Rate And Regulatory Matters	3 Months Ended
Mar. 31, 2026
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 2026, 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 $0.01333 per kWh to $0.01508 per kWh. The primary reason for the rate increase was an under-recovered balance as a result of higher natural gas prices in 2025. Based on circumstances related to ANO 2’s refueling outage, Entergy Arkansas made an adjustment to projected energy costs to phase-in the rate increase gradually. The redetermined rate of $0.01508 per kWh became effective with the first billing cycle in April 2026 through the normal operation of the tariff. Entergy Louisiana As discussed in the Form 10-K, in June 2025 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings (for Entergy Louisiana’s gas operations). The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from January 2023 through June 2025. The LPSC staff issued its audit report in March 2026, and although certain internal record keeping recommendations were made, the LPSC staff did not recommend any disallowances. The next step is for the LPSC to issue its final report, but there is no deadline or timing requirement associated with the issuance of the final report. In February 2026, Entergy Louisiana, in its monthly filing to update its fuel adjustment clause, requested to defer approximately $141.9 million of fuel costs incurred in January 2026 that were primarily attributable to the effects of Winter Storm Fern, consistent with the LPSC’s general order approved at its February 2026 meeting permitting temporary modifications to the LPSC’s fuel adjustment clause general order. The filing proposes to defer the recovery of these fuel costs over a four-month period from March 2026 through June 2026 to mitigate the customer bill impacts of these fuel costs. In April 2026 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment clause for the period from 2023 through 2025. 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 2026 Base Rate Case In February 2026, Entergy Arkansas filed with the APSC a general change in rates, charges, and tariffs. The filing requested a base rate increase to recover a base rate revenue deficiency of $44.6 million and notified the APSC of Entergy Arkansas’s intent to implement a forward test year formula rate plan pursuant to Arkansas legislation passed in 2015. The primary drivers of the revenue deficiency were increased depreciation expense and the impact of net capital additions. Additionally, the filing requested a 9.90% return on common equity and increased depreciation rates as the result of a depreciation study. In March 2026 the APSC issued an order suspending the proposed rates and tariffs filed by Entergy Arkansas and will establish a procedural schedule by subsequent order. Generating Arkansas Jobs Act Rider In March 2026, Entergy Arkansas filed its first annual update to the strategic investment recovery rider, requesting recovery of $110.4 million of financing costs during construction of generation and transmission strategic investments related to Ironwood Power Station, Jefferson Power Station, and the Arkansas Cypress Solar facility. The revised rates are requested to be effective for bills rendered on the first billing cycle of June 2026. In April 2026 the APSC general staff filed testimony arguing that the APSC had not issued an order designating Ironwood Power Station as a strategic investment and that related costs should therefore be removed from the annual update. Also in April 2026, Entergy Arkansas filed testimony asserting that the APSC general staff’s position is contrary to the plain language of the statute, which includes an exception for facilities like Ironwood Power Station that were certified by the APSC within a certain timeframe. A hearing was held in April 2026. Production Tax Credit Tariff As discussed in Note 3 to the financial statements in the Form 10-K, in January 2026 the APSC opened a docket to investigate the sale of Entergy Arkansas’s nuclear production tax credits and the appropriate ratemaking treatment of production tax credits for all of Entergy Arkansas’s eligible resources, including how the proceeds of any sales should flow through to customers. As directed by the APSC, in February 2026, Entergy Arkansas submitted a compliance filing to the APSC verifying the status of the solar production tax credits. The filing also verified that the net proceeds from the sale of the nuclear production tax credits were recorded in FERC accounts that are accruing a return for customers’ benefit at a rate that is above the customer deposit rate. Subsequently, in March 2026, Entergy Arkansas filed testimony setting forth its proposal for the solar production tax credits. Specifically, Entergy Arkansas requested the same ratemaking treatment for all of the solar facilities that the APSC already approved for Walnut Bend (i.e., the total net monetized proceeds from production tax credits expected to be generated over the first ten years of a solar facility’s operation are estimated and then amortized over the expected useful life of the asset, which is typically 30 years). Additionally, consistent with prior orders for these resources, the deferred tax asset balances associated with both the production tax credits and the tax gross-up of the regulatory liability will be recognized as a reduction to the overall accumulated deferred income tax liability balance in Entergy Arkansas’s calculation of its weighted average cost of capital providing a return on the unamortized balance for the benefit of customers. Further, Entergy Arkansas proposes to flow the benefits of the solar production tax credits to customers through Entergy Arkansas’s formula rate plan, effective with the formula rate plan rates that will go into effect January 1, 2027. Entergy Arkansas’s proposal would result in the benefits of the production tax credits being passed through to customers, if approved, as reductions in revenue requirement evenly over the life of the assets, rather than only during the 10-year period in which the production tax credits are generated. In April 2026 the APSC general staff filed testimony proposing an amortization period of no more than 15 years for the monetized proceeds for the tax credits associated with the West Memphis Solar and Driver Solar facilities. An evidentiary hearing is scheduled for July 2026. Special Rate Contract and Arkansas Cypress Solar As discussed in the Form 10-K, in September 2025, Entergy Arkansas filed an application with the APSC seeking a certificate of environmental compatibility and public need for the construction and operation of the Arkansas Cypress Solar facility, a planned 600 MW solar photovoltaic array with a 350 MW battery energy storage system and associated transmission facilities interconnecting at Entergy Arkansas’s White Bluff substation. The estimated cost of the project is $1,602 million. In March 2026 the APSC approved the Arkansas Cypress Solar facility and Entergy Arkansas’s recovery of the costs of the facility through the Generating Arkansas Jobs Act rider. The APSC also ordered implementation of an independent monitor to oversee costs. In April 2026, Entergy Arkansas filed with the APSC its proposal for an independent monitor to oversee the reasonableness of costs. In April 2026 the APSC issued an order consolidating Entergy Arkansas’s cost independent monitor proposals for three pending resources, including the Arkansas Cypress Solar facility, into a single docket and directing parties with full intervention status to respond to the proposals and recommend independent monitor candidates. The facility is expected to be in service by the end of 2028. Filings with the LPSC (Entergy Louisiana) Retail Rates Resilience Plan Cost Recovery Rider In December 2022, Entergy Louisiana filed an application with the LPSC seeking a public interest finding regarding Phase I of Entergy Louisiana’s Future Ready resilience plan and approval of a rider mechanism to recover the program’s costs. Phase I in the December 2022 application reflected the first five years of a ten-year resilience plan and included investment of approximately $5 billion, including hardening investment, transmission dead-end structures, enhanced vegetation management, and telecommunications improvement. In April 2024 the LPSC approved a framework which includes an initial five-year resilience plan providing for an investment of approximately $1.9 billion with cost recovery via a forward-looking rider with semi-annual true-ups. The plan is subject to specified reporting requirements and includes a performance review of the hardened assets. The LPSC order approving the framework does not include any restrictions on Entergy Louisiana’s ability to file applications for approval of additional investments in resilience. In January 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $40.4 million, or $38.9 million in incremental annual revenues from Entergy Louisiana’s first semi-annual filing in July 2024, for projects expected to be placed in service during the rate-effective period of March 2025 through August 2025. In February 2025 the LPSC staff reviewed the filed rider rates and identified no material issues. In July 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $50.2 million, or $9.8 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of September 2025 through February 2026. Additionally, Entergy Louisiana’s true-up filing included an under-recovery totaling $5.6 million to be implemented in the January 2026 semi-annual filing. In August 2025 the LPSC staff reviewed the filed rider rates and identified no material issues. In January 2026, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $101.8 million, or $51.6 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of March 2026 through August 2026. Additionally, Entergy Louisiana’s true-up filing included an over-recovery totaling $16.6 million to be implemented in the July 2026 semi-annual filing. In February 2026 the LPSC staff reviewed the filed rider rates and identified no material issues. Filings with the MPSC (Entergy Mississippi) Retail Rates 2026 Formula Rate Plan Filing In February 2026, Entergy Mississippi submitted its formula rate plan 2026 test year filing and 2025 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2025 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2026 calendar year to also be within the formula rate plan bandwidth. The 2026 test year filing resulted in an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2025 look-back filing compared actual 2025 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 $293 thousand to reflect one outside-the-bandwidth change, a true-up of demand side management costs. A final order is expected in second quarter 2026. Filings with the City Council (Entergy New Orleans) Retail Rates 2026 Formula Rate Plan Filing In April 2026, Entergy New Orleans submitted to the City Council its formula rate plan 2025 test year filing. The 2025 evaluation report produced an earned return on equity of 7.55% compared to the authorized return on equity of 9.35%. Without adjustments, this would result in an increase in rates of $16.6 million. The increase in rates is driven, in part, by an increase in plant in service, as well as the cost of known and measurable capital additions. The increase is also driven by a decrease in total revenues due to a decline in kWh sales. The filing is subject to a 75-day review and discovery period followed by a 25-day period to resolve any disputes among the parties. For any disputed items, the City Council would set a procedural schedule to resolve such disputes. Resulting rates will be effective with the first billing cycle of September 2026 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 2026, 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 $112.5 million annually, or $20.4 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between July 1, 2025 and December 31, 2025. Transmission Cost Recovery Factor (TCRF) Rider As discussed in the Form 10-K, in October 2025, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $30.3 million annually, or $20.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2024 and June 30, 2025 and changes in other transmission charges. In April 2026 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 6, 2026. Generation Cost Recovery Rider In March 2026, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its capital investment in the Orange County Advanced Power Station. The proposed generation cost recovery rider, which includes Entergy Texas’s capital invested in generation for the Orange County Advanced Power Station through December 31, 2025, is designed to collect approximately $150.4 million annually from Entergy Texas’s retail customers. By statute, the proposed generation cost recovery rider rates are to become effective when the Orange County Advanced Power Station is placed into service, which is expected in third quarter 2026. Entergy Arkansas Opportunity Sales Proceeding See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. Complaints Against System Energy See Note 2 to the financial statements in the Form 10-K for information regarding complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints. Unit Power Sales Agreement See Note 2 to the financial statements in the Form 10-K for discussion of the Unit Power Sales Agreement. 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. 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.
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 2026, 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 $0.01333 per kWh to $0.01508 per kWh. The primary reason for the rate increase was an under-recovered balance as a result of higher natural gas prices in 2025. Based on circumstances related to ANO 2’s refueling outage, Entergy Arkansas made an adjustment to projected energy costs to phase-in the rate increase gradually. The redetermined rate of $0.01508 per kWh became effective with the first billing cycle in April 2026 through the normal operation of the tariff. Entergy Louisiana As discussed in the Form 10-K, in June 2025 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings (for Entergy Louisiana’s gas operations). The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from January 2023 through June 2025. The LPSC staff issued its audit report in March 2026, and although certain internal record keeping recommendations were made, the LPSC staff did not recommend any disallowances. The next step is for the LPSC to issue its final report, but there is no deadline or timing requirement associated with the issuance of the final report. In February 2026, Entergy Louisiana, in its monthly filing to update its fuel adjustment clause, requested to defer approximately $141.9 million of fuel costs incurred in January 2026 that were primarily attributable to the effects of Winter Storm Fern, consistent with the LPSC’s general order approved at its February 2026 meeting permitting temporary modifications to the LPSC’s fuel adjustment clause general order. The filing proposes to defer the recovery of these fuel costs over a four-month period from March 2026 through June 2026 to mitigate the customer bill impacts of these fuel costs. In April 2026 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment clause for the period from 2023 through 2025. 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 2026 Base Rate Case In February 2026, Entergy Arkansas filed with the APSC a general change in rates, charges, and tariffs. The filing requested a base rate increase to recover a base rate revenue deficiency of $44.6 million and notified the APSC of Entergy Arkansas’s intent to implement a forward test year formula rate plan pursuant to Arkansas legislation passed in 2015. The primary drivers of the revenue deficiency were increased depreciation expense and the impact of net capital additions. Additionally, the filing requested a 9.90% return on common equity and increased depreciation rates as the result of a depreciation study. In March 2026 the APSC issued an order suspending the proposed rates and tariffs filed by Entergy Arkansas and will establish a procedural schedule by subsequent order. Generating Arkansas Jobs Act Rider In March 2026, Entergy Arkansas filed its first annual update to the strategic investment recovery rider, requesting recovery of $110.4 million of financing costs during construction of generation and transmission strategic investments related to Ironwood Power Station, Jefferson Power Station, and the Arkansas Cypress Solar facility. The revised rates are requested to be effective for bills rendered on the first billing cycle of June 2026. In April 2026 the APSC general staff filed testimony arguing that the APSC had not issued an order designating Ironwood Power Station as a strategic investment and that related costs should therefore be removed from the annual update. Also in April 2026, Entergy Arkansas filed testimony asserting that the APSC general staff’s position is contrary to the plain language of the statute, which includes an exception for facilities like Ironwood Power Station that were certified by the APSC within a certain timeframe. A hearing was held in April 2026. Production Tax Credit Tariff As discussed in Note 3 to the financial statements in the Form 10-K, in January 2026 the APSC opened a docket to investigate the sale of Entergy Arkansas’s nuclear production tax credits and the appropriate ratemaking treatment of production tax credits for all of Entergy Arkansas’s eligible resources, including how the proceeds of any sales should flow through to customers. As directed by the APSC, in February 2026, Entergy Arkansas submitted a compliance filing to the APSC verifying the status of the solar production tax credits. The filing also verified that the net proceeds from the sale of the nuclear production tax credits were recorded in FERC accounts that are accruing a return for customers’ benefit at a rate that is above the customer deposit rate. Subsequently, in March 2026, Entergy Arkansas filed testimony setting forth its proposal for the solar production tax credits. Specifically, Entergy Arkansas requested the same ratemaking treatment for all of the solar facilities that the APSC already approved for Walnut Bend (i.e., the total net monetized proceeds from production tax credits expected to be generated over the first ten years of a solar facility’s operation are estimated and then amortized over the expected useful life of the asset, which is typically 30 years). Additionally, consistent with prior orders for these resources, the deferred tax asset balances associated with both the production tax credits and the tax gross-up of the regulatory liability will be recognized as a reduction to the overall accumulated deferred income tax liability balance in Entergy Arkansas’s calculation of its weighted average cost of capital providing a return on the unamortized balance for the benefit of customers. Further, Entergy Arkansas proposes to flow the benefits of the solar production tax credits to customers through Entergy Arkansas’s formula rate plan, effective with the formula rate plan rates that will go into effect January 1, 2027. Entergy Arkansas’s proposal would result in the benefits of the production tax credits being passed through to customers, if approved, as reductions in revenue requirement evenly over the life of the assets, rather than only during the 10-year period in which the production tax credits are generated. In April 2026 the APSC general staff filed testimony proposing an amortization period of no more than 15 years for the monetized proceeds for the tax credits associated with the West Memphis Solar and Driver Solar facilities. An evidentiary hearing is scheduled for July 2026. Special Rate Contract and Arkansas Cypress Solar As discussed in the Form 10-K, in September 2025, Entergy Arkansas filed an application with the APSC seeking a certificate of environmental compatibility and public need for the construction and operation of the Arkansas Cypress Solar facility, a planned 600 MW solar photovoltaic array with a 350 MW battery energy storage system and associated transmission facilities interconnecting at Entergy Arkansas’s White Bluff substation. The estimated cost of the project is $1,602 million. In March 2026 the APSC approved the Arkansas Cypress Solar facility and Entergy Arkansas’s recovery of the costs of the facility through the Generating Arkansas Jobs Act rider. The APSC also ordered implementation of an independent monitor to oversee costs. In April 2026, Entergy Arkansas filed with the APSC its proposal for an independent monitor to oversee the reasonableness of costs. In April 2026 the APSC issued an order consolidating Entergy Arkansas’s cost independent monitor proposals for three pending resources, including the Arkansas Cypress Solar facility, into a single docket and directing parties with full intervention status to respond to the proposals and recommend independent monitor candidates. The facility is expected to be in service by the end of 2028. Filings with the LPSC (Entergy Louisiana) Retail Rates Resilience Plan Cost Recovery Rider In December 2022, Entergy Louisiana filed an application with the LPSC seeking a public interest finding regarding Phase I of Entergy Louisiana’s Future Ready resilience plan and approval of a rider mechanism to recover the program’s costs. Phase I in the December 2022 application reflected the first five years of a ten-year resilience plan and included investment of approximately $5 billion, including hardening investment, transmission dead-end structures, enhanced vegetation management, and telecommunications improvement. In April 2024 the LPSC approved a framework which includes an initial five-year resilience plan providing for an investment of approximately $1.9 billion with cost recovery via a forward-looking rider with semi-annual true-ups. The plan is subject to specified reporting requirements and includes a performance review of the hardened assets. The LPSC order approving the framework does not include any restrictions on Entergy Louisiana’s ability to file applications for approval of additional investments in resilience. In January 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $40.4 million, or $38.9 million in incremental annual revenues from Entergy Louisiana’s first semi-annual filing in July 2024, for projects expected to be placed in service during the rate-effective period of March 2025 through August 2025. In February 2025 the LPSC staff reviewed the filed rider rates and identified no material issues. In July 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $50.2 million, or $9.8 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of September 2025 through February 2026. Additionally, Entergy Louisiana’s true-up filing included an under-recovery totaling $5.6 million to be implemented in the January 2026 semi-annual filing. In August 2025 the LPSC staff reviewed the filed rider rates and identified no material issues. In January 2026, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $101.8 million, or $51.6 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of March 2026 through August 2026. Additionally, Entergy Louisiana’s true-up filing included an over-recovery totaling $16.6 million to be implemented in the July 2026 semi-annual filing. In February 2026 the LPSC staff reviewed the filed rider rates and identified no material issues. Filings with the MPSC (Entergy Mississippi) Retail Rates 2026 Formula Rate Plan Filing In February 2026, Entergy Mississippi submitted its formula rate plan 2026 test year filing and 2025 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2025 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2026 calendar year to also be within the formula rate plan bandwidth. The 2026 test year filing resulted in an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2025 look-back filing compared actual 2025 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 $293 thousand to reflect one outside-the-bandwidth change, a true-up of demand side management costs. A final order is expected in second quarter 2026. Filings with the City Council (Entergy New Orleans) Retail Rates 2026 Formula Rate Plan Filing In April 2026, Entergy New Orleans submitted to the City Council its formula rate plan 2025 test year filing. The 2025 evaluation report produced an earned return on equity of 7.55% compared to the authorized return on equity of 9.35%. Without adjustments, this would result in an increase in rates of $16.6 million. The increase in rates is driven, in part, by an increase in plant in service, as well as the cost of known and measurable capital additions. The increase is also driven by a decrease in total revenues due to a decline in kWh sales. The filing is subject to a 75-day review and discovery period followed by a 25-day period to resolve any disputes among the parties. For any disputed items, the City Council would set a procedural schedule to resolve such disputes. Resulting rates will be effective with the first billing cycle of September 2026 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 2026, 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 $112.5 million annually, or $20.4 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between July 1, 2025 and December 31, 2025. Transmission Cost Recovery Factor (TCRF) Rider As discussed in the Form 10-K, in October 2025, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $30.3 million annually, or $20.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2024 and June 30, 2025 and changes in other transmission charges. In April 2026 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 6, 2026. Generation Cost Recovery Rider In March 2026, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its capital investment in the Orange County Advanced Power Station. The proposed generation cost recovery rider, which includes Entergy Texas’s capital invested in generation for the Orange County Advanced Power Station through December 31, 2025, is designed to collect approximately $150.4 million annually from Entergy Texas’s retail customers. By statute, the proposed generation cost recovery rider rates are to become effective when the Orange County Advanced Power Station is placed into service, which is expected in third quarter 2026. Entergy Arkansas Opportunity Sales Proceeding See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. Complaints Against System Energy See Note 2 to the financial statements in the Form 10-K for information regarding complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints. Unit Power Sales Agreement See Note 2 to the financial statements in the Form 10-K for discussion of the Unit Power Sales Agreement. 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. 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.
