 31, 2023, 2022 and 2021, respectively. The contributions did not include surcharges. An AEP affiliate, Cook Coal Terminal (CCT), was listed in the plan’s 2021 Form 5500 as providing more than 5 percent of the total contributions for the plan year ending June 30, 2022. The plan’s 2022 Form 5500 is expected to be filed in the second quarter of 2024. | text | 396 | monetaryItemType | text: <entity> 396 </entity> <entity type> monetaryItemType </entity type> <context> AEP affiliates contributed $ 396 thousand, $ 329 thousand and $ 339 thousand to the United Mine Workers of America 1974 Pension Plan for the years ended December 31, 2023, 2022 and 2021, respectively. The contributions did not include surcharges. An AEP affiliate, Cook Coal Terminal (CCT), was listed in the plan’s 2021 Form 5500 as providing more than 5 percent of the total contributions for the plan year ending June 30, 2022. The plan’s 2022 Form 5500 is expected to be filed in the second quarter of 2024. </context> | us-gaap:MultiemployerPlanEmployerContributionCost |
AEP affiliates contributed $ 396 thousand, $ 329 thousand and $ 339 thousand to the United Mine Workers of America 1974 Pension Plan for the years ended December 31, 2023, 2022 and 2021, respectively. The contributions did not include surcharges. An AEP affiliate, Cook Coal Terminal (CCT), was listed in the plan’s 2021 Form 5500 as providing more than 5 percent of the total contributions for the plan year ending June 30, 2022. The plan’s 2022 Form 5500 is expected to be filed in the second quarter of 2024. | text | 329 | monetaryItemType | text: <entity> 329 </entity> <entity type> monetaryItemType </entity type> <context> AEP affiliates contributed $ 396 thousand, $ 329 thousand and $ 339 thousand to the United Mine Workers of America 1974 Pension Plan for the years ended December 31, 2023, 2022 and 2021, respectively. The contributions did not include surcharges. An AEP affiliate, Cook Coal Terminal (CCT), was listed in the plan’s 2021 Form 5500 as providing more than 5 percent of the total contributions for the plan year ending June 30, 2022. The plan’s 2022 Form 5500 is expected to be filed in the second quarter of 2024. </context> | us-gaap:MultiemployerPlanEmployerContributionCost |
AEP affiliates contributed $ 396 thousand, $ 329 thousand and $ 339 thousand to the United Mine Workers of America 1974 Pension Plan for the years ended December 31, 2023, 2022 and 2021, respectively. The contributions did not include surcharges. An AEP affiliate, Cook Coal Terminal (CCT), was listed in the plan’s 2021 Form 5500 as providing more than 5 percent of the total contributions for the plan year ending June 30, 2022. The plan’s 2022 Form 5500 is expected to be filed in the second quarter of 2024. | text | 339 | monetaryItemType | text: <entity> 339 </entity> <entity type> monetaryItemType </entity type> <context> AEP affiliates contributed $ 396 thousand, $ 329 thousand and $ 339 thousand to the United Mine Workers of America 1974 Pension Plan for the years ended December 31, 2023, 2022 and 2021, respectively. The contributions did not include surcharges. An AEP affiliate, Cook Coal Terminal (CCT), was listed in the plan’s 2021 Form 5500 as providing more than 5 percent of the total contributions for the plan year ending June 30, 2022. The plan’s 2022 Form 5500 is expected to be filed in the second quarter of 2024. </context> | us-gaap:MultiemployerPlanEmployerContributionCost |
According to the accounting guidance for “Derivatives and Hedging,” the Registrants reflect the fair values of derivative instruments subject to netting agreements with the same counterparty net of related cash collateral. For certain risk management contracts, the Registrants are required to post or receive cash collateral based on third-party contractual agreements and risk profiles. AEP netted cash collateral received from third-parties against short-term and long-term risk management assets in the amounts of $ 46 million and $ 481 million as of December 31, 2023 and 2022, respectively. There was no cash collateral received from third-parties netted against short-term and long-term risk management assets for the Registrant Subsidiaries as of December 31, 2023 and 2022. The amount of cash collateral paid to third-parties netted against short-term and long-term risk management liabilities was not material for the Registrants as of December 31, 2023 and 2022. | text | 46 | monetaryItemType | text: <entity> 46 </entity> <entity type> monetaryItemType </entity type> <context> According to the accounting guidance for “Derivatives and Hedging,” the Registrants reflect the fair values of derivative instruments subject to netting agreements with the same counterparty net of related cash collateral. For certain risk management contracts, the Registrants are required to post or receive cash collateral based on third-party contractual agreements and risk profiles. AEP netted cash collateral received from third-parties against short-term and long-term risk management assets in the amounts of $ 46 million and $ 481 million as of December 31, 2023 and 2022, respectively. There was no cash collateral received from third-parties netted against short-term and long-term risk management assets for the Registrant Subsidiaries as of December 31, 2023 and 2022. The amount of cash collateral paid to third-parties netted against short-term and long-term risk management liabilities was not material for the Registrants as of December 31, 2023 and 2022. </context> | us-gaap:SecuritiesReceivedAsCollateral |
According to the accounting guidance for “Derivatives and Hedging,” the Registrants reflect the fair values of derivative instruments subject to netting agreements with the same counterparty net of related cash collateral. For certain risk management contracts, the Registrants are required to post or receive cash collateral based on third-party contractual agreements and risk profiles. AEP netted cash collateral received from third-parties against short-term and long-term risk management assets in the amounts of $ 46 million and $ 481 million as of December 31, 2023 and 2022, respectively. There was no cash collateral received from third-parties netted against short-term and long-term risk management assets for the Registrant Subsidiaries as of December 31, 2023 and 2022. The amount of cash collateral paid to third-parties netted against short-term and long-term risk management liabilities was not material for the Registrants as of December 31, 2023 and 2022. | text | 481 | monetaryItemType | text: <entity> 481 </entity> <entity type> monetaryItemType </entity type> <context> According to the accounting guidance for “Derivatives and Hedging,” the Registrants reflect the fair values of derivative instruments subject to netting agreements with the same counterparty net of related cash collateral. For certain risk management contracts, the Registrants are required to post or receive cash collateral based on third-party contractual agreements and risk profiles. AEP netted cash collateral received from third-parties against short-term and long-term risk management assets in the amounts of $ 46 million and $ 481 million as of December 31, 2023 and 2022, respectively. There was no cash collateral received from third-parties netted against short-term and long-term risk management assets for the Registrant Subsidiaries as of December 31, 2023 and 2022. The amount of cash collateral paid to third-parties netted against short-term and long-term risk management liabilities was not material for the Registrants as of December 31, 2023 and 2022. </context> | us-gaap:SecuritiesReceivedAsCollateral |
