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Rate And Regulatory Matters | 3 Months Ended
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Mar. 31, 2025
Public Utilities Disclosure [Text Block] | RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2025, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.00882 per kWh to $0.01333 per kWh. The annual redetermination included a credit related to the remaining balance due to retail customers from the System Energy settlement with the APSC, plus carrying charges and interest. See “Retail Rate Proceedings - Filings with the APSC (Entergy Arkansas) - Retail Rates - Grand Gulf Credit Rider” below for further discussion. The primary reason for the rate increase is an adjustment to account for projected increases in natural gas prices in 2025. This adjustment is expected to reduce the rate change that will be reflected in its 2026 energy cost rate redetermination. The redetermined rate of $0.01333 per kWh became effective with the first billing cycle in April 2025 through the normal operation of the tariff. Entergy Louisiana As discussed in the Form 10-K, in January 2023 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2021 through 2022. In April 2025 the LPSC staff issued its audit report (for Entergy Louisiana’s gas operations), which included several prospective recommendations but no financial disallowances. The next procedural step is for the LPSC to review the report; however there is no deadline for completion of the LPSC’s review. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates Grand Gulf Credit Rider As discussed in the Form 10-K, in June 2024, Entergy Arkansas filed with the APSC a tariff to provide retail customers a credit resulting from the terms of the settlement agreement between Entergy Arkansas, System Energy, additional named Entergy parties, and the APSC pertaining to System Energy’s billings for wholesale sales of energy and capacity from the Grand Gulf nuclear plant. See “Complaints Against System Energy - System Energy Settlement with the APSC” in Note 2 to the financial statements in the Form 10-K for discussion of the System Energy settlement with the APSC. In July 2024 the APSC approved the tariff, under which Entergy Arkansas would refund to retail customers a total of $100.6 million. Entergy Arkansas refunded $92.3 million of the total through one-time bill credits under the Grand Gulf credit rider during the August 2024 billing cycle. In March 2025, Entergy Arkansas included the remaining balance as a credit to retail customers in its energy cost recovery rider rate redetermination filing. See further discussion within "Regulatory Assets and Regulatory Liabilities - Fuel and purchased power cost recovery - Entergy Arkansas - Energy Cost Recovery Rider" above. In April 2025 the APSC approved Entergy Arkansas’s proposal to include the remaining balance in its energy cost recovery rider effective with the first billing cycle of April 2025 and the withdrawal of the Grand Gulf credit rider after all credits have been issued. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2023 Formula Rate Plan Filing As discussed in the Form 10-K, in August 2024, pursuant to the global stipulated settlement agreement, Entergy Louisiana filed its formula rate plan evaluation report for its 2023 calendar year operations. Consistent with the global stipulated settlement agreement, the filing reflected a 9.7% allowed return on common equity with a bandwidth of 40 basis points above and below the midpoint. For the 2023 test year, however, the bandwidth provisions of the formula rate plan are temporarily suspended and, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana implemented the September 2024 formula rate plan rate adjustments effective with the first billing cycle of September 2024. In January 2025, Entergy Louisiana and the LPSC filed a joint report indicating that no disputed issues remained in the proceeding and requesting that the LPSC issue an order accepting Entergy Louisiana’s evaluation report and, ultimately, resolving this matter. In March 2025 the LPSC issued an order accepting the evaluation report. In December 2024, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed an interim rate adjustment for the 2023 test year reflecting the return of $25.1 million of refunds from the System Energy settlement with the LPSC to customers from January through August 2025. In February 2025, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting the divestiture of Entergy Louisiana’s share of Grand Gulf capacity and energy, which was effective as of January 1, 2025. The second interim rate adjustment also reflected a revenue increase of $17.8 million for the recovery of Hurricane Francine costs as approved by the LPSC (on an interim basis). The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the Hurricane Francine proceeding in “Storm Cost Recovery Filings with Retail Regulators – Entergy Louisiana – Hurricane Francine” below. See Note 8 to the financial statements in the Form 10-K for discussion of Entergy Louisiana’s divestiture from the Unit Power Sales Agreement. Additional Generation and Transmission Resources As discussed in the Form 10-K, in October 2024, Entergy Louisiana filed an application with the LPSC seeking approval of a variety of generation and transmission resources proposed in connection with establishing service to a new data center to be developed by a subsidiary of Meta Platforms, Inc. in north Louisiana, for which an electric service agreement has been executed. The filing requests LPSC certification of three new combined cycle combustion turbine generation resources totaling 2,262 MW, each of which will be enabled for future carbon capture and storage, a new 500 kV transmission line, and 500 kV substation upgrades. The application also requests approval to implement a corporate sustainability rider applicable to the new customer. The corporate sustainability rider contemplates the new customer contributing to the costs of the future addition of 1,500 MW of new solar and energy storage resources, agreements involving carbon capture and storage at Entergy Louisiana’s existing Lake Charles Power Station, and potential future wind and nuclear resources. Entergy Louisiana anticipates funding the incremental cost to serve the customer through direct financial contributions from the customer and the revenues it expects to earn under the electric service agreement. The electric service agreement also contains provisions for termination payments that will help ensure that there is no harm to Entergy Louisiana and its customers in the event of early termination. A directive was issued at the LPSC’s November 2024 meeting for the matter to be decided by October 2025. In February 2025 intervenors filed a motion asking the LPSC to deny Entergy Louisiana’s requested exemption from the LPSC’s order addressing competitive solicitation procedures and further asking the LPSC to dismiss the application. The ALJ issued an order denying the motion to dismiss the application and deferring the LPSC’s consideration of the motion regarding the competitive solicitation procedures until the hearing. In March 2025 the same intervenors filed a motion requesting the LPSC to require the customer and its parent company to be joined as parties to the proceeding or dismiss the application. In April 2025 the ALJ issued an order denying the March 2025 motion, and the moving parties filed a motion asking the LPSC to review and reverse the ALJ’s decision. In April 2025 the LPSC staff and intervenors filed direct testimony. The LPSC staff’s testimony discusses the significant projected benefits associated with the data center project and also recommends that the LPSC impose certain conditions on its approval, including a condition that would require, under specified circumstances, certain sharing of net revenues from service to the project with Entergy Louisiana’s other customers. The LPSC staff also recommends that the LPSC deny approval of the corporate sustainability rider terms providing for the customer to supply funding toward the cost of installing carbon capture and storage infrastructure at Entergy Louisiana’s Lake Charles Power Station. The Louisiana Energy Users Group and other intervenors recommended that the LPSC require various changes to the terms of the electric service agreement with the customer that would shift additional risk and cost to the customer rather than Entergy Louisiana’s broader customer base. Certain intervenors also challenged approval on the basis that Entergy Louisiana did not conduct a request for proposals to procure the proposed generation resources to serve the customer’s project; these intervenors also advocate that Entergy Louisiana be required to procure more renewable generation and evaluate transmission alternatives rather than proceeding with development of all of the proposed new generation resources. Entergy Louisiana’s rebuttal testimony is due in May 2025, and a hearing is set for July 2025. Filings with the MPSC (Entergy Mississippi) Retail Rates 2025 Formula Rate Plan Filing In February 2025, Entergy Mississippi submitted its formula rate plan 2025 test year filing and 2024 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2024 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2025 calendar year to also be within the formula rate plan bandwidth. The 2025 test year filing resulted in an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2024 look-back filing compared actual 2024 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues, although Entergy Mississippi proposes to adjust interim rates by $135 thousand to reflect two outside-the-bandwidth changes: (1) the completion of Entergy Mississippi’s return to customers of credits under its restructuring credit rider; and (2) a true-up of demand side management costs. A final order is expected in second quarter 2025. Interim Facilities Rate Adjustments In May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with state legislation passed in January 2024. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed the first of its annual interim facilities rate adjustment reports in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Entergy Mississippi filed its second interim facilities rate adjustment report in November 2024 to recover approximately $46.7 million of these costs over a 12-month period with rates effective beginning in January 2025. In February 2025, Entergy Mississippi filed a true-up interim facilities rate adjustment report to the initial annual interim facilities rate adjustment report filed in May 2024, reflecting the recovery of an additional approximately $1.0 million of costs over a 12-month period with rates effective with the first billing cycle of April 2025. Filings with the City Council (Entergy New Orleans) Retail Rates 2025 Formula Rate Plan Filing In April 2025, Entergy New Orleans submitted to the City Council its formula rate plan 2024 test year filing. The 2024 evaluation report produced an electric earned return on equity of 10.98% and a gas earned return on equity of 8.96% compared to the authorized return on equity for each of 9.35%. Without adjustments, this would result in a decrease in electric rates of $13.8 million and no change in gas rates. The decrease in electric rates is driven by the realignment of regulatory liabilities into the formula from a separate rate mechanism, partially offset by the cost of known and measurable electric capital additions. The filing also commences the previously authorized recovery of certain regulatory costs and requests a revenue-neutral recovery to offset a proposed reduction in bill payment late fees. Taking into account these proposed adjustments, the filing presents a decrease in authorized electric revenues of $8.6 million and an increase in authorized gas revenues of $0.5 million. The filing is subject to a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. For any disputed rate adjustments, however, the City Council would set a procedural schedule to resolve. Resulting rates will be effective with the first billing cycle of September 2025 pursuant to the formula rate plan tariff. Filings with the PUCT and Texas Cities (Entergy Texas) Retail Rates Distribution Cost Recovery Factor (DCRF) Rider In April 2025, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $77.8 million annually, or $29.3 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between July 1, 2024 and December 31, 2024, including distribution-related restoration costs associated with Hurricane Beryl. Transmission Cost Recovery Factor (TCRF) Rider As discussed in the Form 10-K, in October 2024, Entergy Texas filed with the PUCT a request to amend its TCRF rider, which was previously reset to zero in June 2023 as a result of the 2022 base rate case. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $9.7 million annually based on its capital invested in transmission between January 1, 2022 and June 30, 2024 and changes in other transmission charges. In April 2025 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 7, 2025. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s denial of recovery of $135 million of payments to other Utility operating companies in December 2018 relating to off-system sales of electricity from 2002-2009, as ordered by the FERC. The complaint also involved a challenge to the $13.7 million, plus interest, of related refunds ordered by the APSC and paid by Entergy Arkansas in August 2020. The trial was held in February 2023. In March 2024 the U.S. District Court for the Eastern District of Arkansas issued a judgment in favor of the APSC and against Entergy Arkansas. In March 2024 Entergy Arkansas filed a notice of appeal and a motion to expedite oral arguments with the United States Court of Appeals for the Eighth Circuit and the court granted the motion to expedite. As a result of the adverse decision by the U.S. District Court for the Eastern District of Arkansas, Entergy Arkansas concluded that it could no longer support the recognition of its $131.8 million regulatory asset reflecting the previously-expected recovery of a portion of the costs at issue in the opportunity sales proceeding and recorded a $131.8 million ($99.1 million net-of-tax) charge to earnings in first quarter 2024. In December 2024 the United States Court of Appeals for the Eighth Circuit affirmed the decision of the U.S. District Court for the Eastern District of Arkansas, and Entergy Arkansas filed a petition for rehearing en banc. In January 2025 the United States Court of Appeals for the Eighth Circuit denied Entergy Arkansas’s petition. In April 2025, Entergy Arkansas filed a petition for certiorari with the United States Supreme Court. MSS-4 Replacement Tariff - Net Operating Loss Carryforward Proceeding See Note 2 to the financial statements in the Form 10-K for discussion of the MSS-4 replacement tariff net operating loss carryforward proceeding. The MSS-4 replacement tariff, a tariff governing the sales of energy and capacity among the Utility operating companies, includes protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In April 2025, pursuant to such protocols, the City Council filed with the FERC a formal challenge relating to Entergy Services’ inclusion and allocation of net operating loss carryforward accumulated deferred income taxes in the MSS-4 replacement tariff rates charged to Entergy New Orleans’s monthly bills for calendar year 2023. Entergy Services plans to file a response to the formal challenge by the May 2025 deadline. Complaints Against System Energy See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints. The following is an update to that discussion. Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue As discussed in the Form 10-K, in February 2023, System Energy submitted a tariff compliance filing with the FERC to clarify that, consistent with the releases provided in the June 2022 MPSC settlement, Entergy Mississippi would continue to be charged for its allocation of the sale-leaseback renewal costs under the Unit Power Sales Agreement. In March 2023 the MPSC filed a protest to System Energy’s tariff compliance filing. The MPSC argued that the settlement did not specifically address post-settlement sale-leaseback renewal costs and that the sale-leaseback renewal costs may not be recovered under the Unit Power Sales Agreement. In February 2025, System Energy and the MPSC resolved their dispute concerning the sale-leaseback renewal costs. As a result, the MPSC withdrew its protest at the FERC on System Energy’s tariff compliance filing. Entergy Mississippi will continue to pay the allocated sale-leaseback renewal costs of approximately $5.7 million annually and there are no refunds due for prior periods. In March 2025, System Energy filed a status report with the FERC explaining that the dispute is resolved. Storm Cost Recovery Filings with Retail Regulators See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following is an update to that discussion. Entergy Louisiana Hurricane Francine In September 2024, Hurricane Francine caused damage to the areas served by Entergy Louisiana. The storm resulted in widespread power outages, primarily due to damage to distribution infrastructure as a result of strong winds and heavy rain, and the loss of sales during the power outages. In December 2024, and subsequently amended in an errata filed in February 2025, Entergy Louisiana submitted an application to the LPSC seeking a determination that approximately $183.6 million in storm restoration costs associated with Hurricane Francine were reasonable and necessary and, therefore, eligible for recovery from customers, as well as approval to recover approximately $3.6 million in certain carrying costs from customers. In February 2025, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting a revenue increase of $17.8 million from funds approved by the LPSC (on an interim basis) for Hurricane Francine recovery costs. The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the 2023 formula rate plan filing above. Also in February 2025, Entergy Louisiana withdrew $33.5 million from its funded storm reserves. In March 2025 a status conference was held in which a procedural schedule was established including a hearing in November 2025.