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 2026, 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 $0.01333 per kWh to $0.01508 per kWh. The primary reason for the rate increase was an under-recovered balance as a result of higher natural gas prices in 2025. Based on circumstances related to ANO 2’s refueling outage, Entergy Arkansas made an adjustment to projected energy costs to phase-in the rate increase gradually. The redetermined rate of $0.01508 per kWh became effective with the first billing cycle in April 2026 through the normal operation of the tariff. Entergy Louisiana As discussed in the Form 10-K, in June 2025 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings (for Entergy Louisiana’s gas operations). The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from January 2023 through June 2025. The LPSC staff issued its audit report in March 2026, and although certain internal record keeping recommendations were made, the LPSC staff did not recommend any disallowances. The next step is for the LPSC to issue its final report, but there is no deadline or timing requirement associated with the issuance of the final report. In February 2026, Entergy Louisiana, in its monthly filing to update its fuel adjustment clause, requested to defer approximately $141.9 million of fuel costs incurred in January 2026 that were primarily attributable to the effects of Winter Storm Fern, consistent with the LPSC’s general order approved at its February 2026 meeting permitting temporary modifications to the LPSC’s fuel adjustment clause general order. The filing proposes to defer the recovery of these fuel costs over a four-month period from March 2026 through June 2026 to mitigate the customer bill impacts of these fuel costs. In April 2026 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment clause for the period from 2023 through 2025. 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 2026 Base Rate Case In February 2026, Entergy Arkansas filed with the APSC a general change in rates, charges, and tariffs. The filing requested a base rate increase to recover a base rate revenue deficiency of $44.6 million and notified the APSC of Entergy Arkansas’s intent to implement a forward test year formula rate plan pursuant to Arkansas legislation passed in 2015. The primary drivers of the revenue deficiency were increased depreciation expense and the impact of net capital additions. Additionally, the filing requested a 9.90% return on common equity and increased depreciation rates as the result of a depreciation study. In March 2026 the APSC issued an order suspending the proposed rates and tariffs filed by Entergy Arkansas and will establish a procedural schedule by subsequent order. Generating Arkansas Jobs Act Rider In March 2026, Entergy Arkansas filed its first annual update to the strategic investment recovery rider, requesting recovery of $110.4 million of financing costs during construction of generation and transmission strategic investments related to Ironwood Power Station, Jefferson Power Station, and the Arkansas Cypress Solar facility. The revised rates are requested to be effective for bills rendered on the first billing cycle of June 2026. In April 2026 the APSC general staff filed testimony arguing that the APSC had not issued an order designating Ironwood Power Station as a strategic investment and that related costs should therefore be removed from the annual update. Also in April 2026, Entergy Arkansas filed testimony asserting that the APSC general staff’s position is contrary to the plain language of the statute, which includes an exception for facilities like Ironwood Power Station that were certified by the APSC within a certain timeframe. A hearing was held in April 2026. Production Tax Credit Tariff As discussed in Note 3 to the financial statements in the Form 10-K, in January 2026 the APSC opened a docket to investigate the sale of Entergy Arkansas’s nuclear production tax credits and the appropriate ratemaking treatment of production tax credits for all of Entergy Arkansas’s eligible resources, including how the proceeds of any sales should flow through to customers. As directed by the APSC, in February 2026, Entergy Arkansas submitted a compliance filing to the APSC verifying the status of the solar production tax credits. The filing also verified that the net proceeds from the sale of the nuclear production tax credits were recorded in FERC accounts that are accruing a return for customers’ benefit at a rate that is above the customer deposit rate. Subsequently, in March 2026, Entergy Arkansas filed testimony setting forth its proposal for the solar production tax credits. Specifically, Entergy Arkansas requested the same ratemaking treatment for all of the solar facilities that the APSC already approved for Walnut Bend (i.e., the total net monetized proceeds from production tax credits expected to be generated over the first ten years of a solar facility’s operation are estimated and then amortized over the expected useful life of the asset, which is typically 30 years). Additionally, consistent with prior orders for these resources, the deferred tax asset balances associated with both the production tax credits and the tax gross-up of the regulatory liability will be recognized as a reduction to the overall accumulated deferred income tax liability balance in Entergy Arkansas’s calculation of its weighted average cost of capital providing a return on the unamortized balance for the benefit of customers. Further, Entergy Arkansas proposes to flow the benefits of the solar production tax credits to customers through Entergy Arkansas’s formula rate plan, effective with the formula rate plan rates that will go into effect January 1, 2027. Entergy Arkansas’s proposal would result in the benefits of the production tax credits being passed through to customers, if approved, as reductions in revenue requirement evenly over the life of the assets, rather than only during the 10-year period in which the production tax credits are generated. In April 2026 the APSC general staff filed testimony proposing an amortization period of no more than 15 years for the monetized proceeds for the tax credits associated with the West Memphis Solar and Driver Solar facilities. An evidentiary hearing is scheduled for July 2026. Special Rate Contract and Arkansas Cypress Solar As discussed in the Form 10-K, in September 2025, Entergy Arkansas filed an application with the APSC seeking a certificate of environmental compatibility and public need for the construction and operation of the Arkansas Cypress Solar facility, a planned 600 MW solar photovoltaic array with a 350 MW battery energy storage system and associated transmission facilities interconnecting at Entergy Arkansas’s White Bluff substation. The estimated cost of the project is $1,602 million. In March 2026 the APSC approved the Arkansas Cypress Solar facility and Entergy Arkansas’s recovery of the costs of the facility through the Generating Arkansas Jobs Act rider. The APSC also ordered implementation of an independent monitor to oversee costs. In April 2026, Entergy Arkansas filed with the APSC its proposal for an independent monitor to oversee the reasonableness of costs. In April 2026 the APSC issued an order consolidating Entergy Arkansas’s cost independent monitor proposals for three pending resources, including the Arkansas Cypress Solar facility, into a single docket and directing parties with full intervention status to respond to the proposals and recommend independent monitor candidates. The facility is expected to be in service by the end of 2028. Filings with the LPSC (Entergy Louisiana) Retail Rates Resilience Plan Cost Recovery Rider In December 2022, Entergy Louisiana filed an application with the LPSC seeking a public interest finding regarding Phase I of Entergy Louisiana’s Future Ready resilience plan and approval of a rider mechanism to recover the program’s costs. Phase I in the December 2022 application reflected the first five years of a ten-year resilience plan and included investment of approximately $5 billion, including hardening investment, transmission dead-end structures, enhanced vegetation management, and telecommunications improvement. In April 2024 the LPSC approved a framework which includes an initial five-year resilience plan providing for an investment of approximately $1.9 billion with cost recovery via a forward-looking rider with semi-annual true-ups. The plan is subject to specified reporting requirements and includes a performance review of the hardened assets. The LPSC order approving the framework does not include any restrictions on Entergy Louisiana’s ability to file applications for approval of additional investments in resilience. In January 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $40.4 million, or $38.9 million in incremental annual revenues from Entergy Louisiana’s first semi-annual filing in July 2024, for projects expected to be placed in service during the rate-effective period of March 2025 through August 2025. In February 2025 the LPSC staff reviewed the filed rider rates and identified no material issues. In July 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $50.2 million, or $9.8 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of September 2025 through February 2026. Additionally, Entergy Louisiana’s true-up filing included an under-recovery totaling $5.6 million to be implemented in the January 2026 semi-annual filing. In August 2025 the LPSC staff reviewed the filed rider rates and identified no material issues. In January 2026, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $101.8 million, or $51.6 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of March 2026 through August 2026. Additionally, Entergy Louisiana’s true-up filing included an over-recovery totaling $16.6 million to be implemented in the July 2026 semi-annual filing. In February 2026 the LPSC staff reviewed the filed rider rates and identified no material issues. Filings with the MPSC (Entergy Mississippi) Retail Rates 2026 Formula Rate Plan Filing In February 2026, Entergy Mississippi submitted its formula rate plan 2026 test year filing and 2025 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2025 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2026 calendar year to also be within the formula rate plan bandwidth. The 2026 test year filing resulted in an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2025 look-back filing compared actual 2025 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 $293 thousand to reflect one outside-the-bandwidth change, a true-up of demand side management costs. A final order is expected in second quarter 2026. Filings with the City Council (Entergy New Orleans) Retail Rates 2026 Formula Rate Plan Filing In April 2026, Entergy New Orleans submitted to the City Council its formula rate plan 2025 test year filing. The 2025 evaluation report produced an earned return on equity of 7.55% compared to the authorized return on equity of 9.35%. Without adjustments, this would result in an increase in rates of $16.6 million. The increase in rates is driven, in part, by an increase in plant in service, as well as the cost of known and measurable capital additions. The increase is also driven by a decrease in total revenues due to a decline in kWh sales. The filing is subject to a 75-day review and discovery period followed by a 25-day period to resolve any disputes among the parties. For any disputed items, the City Council would set a procedural schedule to resolve such disputes. Resulting rates will be effective with the first billing cycle of September 2026 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 2026, 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 $112.5 million annually, or $20.4 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between July 1, 2025 and December 31, 2025. Transmission Cost Recovery Factor (TCRF) Rider As discussed in the Form 10-K, in October 2025, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $30.3 million annually, or $20.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2024 and June 30, 2025 and changes in other transmission charges. In April 2026 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 6, 2026. Generation Cost Recovery Rider In March 2026, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its capital investment in the Orange County Advanced Power Station. The proposed generation cost recovery rider, which includes Entergy Texas’s capital invested in generation for the Orange County Advanced Power Station through December 31, 2025, is designed to collect approximately $150.4 million annually from Entergy Texas’s retail customers. By statute, the proposed generation cost recovery rider rates are to become effective when the Orange County Advanced Power Station is placed into service, which is expected in third quarter 2026. Entergy Arkansas Opportunity Sales Proceeding See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. Complaints Against System Energy See Note 2 to the financial statements in the Form 10-K for information regarding complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints. Unit Power Sales Agreement See Note 2 to the financial statements in the Form 10-K for discussion of the Unit Power Sales Agreement. 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. 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.
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 2026, 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 $0.01333 per kWh to $0.01508 per kWh. The primary reason for the rate increase was an under-recovered balance as a result of higher natural gas prices in 2025. Based on circumstances related to ANO 2’s refueling outage, Entergy Arkansas made an adjustment to projected energy costs to phase-in the rate increase gradually. The redetermined rate of $0.01508 per kWh became effective with the first billing cycle in April 2026 through the normal operation of the tariff. Entergy Louisiana As discussed in the Form 10-K, in June 2025 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings (for Entergy Louisiana’s gas operations). The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from January 2023 through June 2025. The LPSC staff issued its audit report in March 2026, and although certain internal record keeping recommendations were made, the LPSC staff did not recommend any disallowances. The next step is for the LPSC to issue its final report, but there is no deadline or timing requirement associated with the issuance of the final report. In February 2026, Entergy Louisiana, in its monthly filing to update its fuel adjustment clause, requested to defer approximately $141.9 million of fuel costs incurred in January 2026 that were primarily attributable to the effects of Winter Storm Fern, consistent with the LPSC’s general order approved at its February 2026 meeting permitting temporary modifications to the LPSC’s fuel adjustment clause general order. The filing proposes to defer the recovery of these fuel costs over a four-month period from March 2026 through June 2026 to mitigate the customer bill impacts of these fuel costs. In April 2026 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment clause for the period from 2023 through 2025. 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 2026 Base Rate Case In February 2026, Entergy Arkansas filed with the APSC a general change in rates, charges, and tariffs. The filing requested a base rate increase to recover a base rate revenue deficiency of $44.6 million and notified the APSC of Entergy Arkansas’s intent to implement a forward test year formula rate plan pursuant to Arkansas legislation passed in 2015. The primary drivers of the revenue deficiency were increased depreciation expense and the impact of net capital additions. Additionally, the filing requested a 9.90% return on common equity and increased depreciation rates as the result of a depreciation study. In March 2026 the APSC issued an order suspending the proposed rates and tariffs filed by Entergy Arkansas and will establish a procedural schedule by subsequent order. Generating Arkansas Jobs Act Rider In March 2026, Entergy Arkansas filed its first annual update to the strategic investment recovery rider, requesting recovery of $110.4 million of financing costs during construction of generation and transmission strategic investments related to Ironwood Power Station, Jefferson Power Station, and the Arkansas Cypress Solar facility. The revised rates are requested to be effective for bills rendered on the first billing cycle of June 2026. In April 2026 the APSC general staff filed testimony arguing that the APSC had not issued an order designating Ironwood Power Station as a strategic investment and that related costs should therefore be removed from the annual update. Also in April 2026, Entergy Arkansas filed testimony asserting that the APSC general staff’s position is contrary to the plain language of the statute, which includes an exception for facilities like Ironwood Power Station that were certified by the APSC within a certain timeframe. A hearing was held in April 2026. Production Tax Credit Tariff As discussed in Note 3 to the financial statements in the Form 10-K, in January 2026 the APSC opened a docket to investigate the sale of Entergy Arkansas’s nuclear production tax credits and the appropriate ratemaking treatment of production tax credits for all of Entergy Arkansas’s eligible resources, including how the proceeds of any sales should flow through to customers. As directed by the APSC, in February 2026, Entergy Arkansas submitted a compliance filing to the APSC verifying the status of the solar production tax credits. The filing also verified that the net proceeds from the sale of the nuclear production tax credits were recorded in FERC accounts that are accruing a return for customers’ benefit at a rate that is above the customer deposit rate. Subsequently, in March 2026, Entergy Arkansas filed testimony setting forth its proposal for the solar production tax credits. Specifically, Entergy Arkansas requested the same ratemaking treatment for all of the solar facilities that the APSC already approved for Walnut Bend (i.e., the total net monetized proceeds from production tax credits expected to be generated over the first ten years of a solar facility’s operation are estimated and then amortized over the expected useful life of the asset, which is typically 30 years). Additionally, consistent with prior orders for these resources, the deferred tax asset balances associated with both the production tax credits and the tax gross-up of the regulatory liability will be recognized as a reduction to the overall accumulated deferred income tax liability balance in Entergy Arkansas’s calculation of its weighted average cost of capital providing a return on the unamortized balance for the benefit of customers. Further, Entergy Arkansas proposes to flow the benefits of the solar production tax credits to customers through Entergy Arkansas’s formula rate plan, effective with the formula rate plan rates that will go into effect January 1, 2027. Entergy Arkansas’s proposal would result in the benefits of the production tax credits being passed through to customers, if approved, as reductions in revenue requirement evenly over the life of the assets, rather than only during the 10-year period in which the production tax credits are generated. In April 2026 the APSC general staff filed testimony proposing an amortization period of no more than 15 years for the monetized proceeds for the tax credits associated with the West Memphis Solar and Driver Solar facilities. An evidentiary hearing is scheduled for July 2026. Special Rate Contract and Arkansas Cypress Solar As discussed in the Form 10-K, in September 2025, Entergy Arkansas filed an application with the APSC seeking a certificate of environmental compatibility and public need for the construction and operation of the Arkansas Cypress Solar facility, a planned 600 MW solar photovoltaic array with a 350 MW battery energy storage system