Amounts include $( 30 ) million and $( 38 ) million as of December 31, 2023 and 2022, respectively, for the fair value hedge adjustment of hedged debt obligations for which hedge accounting has been discontinued. | text | 30 | monetaryItemType | text: <entity> 30 </entity> <entity type> monetaryItemType </entity type> <context> Amounts include $( 30 ) million and $( 38 ) million as of December 31, 2023 and 2022, respectively, for the fair value hedge adjustment of hedged debt obligations for which hedge accounting has been discontinued. </context> | us-gaap:HedgedLiabilityDiscontinuedFairValueHedgeCumulativeIncreaseDecrease |
Amounts include $( 30 ) million and $( 38 ) million as of December 31, 2023 and 2022, respectively, for the fair value hedge adjustment of hedged debt obligations for which hedge accounting has been discontinued. | text | 38 | monetaryItemType | text: <entity> 38 </entity> <entity type> monetaryItemType </entity type> <context> Amounts include $( 30 ) million and $( 38 ) million as of December 31, 2023 and 2022, respectively, for the fair value hedge adjustment of hedged debt obligations for which hedge accounting has been discontinued. </context> | us-gaap:HedgedLiabilityDiscontinuedFairValueHedgeCumulativeIncreaseDecrease |
The amount and activity of unrecognized tax benefits was not material for the Registrants for the years ended December 31, 2023, 2022 and 2021. Management believes that there will be no significant net increase or decrease in unrecognized benefits within 12 months of the reporting date. The total amount of unrecognized tax benefits that, if recognized, would affect the effective tax rate for AEP as of December 31, 2023, 2022 and 2021 were $ 13 million, $ 23 million, and $ 14 million, respectively. | text | 13 | monetaryItemType | text: <entity> 13 </entity> <entity type> monetaryItemType </entity type> <context> The amount and activity of unrecognized tax benefits was not material for the Registrants for the years ended December 31, 2023, 2022 and 2021. Management believes that there will be no significant net increase or decrease in unrecognized benefits within 12 months of the reporting date. The total amount of unrecognized tax benefits that, if recognized, would affect the effective tax rate for AEP as of December 31, 2023, 2022 and 2021 were $ 13 million, $ 23 million, and $ 14 million, respectively. </context> | us-gaap:UnrecognizedTaxBenefitsThatWouldImpactEffectiveTaxRate |
The amount and activity of unrecognized tax benefits was not material for the Registrants for the years ended December 31, 2023, 2022 and 2021. Management believes that there will be no significant net increase or decrease in unrecognized benefits within 12 months of the reporting date. The total amount of unrecognized tax benefits that, if recognized, would affect the effective tax rate for AEP as of December 31, 2023, 2022 and 2021 were $ 13 million, $ 23 million, and $ 14 million, respectively. | text | 23 | monetaryItemType | text: <entity> 23 </entity> <entity type> monetaryItemType </entity type> <context> The amount and activity of unrecognized tax benefits was not material for the Registrants for the years ended December 31, 2023, 2022 and 2021. Management believes that there will be no significant net increase or decrease in unrecognized benefits within 12 months of the reporting date. The total amount of unrecognized tax benefits that, if recognized, would affect the effective tax rate for AEP as of December 31, 2023, 2022 and 2021 were $ 13 million, $ 23 million, and $ 14 million, respectively. </context> | us-gaap:UnrecognizedTaxBenefitsThatWouldImpactEffectiveTaxRate |
The amount and activity of unrecognized tax benefits was not material for the Registrants for the years ended December 31, 2023, 2022 and 2021. Management believes that there will be no significant net increase or decrease in unrecognized benefits within 12 months of the reporting date. The total amount of unrecognized tax benefits that, if recognized, would affect the effective tax rate for AEP as of December 31, 2023, 2022 and 2021 were $ 13 million, $ 23 million, and $ 14 million, respectively. | text | 14 | monetaryItemType | text: <entity> 14 </entity> <entity type> monetaryItemType </entity type> <context> The amount and activity of unrecognized tax benefits was not material for the Registrants for the years ended December 31, 2023, 2022 and 2021. Management believes that there will be no significant net increase or decrease in unrecognized benefits within 12 months of the reporting date. The total amount of unrecognized tax benefits that, if recognized, would affect the effective tax rate for AEP as of December 31, 2023, 2022 and 2021 were $ 13 million, $ 23 million, and $ 14 million, respectively. </context> | us-gaap:UnrecognizedTaxBenefitsThatWouldImpactEffectiveTaxRate |
In January and February 2024, I&M retired $ 8 million and $ 8 million, respectively, of Notes Payable related to DCC Fuel. | text | 8 | monetaryItemType | text: <entity> 8 </entity> <entity type> monetaryItemType </entity type> <context> In January and February 2024, I&M retired $ 8 million and $ 8 million, respectively, of Notes Payable related to DCC Fuel. </context> | us-gaap:RepaymentsOfLongTermDebt |
In January and February 2024, Transource Energy issued $ 16 million and $ 2 million, respectively, of variable rate Other Long-term Debt due in 2025. | text | 16 | monetaryItemType | text: <entity> 16 </entity> <entity type> monetaryItemType </entity type> <context> In January and February 2024, Transource Energy issued $ 16 million and $ 2 million, respectively, of variable rate Other Long-term Debt due in 2025. </context> | us-gaap:ProceedsFromIssuanceOfLongTermDebt |
In January and February 2024, Transource Energy issued $ 16 million and $ 2 million, respectively, of variable rate Other Long-term Debt due in 2025. | text | 2 | monetaryItemType | text: <entity> 2 </entity> <entity type> monetaryItemType </entity type> <context> In January and February 2024, Transource Energy issued $ 16 million and $ 2 million, respectively, of variable rate Other Long-term Debt due in 2025. </context> | us-gaap:ProceedsFromIssuanceOfLongTermDebt |