Entergy Arkansas [Member] |
Public Utilities Disclosure [Text Block] | RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2025, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.00882 per kWh to $0.01333 per kWh. The annual redetermination included a credit related to the remaining balance due to retail customers from the System Energy settlement with the APSC, plus carrying charges and interest. See “Retail Rate Proceedings - Filings with the APSC (Entergy Arkansas) - Retail Rates - Grand Gulf Credit Rider” below for further discussion. The primary reason for the rate increase is an adjustment to account for projected increases in natural gas prices in 2025. This adjustment is expected to reduce the rate change that will be reflected in its 2026 energy cost rate redetermination. The redetermined rate of $0.01333 per kWh became effective with the first billing cycle in April 2025 through the normal operation of the tariff. Entergy Louisiana As discussed in the Form 10-K, in January 2023 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2021 through 2022. In April 2025 the LPSC staff issued its audit report (for Entergy Louisiana’s gas operations), which included several prospective recommendations but no financial disallowances. The next procedural step is for the LPSC to review the report; however there is no deadline for completion of the LPSC’s review. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates Grand Gulf Credit Rider As discussed in the Form 10-K, in June 2024, Entergy Arkansas filed with the APSC a tariff to provide retail customers a credit resulting from the terms of the settlement agreement between Entergy Arkansas, System Energy, additional named Entergy parties, and the APSC pertaining to System Energy’s billings for wholesale sales of energy and capacity from the Grand Gulf nuclear plant. See “Complaints Against System Energy - System Energy Settlement with the APSC” in Note 2 to the financial statements in the Form 10-K for discussion of the System Energy settlement with the APSC. In July 2024 the APSC approved the tariff, under which Entergy Arkansas would refund to retail customers a total of $100.6 million. Entergy Arkansas refunded $92.3 million of the total through one-time bill credits under the Grand Gulf credit rider during the August 2024 billing cycle. In March 2025, Entergy Arkansas included the remaining balance as a credit to retail customers in its energy cost recovery rider rate redetermination filing. See further discussion within "Regulatory Assets and Regulatory Liabilities - Fuel and purchased power cost recovery - Entergy Arkansas - Energy Cost Recovery Rider" above. In April 2025 the APSC approved Entergy Arkansas’s proposal to include the remaining balance in its energy cost recovery rider effective with the first billing cycle of April 2025 and the withdrawal of the Grand Gulf credit rider after all credits have been issued. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2023 Formula Rate Plan Filing As discussed in the Form 10-K, in August 2024, pursuant to the global stipulated settlement agreement, Entergy Louisiana filed its formula rate plan evaluation report for its 2023 calendar year operations. Consistent with the global stipulated settlement agreement, the filing reflected a 9.7% allowed return on common equity with a bandwidth of 40 basis points above and below the midpoint. For the 2023 test year, however, the bandwidth provisions of the formula rate plan are temporarily suspended and, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana implemented the September 2024 formula rate plan rate adjustments effective with the first billing cycle of September 2024. In January 2025, Entergy Louisiana and the LPSC filed a joint report indicating that no disputed issues remained in the proceeding and requesting that the LPSC issue an order accepting Entergy Louisiana’s evaluation report and, ultimately, resolving this matter. In March 2025 the LPSC issued an order accepting the evaluation report. In December 2024, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed an interim rate adjustment for the 2023 test year reflecting the return of $25.1 million of refunds from the System Energy settlement with the LPSC to customers from January through August 2025. In February 2025, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting the divestiture of Entergy Louisiana’s share of Grand Gulf capacity and energy, which was effective as of January 1, 2025. The second interim rate adjustment also reflected a revenue increase of $17.8 million for the recovery of Hurricane Francine costs as approved by the LPSC (on an interim basis). The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the Hurricane Francine proceeding in “Storm Cost Recovery Filings with Retail Regulators – Entergy Louisiana – Hurricane Francine” below. See Note 8 to the financial statements in the Form 10-K for discussion of Entergy Louisiana’s divestiture from the Unit Power Sales Agreement. Additional Generation and Transmission Resources As discussed in the Form 10-K, in October 2024, Entergy Louisiana filed an application with the LPSC seeking approval of a variety of generation and transmission resources proposed in connection with establishing service to a new data center to be developed by a subsidiary of Meta Platforms, Inc. in north Louisiana, for which an electric service agreement has been executed. The filing requests LPSC certification of three new combined cycle combustion turbine generation resources totaling 2,262 MW, each of which will be enabled for future carbon capture and storage, a new 500 kV transmission line, and 500 kV substation upgrades. The application also requests approval to implement a corporate sustainability rider applicable to the new customer. The corporate sustainability rider contemplates the new customer contributing to the costs of the future addition of 1,500 MW of new solar and energy storage resources, agreements involving carbon capture and storage at Entergy Louisiana’s existing Lake Charles Power Station, and potential future wind and nuclear resources. Entergy Louisiana anticipates funding the incremental cost to serve the customer through direct financial contributions from the customer and the revenues it expects to earn under the electric service agreement. The electric service agreement also contains provisions for termination payments that will help ensure that there is no harm to Entergy Louisiana and its customers in the event of early termination. A directive was issued at the LPSC’s November 2024 meeting for the matter to be decided by October 2025. In February 2025 intervenors filed a motion asking the LPSC to deny Entergy Louisiana’s requested exemption from the LPSC’s order addressing competitive solicitation procedures and further asking the LPSC to dismiss the application. The ALJ issued an order denying the motion to dismiss the application and deferring the LPSC’s consideration of the motion regarding the competitive solicitation procedures until the hearing. In March 2025 the same intervenors filed a motion requesting the LPSC to require the customer and its parent company to be joined as parties to the proceeding or dismiss the application. In April 2025 the ALJ issued an order denying the March 2025 motion, and the moving parties filed a motion asking the LPSC to review and reverse the ALJ’s decision. In April 2025 the LPSC staff and intervenors filed direct testimony. The LPSC staff’s testimony discusses the significant projected benefits associated with the data center project and also recommends that the LPSC impose certain conditions on its approval, including a condition that would require, under specified circumstances, certain sharing of net revenues from service to the project with Entergy Louisiana’s other customers. The LPSC staff also recommends that the LPSC deny approval of the corporate sustainability rider terms providing for the customer to supply funding toward the cost of installing carbon capture and storage infrastructure at Entergy Louisiana’s Lake Charles Power Station. The Louisiana Energy Users Group and other intervenors recommended that the LPSC require various changes to the terms of the electric service agreement with the customer that would shift additional risk and cost to the customer rather than Entergy Louisiana’s broader customer base. Certain intervenors also challenged approval on the basis that Entergy Louisiana did not conduct a request for proposals to procure the proposed generation resources to serve the customer’s project; these intervenors also advocate that Entergy Louisiana be required to procure more renewable generation and evaluate transmission alternatives rather than proceeding with development of all of the proposed new generation resources. Entergy Louisiana’s rebuttal testimony is due in May 2025, and a hearing is set for July 2025. Filings with the MPSC (Entergy Mississippi) Retail Rates 2025 Formula Rate Plan Filing In February 2025, Entergy Mississippi submitted its formula rate plan 2025 test year filing and 2024 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2024 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2025 calendar year to also be within the formula rate plan bandwidth. The 2025 test year filing resulted in an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2024 look-back filing compared actual 2024 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues, although Entergy Mississippi proposes to adjust interim rates by $135 thousand to reflect two outside-the-bandwidth changes: (1) the completion of Entergy Mississippi’s return to customers of credits under its restructuring credit rider; and (2) a true-up of demand side management costs. A final order is expected in second quarter 2025. Interim Facilities Rate Adjustments In May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with state legislation passed in January 2024. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed the first of its annual interim facilities rate adjustment reports in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Entergy Mississippi filed its second interim facilities rate adjustment report in November 2024 to recover approximately $46.7 million of these costs over a 12-month period with rates effective beginning in January 2025. In February 2025, Entergy Mississippi filed a true-up interim facilities rate adjustment report to the initial annual interim facilities rate adjustment report filed in May 2024, reflecting the recovery of an additional approximately $1.0 million of costs over a 12-month period with rates effective with the first billing cycle of April 2025. Filings with the City Council (Entergy New Orleans) Retail Rates 2025 Formula Rate Plan Filing In April 2025, Entergy New Orleans submitted to the City Council its formula rate plan 2024 test year filing. The 2024 evaluation report produced an electric earned return on equity of 10.98% and a gas earned return on equity of 8.96% compared to the authorized return on equity for each of 9.35%. Without adjustments, this would result in a decrease in electric rates of $13.8 million and no change in gas rates. The decrease in electric rates is driven by the realignment of regulatory liabilities into the formula from a separate rate mechanism, partially offset by the cost of known and measurable electric capital additions. The filing also commences the previously authorized recovery of certain regulatory costs and requests a revenue-neutral recovery to offset a proposed reduction in bill payment late fees. Taking into account these proposed adjustments, the filing presents a decrease in authorized electric revenues of $8.6 million and an increase in authorized gas revenues of $0.5 million. The filing is subject to a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. For any disputed rate adjustments, however, the City Council would set a procedural schedule to resolve. Resulting rates will be effective with the first billing cycle of September 2025 pursuant to the formula rate plan tariff. Filings with the PUCT and Texas Cities (Entergy Texas) Retail Rates Distribution Cost Recovery Factor (DCRF) Rider In April 2025, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $77.8 million annually, or $29.3 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between July 1, 2024 and December 31, 2024, including distribution-related restoration costs associated with Hurricane Beryl. Transmission Cost Recovery Factor (TCRF) Rider As discussed in the Form 10-K, in October 2024, Entergy Texas filed with the PUCT a request to amend its TCRF rider, which was previously reset to zero in June 2023 as a result of the 2022 base rate case. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $9.7 million annually based on its capital invested in transmission between January 1, 2022 and June 30, 2024 and changes in other transmission charges. In April 2025 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 7, 2025. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s denial of recovery of $135 million of payments to other Utility operating companies in December 2018 relating to off-system sales of electricity from 2002-2009, as ordered by the FERC. The complaint also involved a challenge to the $13.7 million, plus interest, of related refunds ordered by the APSC and paid by Entergy Arkansas in August 2020. The trial was held in February 2023. In March 2024 the U.S. District Court for the Eastern District of Arkansas issued a judgment in favor of the APSC and against Entergy Arkansas. In March 2024 Entergy Arkansas filed a notice of appeal and a motion to expedite oral arguments with the United States Court of Appeals for the Eighth Circuit and the court granted the motion to expedite. As a result of the adverse decision by the U.S. District Court for the Eastern District of Arkansas, Entergy Arkansas concluded that it could no longer support the recognition of its $131.8 million regulatory asset reflecting the previously-expected recovery of a portion of the costs at issue in the opportunity sales proceeding and recorded a $131.8 million ($99.1 million net-of-tax) charge to earnings in first quarter 2024. In December 2024 the United States Court of Appeals for the Eighth Circuit affirmed the decision of the U.S. District Court for the Eastern District of Arkansas, and Entergy Arkansas filed a petition for rehearing en banc. In January 2025 the United States Court of Appeals for the Eighth Circuit denied Entergy Arkansas’s petition. In April 2025, Entergy Arkansas filed a petition for certiorari with the United States Supreme Court. MSS-4 Replacement Tariff - Net Operating Loss Carryforward Proceeding See Note 2 to the financial statements in the Form 10-K for discussion of the MSS-4 replacement tariff net operating loss carryforward proceeding. The MSS-4 replacement tariff, a tariff governing the sales of energy and capacity among the Utility operating companies, includes protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In April 2025, pursuant to such protocols, the City Council filed with the FERC a formal challenge relating to Entergy Services’ inclusion and allocation of net operating loss carryforward accumulated deferred income taxes in the MSS-4 replacement tariff rates charged to Entergy New Orleans’s monthly bills for calendar year 2023. Entergy Services plans to file a response to the formal challenge by the May 2025 deadline. Complaints Against System Energy See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints. The following is an update to that discussion. Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue As discussed in the Form 10-K, in February 2023, System Energy submitted a tariff compliance filing with the FERC to clarify that, consistent with the releases provided in the June 2022 MPSC settlement, Entergy Mississippi would continue to be charged for its allocation of the sale-leaseback renewal costs under the Unit Power Sales Agreement. In March 2023 the MPSC filed a protest to System Energy’s tariff compliance filing. The MPSC argued that the settlement did not specifically address post-settlement sale-leaseback renewal costs and that the sale-leaseback renewal costs may not be recovered under the Unit Power Sales Agreement. In February 2025, System Energy and the MPSC resolved their dispute concerning the sale-leaseback renewal costs. As a result, the MPSC withdrew its protest at the FERC on System Energy’s tariff compliance filing. Entergy Mississippi will continue to pay the allocated sale-leaseback renewal costs of approximately $5.7 million annually and there are no refunds due for prior periods. In March 2025, System Energy filed a status report with the FERC explaining that the dispute is resolved. Storm Cost Recovery Filings with Retail Regulators See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following is an update to that discussion. Entergy Louisiana Hurricane Francine In September 2024, Hurricane Francine caused damage to the areas served by Entergy Louisiana. The storm resulted in widespread power outages, primarily due to damage to distribution infrastructure as a result of strong winds and heavy rain, and the loss of sales during the power outages. In December 2024, and subsequently amended in an errata filed in February 2025, Entergy Louisiana submitted an application to the LPSC seeking a determination that approximately $183.6 million in storm restoration costs associated with Hurricane Francine were reasonable and necessary and, therefore, eligible for recovery from customers, as well as approval to recover approximately $3.6 million in certain carrying costs from customers. In February 2025, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting a revenue increase of $17.8 million from funds approved by the LPSC (on an interim basis) for Hurricane Francine recovery costs. The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the 2023 formula rate plan filing above. Also in February 2025, Entergy Louisiana withdrew $33.5 million from its funded storm reserves. In March 2025 a status conference was held in which a procedural schedule was established including a hearing in November 2025.