and associated transmission facilities interconnecting at Entergy Arkansas’s White Bluff substation. The estimated cost of the project is $1,602 million. In March 2026 the APSC approved the Arkansas Cypress Solar facility and Entergy Arkansas’s recovery of the costs of the facility through the Generating Arkansas Jobs Act rider. The APSC also ordered implementation of an independent monitor to oversee costs. In April 2026, Entergy Arkansas filed with the APSC its proposal for an independent monitor to oversee the reasonableness of costs. In April 2026 the APSC issued an order consolidating Entergy Arkansas’s cost independent monitor proposals for three pending resources, including the Arkansas Cypress Solar facility, into a single docket and directing parties with full intervention status to respond to the proposals and recommend independent monitor candidates. The facility is expected to be in service by the end of 2028. Filings with the LPSC (Entergy Louisiana) Retail Rates Resilience Plan Cost Recovery Rider In December 2022, Entergy Louisiana filed an application with the LPSC seeking a public interest finding regarding Phase I of Entergy Louisiana’s Future Ready resilience plan and approval of a rider mechanism to recover the program’s costs. Phase I in the December 2022 application reflected the first five years of a ten-year resilience plan and included investment of approximately $5 billion, including hardening investment, transmission dead-end structures, enhanced vegetation management, and telecommunications improvement. In April 2024 the LPSC approved a framework which includes an initial five-year resilience plan providing for an investment of approximately $1.9 billion with cost recovery via a forward-looking rider with semi-annual true-ups. The plan is subject to specified reporting requirements and includes a performance review of the hardened assets. The LPSC order approving the framework does not include any restrictions on Entergy Louisiana’s ability to file applications for approval of additional investments in resilience. In January 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $40.4 million, or $38.9 million in incremental annual revenues from Entergy Louisiana’s first semi-annual filing in July 2024, for projects expected to be placed in service during the rate-effective period of March 2025 through August 2025. In February 2025 the LPSC staff reviewed the filed rider rates and identified no material issues. In July 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $50.2 million, or $9.8 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of September 2025 through February 2026. Additionally, Entergy Louisiana’s true-up filing included an under-recovery totaling $5.6 million to be implemented in the January 2026 semi-annual filing. In August 2025 the LPSC staff reviewed the filed rider rates and identified no material issues. In January 2026, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $101.8 million, or $51.6 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of March 2026 through August 2026. Additionally, Entergy Louisiana’s true-up filing included an over-recovery totaling $16.6 million to be implemented in the July 2026 semi-annual filing. In February 2026 the LPSC staff reviewed the filed rider rates and identified no material issues. Filings with the MPSC (Entergy Mississippi) Retail Rates 2026 Formula Rate Plan Filing In February 2026, Entergy Mississippi submitted its formula rate plan 2026 test year filing and 2025 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2025 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2026 calendar year to also be within the formula rate plan bandwidth. The 2026 test year filing resulted in an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2025 look-back filing compared actual 2025 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 $293 thousand to reflect one outside-the-bandwidth change, a true-up of demand side management costs. A final order is expected in second quarter 2026. Filings with the City Council (Entergy New Orleans) Retail Rates 2026 Formula Rate Plan Filing In April 2026, Entergy New Orleans submitted to the City Council its formula rate plan 2025 test year filing. The 2025 evaluation report produced an earned return on equity of 7.55% compared to the authorized return on equity of 9.35%. Without adjustments, this would result in an increase in rates of $16.6 million. The increase in rates is driven, in part, by an increase in plant in service, as well as the cost of known and measurable capital additions. The increase is also driven by a decrease in total revenues due to a decline in kWh sales. The filing is subject to a 75-day review and discovery period followed by a 25-day period to resolve any disputes among the parties. For any disputed items, the City Council would set a procedural schedule to resolve such disputes. Resulting rates will be effective with the first billing cycle of September 2026 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 2026, 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 $112.5 million annually, or $20.4 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between July 1, 2025 and December 31, 2025. Transmission Cost Recovery Factor (TCRF) Rider As discussed in the Form 10-K, in October 2025, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $30.3 million annually, or $20.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2024 and June 30, 2025 and changes in other transmission charges. In April 2026 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 6, 2026. Generation Cost Recovery Rider In March 2026, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its capital investment in the Orange County Advanced Power Station. The proposed generation cost recovery rider, which includes Entergy Texas’s capital invested in generation for the Orange County Advanced Power Station through December 31, 2025, is designed to collect approximately $150.4 million annually from Entergy Texas’s retail customers. By statute, the proposed generation cost recovery rider rates are to become effective when the Orange County Advanced Power Station is placed into service, which is expected in third quarter 2026. Entergy Arkansas Opportunity Sales Proceeding See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. Complaints Against System Energy See Note 2 to the financial statements in the Form 10-K for information regarding complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints. Unit Power Sales Agreement See Note 2 to the financial statements in the Form 10-K for discussion of the Unit Power Sales Agreement. 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. 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.
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 2026, 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 $0.01333 per kWh to $0.01508 per kWh. The primary reason for the rate increase was an under-recovered balance as a result of higher natural gas prices in 2025. Based on circumstances related to ANO 2’s refueling outage, Entergy Arkansas made an adjustment to projected energy costs to phase-in the rate increase gradually. The redetermined rate of $0.01508 per kWh became effective with the first billing cycle in April 2026 through the normal operation of the tariff. Entergy Louisiana As discussed in the Form 10-K, in June 2025 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings (for Entergy Louisiana’s gas operations). The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from January 2023 through June 2025. The LPSC staff issued its audit report in March 2026, and although certain internal record keeping recommendations were made, the LPSC staff did not recommend any disallowances. The next step is for the LPSC to issue its final report, but there is no deadline or timing requirement associated with the issuance of the final report. In February 2026, Entergy Louisiana, in its monthly filing to update its fuel adjustment clause, requested to defer approximately $141.9 million of fuel costs incurred in January 2026 that were primarily attributable to the effects of Winter Storm Fern, consistent with the LPSC’s general order approved at its February 2026 meeting permitting temporary modifications to the LPSC’s fuel adjustment clause general order. The filing proposes to defer the recovery of these fuel costs over a four-month period from March 2026 through June 2026 to mitigate the customer bill impacts of these fuel costs. In April 2026 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment clause for the period from 2023 through 2025. 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 2026 Base Rate Case In February 2026, Entergy Arkansas filed with the APSC a general change in rates, charges, and tariffs. The filing requested a base rate increase to recover a base rate revenue deficiency of $44.6 million and notified the APSC of Entergy Arkansas’s intent to implement a forward test year formula rate plan pursuant to Arkansas legislation passed in 2015. The primary drivers of the revenue deficiency were increased depreciation expense and the impact of net capital additions. Additionally, the filing requested a 9.90% return on common equity and increased depreciation rates as the result of a depreciation study. In March 2026 the APSC issued an order suspending the proposed rates and tariffs filed by Entergy Arkansas and will establish a procedural schedule by subsequent order. Generating Arkansas Jobs Act Rider In March 2026, Entergy Arkansas filed its first annual update to the strategic investment recovery rider, requesting recovery of $110.4 million of financing costs during construction of generation and transmission strategic investments related to Ironwood Power Station, Jefferson Power Station, and the Arkansas Cypress Solar facility. The revised rates are requested to be effective for bills rendered on the first billing cycle of June 2026. In April 2026 the APSC general staff filed testimony arguing that the APSC had not issued an order designating Ironwood Power Station as a strategic investment and that related costs should therefore be removed from the annual update. Also in April 2026, Entergy Arkansas filed testimony asserting that the APSC general staff’s position is contrary to the plain language of the statute, which includes an exception for facilities like Ironwood Power Station that were certified by the APSC within a certain timeframe. A hearing was held in April 2026. Production Tax Credit Tariff As discussed in Note 3 to the financial statements in the Form 10-K, in January 2026 the APSC opened a docket to investigate the sale of Entergy Arkansas’s nuclear production tax credits and the appropriate ratemaking treatment of production tax credits for all of Entergy Arkansas’s eligible resources, including how the proceeds of any sales should flow through to customers. As directed by the APSC, in February 2026, Entergy Arkansas submitted a compliance filing to the APSC verifying the status of the solar production tax credits. The filing also verified that the net proceeds from the sale of the nuclear production tax credits were recorded in FERC accounts that are accruing a return for customers’ benefit at a rate that is above the customer deposit rate. Subsequently, in March 2026, Entergy Arkansas filed testimony setting forth its proposal for the solar production tax credits. Specifically, Entergy Arkansas requested the same ratemaking treatment for all of the solar facilities that the APSC already approved for Walnut Bend (i.e., the total net monetized proceeds from production tax credits expected to be generated over the first ten years of a solar facility’s operation are estimated and then amortized over the expected useful life of the asset, which is typically 30 years). Additionally, consistent with prior orders for these resources, the deferred tax asset balances associated with both the production tax credits and the tax gross-up of the regulatory liability will be recognized as a reduction to the overall accumulated deferred income tax liability balance in Entergy Arkansas’s calculation of its weighted average cost of capital providing a return on the unamortized balance for the benefit of customers. Further, Entergy Arkansas proposes to flow the benefits of the solar production tax credits to customers through Entergy Arkansas’s formula rate plan, effective with the formula rate plan rates that will go into effect January 1, 2027. Entergy Arkansas’s proposal would result in the benefits of the production tax credits being passed through to customers, if approved, as reductions in revenue requirement evenly over the life of the assets, rather than only during the 10-year period in which the production tax credits are generated. In April 2026 the APSC general staff filed testimony proposing an amortization period of no more than 15 years for the monetized proceeds for the tax credits associated with the West Memphis Solar and Driver Solar facilities. An evidentiary hearing is scheduled for July 2026. Special Rate Contract and Arkansas Cypress Solar As discussed in the Form 10-K, in September 2025, Entergy Arkansas filed an application with the APSC seeking a certificate of environmental compatibility and public need for the construction and operation of the Arkansas Cypress Solar facility, a planned 600 MW solar photovoltaic array with a 350 MW battery energy storage system and associated transmission facilities interconnecting at Entergy Arkansas’s White Bluff substation. The estimated cost of the project is $1,602 million. In March 2026 the APSC approved the Arkansas Cypress Solar facility and Entergy Arkansas’s recovery of the costs of the facility through the Generating Arkansas Jobs Act rider. The APSC also ordered implementation of an independent monitor to oversee costs. In April 2026, Entergy Arkansas filed with the APSC its proposal for an independent monitor to oversee the reasonableness of costs. In April 2026 the APSC issued an order consolidating Entergy Arkansas’s cost independent monitor proposals for three pending resources, including the Arkansas Cypress Solar facility, into a single docket and directing parties with full intervention status to respond to the proposals and recommend independent monitor candidates. The facility is expected to be in service by the end of 2028. Filings with the LPSC (Entergy Louisiana) Retail Rates Resilience Plan Cost Recovery Rider In December 2022, Entergy Louisiana filed an application with the LPSC seeking a public interest finding regarding Phase I of Entergy Louisiana’s Future Ready resilience plan and approval of a rider mechanism to recover the program’s costs. Phase I in the December 2022 application reflected the first five years of a ten-year resilience plan and included investment of approximately $5 billion, including hardening investment, transmission dead-end structures, enhanced vegetation management, and telecommunications improvement. In April 2024 the LPSC approved a framework which includes an initial five-year resilience plan providing for an investment of approximately $1.9 billion with cost recovery via a forward-looking rider with semi-annual true-ups. The plan is subject to specified reporting requirements and includes a performance review of the hardened assets. The LPSC order approving the framework does not include any restrictions on Entergy Louisiana’s ability to file applications for approval of additional investments in resilience. In January 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $40.4 million, or $38.9 million in incremental annual revenues from Entergy Louisiana’s first semi-annual filing in July 2024, for projects expected to be placed in service during the rate-effective period of March 2025 through August 2025. In February 2025 the LPSC staff reviewed the filed rider rates and identified no material issues. In July 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $50.2 million, or $9.8 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of September 2025 through February 2026. Additionally, Entergy Louisiana’s true-up filing included an under-recovery totaling $5.6 million to be implemented in the January 2026 semi-annual filing. In August 2025 the LPSC staff reviewed the filed rider rates and identified no material issues. In January 2026, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $101.8 million, or $51.6 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of March 2026 through August 2026. Additionally, Entergy Louisiana’s true-up filing included an over-recovery totaling $16.6 million to be implemented in the July 2026 semi-annual filing. In February 2026 the LPSC staff reviewed the filed rider rates and identified no material issues. Filings with the MPSC (Entergy Mississippi) Retail Rates 2026 Formula Rate Plan Filing In February 2026, Entergy Mississippi submitted its formula rate plan 2026 test year filing and 2025 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2025 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2026 calendar year to also be within the formula rate plan bandwidth. The 2026 test year filing resulted in an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2025 look-back filing compared actual 2025 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 $293 thousand to reflect one outside-the-bandwidth change, a true-up of demand side management costs. A final order is expected in second quarter 2026. Filings with the City Council (Entergy New Orleans) Retail Rates 2026 Formula Rate Plan Filing In April 2026, Entergy New Orleans submitted to the City Council its formula rate plan 2025 test year filing. The 2025 evaluation report produced an earned return on equity of 7.55% compared to the authorized return on equity of 9.35%. Without adjustments, this would result in an increase in rates of $16.6 million. The increase in rates is driven, in part, by an increase in plant in service, as well as the cost of known and measurable capital additions. The increase is also driven by a decrease in total revenues due to a decline in kWh sales. The filing is subject to a 75-day review and discovery period followed by a 25-day period to resolve any disputes among the parties. For any disputed items, the City Council would set a procedural schedule to resolve such disputes. Resulting rates will be effective with the first billing cycle of September 2026 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 2026, 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 $112.5 million annually, or $20.4 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between July 1, 2025 and December 31, 2025. Transmission Cost Recovery Factor (TCRF) Rider As discussed in the Form 10-K, in October 2025, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $30.3 million annually, or $20.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2024 and June 30, 2025 and changes in other transmission charges. In April 2026 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 6, 2026. Generation Cost Recovery Rider In March 2026, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its capital investment in the Orange County Advanced Power Station. The proposed generation cost recovery rider, which includes Entergy Texas’s capital invested in generation for the Orange County Advanced Power Station through December 31, 2025, is designed to collect approximately $150.4 million annually from Entergy Texas’s retail customers. By statute, the proposed generation cost recovery rider rates are to become effective when the Orange County Advanced Power Station is placed into service, which is expected in third quarter 2026. Entergy Arkansas Opportunity Sales Proceeding See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. Complaints Against System Energy See Note 2 to the financial statements in the Form 10-K for information regarding complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints. Unit Power Sales Agreement See Note 2 to the financial statements in the Form 10-K for discussion of the Unit Power Sales Agreement. 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. 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.