In February 2024, AEP Texas retired $ 12 million of Securitization Bonds. | text | 12 | monetaryItemType | text: <entity> 12 </entity> <entity type> monetaryItemType </entity type> <context> In February 2024, AEP Texas retired $ 12 million of Securitization Bonds. </context> | us-gaap:RepaymentsOfLongTermDebt |
In February 2024, APCo retired $ 13 million of Securitization Bonds. | text | 13 | monetaryItemType | text: <entity> 13 </entity> <entity type> monetaryItemType </entity type> <context> In February 2024, APCo retired $ 13 million of Securitization Bonds. </context> | us-gaap:RepaymentsOfLongTermDebt |
In August 2020, AEP issued 17 million Equity Units initially in the form of corporate units, at a stated amount of $ 50 per unit, for a total stated amount of $ 850 million. Net proceeds from the issuance were approximately $ 833 million. The proceeds were used to support AEP’s overall capital expenditure plans. | text | 850 | monetaryItemType | text: <entity> 850 </entity> <entity type> monetaryItemType </entity type> <context> In August 2020, AEP issued 17 million Equity Units initially in the form of corporate units, at a stated amount of $ 50 per unit, for a total stated amount of $ 850 million. Net proceeds from the issuance were approximately $ 833 million. The proceeds were used to support AEP’s overall capital expenditure plans. </context> | us-gaap:ProceedsFromIssuanceOfDebt |
Each corporate unit represents a 1/20 undivided beneficial ownership interest in $ 1,000 principal amount of AEP’s 1.30 % Junior Subordinated Notes due in 2025 and a forward equity purchase contract which settled after three years in August 2023 . In June 2023, AEP successfully remarketed the Junior Subordinated Notes on behalf of holders of the corporate units. AEP did not receive any proceeds from the remarketing which were used to purchase a portfolio of treasury securities that matured on August 14, 2023. On August 15, 2023, the proceeds from the treasury portfolio were used to settle the forward equity purchase contract with AEP. The interest rate on the Junior Subordinated Notes was reset to 5.699 % with the maturity remaining in 2025. In August 2023, AEP issued 10,048,668 shares of AEP common stock and received proceeds totaling $ 850 million under the settlement of the forward equity purchase contract. AEP common stock held in treasury was used to settle the forward equity purchase contract. The proceeds were used to pay down debt balances and support AEP’s overall capital expenditure plans. | text | 1.30 | percentItemType | text: <entity> 1.30 </entity> <entity type> percentItemType </entity type> <context> Each corporate unit represents a 1/20 undivided beneficial ownership interest in $ 1,000 principal amount of AEP’s 1.30 % Junior Subordinated Notes due in 2025 and a forward equity purchase contract which settled after three years in August 2023 . In June 2023, AEP successfully remarketed the Junior Subordinated Notes on behalf of holders of the corporate units. AEP did not receive any proceeds from the remarketing which were used to purchase a portfolio of treasury securities that matured on August 14, 2023. On August 15, 2023, the proceeds from the treasury portfolio were used to settle the forward equity purchase contract with AEP. The interest rate on the Junior Subordinated Notes was reset to 5.699 % with the maturity remaining in 2025. In August 2023, AEP issued 10,048,668 shares of AEP common stock and received proceeds totaling $ 850 million under the settlement of the forward equity purchase contract. AEP common stock held in treasury was used to settle the forward equity purchase contract. The proceeds were used to pay down debt balances and support AEP’s overall capital expenditure plans. </context> | us-gaap:DebtInstrumentInterestRateStatedPercentage |
Each corporate unit represents a 1/20 undivided beneficial ownership interest in $ 1,000 principal amount of AEP’s 1.30 % Junior Subordinated Notes due in 2025 and a forward equity purchase contract which settled after three years in August 2023 . In June 2023, AEP successfully remarketed the Junior Subordinated Notes on behalf of holders of the corporate units. AEP did not receive any proceeds from the remarketing which were used to purchase a portfolio of treasury securities that matured on August 14, 2023. On August 15, 2023, the proceeds from the treasury portfolio were used to settle the forward equity purchase contract with AEP. The interest rate on the Junior Subordinated Notes was reset to 5.699 % with the maturity remaining in 2025. In August 2023, AEP issued 10,048,668 shares of AEP common stock and received proceeds totaling $ 850 million under the settlement of the forward equity purchase contract. AEP common stock held in treasury was used to settle the forward equity purchase contract. The proceeds were used to pay down debt balances and support AEP’s overall capital expenditure plans. | text | 5.699 | percentItemType | text: <entity> 5.699 </entity> <entity type> percentItemType </entity type> <context> Each corporate unit represents a 1/20 undivided beneficial ownership interest in $ 1,000 principal amount of AEP’s 1.30 % Junior Subordinated Notes due in 2025 and a forward equity purchase contract which settled after three years in August 2023 . In June 2023, AEP successfully remarketed the Junior Subordinated Notes on behalf of holders of the corporate units. AEP did not receive any proceeds from the remarketing which were used to purchase a portfolio of treasury securities that matured on August 14, 2023. On August 15, 2023, the proceeds from the treasury portfolio were used to settle the forward equity purchase contract with AEP. The interest rate on the Junior Subordinated Notes was reset to 5.699 % with the maturity remaining in 2025. In August 2023, AEP issued 10,048,668 shares of AEP common stock and received proceeds totaling $ 850 million under the settlement of the forward equity purchase contract. AEP common stock held in treasury was used to settle the forward equity purchase contract. The proceeds were used to pay down debt balances and support AEP’s overall capital expenditure plans. </context> | us-gaap:DebtInstrumentInterestRateStatedPercentage |