Entergy Louisiana [Member] |
Public Utilities Disclosure [Text Block] | RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2025, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.00882 per kWh to $0.01333 per kWh. The annual redetermination included a credit related to the remaining balance due to retail customers from the System Energy settlement with the APSC, plus carrying charges and interest. See “Retail Rate Proceedings - Filings with the APSC (Entergy Arkansas) - Retail Rates - Grand Gulf Credit Rider” below for further discussion. The primary reason for the rate increase is an adjustment to account for projected increases in natural gas prices in 2025. This adjustment is expected to reduce the rate change that will be reflected in its 2026 energy cost rate redetermination. The redetermined rate of $0.01333 per kWh became effective with the first billing cycle in April 2025 through the normal operation of the tariff. Entergy Louisiana As discussed in the Form 10-K, in January 2023 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2021 through 2022. In April 2025 the LPSC staff issued its audit report (for Entergy Louisiana’s gas operations), which included several prospective recommendations but no financial disallowances. The next procedural step is for the LPSC to review the report; however there is no deadline for completion of the LPSC’s review. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates Grand Gulf Credit Rider As discussed in the Form 10-K, in June 2024, Entergy Arkansas filed with the APSC a tariff to provide retail customers a credit resulting from the terms of the settlement agreement between Entergy Arkansas, System Energy, additional named Entergy parties, and the APSC pertaining to System Energy’s billings for wholesale sales of energy and capacity from the Grand Gulf nuclear plant. See “Complaints Against System Energy - System Energy Settlement with the APSC” in Note 2 to the financial statements in the Form 10-K for discussion of the System Energy settlement with the APSC. In July 2024 the APSC approved the tariff, under which Entergy Arkansas would refund to retail customers a total of $100.6 million. Entergy Arkansas refunded $92.3 million of the total through one-time bill credits under the Grand Gulf credit rider during the August 2024 billing cycle. In March 2025, Entergy Arkansas included the remaining balance as a credit to retail customers in its energy cost recovery rider rate redetermination filing. See further discussion within "Regulatory Assets and Regulatory Liabilities - Fuel and purchased power cost recovery - Entergy Arkansas - Energy Cost Recovery Rider" above. In April 2025 the APSC approved Entergy Arkansas’s proposal to include the remaining balance in its energy cost recovery rider effective with the first billing cycle of April 2025 and the withdrawal of the Grand Gulf credit rider after all credits have been issued. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2023 Formula Rate Plan Filing As discussed in the Form 10-K, in August 2024, pursuant to the global stipulated settlement agreement, Entergy Louisiana filed its formula rate plan evaluation report for its 2023 calendar year operations. Consistent with the global stipulated settlement agreement, the filing reflected a 9.7% allowed return on common equity with a bandwidth of 40 basis points above and below the midpoint. For the 2023 test year, however, the bandwidth provisions of the formula rate plan are temporarily suspended and, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana implemented the September 2024 formula rate plan rate adjustments effective with the first billing cycle of September 2024. In January 2025, Entergy Louisiana and the LPSC filed a joint report indicating that no disputed issues remained in the proceeding and requesting that the LPSC issue an order accepting Entergy Louisiana’s evaluation report and, ultimately, resolving this matter. In March 2025 the LPSC issued an order accepting the evaluation report. In December 2024, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed an interim rate adjustment for the 2023 test year reflecting the return of $25.1 million of refunds from the System Energy settlement with the LPSC to customers from January through August 2025. In February 2025, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting the divestiture of Entergy Louisiana’s share of Grand Gulf capacity and energy, which was effective as of January 1, 2025. The second interim rate adjustment also reflected a revenue increase of $17.8 million for the recovery of Hurricane Francine costs as approved by the LPSC (on an interim basis). The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the Hurricane Francine proceeding in “Storm Cost Recovery Filings with Retail Regulators – Entergy Louisiana – Hurricane Francine” below. See Note 8 to the financial statements in the Form 10-K for discussion of Entergy Louisiana’s divestiture from the Unit Power Sales Agreement. Additional Generation and Transmission Resources As discussed in the Form 10-K, in October 2024, Entergy Louisiana filed an application with the LPSC seeking approval of a variety of generation and transmission resources proposed in connection with establishing service to a new data center to be developed by a subsidiary of Meta Platforms, Inc. in north Louisiana, for which an electric service agreement has been executed. The filing requests LPSC certification of three new combined cycle combustion turbine generation resources totaling 2,262 MW, each of which will be enabled for future carbon capture and storage, a new 500 kV transmission line, and 500 kV substation upgrades. The application also requests approval to implement a corporate sustainability rider applicable to the new customer. The corporate sustainability rider contemplates the new customer contributing to the costs of the future addition of 1,500 MW of new solar and energy storage resources, agreements involving carbon capture and storage at Entergy Louisiana’s existing Lake Charles Power Station, and potential future wind and nuclear resources. Entergy Louisiana anticipates funding the incremental cost to serve the customer through direct financial contributions from the customer and the revenues it expects to earn under the electric service agreement. The electric service agreement also contains provisions for termination payments that will help ensure that there is no harm to Entergy Louisiana and its customers in the event of early termination. A directive was issued at the LPSC’s November 2024 meeting for the matter to be decided by October 2025. In February 2025 intervenors filed a motion asking the LPSC to deny Entergy Louisiana’s requested exemption from the LPSC’s order addressing competitive solicitation procedures and further asking the LPSC to dismiss the application. The ALJ issued an order denying the motion to dismiss the application and deferring the LPSC’s consideration of the motion regarding the competitive solicitation procedures until the hearing. In March 2025 the same intervenors filed a motion requesting the LPSC to require the customer and its parent company to be joined as parties to the proceeding or dismiss the application. In April 2025 the ALJ issued an order denying the March 2025 motion, and the moving parties filed a motion asking the LPSC to review and reverse the ALJ’s decision. In April 2025 the LPSC staff and intervenors filed direct testimony. The LPSC staff’s testimony discusses the significant projected benefits associated with the data center project and also recommends that the LPSC impose certain conditions on its approval, including a condition that would require, under specified circumstances, certain sharing of net revenues from service to the project with Entergy Louisiana’s other customers. The LPSC staff also recommends that the LPSC deny approval of the corporate sustainability rider terms providing for the customer to supply funding toward the cost of installing carbon capture and storage infrastructure at Entergy Louisiana’s Lake Charles Power Station. The Louisiana Energy Users Group and other intervenors recommended that the LPSC require various changes to the terms of the electric service agreement with the customer that would shift additional risk and cost to the customer rather than Entergy Louisiana’s broader customer base. Certain intervenors also challenged approval on the basis that Entergy Louisiana did not conduct a request for proposals to procure the proposed generation resources to serve the customer’s project; these intervenors also advocate that Entergy Louisiana be required to procure more renewable generation and evaluate transmission alternatives rather than proceeding with development of all of the proposed new generation resources. Entergy Louisiana’s rebuttal testimony is due in May 2025, and a hearing is set for July 2025. Filings with the MPSC (Entergy Mississippi) Retail Rates 2025 Formula Rate Plan Filing In February 2025, Entergy Mississippi submitted its formula rate plan 2025 test year filing and 2024 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2024 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2025 calendar year to also be within the formula rate plan bandwidth. The 2025 test year filing resulted in an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2024 look-back filing compared actual 2024 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues, although Entergy Mississippi proposes to adjust interim rates by $135 thousand to reflect two outside-the-bandwidth changes: (1) the completion of Entergy Mississippi’s return to customers of credits under its restructuring credit rider; and (2) a true-up of demand side management costs. A final order is expected in second quarter 2025. Interim Facilities Rate Adjustments In May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with state legislation passed in January 2024. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed the first of its annual interim facilities rate adjustment reports in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Entergy Mississippi filed its second interim facilities rate adjustment report in November 2024 to recover approximately $46.7 million of these costs over a 12-month period with rates effective beginning in January 2025. In February 2025, Entergy Mississippi filed a true-up interim facilities rate adjustment report to the initial annual interim facilities rate adjustment report filed in May 2024, reflecting the recovery of an additional approximately $1.0 million of costs over a 12-month period with rates effective with the first billing cycle of April 2025. Filings with the City Council (Entergy New Orleans) Retail Rates 2025 Formula Rate Plan Filing In April 2025, Entergy New Orleans submitted to the City Council its formula rate plan 2024 test year filing. The 2024 evaluation report produced an electric earned return on equity of 10.98% and a gas earned return on equity of 8.96% compared to the authorized return on equity for each of 9.35%. Without adjustments, this would result in a decrease in electric rates of $13.8 million and no change in gas rates. The decrease in electric rates is driven by the realignment of regulatory liabilities into the formula from a separate rate mechanism, partially offset by the cost of known and measurable electric capital additions. The filing also commences the previously authorized recovery of certain regulatory costs and requests a revenue-neutral recovery to offset a proposed reduction in bill payment late fees. Taking into account these proposed adjustments, the filing presents a decrease in authorized electric revenues of $8.6 million and an increase in authorized gas revenues of $0.5 million. The filing is subject to a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. For any disputed rate adjustments, however, the City Council would set a procedural schedule to resolve. Resulting rates will be effective with the first billing cycle of September 2025 pursuant to the formula rate plan tariff. Filings with the PUCT and Texas Cities (Entergy Texas) Retail Rates Distribution Cost Recovery Factor (DCRF) Rider In April 2025, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $77.8 million annually, or $29.3 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between July 1, 2024 and December 31, 2024, including distribution-related restoration costs associated with Hurricane Beryl. Transmission Cost Recovery Factor (TCRF) Rider As discussed in the Form 10-K, in October 2024, Entergy Texas filed with the PUCT a request to amend its TCRF rider, which was previously reset to zero in June 2023 as a result of the 2022 base rate case. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $9.7 million annually based on its capital invested in transmission between January 1, 2022 and June 30, 2024 and changes in other transmission charges. In April 2025 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 7, 2025. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s denial of recovery of $135 million of payments to other Utility operating companies in December 2018 relating to off-system sales of electricity from 2002-2009, as ordered by the FERC. The complaint also involved a challenge to the $13.7 million, plus interest, of related refunds ordered by the APSC and paid by Entergy Arkansas in August 2020. The trial was held in February 2023. In March 2024 the U.S. District Court for the Eastern District of Arkansas issued a judgment in favor of the APSC and against Entergy Arkansas. In March 2024 Entergy Arkansas filed a notice of appeal and a motion to expedite oral arguments with the United States Court of Appeals for the Eighth Circuit and the court granted the motion to expedite. As a result of the adverse decision by the U.S. District Court for the Eastern District of Arkansas, Entergy Arkansas concluded that it could no longer support the recognition of its $131.8 million regulatory asset reflecting the previously-expected recovery of a portion of the costs at issue in the opportunity sales proceeding and recorded a $131.8 million ($99.1 million net-of-tax) charge to earnings in first quarter 2024. In December 2024 the United States Court of Appeals for the Eighth Circuit affirmed the decision of the U.S. District Court for the Eastern District of Arkansas, and Entergy Arkansas filed a petition for rehearing en banc. In January 2025 the United States Court of Appeals for the Eighth Circuit denied Entergy Arkansas’s petition. In April 2025, Entergy Arkansas filed a petition for certiorari with the United States Supreme Court. MSS-4 Replacement Tariff - Net Operating Loss Carryforward Proceeding See Note 2 to the financial statements in the Form 10-K for discussion of the MSS-4 replacement tariff net operating loss carryforward proceeding. The MSS-4 replacement tariff, a tariff governing the sales of energy and capacity among the Utility operating companies, includes protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In April 2025, pursuant to such protocols, the City Council filed with the FERC a formal challenge relating to Entergy Services’ inclusion and allocation of net operating loss carryforward accumulated deferred income taxes in the MSS-4 replacement tariff rates charged to Entergy New Orleans’s monthly bills for calendar year 2023. Entergy Services plans to file a response to the formal challenge by the May 2025 deadline. Complaints Against System Energy See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints. The following is an update to that discussion. Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue As discussed in the Form 10-K, in February 2023, System Energy submitted a tariff compliance filing with the FERC to clarify that, consistent with the releases provided in the June 2022 MPSC settlement, Entergy Mississippi would continue to be charged for its allocation of the sale-leaseback renewal costs under the Unit Power Sales Agreement. In March 2023 the MPSC filed a protest to System Energy’s tariff compliance filing. The MPSC argued that the settlement did not specifically address post-settlement sale-leaseback renewal costs and that the sale-leaseback renewal costs may not be recovered under the Unit Power Sales Agreement. In February 2025, System Energy and the MPSC resolved their dispute concerning the sale-leaseback renewal costs. As a result, the MPSC withdrew its protest at the FERC on System Energy’s tariff compliance filing. Entergy Mississippi will continue to pay the allocated sale-leaseback renewal costs of approximately $5.7 million annually and there are no refunds due for prior periods. In March 2025, System Energy filed a status report with the FERC explaining that the dispute is resolved. Storm Cost Recovery Filings with Retail Regulators See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following is an update to that discussion. Entergy Louisiana Hurricane Francine In September 2024, Hurricane Francine caused damage to the areas served by Entergy Louisiana. The storm resulted in widespread power outages, primarily due to damage to distribution infrastructure as a result of strong winds and heavy rain, and the loss of sales during the power outages. In December 2024, and subsequently amended in an errata filed in February 2025, Entergy Louisiana submitted an application to the LPSC seeking a determination that approximately $183.6 million in storm restoration costs associated with Hurricane Francine were reasonable and necessary and, therefore, eligible for recovery from customers, as well as approval to recover approximately $3.6 million in certain carrying costs from customers. In February 2025, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting a revenue increase of $17.8 million from funds approved by the LPSC (on an interim basis) for Hurricane Francine recovery costs. The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the 2023 formula rate plan filing above. Also in February 2025, Entergy Louisiana withdrew $33.5 million from its funded storm reserves. In March 2025 a status conference was held in which a procedural schedule was established including a hearing in November 2025.
Entergy Mississippi [Member] |
Public Utilities Disclosure [Text Block] | RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2025, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.00882 per kWh to $0.01333 per kWh. The annual redetermination included a credit related to the remaining balance due to retail customers from the System Energy settlement with the APSC, plus carrying charges and interest. See “Retail Rate Proceedings - Filings with the APSC (Entergy Arkansas) - Retail Rates - Grand Gulf Credit Rider” below for further discussion. The primary reason for the rate increase is an adjustment to account for projected increases in natural gas prices in 2025. This adjustment is expected to reduce the rate change that will be reflected in its 2026 energy cost rate redetermination. The redetermined rate of $0.01333 per kWh became effective with the first billing cycle in April 2025 through the normal operation of the tariff. Entergy Louisiana As discussed in the Form 10-K, in January 2023 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2021 through 2022. In April 2025 the LPSC staff issued its audit report (for Entergy Louisiana’s gas operations), which included several prospective recommendations but no financial disallowances. The next procedural step is for the LPSC to review the report; however there is no deadline for completion of the LPSC’s review. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates Grand Gulf Credit Rider As discussed in the Form 10-K, in June 2024, Entergy Arkansas filed with the APSC a tariff to provide retail customers a credit resulting from the terms of the settlement agreement between Entergy Arkansas, System Energy, additional named Entergy parties, and the APSC pertaining to System Energy’s billings for wholesale sales of energy and capacity from the Grand Gulf nuclear plant. See “Complaints Against System Energy - System Energy Settlement with the APSC” in Note 2 to the financial statements in the Form 10-K for discussion of the System Energy settlement with the APSC. In July 2024 the APSC approved the tariff, under which Entergy Arkansas would refund to retail customers a total of $100.6 million. Entergy Arkansas refunded $92.3 million of the total through one-time bill credits under the Grand Gulf credit rider during the August 2024 billing cycle. In March 2025, Entergy Arkansas included the remaining balance as a credit to retail customers in its energy cost recovery rider rate redetermination filing. See further discussion within "Regulatory Assets and Regulatory Liabilities - Fuel and purchased power cost recovery - Entergy Arkansas - Energy Cost Recovery Rider" above. In April 2025 the APSC approved Entergy Arkansas’s proposal to include the remaining balance in its energy cost recovery rider effective with the first billing cycle of April 2025 and the withdrawal of the Grand Gulf credit rider after all credits have been issued. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2023 Formula Rate Plan Filing As discussed in the Form 10-K, in August 2024, pursuant to the global stipulated settlement agreement, Entergy Louisiana filed its formula rate plan evaluation report for its 2023 calendar year operations. Consistent with the global stipulated settlement agreement, the filing reflected a 9.7% allowed return on common equity with a bandwidth of 40 basis points above and below the midpoint. For the 2023 test year, however, the bandwidth provisions of the formula rate plan are temporarily suspended and, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana implemented the September 2024 formula rate plan rate adjustments effective with the first billing cycle of September 2024. In January 2025, Entergy Louisiana and the LPSC filed a joint report indicating that no disputed issues remained in the proceeding and requesting that the LPSC issue an order accepting Entergy Louisiana’s evaluation report and, ultimately, resolving this matter. In March 2025 the LPSC issued an order accepting the evaluation report. In December 2024, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed an interim rate adjustment for the 2023 test year reflecting the return of $25.1 million of refunds from the System Energy settlement with the LPSC to customers from January through August 2025. In February 2025, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting the divestiture of Entergy Louisiana’s share of Grand Gulf capacity and energy, which was effective as of January 1, 2025. The second interim rate adjustment also reflected a revenue increase of $17.8 million for the recovery of Hurricane Francine costs as approved by the LPSC (on an interim basis). The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the Hurricane Francine proceeding in “Storm Cost Recovery Filings with Retail Regulators – Entergy Louisiana – Hurricane Francine” below. See Note 8 to the financial statements in the Form 10-K for discussion of Entergy Louisiana’s divestiture from the Unit Power Sales Agreement. Additional Generation and Transmission Resources As discussed in the Form 10-K, in October 2024, Entergy Louisiana filed an application with the LPSC seeking approval of a variety of generation and transmission resources proposed in connection with establishing service to a new data center to be developed by a subsidiary of Meta Platforms, Inc. in north Louisiana, for which an electric service agreement has been executed. The filing requests LPSC certification of three new combined cycle combustion turbine generation resources totaling 2,262 MW, each of which will be enabled for future carbon capture and storage, a new 500 kV transmission line, and 500 kV substation upgrades. The application also requests approval to implement a corporate sustainability rider applicable to the new customer. The corporate sustainability rider contemplates the new customer contributing to the costs of the future addition of 1,500 MW of new solar and energy storage resources, agreements involving carbon capture and storage at Entergy Louisiana’s existing Lake Charles Power Station, and potential future wind and nuclear resources. Entergy Louisiana anticipates funding the incremental cost to serve the customer through direct financial contributions from the customer and the revenues it expects to earn under the electric service agreement. The electric service agreement also contains provisions for termination payments that will help ensure that there is no harm to Entergy Louisiana and its customers in the event of early termination. A directive was issued at the LPSC’s November 2024 meeting for the matter to be decided by October 2025. In February 2025 intervenors filed a motion asking the LPSC to deny Entergy Louisiana’s requested exemption from the LPSC’s order addressing competitive solicitation procedures and further asking the LPSC to dismiss the application. The ALJ issued an order denying the motion to dismiss the application and deferring the LPSC’s consideration of the motion regarding the competitive solicitation procedures until the hearing. In March 2025 the same intervenors filed a motion requesting the LPSC to require the customer and its parent company to be joined as parties to the proceeding or dismiss the application. In April 2025 the ALJ issued an order denying the March 2025 motion, and the moving parties filed a motion asking the LPSC to review and reverse the ALJ’s decision. In April 2025 the LPSC staff and intervenors filed direct testimony. The LPSC staff’s testimony discusses the significant projected benefits associated with the data center project and also recommends that the LPSC impose certain conditions on its approval, including a condition that would require, under specified circumstances, certain sharing of net revenues from service to the project with Entergy Louisiana’s other customers. The LPSC staff also recommends that the LPSC deny approval of the corporate sustainability rider terms providing for the customer to supply funding toward the cost of installing carbon capture and storage infrastructure at Entergy Louisiana’s Lake Charles Power Station. The Louisiana Energy Users Group and other intervenors recommended that the LPSC require various changes to the terms of the electric service agreement with the customer that would shift additional risk and cost to the customer rather than Entergy Louisiana’s broader customer base. Certain intervenors also challenged approval on the basis that Entergy Louisiana did not conduct a request for proposals to procure the proposed generation resources to serve the customer’s project; these intervenors also advocate that Entergy Louisiana be required to procure more renewable generation and evaluate transmission alternatives rather than proceeding with development of all of the proposed new generation resources. Entergy Louisiana’s rebuttal testimony is due in May 2025, and a hearing is set for July 2025. Filings with the MPSC (Entergy Mississippi) Retail Rates 2025 Formula Rate Plan Filing In February 2025, Entergy Mississippi submitted its formula rate plan 2025 test year filing and 2024 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2024 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2025 calendar year to also be within the formula rate plan bandwidth. The 2025 test year filing resulted in an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2024 look-back filing compared actual 2024 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues, although Entergy Mississippi proposes to adjust interim rates by $135 thousand to reflect two outside-the-bandwidth changes: (1) the completion of Entergy Mississippi’s return to customers of credits under its restructuring credit rider; and (2) a true-up of demand side management costs. A final order is expected in second quarter 2025. Interim Facilities Rate Adjustments In May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with state legislation passed in January 2024. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed the first of its annual interim facilities rate adjustment reports in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Entergy Mississippi filed its second interim facilities rate adjustment report in November 2024 to recover approximately $46.7 million of these costs over a 12-month period with rates effective beginning in January 2025. In February 2025, Entergy Mississippi filed a true-up interim facilities rate adjustment report to the initial annual interim facilities rate adjustment report filed in May 2024, reflecting the recovery of an additional approximately $1.0 million of costs over a 12-month period with rates effective with the first billing cycle of April 2025. Filings with the City Council (Entergy New Orleans) Retail Rates 2025 Formula Rate Plan Filing In April 2025, Entergy New Orleans submitted to the City Council its formula rate plan 2024 test year filing. The 2024 evaluation report produced an electric earned return on equity of 10.98% and a gas earned return on equity of 8.96% compared to the authorized return on equity for each of 9.35%. Without adjustments, this would result in a decrease in electric rates of $13.8 million and no change in gas rates. The decrease in electric rates is driven by the realignment of regulatory liabilities into the formula from a separate rate mechanism, partially offset by the cost of known and measurable electric capital additions. The filing also commences the previously authorized recovery of certain regulatory costs and requests a revenue-neutral recovery to offset a proposed reduction in bill payment late fees. Taking into account these proposed adjustments, the filing presents a decrease in authorized electric revenues of $8.6 million and an increase in authorized gas revenues of $0.5 million. The filing is subject to a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. For any disputed rate adjustments, however, the City Council would set a procedural schedule to resolve. Resulting rates will be effective with the first billing cycle of September 2025 pursuant to the formula rate plan tariff. Filings with the PUCT and Texas Cities (Entergy Texas) Retail Rates Distribution Cost Recovery Factor (DCRF) Rider In April 2025, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $77.8 million annually, or $29.3 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between July 1, 2024 and December 31, 2024, including distribution-related restoration costs associated with Hurricane Beryl. Transmission Cost Recovery Factor (TCRF) Rider As discussed in the Form 10-K, in October 2024, Entergy Texas filed with the PUCT a request to amend its TCRF rider, which was previously reset to zero in June 2023 as a result of the 2022 base rate case. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $9.7 million annually based on its capital invested in transmission between January 1, 2022 and June 30, 2024 and changes in other transmission charges. In April 2025 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 7, 2025. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s denial of recovery of $135 million of payments to other Utility operating companies in December 2018 relating to off-system sales of electricity from 2002-2009, as ordered by the FERC. The complaint also involved a challenge to the $13.7 million, plus interest, of related refunds ordered by the APSC and paid by Entergy Arkansas in August 2020. The trial was held in February 2023. In March 2024 the U.S. District Court for the Eastern District of Arkansas issued a judgment in favor of the APSC and against Entergy Arkansas. In March 2024 Entergy Arkansas filed a notice of appeal and a motion to expedite oral arguments with the United States Court of Appeals for the Eighth Circuit and the court granted the motion to expedite. As a result of the adverse decision by the U.S. District Court for the Eastern District of Arkansas, Entergy Arkansas concluded that it could no longer support the recognition of its $131.8 million regulatory asset reflecting the previously-expected recovery of a portion of the costs at issue in the opportunity sales proceeding and recorded a $131.8 million ($99.1 million net-of-tax) charge to earnings in first quarter 2024. In December 2024 the United States Court of Appeals for the Eighth Circuit affirmed the decision of the U.S. District Court for the Eastern District of Arkansas, and Entergy Arkansas filed a petition for rehearing en banc. In January 2025 the United States Court of Appeals for the Eighth Circuit denied Entergy Arkansas’s petition. In April 2025, Entergy Arkansas filed a petition for certiorari with the United States Supreme Court. MSS-4 Replacement Tariff - Net Operating Loss Carryforward Proceeding See Note 2 to the financial statements in the Form 10-K for discussion of the MSS-4 replacement tariff net operating loss carryforward proceeding. The MSS-4 replacement tariff, a tariff governing the sales of energy and capacity among the Utility operating companies, includes protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In April 2025, pursuant to such protocols, the City Council filed with the FERC a formal challenge relating to Entergy Services’ inclusion and allocation of net operating loss carryforward accumulated deferred income taxes in the MSS-4 replacement tariff rates charged to Entergy New Orleans’s monthly bills for calendar year 2023. Entergy Services plans to file a response to the formal challenge by the May 2025 deadline. Complaints Against System Energy See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints. The following is an update to that discussion. Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue As discussed in the Form 10-K, in February 2023, System Energy submitted a tariff compliance filing with the FERC to clarify that, consistent with the releases provided in the June 2022 MPSC settlement, Entergy Mississippi would continue to be charged for its allocation of the sale-leaseback renewal costs under the Unit Power Sales Agreement. In March 2023 the MPSC filed a protest to System Energy’s tariff compliance filing. The MPSC argued that the settlement did not specifically address post-settlement sale-leaseback renewal costs and that the sale-leaseback renewal costs may not be recovered under the Unit Power Sales Agreement. In February 2025, System Energy and the MPSC resolved their dispute concerning the sale-leaseback renewal costs. As a result, the MPSC withdrew its protest at the FERC on System Energy’s tariff compliance filing. Entergy Mississippi will continue to pay the allocated sale-leaseback renewal costs of approximately $5.7 million annually and there are no refunds due for prior periods. In March 2025, System Energy filed a status report with the FERC explaining that the dispute is resolved. Storm Cost Recovery Filings with Retail Regulators See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following is an update to that discussion. Entergy Louisiana Hurricane Francine In September 2024, Hurricane Francine caused damage to the areas served by Entergy Louisiana. The storm resulted in widespread power outages, primarily due to damage to distribution infrastructure as a result of strong winds and heavy rain, and the loss of sales during the power outages. In December 2024, and subsequently amended in an errata filed in February 2025, Entergy Louisiana submitted an application to the LPSC seeking a determination that approximately $183.6 million in storm restoration costs associated with Hurricane Francine were reasonable and necessary and, therefore, eligible for recovery from customers, as well as approval to recover approximately $3.6 million in certain carrying costs from customers. In February 2025, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting a revenue increase of $17.8 million from funds approved by the LPSC (on an interim basis) for Hurricane Francine recovery costs. The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the 2023 formula rate plan filing above. Also in February 2025, Entergy Louisiana withdrew $33.5 million from its funded storm reserves. In March 2025 a status conference was held in which a procedural schedule was established including a hearing in November 2025.
Entergy New Orleans [Member] |
Public Utilities Disclosure [Text Block] | RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2025, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.00882 per kWh to $0.01333 per kWh. The annual redetermination included a credit related to the remaining balance due to retail customers from the System Energy settlement with the APSC, plus carrying charges and interest. See “Retail Rate Proceedings - Filings with the APSC (Entergy Arkansas) - Retail Rates - Grand Gulf Credit Rider” below for further discussion. The primary reason for the rate increase is an adjustment to account for projected increases in natural gas prices in 2025. This adjustment is expected to reduce the rate change that will be reflected in its 2026 energy cost rate redetermination. The redetermined rate of $0.01333 per kWh became effective with the first billing cycle in April 2025 through the normal operation of the tariff. Entergy Louisiana As discussed in the Form 10-K, in January 2023 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2021 through 2022. In April 2025 the LPSC staff issued its audit report (for Entergy Louisiana’s gas operations), which included several prospective recommendations but no financial disallowances. The next procedural step is for the LPSC to review the report; however there is no deadline for completion of the LPSC’s review. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates Grand Gulf Credit Rider As discussed in the Form 10-K, in June 2024, Entergy Arkansas filed with the APSC a tariff to provide retail customers a credit resulting from the terms of the settlement agreement between Entergy Arkansas, System Energy, additional named Entergy parties, and the APSC pertaining to System Energy’s billings for wholesale sales of energy and capacity from the Grand Gulf nuclear plant. See “Complaints Against System Energy - System Energy Settlement with the APSC” in Note 2 to the financial statements in the Form 10-K for discussion of the System Energy settlement with the APSC. In July 2024 the APSC approved the tariff, under which Entergy Arkansas would refund to retail customers a total of $100.6 million. Entergy Arkansas refunded $92.3 million of the total through one-time bill credits under the Grand Gulf credit rider during the August 2024 billing cycle. In March 2025, Entergy Arkansas included the remaining balance as a credit to retail customers in its energy cost recovery rider rate redetermination filing. See further discussion within "Regulatory Assets and Regulatory Liabilities - Fuel and purchased power cost recovery - Entergy Arkansas - Energy Cost Recovery Rider" above. In April 2025 the APSC approved Entergy Arkansas’s proposal to include the remaining balance in its energy cost recovery rider effective with the first billing cycle of April 2025 and the withdrawal of the Grand Gulf credit rider after all credits have been issued. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2023 Formula Rate Plan Filing As discussed in the Form 10-K, in August 2024, pursuant to the global stipulated settlement agreement, Entergy Louisiana filed its formula rate plan evaluation report for its 2023 calendar year operations. Consistent with the global stipulated settlement agreement, the filing reflected a 9.7% allowed return on common equity with a bandwidth of 40 basis points above and below the midpoint. For the 2023 test year, however, the bandwidth provisions of the formula rate plan are temporarily suspended and, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana implemented the September 2024 formula rate plan rate adjustments effective with the first billing cycle of September 2024. In January 2025, Entergy Louisiana and the LPSC filed a joint report indicating that no disputed issues remained in the proceeding and requesting that the LPSC issue an order accepting Entergy Louisiana’s evaluation report and, ultimately, resolving this matter. In March 2025 the LPSC issued an order accepting the evaluation report. In December 2024, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed an interim rate adjustment for the 2023 test year reflecting the return of $25.1 million of refunds from the System Energy settlement with the LPSC to customers from January through August 2025. In February 2025, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting the divestiture of Entergy Louisiana’s share of Grand Gulf capacity and energy, which was effective as of January 1, 2025. The second interim rate adjustment also reflected a revenue increase of $17.8 million for the recovery of Hurricane Francine costs as approved by the LPSC (on an interim basis). The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the Hurricane Francine proceeding in “Storm Cost Recovery Filings with Retail Regulators – Entergy Louisiana – Hurricane Francine” below. See Note 8 to the financial statements in the Form 10-K for discussion of Entergy Louisiana’s divestiture from the Unit Power Sales Agreement. Additional Generation and Transmission Resources As discussed in the Form 10-K, in October 2024, Entergy Louisiana filed an application with the LPSC seeking approval of a variety of generation and transmission resources proposed in connection with establishing service to a new data center to be developed by a subsidiary of Meta Platforms, Inc. in north Louisiana, for which an electric service agreement has been executed. The filing requests LPSC certification of three new combined cycle combustion turbine generation resources totaling 2,262 MW, each of which will be enabled for future carbon capture and storage, a new 500 kV transmission line, and 500 kV substation upgrades. The application also requests approval to implement a corporate sustainability rider applicable to the new customer. The corporate sustainability rider contemplates the new customer contributing to the costs of the future addition of 1,500 MW of new solar and energy storage resources, agreements involving carbon capture and storage at Entergy Louisiana’s existing Lake Charles Power Station, and potential future wind and nuclear resources. Entergy Louisiana anticipates funding the incremental cost to serve the customer through direct financial contributions from the customer and the revenues it expects to earn under the electric service agreement. The electric service agreement also contains provisions for termination payments that will help ensure that there is no harm to Entergy Louisiana and its customers in the event of early termination. A directive was issued at the LPSC’s November 2024 meeting for the matter to be decided by October 2025. In February 2025 intervenors filed a motion asking the LPSC to deny Entergy Louisiana’s requested exemption from the LPSC’s order addressing competitive solicitation procedures and further asking the LPSC to dismiss the application. The ALJ issued an order denying the motion to dismiss the application and deferring the LPSC’s consideration of the motion regarding the competitive solicitation procedures until the hearing. In March 2025 the same intervenors filed a motion requesting the LPSC to require the customer and its parent company to be joined as parties to the proceeding or dismiss the application. In April 2025 the ALJ issued an order denying the March 2025 motion, and the moving parties filed a motion asking the LPSC to review and reverse the ALJ’s decision. In April 2025 the LPSC staff and intervenors filed direct testimony. The LPSC staff’s testimony discusses the significant projected benefits associated with the data center project and also recommends that the LPSC impose certain conditions on its approval, including a condition that would require, under specified circumstances, certain sharing of net revenues from service to the project with Entergy Louisiana’s other customers. The LPSC staff also recommends that the LPSC deny approval of the corporate sustainability rider terms providing for the customer to supply funding toward the cost of installing carbon capture and storage infrastructure at Entergy Louisiana’s Lake Charles Power Station. The Louisiana Energy Users Group and other intervenors recommended that the LPSC require various changes to the terms of the electric service agreement with the customer that would shift additional risk and cost to the customer rather than Entergy Louisiana’s broader customer base. Certain intervenors also challenged approval on the basis that Entergy Louisiana did not conduct a request for proposals to procure the proposed generation resources to serve the customer’s project; these intervenors also advocate that Entergy Louisiana be required to procure more renewable generation and evaluate transmission alternatives rather than proceeding with development of all of the proposed new generation resources. Entergy Louisiana’s rebuttal testimony is due in May 2025, and a hearing is set for July 2025. Filings with the MPSC (Entergy Mississippi) Retail Rates 2025 Formula Rate Plan Filing In February 2025, Entergy Mississippi submitted its formula rate plan 2025 test year filing and 2024 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2024 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2025 calendar year to also be within the formula rate plan bandwidth. The 2025 test year filing resulted in an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2024 look-back filing compared actual 2024 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues, although Entergy Mississippi proposes to adjust interim rates by $135 thousand to reflect two outside-the-bandwidth changes: (1) the completion of Entergy Mississippi’s return to customers of credits under its restructuring credit rider; and (2) a true-up of demand side management costs. A final order is expected in second quarter 2025. Interim Facilities Rate Adjustments In May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with state legislation passed in January 2024. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed the first of its annual interim facilities rate adjustment reports in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Entergy Mississippi filed its second interim facilities rate adjustment report in November 2024 to recover approximately $46.7 million of these costs over a 12-month period with rates effective beginning in January 2025. In February 2025, Entergy Mississippi filed a true-up interim facilities rate adjustment report to the initial annual interim facilities rate adjustment report filed in May 2024, reflecting the recovery of an additional approximately $1.0 million of costs over a 12-month period with rates effective with the first billing cycle of April 2025. Filings with the City Council (Entergy New Orleans) Retail Rates 2025 Formula Rate Plan Filing In April 2025, Entergy New Orleans submitted to the City Council its formula rate plan 2024 test year filing. The 2024 evaluation report produced an electric earned return on equity of 10.98% and a gas earned return on equity of 8.96% compared to the authorized return on equity for each of 9.35%. Without adjustments, this would result in a decrease in electric rates of $13.8 million and no change in gas rates. The decrease in electric rates is driven by the realignment of regulatory liabilities into the formula from a separate rate mechanism, partially offset by the cost of known and measurable electric capital additions. The filing also commences the previously authorized recovery of certain regulatory costs and requests a revenue-neutral recovery to offset a proposed reduction in bill payment late fees. Taking into account these proposed adjustments, the filing presents a decrease in authorized electric revenues of $8.6 million and an increase in authorized gas revenues of $0.5 million. The filing is subject to a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. For any disputed rate adjustments, however, the City Council would set a procedural schedule to resolve. Resulting rates will be effective with the first billing cycle of September 2025 pursuant to the formula rate plan tariff. Filings with the PUCT and Texas Cities (Entergy Texas) Retail Rates Distribution Cost Recovery Factor (DCRF) Rider In April 2025, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $77.8 million annually, or $29.3 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between July 1, 2024 and December 31, 2024, including distribution-related restoration costs associated with Hurricane Beryl. Transmission Cost Recovery Factor (TCRF) Rider As discussed in the Form 10-K, in October 2024, Entergy Texas filed with the PUCT a request to amend its TCRF rider, which was previously reset to zero in June 2023 as a result of the 2022 base rate case. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $9.7 million annually based on its capital invested in transmission between January 1, 2022 and June 30, 2024 and changes in other transmission charges. In April 2025 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 7, 2025. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s denial of recovery of $135 million of payments to other Utility operating companies in December 2018 relating to off-system sales of electricity from 2002-2009, as ordered by the FERC. The complaint also involved a challenge to the $13.7 million, plus interest, of related refunds ordered by the APSC and paid by Entergy Arkansas in August 2020. The trial was held in February 2023. In March 2024 the U.S. District Court for the Eastern District of Arkansas issued a judgment in favor of the APSC and against Entergy Arkansas. In March 2024 Entergy Arkansas filed a notice of appeal and a motion to expedite oral arguments with the United States Court of Appeals for the Eighth Circuit and the court granted the motion to expedite. As a result of the adverse decision by the U.S. District Court for the Eastern District of Arkansas, Entergy Arkansas concluded that it could no longer support the recognition of its $131.8 million regulatory asset reflecting the previously-expected recovery of a portion of the costs at issue in the opportunity sales proceeding and recorded a $131.8 million ($99.1 million net-of-tax) charge to earnings in first quarter 2024. In December 2024 the United States Court of Appeals for the Eighth Circuit affirmed the decision of the U.S. District Court for the Eastern District of Arkansas, and Entergy Arkansas filed a petition for rehearing en banc. In January 2025 the United States Court of Appeals for the Eighth Circuit denied Entergy Arkansas’s petition. In April 2025, Entergy Arkansas filed a petition for certiorari with the United States Supreme Court. MSS-4 Replacement Tariff - Net Operating Loss Carryforward Proceeding See Note 2 to the financial statements in the Form 10-K for discussion of the MSS-4 replacement tariff net operating loss carryforward proceeding. The MSS-4 replacement tariff, a tariff governing the sales of energy and capacity among the Utility operating companies, includes protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In April 2025, pursuant to such protocols, the City Council filed with the FERC a formal challenge relating to Entergy Services’ inclusion and allocation of net operating loss carryforward accumulated deferred income taxes in the MSS-4 replacement tariff rates charged to Entergy New Orleans’s monthly bills for calendar year 2023. Entergy Services plans to file a response to the formal challenge by the May 2025 deadline. Complaints Against System Energy See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints. The following is an update to that discussion. Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue As discussed in the Form 10-K, in February 2023, System Energy submitted a tariff compliance filing with the FERC to clarify that, consistent with the releases provided in the June 2022 MPSC settlement, Entergy Mississippi would continue to be charged for its allocation of the sale-leaseback renewal costs under the Unit Power Sales Agreement. In March 2023 the MPSC filed a protest to System Energy’s tariff compliance filing. The MPSC argued that the settlement did not specifically address post-settlement sale-leaseback renewal costs and that the sale-leaseback renewal costs may not be recovered under the Unit Power Sales Agreement. In February 2025, System Energy and the MPSC resolved their dispute concerning the sale-leaseback renewal costs. As a result, the MPSC withdrew its protest at the FERC on System Energy’s tariff compliance filing. Entergy Mississippi will continue to pay the allocated sale-leaseback renewal costs of approximately $5.7 million annually and there are no refunds due for prior periods. In March 2025, System Energy filed a status report with the FERC explaining that the dispute is resolved. Storm Cost Recovery Filings with Retail Regulators See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following is an update to that discussion. Entergy Louisiana Hurricane Francine In September 2024, Hurricane Francine caused damage to the areas served by Entergy Louisiana. The storm resulted in widespread power outages, primarily due to damage to distribution infrastructure as a result of strong winds and heavy rain, and the loss of sales during the power outages. In December 2024, and subsequently amended in an errata filed in February 2025, Entergy Louisiana submitted an application to the LPSC seeking a determination that approximately $183.6 million in storm restoration costs associated with Hurricane Francine were reasonable and necessary and, therefore, eligible for recovery from customers, as well as approval to recover approximately $3.6 million in certain carrying costs from customers. In February 2025, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting a revenue increase of $17.8 million from funds approved by the LPSC (on an interim basis) for Hurricane Francine recovery costs. The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the 2023 formula rate plan filing above. Also in February 2025, Entergy Louisiana withdrew $33.5 million from its funded storm reserves. In March 2025 a status conference was held in which a procedural schedule was established including a hearing in November 2025.