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 2026, 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 $0.01333 per kWh to $0.01508 per kWh. The primary reason for the rate increase was an under-recovered balance as a result of higher natural gas prices in 2025. Based on circumstances related to ANO 2’s refueling outage, Entergy Arkansas made an adjustment to projected energy costs to phase-in the rate increase gradually. The redetermined rate of $0.01508 per kWh became effective with the first billing cycle in April 2026 through the normal operation of the tariff. Entergy Louisiana As discussed in the Form 10-K, in June 2025 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings (for Entergy Louisiana’s gas operations). The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from January 2023 through June 2025. The LPSC staff issued its audit report in March 2026, and although certain internal record keeping recommendations were made, the LPSC staff did not recommend any disallowances. The next step is for the LPSC to issue its final report, but there is no deadline or timing requirement associated with the issuance of the final report. In February 2026, Entergy Louisiana, in its monthly filing to update its fuel adjustment clause, requested to defer approximately $141.9 million of fuel costs incurred in January 2026 that were primarily attributable to the effects of Winter Storm Fern, consistent with the LPSC’s general order approved at its February 2026 meeting permitting temporary modifications to the LPSC’s fuel adjustment clause general order. The filing proposes to defer the recovery of these fuel costs over a four-month period from March 2026 through June 2026 to mitigate the customer bill impacts of these fuel costs. In April 2026 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment clause for the period from 2023 through 2025. 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 2026 Base Rate Case In February 2026, Entergy Arkansas filed with the APSC a general change in rates, charges, and tariffs. The filing requested a base rate increase to recover a base rate revenue deficiency of $44.6 million and notified the APSC of Entergy Arkansas’s intent to implement a forward test year formula rate plan pursuant to Arkansas legislation passed in 2015. The primary drivers of the revenue deficiency were increased depreciation expense and the impact of net capital additions. Additionally, the filing requested a 9.90% return on common equity and increased depreciation rates as the result of a depreciation study. In March 2026 the APSC issued an order suspending the proposed rates and tariffs filed by Entergy Arkansas and will establish a procedural schedule by subsequent order. Generating Arkansas Jobs Act Rider In March 2026, Entergy Arkansas filed its first annual update to the strategic investment recovery rider, requesting recovery of $110.4 million of financing costs during construction of generation and transmission strategic investments related to Ironwood Power Station, Jefferson Power Station, and the Arkansas Cypress Solar facility. The revised rates are requested to be effective for bills rendered on the first billing cycle of June 2026. In April 2026 the APSC general staff filed testimony arguing that the APSC had not issued an order designating Ironwood Power Station as a strategic investment and that related costs should therefore be removed from the annual update. Also in April 2026, Entergy Arkansas filed testimony asserting that the APSC general staff’s position is contrary to the plain language of the statute, which includes an exception for facilities like Ironwood Power Station that were certified by the APSC within a certain timeframe. A hearing was held in April 2026. Production Tax Credit Tariff As discussed in Note 3 to the financial statements in the Form 10-K, in January 2026 the APSC opened a docket to investigate the sale of Entergy Arkansas’s nuclear production tax credits and the appropriate ratemaking treatment of production tax credits for all of Entergy Arkansas’s eligible resources, including how the proceeds of any sales should flow through to customers. As directed by the APSC, in February 2026, Entergy Arkansas submitted a compliance filing to the APSC verifying the status of the solar production tax credits. The filing also verified that the net proceeds from the sale of the nuclear production tax credits were recorded in FERC accounts that are accruing a return for customers’ benefit at a rate that is above the customer deposit rate. Subsequently, in March 2026, Entergy Arkansas filed testimony setting forth its proposal for the solar production tax credits. Specifically, Entergy Arkansas requested the same ratemaking treatment for all of the solar facilities that the APSC already approved for Walnut Bend (i.e., the total net monetized proceeds from production tax credits expected to be generated over the first ten years of a solar facility’s operation are estimated and then amortized over the expected useful life of the asset, which is typically 30 years). Additionally, consistent with prior orders for these resources, the deferred tax asset balances associated with both the production tax credits and the tax gross-up of the regulatory liability will be recognized as a reduction to the overall accumulated deferred income tax liability balance in Entergy Arkansas’s calculation of its weighted average cost of capital providing a return on the unamortized balance for the benefit of customers. Further, Entergy Arkansas proposes to flow the benefits of the solar production tax credits to customers through Entergy Arkansas’s formula rate plan, effective with the formula rate plan rates that will go into effect January 1, 2027. Entergy Arkansas’s proposal would result in the benefits of the production tax credits being passed through to customers, if approved, as reductions in revenue requirement evenly over the life of the assets, rather than only during the 10-year period in which the production tax credits are generated. In April 2026 the APSC general staff filed testimony proposing an amortization period of no more than 15 years for the monetized proceeds for the tax credits associated with the West Memphis Solar and Driver Solar facilities. An evidentiary hearing is scheduled for July 2026. Special Rate Contract and Arkansas Cypress Solar As discussed in the Form 10-K, in September 2025, Entergy Arkansas filed an application with the APSC seeking a certificate of environmental compatibility and public need for the construction and operation of the Arkansas Cypress Solar facility, a planned 600 MW solar photovoltaic array with a 350 MW battery energy storage system and associated transmission facilities interconnecting at Entergy Arkansas’s White Bluff substation. The estimated cost of the project is $1,602 million. In March 2026 the APSC approved the Arkansas Cypress Solar facility and Entergy Arkansas’s recovery of the costs of the facility through the Generating Arkansas Jobs Act rider. The APSC also ordered implementation of an independent monitor to oversee costs. In April 2026, Entergy Arkansas filed with the APSC its proposal for an independent monitor to oversee the reasonableness of costs. In April 2026 the APSC issued an order consolidating Entergy Arkansas’s cost independent monitor proposals for three pending resources, including the Arkansas Cypress Solar facility, into a single docket and directing parties with full intervention status to respond to the proposals and recommend independent monitor candidates. The facility is expected to be in service by the end of 2028. Filings with the LPSC (Entergy Louisiana) Retail Rates Resilience Plan Cost Recovery Rider In December 2022, Entergy Louisiana filed an application with the LPSC seeking a public interest finding regarding Phase I of Entergy Louisiana’s Future Ready resilience plan and approval of a rider mechanism to recover the program’s costs. Phase I in the December 2022 application reflected the first five years of a ten-year resilience plan and included investment of approximately $5 billion, including hardening investment, transmission dead-end structures, enhanced vegetation management, and telecommunications improvement. In April 2024 the LPSC approved a framework which includes an initial five-year resilience plan providing for an investment of approximately $1.9 billion with cost recovery via a forward-looking rider with semi-annual true-ups. The plan is subject to specified reporting requirements and includes a performance review of the hardened assets. The LPSC order approving the framework does not include any restrictions on Entergy Louisiana’s ability to file applications for approval of additional investments in resilience. In January 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $40.4 million, or $38.9 million in incremental annual revenues from Entergy Louisiana’s first semi-annual filing in July 2024, for projects expected to be placed in service during the rate-effective period of March 2025 through August 2025. In February 2025 the LPSC staff reviewed the filed rider rates and identified no material issues. In July 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $50.2 million, or $9.8 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of September 2025 through February 2026. Additionally, Entergy Louisiana’s true-up filing included an under-recovery totaling $5.6 million to be implemented in the January 2026 semi-annual filing. In August 2025 the LPSC staff reviewed the filed rider rates and identified no material issues. In January 2026, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $101.8 million, or $51.6 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of March 2026 through August 2026. Additionally, Entergy Louisiana’s true-up filing included an over-recovery totaling $16.6 million to be implemented in the July 2026 semi-annual filing. In February 2026 the LPSC staff reviewed the filed rider rates and identified no material issues. Filings with the MPSC (Entergy Mississippi) Retail Rates 2026 Formula Rate Plan Filing In February 2026, Entergy Mississippi submitted its formula rate plan 2026 test year filing and 2025 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2025 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2026 calendar year to also be within the formula rate plan bandwidth. The 2026 test year filing resulted in an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2025 look-back filing compared actual 2025 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 $293 thousand to reflect one outside-the-bandwidth change, a true-up of demand side management costs. A final order is expected in second quarter 2026. Filings with the City Council (Entergy New Orleans) Retail Rates 2026 Formula Rate Plan Filing In April 2026, Entergy New Orleans submitted to the City Council its formula rate plan 2025 test year filing. The 2025 evaluation report produced an earned return on equity of 7.55% compared to the authorized return on equity of 9.35%. Without adjustments, this would result in an increase in rates of $16.6 million. The increase in rates is driven, in part, by an increase in plant in service, as well as the cost of known and measurable capital additions. The increase is also driven by a decrease in total revenues due to a decline in kWh sales. The filing is subject to a 75-day review and discovery period followed by a 25-day period to resolve any disputes among the parties. For any disputed items, the City Council would set a procedural schedule to resolve such disputes. Resulting rates will be effective with the first billing cycle of September 2026 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 2026, 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 $112.5 million annually, or $20.4 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between July 1, 2025 and December 31, 2025. Transmission Cost Recovery Factor (TCRF) Rider As discussed in the Form 10-K, in October 2025, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $30.3 million annually, or $20.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2024 and June 30, 2025 and changes in other transmission charges. In April 2026 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 6, 2026. Generation Cost Recovery Rider In March 2026, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its capital investment in the Orange County Advanced Power Station. The proposed generation cost recovery rider, which includes Entergy Texas’s capital invested in generation for the Orange County Advanced Power Station through December 31, 2025, is designed to collect approximately $150.4 million annually from Entergy Texas’s retail customers. By statute, the proposed generation cost recovery rider rates are to become effective when the Orange County Advanced Power Station is placed into service, which is expected in third quarter 2026. Entergy Arkansas Opportunity Sales Proceeding See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. Complaints Against System Energy See Note 2 to the financial statements in the Form 10-K for information regarding complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints. Unit Power Sales Agreement See Note 2 to the financial statements in the Form 10-K for discussion of the Unit Power Sales Agreement. 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. 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.
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 2026, 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 $0.01333 per kWh to $0.01508 per kWh. The primary reason for the rate increase was an under-recovered balance as a result of higher natural gas prices in 2025. Based on circumstances related to ANO 2’s refueling outage, Entergy Arkansas made an adjustment to projected energy costs to phase-in the rate increase gradually. The redetermined rate of $0.01508 per kWh became effective with the first billing cycle in April 2026 through the normal operation of the tariff. Entergy Louisiana As discussed in the Form 10-K, in June 2025 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings (for Entergy Louisiana’s gas operations). The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from January 2023 through June 2025. The LPSC staff issued its audit report in March 2026, and although certain internal record keeping recommendations were made, the LPSC staff did not recommend any disallowances. The next step is for the LPSC to issue its final report, but there is no deadline or timing requirement associated with the issuance of the final report. In February 2026, Entergy Louisiana, in its monthly filing to update its fuel adjustment clause, requested to defer approximately $141.9 million of fuel costs incurred in January 2026 that were primarily attributable to the effects of Winter Storm Fern, consistent with the LPSC’s general order approved at its February 2026 meeting permitting temporary modifications to the LPSC’s fuel adjustment clause general order. The filing proposes to defer the recovery of these fuel costs over a four-month period from March 2026 through June 2026 to mitigate the customer bill impacts of these fuel costs. In April 2026 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment clause for the period from 2023 through 2025. 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 2026 Base Rate Case In February 2026, Entergy Arkansas filed with the APSC a general change in rates, charges, and tariffs. The filing requested a base rate increase to recover a base rate revenue deficiency of $44.6 million and notified the APSC of Entergy Arkansas’s intent to implement a forward test year formula rate plan pursuant to Arkansas legislation passed in 2015. The primary drivers of the revenue deficiency were increased depreciation expense and the impact of net capital additions. Additionally, the filing requested a 9.90% return on common equity and increased depreciation rates as the result of a depreciation study. In March 2026 the APSC issued an order suspending the proposed rates and tariffs filed by Entergy Arkansas and will establish a procedural schedule by subsequent order. Generating Arkansas Jobs Act Rider In March 2026, Entergy Arkansas filed its first annual update to the strategic investment recovery rider, requesting recovery of $110.4 million of financing costs during construction of generation and transmission strategic investments related to Ironwood Power Station, Jefferson Power Station, and the Arkansas Cypress Solar facility. The revised rates are requested to be effective for bills rendered on the first billing cycle of June 2026. In April 2026 the APSC general staff filed testimony arguing that the APSC had not issued an order designating Ironwood Power Station as a strategic investment and that related costs should therefore be removed from the annual update. Also in April 2026, Entergy Arkansas filed testimony asserting that the APSC general staff’s position is contrary to the plain language of the statute, which includes an exception for facilities like Ironwood Power Station that were certified by the APSC within a certain timeframe. A hearing was held in April 2026. Production Tax Credit Tariff As discussed in Note 3 to the financial statements in the Form 10-K, in January 2026 the APSC opened a docket to investigate the sale of Entergy Arkansas’s nuclear production tax credits and the appropriate ratemaking treatment of production tax credits for all of Entergy Arkansas’s eligible resources, including how the proceeds of any sales should flow through to customers. As directed by the APSC, in February 2026, Entergy Arkansas submitted a compliance filing to the APSC verifying the status of the solar production tax credits. The filing also verified that the net proceeds from the sale of the nuclear production tax credits were recorded in FERC accounts that are accruing a return for customers’ benefit at a rate that is above the customer deposit rate. Subsequently, in March 2026, Entergy Arkansas filed testimony setting forth its proposal for the solar production tax credits. Specifically, Entergy Arkansas requested the same ratemaking treatment for all of the solar facilities that the APSC already approved for Walnut Bend (i.e., the total net monetized proceeds from production tax credits expected to be generated over the first ten years of a solar facility’s operation are estimated and then amortized over the expected useful life of the asset, which is typically 30 years). Additionally, consistent with prior orders for these resources, the deferred tax asset balances associated with both the production tax credits and the tax gross-up of the regulatory liability will be recognized as a reduction to the overall accumulated deferred income tax liability balance in Entergy Arkansas’s calculation of its weighted average cost of capital providing a return on the unamortized balance for the benefit of customers. Further, Entergy Arkansas proposes to flow the benefits of the solar production tax credits to customers through Entergy Arkansas’s formula rate plan, effective with the formula rate plan rates that will go into effect January 1, 2027. Entergy Arkansas’s proposal would result in the benefits of the production tax credits being passed through to customers, if approved, as reductions in revenue requirement evenly over the life of the assets, rather than only during the 10-year period in which the production tax credits are generated. In April 2026 the APSC general staff filed testimony proposing an amortization period of no more than 15 years for the monetized proceeds for the tax credits associated with the West Memphis Solar and Driver Solar facilities. An evidentiary hearing is scheduled for July 2026. Special Rate Contract and Arkansas Cypress Solar As discussed in the Form 10-K, in September 2025, Entergy Arkansas filed an application with the APSC seeking a certificate of environmental compatibility and public need for the construction and operation of the Arkansas Cypress Solar facility, a planned 600 MW solar photovoltaic array with a 350 MW battery energy storage system and associated transmission facilities interconnecting at Entergy Arkansas’s White Bluff substation. The estimated cost of the project is $1,602 million. In March 2026 the APSC approved the Arkansas Cypress Solar facility and Entergy Arkansas’s recovery of the costs of the facility through the Generating Arkansas Jobs Act rider. The APSC also ordered implementation of an independent monitor to oversee costs. In April 2026, Entergy Arkansas filed with the APSC its proposal for an independent monitor to oversee the reasonableness of costs. In April 2026 the APSC issued an order consolidating Entergy Arkansas’s cost independent monitor proposals for three pending resources, including the Arkansas Cypress Solar facility, into a single docket and directing parties with full intervention status to respond to the proposals and recommend independent monitor candidates. The facility is expected to be in service by the end of 2028. Filings with the LPSC (Entergy Louisiana) Retail Rates Resilience Plan Cost Recovery Rider In December 2022, Entergy Louisiana filed an application with the LPSC seeking a public interest finding regarding Phase I of Entergy Louisiana’s Future Ready resilience plan and approval of a rider mechanism to recover the program’s costs. Phase I in the December 2022 application reflected the first five years of a ten-year resilience plan and included investment of approximately $5 billion, including hardening investment, transmission dead-end structures, enhanced vegetation management, and telecommunications improvement. In April 2024 the LPSC approved a framework which includes an initial five-year resilience plan providing for an investment of approximately $1.9 billion with cost recovery via a forward-looking rider with semi-annual true-ups. The plan is subject to specified reporting requirements and includes a performance review of the hardened assets. The LPSC order approving the framework does not include any restrictions on Entergy Louisiana’s ability to file applications for approval of additional investments in resilience. In January 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $40.4 million, or $38.9 million in incremental annual revenues from Entergy Louisiana’s first semi-annual filing in July 2024, for projects expected to be placed in service during the rate-effective period of March 2025 through August 2025. In February 2025 the LPSC staff reviewed the filed rider rates and identified no material issues. In July 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $50.2 million, or $9.8 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of September 2025 through February 2026. Additionally, Entergy Louisiana’s true-up filing included an under-recovery totaling $5.6 million to be implemented in the January 2026 semi-annual filing. In August 2025 the LPSC staff reviewed the filed rider rates and identified no material issues. In January 2026, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $101.8 million, or $51.6 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of March 2026 through August 2026. Additionally, Entergy Louisiana’s true-up filing included an over-recovery totaling $16.6 million to be implemented in the July 2026 semi-annual filing. In February 2026 the LPSC staff reviewed the filed rider rates and identified no material issues. Filings with the MPSC (Entergy Mississippi) Retail Rates 2026 Formula Rate Plan Filing In February 2026, Entergy Mississippi submitted its formula rate plan 2026 test year filing and 2025 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2025 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2026 calendar year to also be within the formula rate plan bandwidth. The 2026 test year filing resulted in an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2025 look-back filing compared actual 2025 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 $293 thousand to reflect one outside-the-bandwidth change, a true-up of demand side management costs. A final order is expected in second quarter 2026. Filings with the City Council (Entergy New Orleans) Retail Rates 2026 Formula Rate Plan Filing In April 2026, Entergy New Orleans submitted to the City Council its formula rate plan 2025 test year filing. The 2025 evaluation report produced an earned return on equity of 7.55% compared to the authorized return on equity of 9.35%. Without adjustments, this would result in an increase in rates of $16.6 million. The increase in rates is driven, in part, by an increase in plant in service, as well as the cost of known and measurable capital additions. The increase is also driven by a decrease in total revenues due to a decline in kWh sales. The filing is subject to a 75-day review and discovery period followed by a 25-day period to resolve any disputes among the parties. For any disputed items, the City Council would set a procedural schedule to resolve such disputes. Resulting rates will be effective with the first billing cycle of September 2026 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 2026, 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 $112.5 million annually, or $20.4 million in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between July 1, 2025 and December 31, 2025. Transmission Cost Recovery Factor (TCRF) Rider As discussed in the Form 10-K, in October 2025, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $30.3 million annually, or $20.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2024 and June 30, 2025 and changes in other transmission charges. In April 2026 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 6, 2026. Generation Cost Recovery Rider In March 2026, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its capital investment in the Orange County Advanced Power Station. The proposed generation cost recovery rider, which includes Entergy Texas’s capital invested in generation for the Orange County Advanced Power Station through December 31, 2025, is designed to collect approximately $150.4 million annually from Entergy Texas’s retail customers. By statute, the proposed generation cost recovery rider rates are to become effective when the Orange County Advanced Power Station is placed into service, which is expected in third quarter 2026. Entergy Arkansas Opportunity Sales Proceeding See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. Complaints Against System Energy See Note 2 to the financial statements in the Form 10-K for information regarding complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints. Unit Power Sales Agreement See Note 2 to the financial statements in the Form 10-K for discussion of the Unit Power Sales Agreement. 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. 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.