Each corporate unit represents a 1/20 undivided beneficial ownership interest in $ 1,000 principal amount of AEP’s 1.30 % Junior Subordinated Notes due in 2025 and a forward equity purchase contract which settled after three years in August 2023 . In June 2023, AEP successfully remarketed the Junior Subordinated Notes on behalf of holders of the corporate units. AEP did not receive any proceeds from the remarketing which were used to purchase a portfolio of treasury securities that matured on August 14, 2023. On August 15, 2023, the proceeds from the treasury portfolio were used to settle the forward equity purchase contract with AEP. The interest rate on the Junior Subordinated Notes was reset to 5.699 % with the maturity remaining in 2025. In August 2023, AEP issued 10,048,668 shares of AEP common stock and received proceeds totaling $ 850 million under the settlement of the forward equity purchase contract. AEP common stock held in treasury was used to settle the forward equity purchase contract. The proceeds were used to pay down debt balances and support AEP’s overall capital expenditure plans. | text | 10048668 | sharesItemType | text: <entity> 10048668 </entity> <entity type> sharesItemType </entity type> <context> Each corporate unit represents a 1/20 undivided beneficial ownership interest in $ 1,000 principal amount of AEP’s 1.30 % Junior Subordinated Notes due in 2025 and a forward equity purchase contract which settled after three years in August 2023 . In June 2023, AEP successfully remarketed the Junior Subordinated Notes on behalf of holders of the corporate units. AEP did not receive any proceeds from the remarketing which were used to purchase a portfolio of treasury securities that matured on August 14, 2023. On August 15, 2023, the proceeds from the treasury portfolio were used to settle the forward equity purchase contract with AEP. The interest rate on the Junior Subordinated Notes was reset to 5.699 % with the maturity remaining in 2025. In August 2023, AEP issued 10,048,668 shares of AEP common stock and received proceeds totaling $ 850 million under the settlement of the forward equity purchase contract. AEP common stock held in treasury was used to settle the forward equity purchase contract. The proceeds were used to pay down debt balances and support AEP’s overall capital expenditure plans. </context> | us-gaap:StockIssuedDuringPeriodSharesNewIssues |
Each corporate unit represents a 1/20 undivided beneficial ownership interest in $ 1,000 principal amount of AEP’s 1.30 % Junior Subordinated Notes due in 2025 and a forward equity purchase contract which settled after three years in August 2023 . In June 2023, AEP successfully remarketed the Junior Subordinated Notes on behalf of holders of the corporate units. AEP did not receive any proceeds from the remarketing which were used to purchase a portfolio of treasury securities that matured on August 14, 2023. On August 15, 2023, the proceeds from the treasury portfolio were used to settle the forward equity purchase contract with AEP. The interest rate on the Junior Subordinated Notes was reset to 5.699 % with the maturity remaining in 2025. In August 2023, AEP issued 10,048,668 shares of AEP common stock and received proceeds totaling $ 850 million under the settlement of the forward equity purchase contract. AEP common stock held in treasury was used to settle the forward equity purchase contract. The proceeds were used to pay down debt balances and support AEP’s overall capital expenditure plans. | text | 850 | monetaryItemType | text: <entity> 850 </entity> <entity type> monetaryItemType </entity type> <context> Each corporate unit represents a 1/20 undivided beneficial ownership interest in $ 1,000 principal amount of AEP’s 1.30 % Junior Subordinated Notes due in 2025 and a forward equity purchase contract which settled after three years in August 2023 . In June 2023, AEP successfully remarketed the Junior Subordinated Notes on behalf of holders of the corporate units. AEP did not receive any proceeds from the remarketing which were used to purchase a portfolio of treasury securities that matured on August 14, 2023. On August 15, 2023, the proceeds from the treasury portfolio were used to settle the forward equity purchase contract with AEP. The interest rate on the Junior Subordinated Notes was reset to 5.699 % with the maturity remaining in 2025. In August 2023, AEP issued 10,048,668 shares of AEP common stock and received proceeds totaling $ 850 million under the settlement of the forward equity purchase contract. AEP common stock held in treasury was used to settle the forward equity purchase contract. The proceeds were used to pay down debt balances and support AEP’s overall capital expenditure plans. </context> | us-gaap:ProceedsFromIssuanceOfCommonStock |
Pursuant to the leverage restrictions in credit agreements, AEP must maintain a percentage of debt-to-total capitalization at a level that does not exceed 67.5 %. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. As of December 31, 2023, AEP had $ 7.6 billion of available retained earnings to pay dividends to common shareholders. AEP paid $ 1.8 billion, $ 1.6 billion and $ 1.5 billion of dividends to common shareholders for the years ended December 31, 2023, 2022 and 2021, respectively. | text | 7.6 | monetaryItemType | text: <entity> 7.6 </entity> <entity type> monetaryItemType </entity type> <context> Pursuant to the leverage restrictions in credit agreements, AEP must maintain a percentage of debt-to-total capitalization at a level that does not exceed 67.5 %. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. As of December 31, 2023, AEP had $ 7.6 billion of available retained earnings to pay dividends to common shareholders. AEP paid $ 1.8 billion, $ 1.6 billion and $ 1.5 billion of dividends to common shareholders for the years ended December 31, 2023, 2022 and 2021, respectively. </context> | us-gaap:RetainedEarningsUnappropriated |
Pursuant to the leverage restrictions in credit agreements, AEP must maintain a percentage of debt-to-total capitalization at a level that does not exceed 67.5 %. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. As of December 31, 2023, AEP had $ 7.6 billion of available retained earnings to pay dividends to common shareholders. AEP paid $ 1.8 billion, $ 1.6 billion and $ 1.5 billion of dividends to common shareholders for the years ended December 31, 2023, 2022 and 2021, respectively. | text | 1.8 | monetaryItemType | text: <entity> 1.8 </entity> <entity type> monetaryItemType </entity type> <context> Pursuant to the leverage restrictions in credit agreements, AEP must maintain a percentage of debt-to-total capitalization at a level that does not exceed 67.5 %. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. As of December 31, 2023, AEP had $ 7.6 billion of available retained earnings to pay dividends to common shareholders. AEP paid $ 1.8 billion, $ 1.6 billion and $ 1.5 billion of dividends to common shareholders for the years ended December 31, 2023, 2022 and 2021, respectively. </context> | us-gaap:PaymentsOfDividendsCommonStock |
Pursuant to the leverage restrictions in credit agreements, AEP must maintain a percentage of debt-to-total capitalization at a level that does not exceed 67.5 %. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. As of December 31, 2023, AEP had $ 7.6 billion of available retained earnings to pay dividends to common shareholders. AEP paid $ 1.8 billion, $ 1.6 billion and $ 1.5 billion of dividends to common shareholders for the years ended December 31, 2023, 2022 and 2021, respectively. | text | 1.6 | monetaryItemType | text: <entity> 1.6 </entity> <entity type> monetaryItemType </entity type> <context> Pursuant to the leverage restrictions in credit agreements, AEP must maintain a percentage of debt-to-total capitalization at a level that does not exceed 67.5 %. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. As of December 31, 2023, AEP had $ 7.6 billion of available retained earnings to pay dividends to common shareholders. AEP paid $ 1.8 billion, $ 1.6 billion and $ 1.5 billion of dividends to common shareholders for the years ended December 31, 2023, 2022 and 2021, respectively. </context> | us-gaap:PaymentsOfDividendsCommonStock |