Entergy Texas [Member] |
Public Utilities Disclosure [Text Block] | RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2025, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.00882 per kWh to $0.01333 per kWh. The annual redetermination included a credit related to the remaining balance due to retail customers from the System Energy settlement with the APSC, plus carrying charges and interest. See “Retail Rate Proceedings - Filings with the APSC (Entergy Arkansas) - Retail Rates - Grand Gulf Credit Rider” below for further discussion. The primary reason for the rate increase is an adjustment to account for projected increases in natural gas prices in 2025. This adjustment is expected to reduce the rate change that will be reflected in its 2026 energy cost rate redetermination. The redetermined rate of $0.01333 per kWh became effective with the first billing cycle in April 2025 through the normal operation of the tariff. Entergy Louisiana As discussed in the Form 10-K, in January 2023 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2021 through 2022. In April 2025 the LPSC staff issued its audit report (for Entergy Louisiana’s gas operations), which included several prospective recommendations but no financial disallowances. The next procedural step is for the LPSC to review the report; however there is no deadline for completion of the LPSC’s review. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates Grand Gulf Credit Rider As discussed in the Form 10-K, in June 2024, Entergy Arkansas filed with the APSC a tariff to provide retail customers a credit resulting from the terms of the settlement agreement between Entergy Arkansas, System Energy, additional named Entergy parties, and the APSC pertaining to System Energy’s billings for wholesale sales of energy and capacity from the Grand Gulf nuclear plant. See “Complaints Against System Energy - System Energy Settlement with the APSC” in Note 2 to the financial statements in the Form 10-K for discussion of the System Energy settlement with the APSC. In July 2024 the APSC approved the tariff, under which Entergy Arkansas would refund to retail customers a total of $100.6 million. Entergy Arkansas refunded $92.3 million of the total through one-time bill credits under the Grand Gulf credit rider during the August 2024 billing cycle. In March 2025, Entergy Arkansas included the remaining balance as a credit to retail customers in its energy cost recovery rider rate redetermination filing. See further discussion within "Regulatory Assets and Regulatory Liabilities - Fuel and purchased power cost recovery - Entergy Arkansas - Energy Cost Recovery Rider" above. In April 2025 the APSC approved Entergy Arkansas’s proposal to include the remaining balance in its energy cost recovery rider effective with the first billing cycle of April 2025 and the withdrawal of the Grand Gulf credit rider after all credits have been issued. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2023 Formula Rate Plan Filing As discussed in the Form 10-K, in August 2024, pursuant to the global stipulated settlement agreement, Entergy Louisiana filed its formula rate plan evaluation report for its 2023 calendar year operations. Consistent with the global stipulated settlement agreement, the filing reflected a 9.7% allowed return on common equity with a bandwidth of 40 basis points above and below the midpoint. For the 2023 test year, however, the bandwidth provisions of the formula rate plan are temporarily suspended and, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana implemented the September 2024 formula rate plan rate adjustments effective with the first billing cycle of September 2024. In January 2025, Entergy Louisiana and the LPSC filed a joint report indicating that no disputed issues remained in the proceeding and requesting that the LPSC issue an order accepting Entergy Louisiana’s evaluation report and, ultimately, resolving this matter. In March 2025 the LPSC issued an order accepting the evaluation report. In December 2024, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed an interim rate adjustment for the 2023 test year reflecting the return of $25.1 million of refunds from the System Energy settlement with the LPSC to customers from January through August 2025. In February 2025, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting the divestiture of Entergy Louisiana’s share of Grand Gulf capacity and energy, which was effective as of January 1, 2025. The second interim rate adjustment also reflected a revenue increase of $17.8 million for the recovery of Hurricane Francine costs as approved by the LPSC (on an interim basis). The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the Hurricane Francine proceeding in “Storm Cost Recovery Filings with Retail Regulators – Entergy Louisiana – Hurricane Francine” below. See Note 8 to the financial statements in the Form 10-K for discussion of Entergy Louisiana’s divestiture from the Unit Power Sales Agreement. Additional Generation and Transmission Resources As discussed in the Form 10-K, in October 2024, Entergy Louisiana filed an application with the LPSC seeking approval of a variety of generation and transmission resources proposed in connection with establishing service to a new data center to be developed by a subsidiary of Meta Platforms, Inc. in north Louisiana, for which an electric service agreement has been executed. The filing requests LPSC certification of three new combined cycle combustion turbine generation resources totaling 2,262 MW, each of which will be enabled for future carbon capture and storage, a new 500 kV transmission line, and 500 kV substation upgrades. The application also requests approval to implement a corporate sustainability rider applicable to the new customer. The corporate sustainability rider contemplates the new customer contributing to the costs of the future addition of 1,500 MW of new solar and energy storage resources, agreements involving carbon capture and storage at Entergy Louisiana’s existing Lake Charles Power Station, and potential future wind and nuclear resources. Entergy Louisiana anticipates funding the incremental cost to serve the customer through direct financial contributions from the customer and the revenues it expects to earn under the electric service agreement. The electric service agreement also contains provisions for termination payments that will help ensure that there is no harm to Entergy Louisiana and its customers in the event of early termination. A directive was issued at the LPSC’s November 2024 meeting for the matter to be decided by October 2025. In February 2025 intervenors filed a motion asking the LPSC to deny Entergy Louisiana’s requested exemption from the LPSC’s order addressing competitive solicitation procedures and further asking the LPSC to dismiss the application. The ALJ issued an order denying the motion to dismiss the application and deferring the LPSC’s consideration of the motion regarding the competitive solicitation procedures until the hearing. In March 2025 the same intervenors filed a motion requesting the LPSC to require the customer and its parent company to be joined as parties to the proceeding or dismiss the application. In April 2025 the ALJ issued an order denying the March 2025 motion, and the moving parties filed a motion asking the LPSC to review and reverse the ALJ’s decision. In April 2025 the LPSC staff and intervenors filed direct testimony. The LPSC staff’s testimony discusses the significant projected benefits associated with the data center project and also recommends that the LPSC impose certain conditions on its approval, including a condition that would require, under specified circumstances, certain sharing of net revenues from service to the project with Entergy Louisiana’s other customers. The LPSC staff also recommends that the LPSC deny approval of the corporate sustainability rider terms providing for the customer to supply funding toward the cost of installing carbon capture and storage infrastructure at Entergy Louisiana’s Lake Charles Power Station. The Louisiana Energy Users Group and other intervenors recommended that the LPSC require various changes to the terms of the electric service agreement with the customer that would shift additional risk and cost to the customer rather than Entergy Louisiana’s broader customer base. Certain intervenors also challenged approval on the basis that Entergy Louisiana did not conduct a request for proposals to procure the proposed generation resources to serve the customer’s project; these intervenors also advocate that Entergy Louisiana be required to procure more renewable generation and evaluate transmission alternatives rather than proceeding with development of all of the proposed new generation resources. Entergy Louisiana’s rebuttal testimony is due in May 2025, and a hearing is set for July 2025. Filings with the MPSC (Entergy Mississippi) Retail Rates 2025 Formula Rate Plan Filing In February 2025, Entergy Mississippi submitted its formula rate plan 2025 test year filing and 2024 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2024 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2025 calendar year to also be within the formula rate plan bandwidth. The 2025 test year filing resulted in an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2024 look-back filing compared actual 2024 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues, although Entergy Mississippi proposes to adjust interim rates by $135 thousand to reflect two outside-the-bandwidth changes: (1) the completion of Entergy Mississippi’s return to customers of credits under its restructuring credit rider; and (2) a true-up of demand side management costs. A final order is expected in second quarter 2025. Interim Facilities Rate Adjustments In May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with state legislation passed in January 2024. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed the first of its annual interim facilities rate adjustment reports in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Entergy Mississippi filed its second interim facilities rate adjustment report in November 2024 to recover approximately $46.7 million of these costs over a 12-month period with rates effective beginning in January 2025. In February 2025, Entergy Mississippi filed a true-up interim facilities rate adjustment report to the initial annual interim facilities rate adjustment report filed in May 2024, reflecting the recovery of an additional approximately $1.0 million of costs over a 12-month period with rates effective with the first billing cycle of April 2025. Filings with the City Council (Entergy New Orleans) Retail Rates 2025 Formula Rate Plan Filing In April 2025, Entergy New Orleans submitted to the City Council its formula rate plan 2024 test year filing. The 2024 evaluation report produced an electric earned return on equity of 10.98% and a gas earned return on equity of 8.96% compared to the authorized return on equity for each of 9.35%. Without adjustments, this would result in a decrease in electric rates of $13.8 million and no change in gas rates. The decrease in electric rates is driven by the realignment of regulatory liabilities into the formula from a separate rate mechanism, partially offset by the cost of known and measurable electric capital additions. The filing also commences the previously authorized recovery of certain regulatory costs and requests a revenue-neutral recovery to offset a proposed reduction in bill payment late fees. Taking into account these proposed adjustments, the filing presents a decrease in authorized electric revenues of $8.6 million and an increase in authorized gas revenues of $0.5 million. The filing is subject to a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. For any disputed rate adjustments, however, the City Council would set a procedural schedule to resolve. Resulting rates will be effective with the first billing cycle of September 2025 pursuant to the formula rate plan tariff. Filings with the PUCT and Texas Cities (Entergy Texas) Retail Rates Distribution Cost Recovery Factor (DCRF) Rider In April 2025, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $77.8 million annually, or $29.3 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between July 1, 2024 and December 31, 2024, including distribution-related restoration costs associated with Hurricane Beryl. Transmission Cost Recovery Factor (TCRF) Rider As discussed in the Form 10-K, in October 2024, Entergy Texas filed with the PUCT a request to amend its TCRF rider, which was previously reset to zero in June 2023 as a result of the 2022 base rate case. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $9.7 million annually based on its capital invested in transmission between January 1, 2022 and June 30, 2024 and changes in other transmission charges. In April 2025 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 7, 2025. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s denial of recovery of $135 million of payments to other Utility operating companies in December 2018 relating to off-system sales of electricity from 2002-2009, as ordered by the FERC. The complaint also involved a challenge to the $13.7 million, plus interest, of related refunds ordered by the APSC and paid by Entergy Arkansas in August 2020. The trial was held in February 2023. In March 2024 the U.S. District Court for the Eastern District of Arkansas issued a judgment in favor of the APSC and against Entergy Arkansas. In March 2024 Entergy Arkansas filed a notice of appeal and a motion to expedite oral arguments with the United States Court of Appeals for the Eighth Circuit and the court granted the motion to expedite. As a result of the adverse decision by the U.S. District Court for the Eastern District of Arkansas, Entergy Arkansas concluded that it could no longer support the recognition of its $131.8 million regulatory asset reflecting the previously-expected recovery of a portion of the costs at issue in the opportunity sales proceeding and recorded a $131.8 million ($99.1 million net-of-tax) charge to earnings in first quarter 2024. In December 2024 the United States Court of Appeals for the Eighth Circuit affirmed the decision of the U.S. District Court for the Eastern District of Arkansas, and Entergy Arkansas filed a petition for rehearing en banc. In January 2025 the United States Court of Appeals for the Eighth Circuit denied Entergy Arkansas’s petition. In April 2025, Entergy Arkansas filed a petition for certiorari with the United States Supreme Court. MSS-4 Replacement Tariff - Net Operating Loss Carryforward Proceeding See Note 2 to the financial statements in the Form 10-K for discussion of the MSS-4 replacement tariff net operating loss carryforward proceeding. The MSS-4 replacement tariff, a tariff governing the sales of energy and capacity among the Utility operating companies, includes protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In April 2025, pursuant to such protocols, the City Council filed with the FERC a formal challenge relating to Entergy Services’ inclusion and allocation of net operating loss carryforward accumulated deferred income taxes in the MSS-4 replacement tariff rates charged to Entergy New Orleans’s monthly bills for calendar year 2023. Entergy Services plans to file a response to the formal challenge by the May 2025 deadline. Complaints Against System Energy See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints. The following is an update to that discussion. Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue As discussed in the Form 10-K, in February 2023, System Energy submitted a tariff compliance filing with the FERC to clarify that, consistent with the releases provided in the June 2022 MPSC settlement, Entergy Mississippi would continue to be charged for its allocation of the sale-leaseback renewal costs under the Unit Power Sales Agreement. In March 2023 the MPSC filed a protest to System Energy’s tariff compliance filing. The MPSC argued that the settlement did not specifically address post-settlement sale-leaseback renewal costs and that the sale-leaseback renewal costs may not be recovered under the Unit Power Sales Agreement. In February 2025, System Energy and the MPSC resolved their dispute concerning the sale-leaseback renewal costs. As a result, the MPSC withdrew its protest at the FERC on System Energy’s tariff compliance filing. Entergy Mississippi will continue to pay the allocated sale-leaseback renewal costs of approximately $5.7 million annually and there are no refunds due for prior periods. In March 2025, System Energy filed a status report with the FERC explaining that the dispute is resolved. Storm Cost Recovery Filings with Retail Regulators See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following is an update to that discussion. Entergy Louisiana Hurricane Francine In September 2024, Hurricane Francine caused damage to the areas served by Entergy Louisiana. The storm resulted in widespread power outages, primarily due to damage to distribution infrastructure as a result of strong winds and heavy rain, and the loss of sales during the power outages. In December 2024, and subsequently amended in an errata filed in February 2025, Entergy Louisiana submitted an application to the LPSC seeking a determination that approximately $183.6 million in storm restoration costs associated with Hurricane Francine were reasonable and necessary and, therefore, eligible for recovery from customers, as well as approval to recover approximately $3.6 million in certain carrying costs from customers. In February 2025, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting a revenue increase of $17.8 million from funds approved by the LPSC (on an interim basis) for Hurricane Francine recovery costs. The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the 2023 formula rate plan filing above. Also in February 2025, Entergy Louisiana withdrew $33.5 million from its funded storm reserves. In March 2025 a status conference was held in which a procedural schedule was established including a hearing in November 2025.