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 2026, 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 $0.01333 per kWh to $0.01508 per kWh. The primary reason for the rate increase was an under-recovered balance as a result of higher natural gas prices in 2025. Based on circumstances related to ANO 2’s refueling outage, Entergy Arkansas made an adjustment to projected energy costs to phase-in the rate increase gradually. The redetermined rate of $0.01508 per kWh became effective with the first billing cycle in April 2026 through the normal operation of the tariff.

Entergy Louisiana

As discussed in the Form 10-K, in June 2025 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings (for Entergy Louisiana’s gas operations). The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from January 2023 through June 2025. The LPSC staff issued its audit report in March 2026, and although certain internal record keeping recommendations were made, the LPSC staff did not recommend any disallowances. The next step is for the LPSC to issue its final report, but there is no deadline or timing requirement associated with the issuance of the final report.

In February 2026, Entergy Louisiana, in its monthly filing to update its fuel adjustment clause, requested to defer approximately $141.9 million of fuel costs incurred in January 2026 that were primarily attributable to the effects of Winter Storm Fern, consistent with the LPSC’s general order approved at its February 2026 meeting

permitting temporary modifications to the LPSC’s fuel adjustment clause general order. The filing proposes to defer the recovery of these fuel costs over a four-month period from March 2026 through June 2026 to mitigate the customer bill impacts of these fuel costs.

In April 2026 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment clause for the period from 2023 through 2025.

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

2026 Base Rate Case

In February 2026, Entergy Arkansas filed with the APSC a general change in rates, charges, and tariffs. The filing requested a base rate increase to recover a base rate revenue deficiency of $44.6 million and notified the APSC of Entergy Arkansas’s intent to implement a forward test year formula rate plan pursuant to Arkansas legislation passed in 2015. The primary drivers of the revenue deficiency were increased depreciation expense and the impact of net capital additions. Additionally, the filing requested a 9.90% return on common equity and increased depreciation rates as the result of a depreciation study. In March 2026 the APSC issued an order suspending the proposed rates and tariffs filed by Entergy Arkansas and will establish a procedural schedule by subsequent order.

Generating Arkansas Jobs Act Rider

In March 2026, Entergy Arkansas filed its first annual update to the strategic investment recovery rider, requesting recovery of $110.4 million of financing costs during construction of generation and transmission strategic investments related to Ironwood Power Station, Jefferson Power Station, and the Arkansas Cypress Solar facility. The revised rates are requested to be effective for bills rendered on the first billing cycle of June 2026. In April 2026 the APSC general staff filed testimony arguing that the APSC had not issued an order designating Ironwood Power Station as a strategic investment and that related costs should therefore be removed from the annual update. Also in April 2026, Entergy Arkansas filed testimony asserting that the APSC general staff’s position is contrary to the plain language of the statute, which includes an exception for facilities like Ironwood Power Station that were certified by the APSC within a certain timeframe. A hearing was held in April 2026.

Production Tax Credit Tariff

As discussed in Note 3 to the financial statements in the Form 10-K, in January 2026 the APSC opened a docket to investigate the sale of Entergy Arkansas’s nuclear production tax credits and the appropriate ratemaking treatment of production tax credits for all of Entergy Arkansas’s eligible resources, including how the proceeds of any sales should flow through to customers. As directed by the APSC, in February 2026, Entergy Arkansas submitted a compliance filing to the APSC verifying the status of the solar production tax credits. The filing also verified that the net proceeds from the sale of the nuclear production tax credits were recorded in FERC accounts that are accruing a return for customers’ benefit at a rate that is above the customer deposit rate. Subsequently, in March 2026, Entergy Arkansas filed testimony setting forth its proposal for the solar production tax credits. Specifically, Entergy Arkansas requested the same ratemaking treatment for all of the solar facilities that the APSC already approved for Walnut Bend (i.e., the total net monetized proceeds from production tax credits expected to be

generated over the first ten years of a solar facility’s operation are estimated and then amortized over the expected useful life of the asset, which is typically 30 years). Additionally, consistent with prior orders for these resources, the deferred tax asset balances associated with both the production tax credits and the tax gross-up of the regulatory liability will be recognized as a reduction to the overall accumulated deferred income tax liability balance in Entergy Arkansas’s calculation of its weighted average cost of capital providing a return on the unamortized balance for the benefit of customers. Further, Entergy Arkansas proposes to flow the benefits of the solar production tax credits to customers through Entergy Arkansas’s formula rate plan, effective with the formula rate plan rates that will go into effect January 1, 2027. Entergy Arkansas’s proposal would result in the benefits of the production tax credits being passed through to customers, if approved, as reductions in revenue requirement evenly over the life of the assets, rather than only during the 10-year period in which the production tax credits are generated. In April 2026 the APSC general staff filed testimony proposing an amortization period of no more than 15 years for the monetized proceeds for the tax credits associated with the West Memphis Solar and Driver Solar facilities. An evidentiary hearing is scheduled for July 2026.

Special Rate Contract and Arkansas Cypress Solar

As discussed in the Form 10-K, in September 2025, Entergy Arkansas filed an application with the APSC seeking a certificate of environmental compatibility and public need for the construction and operation of the Arkansas Cypress Solar facility, a planned 600 MW solar photovoltaic array with a 350 MW battery energy storage system and associated transmission facilities interconnecting at Entergy Arkansas’s White Bluff substation. The estimated cost of the project is $1,602 million. In March 2026 the APSC approved the Arkansas Cypress Solar facility and Entergy Arkansas’s recovery of the costs of the facility through the Generating Arkansas Jobs Act rider. The APSC also ordered implementation of an independent monitor to oversee costs. In April 2026, Entergy Arkansas filed with the APSC its proposal for an independent monitor to oversee the reasonableness of costs. In April 2026 the APSC issued an order consolidating Entergy Arkansas’s cost independent monitor proposals for three pending resources, including the Arkansas Cypress Solar facility, into a single docket and directing parties with full intervention status to respond to the proposals and recommend independent monitor candidates. The facility is expected to be in service by the end of 2028.