Pursuant to the leverage restrictions in credit agreements, AEP must maintain a percentage of debt-to-total capitalization at a level that does not exceed 67.5 %. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. As of December 31, 2023, AEP had $ 7.6 billion of available retained earnings to pay dividends to common shareholders. AEP paid $ 1.8 billion, $ 1.6 billion and $ 1.5 billion of dividends to common shareholders for the years ended December 31, 2023, 2022 and 2021, respectively. | text | 1.5 | monetaryItemType | text: <entity> 1.5 </entity> <entity type> monetaryItemType </entity type> <context> Pursuant to the leverage restrictions in credit agreements, AEP must maintain a percentage of debt-to-total capitalization at a level that does not exceed 67.5 %. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. As of December 31, 2023, AEP had $ 7.6 billion of available retained earnings to pay dividends to common shareholders. AEP paid $ 1.8 billion, $ 1.6 billion and $ 1.5 billion of dividends to common shareholders for the years ended December 31, 2023, 2022 and 2021, respectively. </context> | us-gaap:PaymentsOfDividendsCommonStock |
AEP uses its commercial paper program to meet the short-term borrowing needs of its subsidiaries. The program funds a Utility Money Pool, which funds AEP’s utility subsidiaries; a Nonutility Money Pool, which funds certain AEP nonutility subsidiaries; and the short-term debt requirements of subsidiaries that are not participating in either money pool for regulatory or operational reasons, as direct borrowers. As of December 31, 2023, AEP had $ 5 billion in revolving credit facilities to support its commercial paper program. Securitized Debt for Receivables, for the year ended 2023, had a weighted-average interest rate of 5.33 % and a maximum amount outstanding of $ 900 million. The commercial paper program, for the year ended 2023, had a weighted-average interest rate of 5.38 % and a maximum amount outstanding of $ 3.2 billion. AEP’s outstanding short-term debt was as follows: | text | 5.33 | percentItemType | text: <entity> 5.33 </entity> <entity type> percentItemType </entity type> <context> AEP uses its commercial paper program to meet the short-term borrowing needs of its subsidiaries. The program funds a Utility Money Pool, which funds AEP’s utility subsidiaries; a Nonutility Money Pool, which funds certain AEP nonutility subsidiaries; and the short-term debt requirements of subsidiaries that are not participating in either money pool for regulatory or operational reasons, as direct borrowers. As of December 31, 2023, AEP had $ 5 billion in revolving credit facilities to support its commercial paper program. Securitized Debt for Receivables, for the year ended 2023, had a weighted-average interest rate of 5.33 % and a maximum amount outstanding of $ 900 million. The commercial paper program, for the year ended 2023, had a weighted-average interest rate of 5.38 % and a maximum amount outstanding of $ 3.2 billion. AEP’s outstanding short-term debt was as follows: </context> | us-gaap:DebtInstrumentInterestRateDuringPeriod |
AEP uses its commercial paper program to meet the short-term borrowing needs of its subsidiaries. The program funds a Utility Money Pool, which funds AEP’s utility subsidiaries; a Nonutility Money Pool, which funds certain AEP nonutility subsidiaries; and the short-term debt requirements of subsidiaries that are not participating in either money pool for regulatory or operational reasons, as direct borrowers. As of December 31, 2023, AEP had $ 5 billion in revolving credit facilities to support its commercial paper program. Securitized Debt for Receivables, for the year ended 2023, had a weighted-average interest rate of 5.33 % and a maximum amount outstanding of $ 900 million. The commercial paper program, for the year ended 2023, had a weighted-average interest rate of 5.38 % and a maximum amount outstanding of $ 3.2 billion. AEP’s outstanding short-term debt was as follows: | text | 900 | monetaryItemType | text: <entity> 900 </entity> <entity type> monetaryItemType </entity type> <context> AEP uses its commercial paper program to meet the short-term borrowing needs of its subsidiaries. The program funds a Utility Money Pool, which funds AEP’s utility subsidiaries; a Nonutility Money Pool, which funds certain AEP nonutility subsidiaries; and the short-term debt requirements of subsidiaries that are not participating in either money pool for regulatory or operational reasons, as direct borrowers. As of December 31, 2023, AEP had $ 5 billion in revolving credit facilities to support its commercial paper program. Securitized Debt for Receivables, for the year ended 2023, had a weighted-average interest rate of 5.33 % and a maximum amount outstanding of $ 900 million. The commercial paper program, for the year ended 2023, had a weighted-average interest rate of 5.38 % and a maximum amount outstanding of $ 3.2 billion. AEP’s outstanding short-term debt was as follows: </context> | us-gaap:TransfersAccountedForAsSecuredBorrowingsAssociatedLiabilitiesCarryingAmount |
AEP uses its commercial paper program to meet the short-term borrowing needs of its subsidiaries. The program funds a Utility Money Pool, which funds AEP’s utility subsidiaries; a Nonutility Money Pool, which funds certain AEP nonutility subsidiaries; and the short-term debt requirements of subsidiaries that are not participating in either money pool for regulatory or operational reasons, as direct borrowers. As of December 31, 2023, AEP had $ 5 billion in revolving credit facilities to support its commercial paper program. Securitized Debt for Receivables, for the year ended 2023, had a weighted-average interest rate of 5.33 % and a maximum amount outstanding of $ 900 million. The commercial paper program, for the year ended 2023, had a weighted-average interest rate of 5.38 % and a maximum amount outstanding of $ 3.2 billion. AEP’s outstanding short-term debt was as follows: | text | 5.38 | percentItemType | text: <entity> 5.38 </entity> <entity type> percentItemType </entity type> <context> AEP uses its commercial paper program to meet the short-term borrowing needs of its subsidiaries. The program funds a Utility Money Pool, which funds AEP’s utility subsidiaries; a Nonutility Money Pool, which funds certain AEP nonutility subsidiaries; and the short-term debt requirements of subsidiaries that are not participating in either money pool for regulatory or operational reasons, as direct borrowers. As of December 31, 2023, AEP had $ 5 billion in revolving credit facilities to support its commercial paper program. Securitized Debt for Receivables, for the year ended 2023, had a weighted-average interest rate of 5.33 % and a maximum amount outstanding of $ 900 million. The commercial paper program, for the year ended 2023, had a weighted-average interest rate of 5.38 % and a maximum amount outstanding of $ 3.2 billion. AEP’s outstanding short-term debt was as follows: </context> | us-gaap:DebtInstrumentInterestRateDuringPeriod |