System Energy [Member] |
Public Utilities Disclosure [Text Block] | RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2025, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.00882 per kWh to $0.01333 per kWh. The annual redetermination included a credit related to the remaining balance due to retail customers from the System Energy settlement with the APSC, plus carrying charges and interest. See “Retail Rate Proceedings - Filings with the APSC (Entergy Arkansas) - Retail Rates - Grand Gulf Credit Rider” below for further discussion. The primary reason for the rate increase is an adjustment to account for projected increases in natural gas prices in 2025. This adjustment is expected to reduce the rate change that will be reflected in its 2026 energy cost rate redetermination. The redetermined rate of $0.01333 per kWh became effective with the first billing cycle in April 2025 through the normal operation of the tariff. Entergy Louisiana As discussed in the Form 10-K, in January 2023 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2021 through 2022. In April 2025 the LPSC staff issued its audit report (for Entergy Louisiana’s gas operations), which included several prospective recommendations but no financial disallowances. The next procedural step is for the LPSC to review the report; however there is no deadline for completion of the LPSC’s review. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates Grand Gulf Credit Rider As discussed in the Form 10-K, in June 2024, Entergy Arkansas filed with the APSC a tariff to provide retail customers a credit resulting from the terms of the settlement agreement between Entergy Arkansas, System Energy, additional named Entergy parties, and the APSC pertaining to System Energy’s billings for wholesale sales of energy and capacity from the Grand Gulf nuclear plant. See “Complaints Against System Energy - System Energy Settlement with the APSC” in Note 2 to the financial statements in the Form 10-K for discussion of the System Energy settlement with the APSC. In July 2024 the APSC approved the tariff, under which Entergy Arkansas would refund to retail customers a total of $100.6 million. Entergy Arkansas refunded $92.3 million of the total through one-time bill credits under the Grand Gulf credit rider during the August 2024 billing cycle. In March 2025, Entergy Arkansas included the remaining balance as a credit to retail customers in its energy cost recovery rider rate redetermination filing. See further discussion within "Regulatory Assets and Regulatory Liabilities - Fuel and purchased power cost recovery - Entergy Arkansas - Energy Cost Recovery Rider" above. In April 2025 the APSC approved Entergy Arkansas’s proposal to include the remaining balance in its energy cost recovery rider effective with the first billing cycle of April 2025 and the withdrawal of the Grand Gulf credit rider after all credits have been issued. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2023 Formula Rate Plan Filing As discussed in the Form 10-K, in August 2024, pursuant to the global stipulated settlement agreement, Entergy Louisiana filed its formula rate plan evaluation report for its 2023 calendar year operations. Consistent with the global stipulated settlement agreement, the filing reflected a 9.7% allowed return on common equity with a bandwidth of 40 basis points above and below the midpoint. For the 2023 test year, however, the bandwidth provisions of the formula rate plan are temporarily suspended and, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana implemented the September 2024 formula rate plan rate adjustments effective with the first billing cycle of September 2024. In January 2025, Entergy Louisiana and the LPSC filed a joint report indicating that no disputed issues remained in the proceeding and requesting that the LPSC issue an order accepting Entergy Louisiana’s evaluation report and, ultimately, resolving this matter. In March 2025 the LPSC issued an order accepting the evaluation report. In December 2024, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed an interim rate adjustment for the 2023 test year reflecting the return of $25.1 million of refunds from the System Energy settlement with the LPSC to customers from January through August 2025. In February 2025, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting the divestiture of Entergy Louisiana’s share of Grand Gulf capacity and energy, which was effective as of January 1, 2025. The second interim rate adjustment also reflected a revenue increase of $17.8 million for the recovery of Hurricane Francine costs as approved by the LPSC (on an interim basis). The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the Hurricane Francine proceeding in “Storm Cost Recovery Filings with Retail Regulators – Entergy Louisiana – Hurricane Francine” below. See Note 8 to the financial statements in the Form 10-K for discussion of Entergy Louisiana’s divestiture from the Unit Power Sales Agreement. Additional Generation and Transmission Resources As discussed in the Form 10-K, in October 2024, Entergy Louisiana filed an application with the LPSC seeking approval of a variety of generation and transmission resources proposed in connection with establishing service to a new data center to be developed by a subsidiary of Meta Platforms, Inc. in north Louisiana, for which an electric service agreement has been executed. The filing requests LPSC certification of three new combined cycle combustion turbine generation resources totaling 2,262 MW, each of which will be enabled for future carbon capture and storage, a new 500 kV transmission line, and 500 kV substation upgrades. The application also requests approval to implement a corporate sustainability rider applicable to the new customer. The corporate sustainability rider contemplates the new customer contributing to the costs of the future addition of 1,500 MW of new solar and energy storage resources, agreements involving carbon capture and storage at Entergy Louisiana’s existing Lake Charles Power Station, and potential future wind and nuclear resources. Entergy Louisiana anticipates funding the incremental cost to serve the customer through direct financial contributions from the customer and the revenues it expects to earn under the electric service agreement. The electric service agreement also contains provisions for termination payments that will help ensure that there is no harm to Entergy Louisiana and its customers in the event of early termination. A directive was issued at the LPSC’s November 2024 meeting for the matter to be decided by October 2025. In February 2025 intervenors filed a motion asking the LPSC to deny Entergy Louisiana’s requested exemption from the LPSC’s order addressing competitive solicitation procedures and further asking the LPSC to dismiss the application. The ALJ issued an order denying the motion to dismiss the application and deferring the LPSC’s consideration of the motion regarding the competitive solicitation procedures until the hearing. In March 2025 the same intervenors filed a motion requesting the LPSC to require the customer and its parent company to be joined as parties to the proceeding or dismiss the application. In April 2025 the ALJ issued an order denying the March 2025 motion, and the moving parties filed a motion asking the LPSC to review and reverse the ALJ’s decision. In April 2025 the LPSC staff and intervenors filed direct testimony. The LPSC staff’s testimony discusses the significant projected benefits associated with the data center project and also recommends that the LPSC impose certain conditions on its approval, including a condition that would require, under specified circumstances, certain sharing of net revenues from service to the project with Entergy Louisiana’s other customers. The LPSC staff also recommends that the LPSC deny approval of the corporate sustainability rider terms providing for the customer to supply funding toward the cost of installing carbon capture and storage infrastructure at Entergy Louisiana’s Lake Charles Power Station. The Louisiana Energy Users Group and other intervenors recommended that the LPSC require various changes to the terms of the electric service agreement with the customer that would shift additional risk and cost to the customer rather than Entergy Louisiana’s broader customer base. Certain intervenors also challenged approval on the basis that Entergy Louisiana did not conduct a request for proposals to procure the proposed generation resources to serve the customer’s project; these intervenors also advocate that Entergy Louisiana be required to procure more renewable generation and evaluate transmission alternatives rather than proceeding with development of all of the proposed new generation resources. Entergy Louisiana’s rebuttal testimony is due in May 2025, and a hearing is set for July 2025. Filings with the MPSC (Entergy Mississippi) Retail Rates 2025 Formula Rate Plan Filing In February 2025, Entergy Mississippi submitted its formula rate plan 2025 test year filing and 2024 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2024 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2025 calendar year to also be within the formula rate plan bandwidth. The 2025 test year filing resulted in an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2024 look-back filing compared actual 2024 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues, although Entergy Mississippi proposes to adjust interim rates by $135 thousand to reflect two outside-the-bandwidth changes: (1) the completion of Entergy Mississippi’s return to customers of credits under its restructuring credit rider; and (2) a true-up of demand side management costs. A final order is expected in second quarter 2025. Interim Facilities Rate Adjustments In May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with state legislation passed in January 2024. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed the first of its annual interim facilities rate adjustment reports in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Entergy Mississippi filed its second interim facilities rate adjustment report in November 2024 to recover approximately $46.7 million of these costs over a 12-month period with rates effective beginning in January 2025. In February 2025, Entergy Mississippi filed a true-up interim facilities rate adjustment report to the initial annual interim facilities rate adjustment report filed in May 2024, reflecting the recovery of an additional approximately $1.0 million of costs over a 12-month period with rates effective with the first billing cycle of April 2025. Filings with the City Council (Entergy New Orleans) Retail Rates 2025 Formula Rate Plan Filing In April 2025, Entergy New Orleans submitted to the City Council its formula rate plan 2024 test year filing. The 2024 evaluation report produced an electric earned return on equity of 10.98% and a gas earned return on equity of 8.96% compared to the authorized return on equity for each of 9.35%. Without adjustments, this would result in a decrease in electric rates of $13.8 million and no change in gas rates. The decrease in electric rates is driven by the realignment of regulatory liabilities into the formula from a separate rate mechanism, partially offset by the cost of known and measurable electric capital additions. The filing also commences the previously authorized recovery of certain regulatory costs and requests a revenue-neutral recovery to offset a proposed reduction in bill payment late fees. Taking into account these proposed adjustments, the filing presents a decrease in authorized electric revenues of $8.6 million and an increase in authorized gas revenues of $0.5 million. The filing is subject to a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. For any disputed rate adjustments, however, the City Council would set a procedural schedule to resolve. Resulting rates will be effective with the first billing cycle of September 2025 pursuant to the formula rate plan tariff. Filings with the PUCT and Texas Cities (Entergy Texas) Retail Rates Distribution Cost Recovery Factor (DCRF) Rider In April 2025, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $77.8 million annually, or $29.3 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between July 1, 2024 and December 31, 2024, including distribution-related restoration costs associated with Hurricane Beryl. Transmission Cost Recovery Factor (TCRF) Rider As discussed in the Form 10-K, in October 2024, Entergy Texas filed with the PUCT a request to amend its TCRF rider, which was previously reset to zero in June 2023 as a result of the 2022 base rate case. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $9.7 million annually based on its capital invested in transmission between January 1, 2022 and June 30, 2024 and changes in other transmission charges. In April 2025 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 7, 2025. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s denial of recovery of $135 million of payments to other Utility operating companies in December 2018 relating to off-system sales of electricity from 2002-2009, as ordered by the FERC. The complaint also involved a challenge to the $13.7 million, plus interest, of related refunds ordered by the APSC and paid by Entergy Arkansas in August 2020. The trial was held in February 2023. In March 2024 the U.S. District Court for the Eastern District of Arkansas issued a judgment in favor of the APSC and against Entergy Arkansas. In March 2024 Entergy Arkansas filed a notice of appeal and a motion to expedite oral arguments with the United States Court of Appeals for the Eighth Circuit and the court granted the motion to expedite. As a result of the adverse decision by the U.S. District Court for the Eastern District of Arkansas, Entergy Arkansas concluded that it could no longer support the recognition of its $131.8 million regulatory asset reflecting the previously-expected recovery of a portion of the costs at issue in the opportunity sales proceeding and recorded a $131.8 million ($99.1 million net-of-tax) charge to earnings in first quarter 2024. In December 2024 the United States Court of Appeals for the Eighth Circuit affirmed the decision of the U.S. District Court for the Eastern District of Arkansas, and Entergy Arkansas filed a petition for rehearing en banc. In January 2025 the United States Court of Appeals for the Eighth Circuit denied Entergy Arkansas’s petition. In April 2025, Entergy Arkansas filed a petition for certiorari with the United States Supreme Court. MSS-4 Replacement Tariff - Net Operating Loss Carryforward Proceeding See Note 2 to the financial statements in the Form 10-K for discussion of the MSS-4 replacement tariff net operating loss carryforward proceeding. The MSS-4 replacement tariff, a tariff governing the sales of energy and capacity among the Utility operating companies, includes protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In April 2025, pursuant to such protocols, the City Council filed with the FERC a formal challenge relating to Entergy Services’ inclusion and allocation of net operating loss carryforward accumulated deferred income taxes in the MSS-4 replacement tariff rates charged to Entergy New Orleans’s monthly bills for calendar year 2023. Entergy Services plans to file a response to the formal challenge by the May 2025 deadline. Complaints Against System Energy See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints. The following is an update to that discussion. Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue As discussed in the Form 10-K, in February 2023, System Energy submitted a tariff compliance filing with the FERC to clarify that, consistent with the releases provided in the June 2022 MPSC settlement, Entergy Mississippi would continue to be charged for its allocation of the sale-leaseback renewal costs under the Unit Power Sales Agreement. In March 2023 the MPSC filed a protest to System Energy’s tariff compliance filing. The MPSC argued that the settlement did not specifically address post-settlement sale-leaseback renewal costs and that the sale-leaseback renewal costs may not be recovered under the Unit Power Sales Agreement. In February 2025, System Energy and the MPSC resolved their dispute concerning the sale-leaseback renewal costs. As a result, the MPSC withdrew its protest at the FERC on System Energy’s tariff compliance filing. Entergy Mississippi will continue to pay the allocated sale-leaseback renewal costs of approximately $5.7 million annually and there are no refunds due for prior periods. In March 2025, System Energy filed a status report with the FERC explaining that the dispute is resolved. Storm Cost Recovery Filings with Retail Regulators See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following is an update to that discussion. Entergy Louisiana Hurricane Francine In September 2024, Hurricane Francine caused damage to the areas served by Entergy Louisiana. The storm resulted in widespread power outages, primarily due to damage to distribution infrastructure as a result of strong winds and heavy rain, and the loss of sales during the power outages. In December 2024, and subsequently amended in an errata filed in February 2025, Entergy Louisiana submitted an application to the LPSC seeking a determination that approximately $183.6 million in storm restoration costs associated with Hurricane Francine were reasonable and necessary and, therefore, eligible for recovery from customers, as well as approval to recover approximately $3.6 million in certain carrying costs from customers. In February 2025, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting a revenue increase of $17.8 million from funds approved by the LPSC (on an interim basis) for Hurricane Francine recovery costs. The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the 2023 formula rate plan filing above. Also in February 2025, Entergy Louisiana withdrew $33.5 million from its funded storm reserves. In March 2025 a status conference was held in which a procedural schedule was established including a hearing in November 2025.

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