Filings with the LPSC (Entergy Louisiana)

Retail Rates

Resilience Plan Cost Recovery Rider

In December 2022, Entergy Louisiana filed an application with the LPSC seeking a public interest finding regarding Phase I of Entergy Louisiana’s Future Ready resilience plan and approval of a rider mechanism to recover the program’s costs. Phase I in the December 2022 application reflected the first five years of a ten-year resilience plan and included investment of approximately $5 billion, including hardening investment, transmission dead-end structures, enhanced vegetation management, and telecommunications improvement. In April 2024 the LPSC approved a framework which includes an initial five-year resilience plan providing for an investment of approximately $1.9 billion with cost recovery via a forward-looking rider with semi-annual true-ups. The plan is subject to specified reporting requirements and includes a performance review of the hardened assets. The LPSC order approving the framework does not include any restrictions on Entergy Louisiana’s ability to file applications for approval of additional investments in resilience.

In January 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $40.4 million, or $38.9 million in incremental annual revenues from Entergy Louisiana’s first semi-annual filing in July 2024, for projects expected to be placed in service during the rate-effective period of March 2025 through August 2025. In February 2025 the LPSC staff reviewed the filed rider rates and identified no material issues.

In July 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $50.2 million, or $9.8 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of September 2025 through February 2026. Additionally, Entergy Louisiana’s true-up filing included an under-recovery totaling $5.6 million to be implemented in the January 2026 semi-annual filing. In August 2025 the LPSC staff reviewed the filed rider rates and identified no material issues.

In January 2026, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $101.8 million, or $51.6 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of March 2026 through August 2026. Additionally, Entergy Louisiana’s true-up filing included an over-recovery totaling $16.6 million to be implemented in the July 2026 semi-annual filing. In February 2026 the LPSC staff reviewed the filed rider rates and identified no material issues.

Filings with the MPSC (Entergy Mississippi)

Retail Rates

2026 Formula Rate Plan Filing

In February 2026, Entergy Mississippi submitted its formula rate plan 2026 test year filing and 2025 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2025 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2026 calendar year to also be within the formula rate plan bandwidth. The 2026 test year filing resulted in an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2025 look-back filing compared actual 2025 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 $293 thousand to reflect one outside-the-bandwidth change, a true-up of demand side management costs. A final order is expected in second quarter 2026.

Filings with the City Council (Entergy New Orleans)

Retail Rates

2026 Formula Rate Plan Filing

In April 2026, Entergy New Orleans submitted to the City Council its formula rate plan 2025 test year filing. The 2025 evaluation report produced an earned return on equity of 7.55% compared to the authorized return on equity of 9.35%. Without adjustments, this would result in an increase in rates of $16.6 million. The increase in rates is driven, in part, by an increase in plant in service, as well as the cost of known and measurable capital additions. The increase is also driven by a decrease in total revenues due to a decline in kWh sales. The filing is subject to a 75-day review and discovery period followed by a 25-day period to resolve any disputes among the parties. For any disputed items, the City Council would set a procedural schedule to resolve such disputes. Resulting rates will be effective with the first billing cycle of September 2026 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 2026, 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 $112.5 million annually, or $20.4 million

in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between July 1, 2025 and December 31, 2025.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2025, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $30.3 million annually, or $20.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2024 and June 30, 2025 and changes in other transmission charges. In April 2026 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 6, 2026.

Generation Cost Recovery Rider

In March 2026, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its capital investment in the Orange County Advanced Power Station. The proposed generation cost recovery rider, which includes Entergy Texas’s capital invested in generation for the Orange County Advanced Power Station through December 31, 2025, is designed to collect approximately $150.4 million annually from Entergy Texas’s retail customers. By statute, the proposed generation cost recovery rider rates are to become effective when the Orange County Advanced Power Station is placed into service, which is expected in third quarter 2026.

Entergy Arkansas Opportunity Sales Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints.

Unit Power Sales Agreement

See Note 2 to the financial statements in the Form 10-K for discussion of the Unit Power Sales Agreement.

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.

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.

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 2026, 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 $0.01333 per kWh to $0.01508 per kWh. The primary reason for the rate increase was an under-recovered balance as a result of higher natural gas prices in 2025. Based on circumstances related to ANO 2’s refueling outage, Entergy Arkansas made an adjustment to projected energy costs to phase-in the rate increase gradually. The redetermined rate of $0.01508 per kWh became effective with the first billing cycle in April 2026 through the normal operation of the tariff.

Entergy Louisiana

As discussed in the Form 10-K, in June 2025 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings (for Entergy Louisiana’s gas operations). The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from January 2023 through June 2025. The LPSC staff issued its audit report in March 2026, and although certain internal record keeping recommendations were made, the LPSC staff did not recommend any disallowances. The next step is for the LPSC to issue its final report, but there is no deadline or timing requirement associated with the issuance of the final report.

In February 2026, Entergy Louisiana, in its monthly filing to update its fuel adjustment clause, requested to defer approximately $141.9 million of fuel costs incurred in January 2026 that were primarily attributable to the effects of Winter Storm Fern, consistent with the LPSC’s general order approved at its February 2026 meeting

permitting temporary modifications to the LPSC’s fuel adjustment clause general order. The filing proposes to defer the recovery of these fuel costs over a four-month period from March 2026 through June 2026 to mitigate the customer bill impacts of these fuel costs.

In April 2026 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment clause for the period from 2023 through 2025.

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

2026 Base Rate Case

In February 2026, Entergy Arkansas filed with the APSC a general change in rates, charges, and tariffs. The filing requested a base rate increase to recover a base rate revenue deficiency of $44.6 million and notified the APSC of Entergy Arkansas’s intent to implement a forward test year formula rate plan pursuant to Arkansas legislation passed in 2015. The primary drivers of the revenue deficiency were increased depreciation expense and the impact of net capital additions. Additionally, the filing requested a 9.90% return on common equity and increased depreciation rates as the result of a depreciation study. In March 2026 the APSC issued an order suspending the proposed rates and tariffs filed by Entergy Arkansas and will establish a procedural schedule by subsequent order.

Generating Arkansas Jobs Act Rider

In March 2026, Entergy Arkansas filed its first annual update to the strategic investment recovery rider, requesting recovery of $110.4 million of financing costs during construction of generation and transmission strategic investments related to Ironwood Power Station, Jefferson Power Station, and the Arkansas Cypress Solar facility. The revised rates are requested to be effective for bills rendered on the first billing cycle of June 2026. In April 2026 the APSC general staff filed testimony arguing that the APSC had not issued an order designating Ironwood Power Station as a strategic investment and that related costs should therefore be removed from the annual update. Also in April 2026, Entergy Arkansas filed testimony asserting that the APSC general staff’s position is contrary to the plain language of the statute, which includes an exception for facilities like Ironwood Power Station that were certified by the APSC within a certain timeframe. A hearing was held in April 2026.

Production Tax Credit Tariff

As discussed in Note 3 to the financial statements in the Form 10-K, in January 2026 the APSC opened a docket to investigate the sale of Entergy Arkansas’s nuclear production tax credits and the appropriate ratemaking treatment of production tax credits for all of Entergy Arkansas’s eligible resources, including how the proceeds of any sales should flow through to customers. As directed by the APSC, in February 2026, Entergy Arkansas submitted a compliance filing to the APSC verifying the status of the solar production tax credits. The filing also verified that the net proceeds from the sale of the nuclear production tax credits were recorded in FERC accounts that are accruing a return for customers’ benefit at a rate that is above the customer deposit rate. Subsequently, in March 2026, Entergy Arkansas filed testimony setting forth its proposal for the solar production tax credits. Specifically, Entergy Arkansas requested the same ratemaking treatment for all of the solar facilities that the APSC already approved for Walnut Bend (i.e., the total net monetized proceeds from production tax credits expected to be

generated over the first ten years of a solar facility’s operation are estimated and then amortized over the expected useful life of the asset, which is typically 30 years). Additionally, consistent with prior orders for these resources, the deferred tax asset balances associated with both the production tax credits and the tax gross-up of the regulatory liability will be recognized as a reduction to the overall accumulated deferred income tax liability balance in Entergy Arkansas’s calculation of its weighted average cost of capital providing a return on the unamortized balance for the benefit of customers. Further, Entergy Arkansas proposes to flow the benefits of the solar production tax credits to customers through Entergy Arkansas’s formula rate plan, effective with the formula rate plan rates that will go into effect January 1, 2027. Entergy Arkansas’s proposal would result in the benefits of the production tax credits being passed through to customers, if approved, as reductions in revenue requirement evenly over the life of the assets, rather than only during the 10-year period in which the production tax credits are generated. In April 2026 the APSC general staff filed testimony proposing an amortization period of no more than 15 years for the monetized proceeds for the tax credits associated with the West Memphis Solar and Driver Solar facilities. An evidentiary hearing is scheduled for July 2026.

Special Rate Contract and Arkansas Cypress Solar

As discussed in the Form 10-K, in September 2025, Entergy Arkansas filed an application with the APSC seeking a certificate of environmental compatibility and public need for the construction and operation of the Arkansas Cypress Solar facility, a planned 600 MW solar photovoltaic array with a 350 MW battery energy storage system and associated transmission facilities interconnecting at Entergy Arkansas’s White Bluff substation. The estimated cost of the project is $1,602 million. In March 2026 the APSC approved the Arkansas Cypress Solar facility and Entergy Arkansas’s recovery of the costs of the facility through the Generating Arkansas Jobs Act rider. The APSC also ordered implementation of an independent monitor to oversee costs. In April 2026, Entergy Arkansas filed with the APSC its proposal for an independent monitor to oversee the reasonableness of costs. In April 2026 the APSC issued an order consolidating Entergy Arkansas’s cost independent monitor proposals for three pending resources, including the Arkansas Cypress Solar facility, into a single docket and directing parties with full intervention status to respond to the proposals and recommend independent monitor candidates. The facility is expected to be in service by the end of 2028.

Filings with the LPSC (Entergy Louisiana)

Retail Rates

Resilience Plan Cost Recovery Rider

In December 2022, Entergy Louisiana filed an application with the LPSC seeking a public interest finding regarding Phase I of Entergy Louisiana’s Future Ready resilience plan and approval of a rider mechanism to recover the program’s costs. Phase I in the December 2022 application reflected the first five years of a ten-year resilience plan and included investment of approximately $5 billion, including hardening investment, transmission dead-end structures, enhanced vegetation management, and telecommunications improvement. In April 2024 the LPSC approved a framework which includes an initial five-year resilience plan providing for an investment of approximately $1.9 billion with cost recovery via a forward-looking rider with semi-annual true-ups. The plan is subject to specified reporting requirements and includes a performance review of the hardened assets. The LPSC order approving the framework does not include any restrictions on Entergy Louisiana’s ability to file applications for approval of additional investments in resilience.

In January 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $40.4 million, or $38.9 million in incremental annual revenues from Entergy Louisiana’s first semi-annual filing in July 2024, for projects expected to be placed in service during the rate-effective period of March 2025 through August 2025. In February 2025 the LPSC staff reviewed the filed rider rates and identified no material issues.

In July 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $50.2 million, or $9.8 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of September 2025 through February 2026. Additionally, Entergy Louisiana’s true-up filing included an under-recovery totaling $5.6 million to be implemented in the January 2026 semi-annual filing. In August 2025 the LPSC staff reviewed the filed rider rates and identified no material issues.

In January 2026, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $101.8 million, or $51.6 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of March 2026 through August 2026. Additionally, Entergy Louisiana’s true-up filing included an over-recovery totaling $16.6 million to be implemented in the July 2026 semi-annual filing. In February 2026 the LPSC staff reviewed the filed rider rates and identified no material issues.

Filings with the MPSC (Entergy Mississippi)

Retail Rates

2026 Formula Rate Plan Filing

In February 2026, Entergy Mississippi submitted its formula rate plan 2026 test year filing and 2025 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2025 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2026 calendar year to also be within the formula rate plan bandwidth. The 2026 test year filing resulted in an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2025 look-back filing compared actual 2025 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 $293 thousand to reflect one outside-the-bandwidth change, a true-up of demand side management costs. A final order is expected in second quarter 2026.

Filings with the City Council (Entergy New Orleans)

Retail Rates

2026 Formula Rate Plan Filing

In April 2026, Entergy New Orleans submitted to the City Council its formula rate plan 2025 test year filing. The 2025 evaluation report produced an earned return on equity of 7.55% compared to the authorized return on equity of 9.35%. Without adjustments, this would result in an increase in rates of $16.6 million. The increase in rates is driven, in part, by an increase in plant in service, as well as the cost of known and measurable capital additions. The increase is also driven by a decrease in total revenues due to a decline in kWh sales. The filing is subject to a 75-day review and discovery period followed by a 25-day period to resolve any disputes among the parties. For any disputed items, the City Council would set a procedural schedule to resolve such disputes. Resulting rates will be effective with the first billing cycle of September 2026 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 2026, 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 $112.5 million annually, or $20.4 million

in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between July 1, 2025 and December 31, 2025.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2025, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $30.3 million annually, or $20.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2024 and June 30, 2025 and changes in other transmission charges. In April 2026 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 6, 2026.

Generation Cost Recovery Rider

In March 2026, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its capital investment in the Orange County Advanced Power Station. The proposed generation cost recovery rider, which includes Entergy Texas’s capital invested in generation for the Orange County Advanced Power Station through December 31, 2025, is designed to collect approximately $150.4 million annually from Entergy Texas’s retail customers. By statute, the proposed generation cost recovery rider rates are to become effective when the Orange County Advanced Power Station is placed into service, which is expected in third quarter 2026.

Entergy Arkansas Opportunity Sales Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints.

Unit Power Sales Agreement

See Note 2 to the financial statements in the Form 10-K for discussion of the Unit Power Sales Agreement.

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.

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.

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 2026, 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 $0.01333 per kWh to $0.01508 per kWh. The primary reason for the rate increase was an under-recovered balance as a result of higher natural gas prices in 2025. Based on circumstances related to ANO 2’s refueling outage, Entergy Arkansas made an adjustment to projected energy costs to phase-in the rate increase gradually. The redetermined rate of $0.01508 per kWh became effective with the first billing cycle in April 2026 through the normal operation of the tariff.

Entergy Louisiana

As discussed in the Form 10-K, in June 2025 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings (for Entergy Louisiana’s gas operations). The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from January 2023 through June 2025. The LPSC staff issued its audit report in March 2026, and although certain internal record keeping recommendations were made, the LPSC staff did not recommend any disallowances. The next step is for the LPSC to issue its final report, but there is no deadline or timing requirement associated with the issuance of the final report.

In February 2026, Entergy Louisiana, in its monthly filing to update its fuel adjustment clause, requested to defer approximately $141.9 million of fuel costs incurred in January 2026 that were primarily attributable to the effects of Winter Storm Fern, consistent with the LPSC’s general order approved at its February 2026 meeting

permitting temporary modifications to the LPSC’s fuel adjustment clause general order. The filing proposes to defer the recovery of these fuel costs over a four-month period from March 2026 through June 2026 to mitigate the customer bill impacts of these fuel costs.

In April 2026 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment clause for the period from 2023 through 2025.