AEP uses its commercial paper program to meet the short-term borrowing needs of its subsidiaries. The program funds a Utility Money Pool, which funds AEP’s utility subsidiaries; a Nonutility Money Pool, which funds certain AEP nonutility subsidiaries; and the short-term debt requirements of subsidiaries that are not participating in either money pool for regulatory or operational reasons, as direct borrowers. As of December 31, 2023, AEP had $ 5 billion in revolving credit facilities to support its commercial paper program. Securitized Debt for Receivables, for the year ended 2023, had a weighted-average interest rate of 5.33 % and a maximum amount outstanding of $ 900 million. The commercial paper program, for the year ended 2023, had a weighted-average interest rate of 5.38 % and a maximum amount outstanding of $ 3.2 billion. AEP’s outstanding short-term debt was as follows: | text | 3.2 | monetaryItemType | text: <entity> 3.2 </entity> <entity type> monetaryItemType </entity type> <context> AEP uses its commercial paper program to meet the short-term borrowing needs of its subsidiaries. The program funds a Utility Money Pool, which funds AEP’s utility subsidiaries; a Nonutility Money Pool, which funds certain AEP nonutility subsidiaries; and the short-term debt requirements of subsidiaries that are not participating in either money pool for regulatory or operational reasons, as direct borrowers. As of December 31, 2023, AEP had $ 5 billion in revolving credit facilities to support its commercial paper program. Securitized Debt for Receivables, for the year ended 2023, had a weighted-average interest rate of 5.33 % and a maximum amount outstanding of $ 900 million. The commercial paper program, for the year ended 2023, had a weighted-average interest rate of 5.38 % and a maximum amount outstanding of $ 3.2 billion. AEP’s outstanding short-term debt was as follows: </context> | us-gaap:ShorttermDebtMaximumAmountOutstandingDuringPeriod |
Awards under the American Electric Power System 2015 Long-Term Incentive Plan (2015 LTIP), which replaced prior long-term incentive plans effective April 2015, may be granted to employees and directors. The 2015 LTIP was subsequently amended in September 2016. The 2015 LTIP provides for a maximum of 10 million AEP common shares to be available for grant to eligible employees and directors. As of December 31, 2023, 3,698,144 shares remained available for issuance under the 2015 LTIP. No new awards may be granted under the Prior Plan. Awards granted under the 2015 LTIP awards may be made in the form of stock options, stock appreciation rights, restricted stock, restricted stock units, performance shares, performance units, cash-based awards and other stock-based awards. Shares issued pursuant to a stock option or a stock appreciation right reduce the shares remaining available for grants under the 2015 LTIP by 0.286 of a share. Each share issued for any other award that settles in AEP stock reduces the shares remaining available for grants under the 2015 LTIP by one share. Cash settled awards do not reduce the number of shares remaining available under the 2015 LTIP. The following sections provide further information regarding each type of stock-based compensation award granted under these plans. | text | 10 | sharesItemType | text: <entity> 10 </entity> <entity type> sharesItemType </entity type> <context> Awards under the American Electric Power System 2015 Long-Term Incentive Plan (2015 LTIP), which replaced prior long-term incentive plans effective April 2015, may be granted to employees and directors. The 2015 LTIP was subsequently amended in September 2016. The 2015 LTIP provides for a maximum of 10 million AEP common shares to be available for grant to eligible employees and directors. As of December 31, 2023, 3,698,144 shares remained available for issuance under the 2015 LTIP. No new awards may be granted under the Prior Plan. Awards granted under the 2015 LTIP awards may be made in the form of stock options, stock appreciation rights, restricted stock, restricted stock units, performance shares, performance units, cash-based awards and other stock-based awards. Shares issued pursuant to a stock option or a stock appreciation right reduce the shares remaining available for grants under the 2015 LTIP by 0.286 of a share. Each share issued for any other award that settles in AEP stock reduces the shares remaining available for grants under the 2015 LTIP by one share. Cash settled awards do not reduce the number of shares remaining available under the 2015 LTIP. The following sections provide further information regarding each type of stock-based compensation award granted under these plans. </context> | us-gaap:ShareBasedCompensationArrangementByShareBasedPaymentAwardNumberOfSharesAvailableForGrant |
Awards under the American Electric Power System 2015 Long-Term Incentive Plan (2015 LTIP), which replaced prior long-term incentive plans effective April 2015, may be granted to employees and directors. The 2015 LTIP was subsequently amended in September 2016. The 2015 LTIP provides for a maximum of 10 million AEP common shares to be available for grant to eligible employees and directors. As of December 31, 2023, 3,698,144 shares remained available for issuance under the 2015 LTIP. No new awards may be granted under the Prior Plan. Awards granted under the 2015 LTIP awards may be made in the form of stock options, stock appreciation rights, restricted stock, restricted stock units, performance shares, performance units, cash-based awards and other stock-based awards. Shares issued pursuant to a stock option or a stock appreciation right reduce the shares remaining available for grants under the 2015 LTIP by 0.286 of a share. Each share issued for any other award that settles in AEP stock reduces the shares remaining available for grants under the 2015 LTIP by one share. Cash settled awards do not reduce the number of shares remaining available under the 2015 LTIP. The following sections provide further information regarding each type of stock-based compensation award granted under these plans. | text | 3698144 | sharesItemType | text: <entity> 3698144 </entity> <entity type> sharesItemType </entity type> <context> Awards under the American Electric Power System 2015 Long-Term Incentive Plan (2015 LTIP), which replaced prior long-term incentive plans effective April 2015, may be granted to employees and directors. The 2015 LTIP was subsequently amended in