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

2026 Base Rate Case

In February 2026, Entergy Arkansas filed with the APSC a general change in rates, charges, and tariffs. The filing requested a base rate increase to recover a base rate revenue deficiency of $44.6 million and notified the APSC of Entergy Arkansas’s intent to implement a forward test year formula rate plan pursuant to Arkansas legislation passed in 2015. The primary drivers of the revenue deficiency were increased depreciation expense and the impact of net capital additions. Additionally, the filing requested a 9.90% return on common equity and increased depreciation rates as the result of a depreciation study. In March 2026 the APSC issued an order suspending the proposed rates and tariffs filed by Entergy Arkansas and will establish a procedural schedule by subsequent order.

Generating Arkansas Jobs Act Rider

In March 2026, Entergy Arkansas filed its first annual update to the strategic investment recovery rider, requesting recovery of $110.4 million of financing costs during construction of generation and transmission strategic investments related to Ironwood Power Station, Jefferson Power Station, and the Arkansas Cypress Solar facility. The revised rates are requested to be effective for bills rendered on the first billing cycle of June 2026. In April 2026 the APSC general staff filed testimony arguing that the APSC had not issued an order designating Ironwood Power Station as a strategic investment and that related costs should therefore be removed from the annual update. Also in April 2026, Entergy Arkansas filed testimony asserting that the APSC general staff’s position is contrary to the plain language of the statute, which includes an exception for facilities like Ironwood Power Station that were certified by the APSC within a certain timeframe. A hearing was held in April 2026.

Production Tax Credit Tariff

As discussed in Note 3 to the financial statements in the Form 10-K, in January 2026 the APSC opened a docket to investigate the sale of Entergy Arkansas’s nuclear production tax credits and the appropriate ratemaking treatment of production tax credits for all of Entergy Arkansas’s eligible resources, including how the proceeds of any sales should flow through to customers. As directed by the APSC, in February 2026, Entergy Arkansas submitted a compliance filing to the APSC verifying the status of the solar production tax credits. The filing also verified that the net proceeds from the sale of the nuclear production tax credits were recorded in FERC accounts that are accruing a return for customers’ benefit at a rate that is above the customer deposit rate. Subsequently, in March 2026, Entergy Arkansas filed testimony setting forth its proposal for the solar production tax credits. Specifically, Entergy Arkansas requested the same ratemaking treatment for all of the solar facilities that the APSC already approved for Walnut Bend (i.e., the total net monetized proceeds from production tax credits expected to be

generated over the first ten years of a solar facility’s operation are estimated and then amortized over the expected useful life of the asset, which is typically 30 years). Additionally, consistent with prior orders for these resources, the deferred tax asset balances associated with both the production tax credits and the tax gross-up of the regulatory liability will be recognized as a reduction to the overall accumulated deferred income tax liability balance in Entergy Arkansas’s calculation of its weighted average cost of capital providing a return on the unamortized balance for the benefit of customers. Further, Entergy Arkansas proposes to flow the benefits of the solar production tax credits to customers through Entergy Arkansas’s formula rate plan, effective with the formula rate plan rates that will go into effect January 1, 2027. Entergy Arkansas’s proposal would result in the benefits of the production tax credits being passed through to customers, if approved, as reductions in revenue requirement evenly over the life of the assets, rather than only during the 10-year period in which the production tax credits are generated. In April 2026 the APSC general staff filed testimony proposing an amortization period of no more than 15 years for the monetized proceeds for the tax credits associated with the West Memphis Solar and Driver Solar facilities. An evidentiary hearing is scheduled for July 2026.

Special Rate Contract and Arkansas Cypress Solar

As discussed in the Form 10-K, in September 2025, Entergy Arkansas filed an application with the APSC seeking a certificate of environmental compatibility and public need for the construction and operation of the Arkansas Cypress Solar facility, a planned 600 MW solar photovoltaic array with a 350 MW battery energy storage system and associated transmission facilities interconnecting at Entergy Arkansas’s White Bluff substation. The estimated cost of the project is $1,602 million. In March 2026 the APSC approved the Arkansas Cypress Solar facility and Entergy Arkansas’s recovery of the costs of the facility through the Generating Arkansas Jobs Act rider. The APSC also ordered implementation of an independent monitor to oversee costs. In April 2026, Entergy Arkansas filed with the APSC its proposal for an independent monitor to oversee the reasonableness of costs. In April 2026 the APSC issued an order consolidating Entergy Arkansas’s cost independent monitor proposals for three pending resources, including the Arkansas Cypress Solar facility, into a single docket and directing parties with full intervention status to respond to the proposals and recommend independent monitor candidates. The facility is expected to be in service by the end of 2028.

Filings with the LPSC (Entergy Louisiana)

Retail Rates

Resilience Plan Cost Recovery Rider

In December 2022, Entergy Louisiana filed an application with the LPSC seeking a public interest finding regarding Phase I of Entergy Louisiana’s Future Ready resilience plan and approval of a rider mechanism to recover the program’s costs. Phase I in the December 2022 application reflected the first five years of a ten-year resilience plan and included investment of approximately $5 billion, including hardening investment, transmission dead-end structures, enhanced vegetation management, and telecommunications improvement. In April 2024 the LPSC approved a framework which includes an initial five-year resilience plan providing for an investment of approximately $1.9 billion with cost recovery via a forward-looking rider with semi-annual true-ups. The plan is subject to specified reporting requirements and includes a performance review of the hardened assets. The LPSC order approving the framework does not include any restrictions on Entergy Louisiana’s ability to file applications for approval of additional investments in resilience.

In January 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $40.4 million, or $38.9 million in incremental annual revenues from Entergy Louisiana’s first semi-annual filing in July 2024, for projects expected to be placed in service during the rate-effective period of March 2025 through August 2025. In February 2025 the LPSC staff reviewed the filed rider rates and identified no material issues.

In July 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $50.2 million, or $9.8 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of September 2025 through February 2026. Additionally, Entergy Louisiana’s true-up filing included an under-recovery totaling $5.6 million to be implemented in the January 2026 semi-annual filing. In August 2025 the LPSC staff reviewed the filed rider rates and identified no material issues.

In January 2026, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $101.8 million, or $51.6 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of March 2026 through August 2026. Additionally, Entergy Louisiana’s true-up filing included an over-recovery totaling $16.6 million to be implemented in the July 2026 semi-annual filing. In February 2026 the LPSC staff reviewed the filed rider rates and identified no material issues.

Filings with the MPSC (Entergy Mississippi)

Retail Rates

2026 Formula Rate Plan Filing

In February 2026, Entergy Mississippi submitted its formula rate plan 2026 test year filing and 2025 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2025 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2026 calendar year to also be within the formula rate plan bandwidth. The 2026 test year filing resulted in an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2025 look-back filing compared actual 2025 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 $293 thousand to reflect one outside-the-bandwidth change, a true-up of demand side management costs. A final order is expected in second quarter 2026.

Filings with the City Council (Entergy New Orleans)

Retail Rates

2026 Formula Rate Plan Filing

In April 2026, Entergy New Orleans submitted to the City Council its formula rate plan 2025 test year filing. The 2025 evaluation report produced an earned return on equity of 7.55% compared to the authorized return on equity of 9.35%. Without adjustments, this would result in an increase in rates of $16.6 million. The increase in rates is driven, in part, by an increase in plant in service, as well as the cost of known and measurable capital additions. The increase is also driven by a decrease in total revenues due to a decline in kWh sales. The filing is subject to a 75-day review and discovery period followed by a 25-day period to resolve any disputes among the parties. For any disputed items, the City Council would set a procedural schedule to resolve such disputes. Resulting rates will be effective with the first billing cycle of September 2026 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 2026, 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 $112.5 million annually, or $20.4 million

in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between July 1, 2025 and December 31, 2025.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2025, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $30.3 million annually, or $20.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2024 and June 30, 2025 and changes in other transmission charges. In April 2026 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 6, 2026.

Generation Cost Recovery Rider

In March 2026, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its capital investment in the Orange County Advanced Power Station. The proposed generation cost recovery rider, which includes Entergy Texas’s capital invested in generation for the Orange County Advanced Power Station through December 31, 2025, is designed to collect approximately $150.4 million annually from Entergy Texas’s retail customers. By statute, the proposed generation cost recovery rider rates are to become effective when the Orange County Advanced Power Station is placed into service, which is expected in third quarter 2026.

Entergy Arkansas Opportunity Sales Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints.

Unit Power Sales Agreement

See Note 2 to the financial statements in the Form 10-K for discussion of the Unit Power Sales Agreement.

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.

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.

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 2026, 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 $0.01333 per kWh to $0.01508 per kWh. The primary reason for the rate increase was an under-recovered balance as a result of higher natural gas prices in 2025. Based on circumstances related to ANO 2’s refueling outage, Entergy Arkansas made an adjustment to projected energy costs to phase-in the rate increase gradually. The redetermined rate of $0.01508 per kWh became effective with the first billing cycle in April 2026 through the normal operation of the tariff.

Entergy Louisiana

As discussed in the Form 10-K, in June 2025 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings (for Entergy Louisiana’s gas operations). The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from January 2023 through June 2025. The LPSC staff issued its audit report in March 2026, and although certain internal record keeping recommendations were made, the LPSC staff did not recommend any disallowances. The next step is for the LPSC to issue its final report, but there is no deadline or timing requirement associated with the issuance of the final report.

In February 2026, Entergy Louisiana, in its monthly filing to update its fuel adjustment clause, requested to defer approximately $141.9 million of fuel costs incurred in January 2026 that were primarily attributable to the effects of Winter Storm Fern, consistent with the LPSC’s general order approved at its February 2026 meeting

permitting temporary modifications to the LPSC’s fuel adjustment clause general order. The filing proposes to defer the recovery of these fuel costs over a four-month period from March 2026 through June 2026 to mitigate the customer bill impacts of these fuel costs.

In April 2026 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment clause for the period from 2023 through 2025.

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

2026 Base Rate Case

In February 2026, Entergy Arkansas filed with the APSC a general change in rates, charges, and tariffs. The filing requested a base rate increase to recover a base rate revenue deficiency of $44.6 million and notified the APSC of Entergy Arkansas’s intent to implement a forward test year formula rate plan pursuant to Arkansas legislation passed in 2015. The primary drivers of the revenue deficiency were increased depreciation expense and the impact of net capital additions. Additionally, the filing requested a 9.90% return on common equity and increased depreciation rates as the result of a depreciation study. In March 2026 the APSC issued an order suspending the proposed rates and tariffs filed by Entergy Arkansas and will establish a procedural schedule by subsequent order.

Generating Arkansas Jobs Act Rider

In March 2026, Entergy Arkansas filed its first annual update to the strategic investment recovery rider, requesting recovery of $110.4 million of financing costs during construction of generation and transmission strategic investments related to Ironwood Power Station, Jefferson Power Station, and the Arkansas Cypress Solar facility. The revised rates are requested to be effective for bills rendered on the first billing cycle of June 2026. In April 2026 the APSC general staff filed testimony arguing that the APSC had not issued an order designating Ironwood Power Station as a strategic investment and that related costs should therefore be removed from the annual update. Also in April 2026, Entergy Arkansas filed testimony asserting that the APSC general staff’s position is contrary to the plain language of the statute, which includes an exception for facilities like Ironwood Power Station that were certified by the APSC within a certain timeframe. A hearing was held in April 2026.

Production Tax Credit Tariff

As discussed in Note 3 to the financial statements in the Form 10-K, in January 2026 the APSC opened a docket to investigate the sale of Entergy Arkansas’s nuclear production tax credits and the appropriate ratemaking treatment of production tax credits for all of Entergy Arkansas’s eligible resources, including how the proceeds of any sales should flow through to customers. As directed by the APSC, in February 2026, Entergy Arkansas submitted a compliance filing to the APSC verifying the status of the solar production tax credits. The filing also verified that the net proceeds from the sale of the nuclear production tax credits were recorded in FERC accounts that are accruing a return for customers’ benefit at a rate that is above the customer deposit rate. Subsequently, in March 2026, Entergy Arkansas filed testimony setting forth its proposal for the solar production tax credits. Specifically, Entergy Arkansas requested the same ratemaking treatment for all of the solar facilities that the APSC already approved for Walnut Bend (i.e., the total net monetized proceeds from production tax credits expected to be

generated over the first ten years of a solar facility’s operation are estimated and then amortized over the expected useful life of the asset, which is typically 30 years). Additionally, consistent with prior orders for these resources, the deferred tax asset balances associated with both the production tax credits and the tax gross-up of the regulatory liability will be recognized as a reduction to the overall accumulated deferred income tax liability balance in Entergy Arkansas’s calculation of its weighted average cost of capital providing a return on the unamortized balance for the benefit of customers. Further, Entergy Arkansas proposes to flow the benefits of the solar production tax credits to customers through Entergy Arkansas’s formula rate plan, effective with the formula rate plan rates that will go into effect January 1, 2027. Entergy Arkansas’s proposal would result in the benefits of the production tax credits being passed through to customers, if approved, as reductions in revenue requirement evenly over the life of the assets, rather than only during the 10-year period in which the production tax credits are generated. In April 2026 the APSC general staff filed testimony proposing an amortization period of no more than 15 years for the monetized proceeds for the tax credits associated with the West Memphis Solar and Driver Solar facilities. An evidentiary hearing is scheduled for July 2026.

Special Rate Contract and Arkansas Cypress Solar

As discussed in the Form 10-K, in September 2025, Entergy Arkansas filed an application with the APSC seeking a certificate of environmental compatibility and public need for the construction and operation of the Arkansas Cypress Solar facility, a planned 600 MW solar photovoltaic array with a 350 MW battery energy storage system and associated transmission facilities interconnecting at Entergy Arkansas’s White Bluff substation. The estimated cost of the project is $1,602 million. In March 2026 the APSC approved the Arkansas Cypress Solar facility and Entergy Arkansas’s recovery of the costs of the facility through the Generating Arkansas Jobs Act rider. The APSC also ordered implementation of an independent monitor to oversee costs. In April 2026, Entergy Arkansas filed with the APSC its proposal for an independent monitor to oversee the reasonableness of costs. In April 2026 the APSC issued an order consolidating Entergy Arkansas’s cost independent monitor proposals for three pending resources, including the Arkansas Cypress Solar facility, into a single docket and directing parties with full intervention status to respond to the proposals and recommend independent monitor candidates. The facility is expected to be in service by the end of 2028.

Filings with the LPSC (Entergy Louisiana)

Retail Rates

Resilience Plan Cost Recovery Rider

In December 2022, Entergy Louisiana filed an application with the LPSC seeking a public interest finding regarding Phase I of Entergy Louisiana’s Future Ready resilience plan and approval of a rider mechanism to recover the program’s costs. Phase I in the December 2022 application reflected the first five years of a ten-year resilience plan and included investment of approximately $5 billion, including hardening investment, transmission dead-end structures, enhanced vegetation management, and telecommunications improvement. In April 2024 the LPSC approved a framework which includes an initial five-year resilience plan providing for an investment of approximately $1.9 billion with cost recovery via a forward-looking rider with semi-annual true-ups. The plan is subject to specified reporting requirements and includes a performance review of the hardened assets. The LPSC order approving the framework does not include any restrictions on Entergy Louisiana’s ability to file applications for approval of additional investments in resilience.