September 2016. The 2015 LTIP provides for a maximum of 10 million AEP common shares to be available for grant to eligible employees and directors. As of December 31, 2023, 3,698,144 shares remained available for issuance under the 2015 LTIP. No new awards may be granted under the Prior Plan. Awards granted under the 2015 LTIP awards may be made in the form of stock options, stock appreciation rights, restricted stock, restricted stock units, performance shares, performance units, cash-based awards and other stock-based awards. Shares issued pursuant to a stock option or a stock appreciation right reduce the shares remaining available for grants under the 2015 LTIP by 0.286 of a share. Each share issued for any other award that settles in AEP stock reduces the shares remaining available for grants under the 2015 LTIP by one share. Cash settled awards do not reduce the number of shares remaining available under the 2015 LTIP. The following sections provide further information regarding each type of stock-based compensation award granted under these plans. </context> | us-gaap:CommonStockCapitalSharesReservedForFutureIssuance |
The total aggregate intrinsic value of nonvested RSUs as of December 31, 2023 was $ 33 million and the weighted-average remaining contractual life was 1.5 years. | text | 33 | monetaryItemType | text: <entity> 33 </entity> <entity type> monetaryItemType </entity type> <context> The total aggregate intrinsic value of nonvested RSUs as of December 31, 2023 was $ 33 million and the weighted-average remaining contractual life was 1.5 years. </context> | us-gaap:SharebasedCompensationArrangementBySharebasedPaymentAwardEquityInstrumentsOtherThanOptionsAggregateIntrinsicValueNonvested |
As of December 31, 2023, there was $ 66 million of total unrecognized compensation cost related to unvested share-based compensation arrangements granted under the 2015 LTIP. Unrecognized compensation cost related to unvested share-based arrangements will change as the fair value of performance shares is adjusted each period and as forfeitures for all award types are realized. AEP’s unrecognized compensation cost will be recognized over a weighted-average period of 1.4 years. | text | 66 | monetaryItemType | text: <entity> 66 </entity> <entity type> monetaryItemType </entity type> <context> As of December 31, 2023, there was $ 66 million of total unrecognized compensation cost related to unvested share-based compensation arrangements granted under the 2015 LTIP. Unrecognized compensation cost related to unvested share-based arrangements will change as the fair value of performance shares is adjusted each period and as forfeitures for all award types are realized. AEP’s unrecognized compensation cost will be recognized over a weighted-average period of 1.4 years. </context> | us-gaap:EmployeeServiceShareBasedCompensationNonvestedAwardsTotalCompensationCostNotYetRecognized |
of mine reclamation costs in ARO and $ 34 million in Accounts Payable - Affiliated Companies for collected reclamation costs that have been billed to SWEPCo. SWEPCo has collected | text | 34 | monetaryItemType | text: <entity> 34 </entity> <entity type> monetaryItemType </entity type> <context> of mine reclamation costs in ARO and $ 34 million in Accounts Payable - Affiliated Companies for collected reclamation costs that have been billed to SWEPCo. SWEPCo has collected </context> | us-gaap:AccountsPayableCurrent |
and $ 70 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, on the balance sheets. The securitized bonds included in Long-term Debt - Nonaffiliated were immaterial and $ 71 million as of December 31, 2023 and 2022, respectively, on the balance sheets. Transition Funding has securitized transition assets of | text | 70 | monetaryItemType | text: <entity> 70 </entity> <entity type> monetaryItemType </entity type> <context> and $ 70 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, on the balance sheets. The securitized bonds included in Long-term Debt - Nonaffiliated were immaterial and $ 71 million as of December 31, 2023 and 2022, respectively, on the balance sheets. Transition Funding has securitized transition assets of </context> | us-gaap:SecuredDebt |
and $ 70 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, on the balance sheets. The securitized bonds included in Long-term Debt - Nonaffiliated were immaterial and $ 71 million as of December 31, 2023 and 2022, respectively, on the balance sheets. Transition Funding has securitized transition assets of | text | 71 | monetaryItemType | text: <entity> 71 </entity> <entity type> monetaryItemType </entity type> <context> and $ 70 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, on the balance sheets. The securitized bonds included in Long-term Debt - Nonaffiliated were immaterial and $ 71 million as of December 31, 2023 and 2022, respectively, on the balance sheets. Transition Funding has securitized transition assets of </context> | us-gaap:SecuredDebt |
and $ 125 million as of December 31, 2023 and 2022, respectively, which are presented separately on the face of the balance sheets. The securitized transition assets represent the right to impose and collect Texas true-up costs from customers receiving electric transmission or distribution service from AEP Texas under-recovery mechanisms approved by the PUCT. The securitization bonds are payable only from and secured by the securitized transition assets. The bondholders have no recourse to AEP Texas or any other AEP entity. AEP Texas acts as the servicer for Transition Funding’s securitized transition assets and remits all related amounts collected from customers to Transition Funding for interest and principal payments on the securitization bonds and related costs. See the tables below for the classification of Transition Funding’s assets and liabilities on the balance sheets. | text | 125 | monetaryItemType | text: <entity> 125 </entity> <entity type> monetaryItemType </entity type> <context> and $ 125 million as of December 31, 2023 and 2022, respectively, which are presented separately on the face of the balance sheets. The securitized transition assets represent the right to impose and collect Texas true-up costs from customers receiving electric transmission or distribution service from AEP Texas under-recovery mechanisms approved by the PUCT. The securitization bonds are payable only from and secured by the securitized transition assets. The bondholders have no recourse to AEP Texas or any other AEP entity. AEP Texas acts as the servicer for Transition Funding’s securitized transition assets and remits all related amounts collected from customers to Transition Funding for interest and principal payments on the securitization bonds and related costs. See the tables below for the classification of Transition Funding’s assets and liabilities on the balance sheets. </context> | us-gaap:SecuritizedRegulatoryTransitionAssetsNoncurrent |
and $ 24 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and | text | 24 | monetaryItemType | text: <entity> 24 </entity> <entity type> monetaryItemType </entity type> <context> and $ 24 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and </context> | us-gaap:SecuredDebt |
and $ 150 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Restoration Funding has securitized assets of | text | 150 | monetaryItemType | text: <entity> 150 </entity> <entity type> monetaryItemType </entity type> <context> and $ 150 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Restoration Funding has securitized assets of </context> | us-gaap:SecuredDebt |
and $ 161 million as of December 31, 2023 and 2022, respectively, which are presented separately on the face of the balance sheets. The securitized restoration assets represent the right to impose and collect Texas storm restoration costs from customers receiving electric transmission or distribution service from AEP Texas under-recovery mechanisms approved by the PUCT. The securitization bonds are payable only from and secured by the securitized assets. The bondholders have no recourse to AEP Texas or any other AEP entity. AEP Texas acts as the servicer for Restoration Funding’s securitized assets and remits all related amounts collected from customers to Restoration Funding for interest and principal payments on the securitization bonds and related costs. See the tables below for the classification of Restoration Funding’s assets and liabilities on the balance sheets. | text | 161 | monetaryItemType | text: <entity> 161 </entity> <entity type> monetaryItemType </entity type> <context> and $ 161 million as of December 31, 2023 and 2022, respectively, which are presented separately on the face of the balance sheets. The securitized restoration assets represent the right to impose and collect Texas storm restoration costs from customers receiving electric transmission or distribution service from AEP Texas under-recovery mechanisms approved by the PUCT. The securitization bonds are payable only from and secured by the securitized assets. The bondholders have no recourse to AEP Texas or any other AEP entity. AEP Texas acts as the servicer for Restoration Funding’s securitized assets and remits all related amounts collected from customers to Restoration Funding for interest and principal payments on the securitization bonds and related costs. See the tables below for the classification of Restoration Funding’s assets and liabilities on the balance sheets. </context> | us-gaap:SecuritizedRegulatoryTransitionAssetsNoncurrent |
and $ 26 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and | text | 26 | monetaryItemType | text: <entity> 26 </entity> <entity type> monetaryItemType </entity type> <context> and $ 26 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and </context> | us-gaap:SecuredDebt |
and $ 147 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Appalachian Consumer Rate Relief Funding has securitized assets of | text | 147 | monetaryItemType | text: <entity> 147 </entity> <entity type> monetaryItemType </entity type> <context> and $ 147 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Appalachian Consumer Rate Relief Funding has securitized assets of </context> | us-gaap:SecuredDebt |
and $ 160 million as of December 31, 2023 and 2022, respectively, which are presented separately on the face of the balance sheets. The phase-in recovery property represents the right to impose and collect West Virginia deferred generation charges from customers receiving electric transmission, distribution and generation service from APCo under a recovery mechanism approved by the WVPSC. In November 2013, securitization bonds were issued. The securitization bonds are payable only from and secured by the securitized assets. The bondholders have no recourse to APCo or any other AEP entity. APCo acts as the servicer for Appalachian Consumer Rate Relief Funding’s securitized assets and remits all related amounts collected from customers to Appalachian Consumer Rate Relief Funding for interest and principal payments on the securitization bonds and related costs. See the tables below for the classification of Appalachian Consumer Rate Relief Funding’s assets and liabilities on APCo’s balance sheets. | text | 160 | monetaryItemType | text: <entity> 160 </entity> <entity type> monetaryItemType </entity type> <context> and $ 160 million as of December 31, 2023 and 2022, respectively, which are presented separately on the face of the balance sheets. The phase-in recovery property represents the right to impose and collect West Virginia deferred generation charges from customers receiving electric transmission, distribution and generation service from APCo under a recovery mechanism approved by the WVPSC. In November 2013, securitization bonds were issued. The securitization bonds are payable only from and secured by the securitized assets. The bondholders have no recourse to APCo or any other AEP entity. APCo acts as the servicer for Appalachian Consumer Rate Relief Funding’s securitized assets and remits all related amounts collected from customers to Appalachian Consumer Rate Relief Funding for interest and principal payments on the securitization bonds and related costs. See the tables below for the classification of Appalachian Consumer Rate Relief Funding’s assets and liabilities on APCo’s balance sheets. </context> | us-gaap:SecuritizedRegulatoryTransitionAssetsNoncurrent |
As of December 31, 2023, Apple Blossom, Black Oak, Santa Rita East and Dry Lake are no longer consolidated VIEs due to the sale of the Competitive Contracted Renewables Portfolio. See the table below for the classification of assets and liabilities on the balance sheets. As of December 31, 2022, nonaffiliated interests in Apple Blossom and Black Oak, Santa Rita East and Dry Lake were $ 94 million, $ 58 million and $ 34 million, respectively, presented in Noncontrolling Interests on the balance sheets. The results of operations for these interests for the years ended December 31, 2023, 2022 and 2021 were not material to the AEP statements of income. | text | 94 | monetaryItemType | text: <entity> 94 </entity> <entity type> monetaryItemType </entity type> <context> As of December 31, 2023, Apple Blossom, Black Oak, Santa Rita East and Dry Lake are no longer consolidated VIEs due to the sale of the Competitive Contracted Renewables Portfolio. See the table below for the classification of assets and liabilities on the balance sheets. As of December 31, 2022, nonaffiliated interests in Apple Blossom and Black Oak, Santa Rita East and Dry Lake were $ 94 million, $ 58 million and $ 34 million, respectively, presented in Noncontrolling Interests on the balance sheets. The results of operations for these interests for the years ended December 31, 2023, 2022 and 2021 were not material to the AEP statements of income. </context> | us-gaap:NoncontrollingInterestInVariableInterestEntity |
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