In January 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $40.4 million, or $38.9 million in incremental annual revenues from Entergy Louisiana’s first semi-annual filing in July 2024, for projects expected to be placed in service during the rate-effective period of March 2025 through August 2025. In February 2025 the LPSC staff reviewed the filed rider rates and identified no material issues.

In July 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $50.2 million, or $9.8 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of September 2025 through February 2026. Additionally, Entergy Louisiana’s true-up filing included an under-recovery totaling $5.6 million to be implemented in the January 2026 semi-annual filing. In August 2025 the LPSC staff reviewed the filed rider rates and identified no material issues.

In January 2026, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $101.8 million, or $51.6 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of March 2026 through August 2026. Additionally, Entergy Louisiana’s true-up filing included an over-recovery totaling $16.6 million to be implemented in the July 2026 semi-annual filing. In February 2026 the LPSC staff reviewed the filed rider rates and identified no material issues.

Filings with the MPSC (Entergy Mississippi)

Retail Rates

2026 Formula Rate Plan Filing

In February 2026, Entergy Mississippi submitted its formula rate plan 2026 test year filing and 2025 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2025 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2026 calendar year to also be within the formula rate plan bandwidth. The 2026 test year filing resulted in an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2025 look-back filing compared actual 2025 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 $293 thousand to reflect one outside-the-bandwidth change, a true-up of demand side management costs. A final order is expected in second quarter 2026.

Filings with the City Council (Entergy New Orleans)

Retail Rates

2026 Formula Rate Plan Filing

In April 2026, Entergy New Orleans submitted to the City Council its formula rate plan 2025 test year filing. The 2025 evaluation report produced an earned return on equity of 7.55% compared to the authorized return on equity of 9.35%. Without adjustments, this would result in an increase in rates of $16.6 million. The increase in rates is driven, in part, by an increase in plant in service, as well as the cost of known and measurable capital additions. The increase is also driven by a decrease in total revenues due to a decline in kWh sales. The filing is subject to a 75-day review and discovery period followed by a 25-day period to resolve any disputes among the parties. For any disputed items, the City Council would set a procedural schedule to resolve such disputes. Resulting rates will be effective with the first billing cycle of September 2026 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 2026, 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 $112.5 million annually, or $20.4 million

in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between July 1, 2025 and December 31, 2025.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2025, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $30.3 million annually, or $20.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2024 and June 30, 2025 and changes in other transmission charges. In April 2026 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 6, 2026.

Generation Cost Recovery Rider

In March 2026, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its capital investment in the Orange County Advanced Power Station. The proposed generation cost recovery rider, which includes Entergy Texas’s capital invested in generation for the Orange County Advanced Power Station through December 31, 2025, is designed to collect approximately $150.4 million annually from Entergy Texas’s retail customers. By statute, the proposed generation cost recovery rider rates are to become effective when the Orange County Advanced Power Station is placed into service, which is expected in third quarter 2026.

Entergy Arkansas Opportunity Sales Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints.

Unit Power Sales Agreement

See Note 2 to the financial statements in the Form 10-K for discussion of the Unit Power Sales Agreement.

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.

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.

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 2026, 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 $0.01333 per kWh to $0.01508 per kWh. The primary reason for the rate increase was an under-recovered balance as a result of higher natural gas prices in 2025. Based on circumstances related to ANO 2’s refueling outage, Entergy Arkansas made an adjustment to projected energy costs to phase-in the rate increase gradually. The redetermined rate of $0.01508 per kWh became effective with the first billing cycle in April 2026 through the normal operation of the tariff.

Entergy Louisiana

As discussed in the Form 10-K, in June 2025 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings (for Entergy Louisiana’s gas operations). The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from January 2023 through June 2025. The LPSC staff issued its audit report in March 2026, and although certain internal record keeping recommendations were made, the LPSC staff did not recommend any disallowances. The next step is for the LPSC to issue its final report, but there is no deadline or timing requirement associated with the issuance of the final report.

In February 2026, Entergy Louisiana, in its monthly filing to update its fuel adjustment clause, requested to defer approximately $141.9 million of fuel costs incurred in January 2026 that were primarily attributable to the effects of Winter Storm Fern, consistent with the LPSC’s general order approved at its February 2026 meeting

permitting temporary modifications to the LPSC’s fuel adjustment clause general order. The filing proposes to defer the recovery of these fuel costs over a four-month period from March 2026 through June 2026 to mitigate the customer bill impacts of these fuel costs.

In April 2026 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment clause for the period from 2023 through 2025.

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

2026 Base Rate Case

In February 2026, Entergy Arkansas filed with the APSC a general change in rates, charges, and tariffs. The filing requested a base rate increase to recover a base rate revenue deficiency of $44.6 million and notified the APSC of Entergy Arkansas’s intent to implement a forward test year formula rate plan pursuant to Arkansas legislation passed in 2015. The primary drivers of the revenue deficiency were increased depreciation expense and the impact of net capital additions. Additionally, the filing requested a 9.90% return on common equity and increased depreciation rates as the result of a depreciation study. In March 2026 the APSC issued an order suspending the proposed rates and tariffs filed by Entergy Arkansas and will establish a procedural schedule by subsequent order.

Generating Arkansas Jobs Act Rider

In March 2026, Entergy Arkansas filed its first annual update to the strategic investment recovery rider, requesting recovery of $110.4 million of financing costs during construction of generation and transmission strategic investments related to Ironwood Power Station, Jefferson Power Station, and the Arkansas Cypress Solar facility. The revised rates are requested to be effective for bills rendered on the first billing cycle of June 2026. In April 2026 the APSC general staff filed testimony arguing that the APSC had not issued an order designating Ironwood Power Station as a strategic investment and that related costs should therefore be removed from the annual update. Also in April 2026, Entergy Arkansas filed testimony asserting that the APSC general staff’s position is contrary to the plain language of the statute, which includes an exception for facilities like Ironwood Power Station that were certified by the APSC within a certain timeframe. A hearing was held in April 2026.

Production Tax Credit Tariff

As discussed in Note 3 to the financial statements in the Form 10-K, in January 2026 the APSC opened a docket to investigate the sale of Entergy Arkansas’s nuclear production tax credits and the appropriate ratemaking treatment of production tax credits for all of Entergy Arkansas’s eligible resources, including how the proceeds of any sales should flow through to customers. As directed by the APSC, in February 2026, Entergy Arkansas submitted a compliance filing to the APSC verifying the status of the solar production tax credits. The filing also verified that the net proceeds from the sale of the nuclear production tax credits were recorded in FERC accounts that are accruing a return for customers’ benefit at a rate that is above the customer deposit rate. Subsequently, in March 2026, Entergy Arkansas filed testimony setting forth its proposal for the solar production tax credits. Specifically, Entergy Arkansas requested the same ratemaking treatment for all of the solar facilities that the APSC already approved for Walnut Bend (i.e., the total net monetized proceeds from production tax credits expected to be

generated over the first ten years of a solar facility’s operation are estimated and then amortized over the expected useful life of the asset, which is typically 30 years). Additionally, consistent with prior orders for these resources, the deferred tax asset balances associated with both the production tax credits and the tax gross-up of the regulatory liability will be recognized as a reduction to the overall accumulated deferred income tax liability balance in Entergy Arkansas’s calculation of its weighted average cost of capital providing a return on the unamortized balance for the benefit of customers. Further, Entergy Arkansas proposes to flow the benefits of the solar production tax credits to customers through Entergy Arkansas’s formula rate plan, effective with the formula rate plan rates that will go into effect January 1, 2027. Entergy Arkansas’s proposal would result in the benefits of the production tax credits being passed through to customers, if approved, as reductions in revenue requirement evenly over the life of the assets, rather than only during the 10-year period in which the production tax credits are generated. In April 2026 the APSC general staff filed testimony proposing an amortization period of no more than 15 years for the monetized proceeds for the tax credits associated with the West Memphis Solar and Driver Solar facilities. An evidentiary hearing is scheduled for July 2026.

Special Rate Contract and Arkansas Cypress Solar

As discussed in the Form 10-K, in September 2025, Entergy Arkansas filed an application with the APSC seeking a certificate of environmental compatibility and public need for the construction and operation of the Arkansas Cypress Solar facility, a planned 600 MW solar photovoltaic array with a 350 MW battery energy storage system and associated transmission facilities interconnecting at Entergy Arkansas’s White Bluff substation. The estimated cost of the project is $1,602 million. In March 2026 the APSC approved the Arkansas Cypress Solar facility and Entergy Arkansas’s recovery of the costs of the facility through the Generating Arkansas Jobs Act rider. The APSC also ordered implementation of an independent monitor to oversee costs. In April 2026, Entergy Arkansas filed with the APSC its proposal for an independent monitor to oversee the reasonableness of costs. In April 2026 the APSC issued an order consolidating Entergy Arkansas’s cost independent monitor proposals for three pending resources, including the Arkansas Cypress Solar facility, into a single docket and directing parties with full intervention status to respond to the proposals and recommend independent monitor candidates. The facility is expected to be in service by the end of 2028.

Filings with the LPSC (Entergy Louisiana)

Retail Rates

Resilience Plan Cost Recovery Rider

In December 2022, Entergy Louisiana filed an application with the LPSC seeking a public interest finding regarding Phase I of Entergy Louisiana’s Future Ready resilience plan and approval of a rider mechanism to recover the program’s costs. Phase I in the December 2022 application reflected the first five years of a ten-year resilience plan and included investment of approximately $5 billion, including hardening investment, transmission dead-end structures, enhanced vegetation management, and telecommunications improvement. In April 2024 the LPSC approved a framework which includes an initial five-year resilience plan providing for an investment of approximately $1.9 billion with cost recovery via a forward-looking rider with semi-annual true-ups. The plan is subject to specified reporting requirements and includes a performance review of the hardened assets. The LPSC order approving the framework does not include any restrictions on Entergy Louisiana’s ability to file applications for approval of additional investments in resilience.

In January 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $40.4 million, or $38.9 million in incremental annual revenues from Entergy Louisiana’s first semi-annual filing in July 2024, for projects expected to be placed in service during the rate-effective period of March 2025 through August 2025. In February 2025 the LPSC staff reviewed the filed rider rates and identified no material issues.

In July 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $50.2 million, or $9.8 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of September 2025 through February 2026. Additionally, Entergy Louisiana’s true-up filing included an under-recovery totaling $5.6 million to be implemented in the January 2026 semi-annual filing. In August 2025 the LPSC staff reviewed the filed rider rates and identified no material issues.

In January 2026, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $101.8 million, or $51.6 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of March 2026 through August 2026. Additionally, Entergy Louisiana’s true-up filing included an over-recovery totaling $16.6 million to be implemented in the July 2026 semi-annual filing. In February 2026 the LPSC staff reviewed the filed rider rates and identified no material issues.

Filings with the MPSC (Entergy Mississippi)

Retail Rates

2026 Formula Rate Plan Filing

In February 2026, Entergy Mississippi submitted its formula rate plan 2026 test year filing and 2025 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2025 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2026 calendar year to also be within the formula rate plan bandwidth. The 2026 test year filing resulted in an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2025 look-back filing compared actual 2025 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 $293 thousand to reflect one outside-the-bandwidth change, a true-up of demand side management costs. A final order is expected in second quarter 2026.

Filings with the City Council (Entergy New Orleans)

Retail Rates

2026 Formula Rate Plan Filing

In April 2026, Entergy New Orleans submitted to the City Council its formula rate plan 2025 test year filing. The 2025 evaluation report produced an earned return on equity of 7.55% compared to the authorized return on equity of 9.35%. Without adjustments, this would result in an increase in rates of $16.6 million. The increase in rates is driven, in part, by an increase in plant in service, as well as the cost of known and measurable capital additions. The increase is also driven by a decrease in total revenues due to a decline in kWh sales. The filing is subject to a 75-day review and discovery period followed by a 25-day period to resolve any disputes among the parties. For any disputed items, the City Council would set a procedural schedule to resolve such disputes. Resulting rates will be effective with the first billing cycle of September 2026 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 2026, 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 $112.5 million annually, or $20.4 million

in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between July 1, 2025 and December 31, 2025.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2025, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $30.3 million annually, or $20.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2024 and June 30, 2025 and changes in other transmission charges. In April 2026 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 6, 2026.

Generation Cost Recovery Rider

In March 2026, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its capital investment in the Orange County Advanced Power Station. The proposed generation cost recovery rider, which includes Entergy Texas’s capital invested in generation for the Orange County Advanced Power Station through December 31, 2025, is designed to collect approximately $150.4 million annually from Entergy Texas’s retail customers. By statute, the proposed generation cost recovery rider rates are to become effective when the Orange County Advanced Power Station is placed into service, which is expected in third quarter 2026.

Entergy Arkansas Opportunity Sales Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints.

Unit Power Sales Agreement

See Note 2 to the financial statements in the Form 10-K for discussion of the Unit Power Sales Agreement.

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.

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.

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 2026, 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 $0.01333 per kWh to $0.01508 per kWh. The primary reason for the rate increase was an under-recovered balance as a result of higher natural gas prices in 2025. Based on circumstances related to ANO 2’s refueling outage, Entergy Arkansas made an adjustment to projected energy costs to phase-in the rate increase gradually. The redetermined rate of $0.01508 per kWh became effective with the first billing cycle in April 2026 through the normal operation of the tariff.

Entergy Louisiana

As discussed in the Form 10-K, in June 2025 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings (for Entergy Louisiana’s gas operations). The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from January 2023 through June 2025. The LPSC staff issued its audit report in March 2026, and although certain internal record keeping recommendations were made, the LPSC staff did not recommend any disallowances. The next step is for the LPSC to issue its final report, but there is no deadline or timing requirement associated with the issuance of the final report.

In February 2026, Entergy Louisiana, in its monthly filing to update its fuel adjustment clause, requested to defer approximately $141.9 million of fuel costs incurred in January 2026 that were primarily attributable to the effects of Winter Storm Fern, consistent with the LPSC’s general order approved at its February 2026 meeting

permitting temporary modifications to the LPSC’s fuel adjustment clause general order. The filing proposes to defer the recovery of these fuel costs over a four-month period from March 2026 through June 2026 to mitigate the customer bill impacts of these fuel costs.

In April 2026 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment clause for the period from 2023 through 2025.

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

2026 Base Rate Case

In February 2026, Entergy Arkansas filed with the APSC a general change in rates, charges, and tariffs. The filing requested a base rate increase to recover a base rate revenue deficiency of $44.6 million and notified the APSC of Entergy Arkansas’s intent to implement a forward test year formula rate plan pursuant to Arkansas legislation passed in 2015. The primary drivers of the revenue deficiency were increased depreciation expense and the impact of net capital additions. Additionally, the filing requested a 9.90% return on common equity and increased depreciation rates as the result of a depreciation study. In March 2026 the APSC issued an order suspending the proposed rates and tariffs filed by Entergy Arkansas and will establish a procedural schedule by subsequent order.

Generating Arkansas Jobs Act Rider

In March 2026, Entergy Arkansas filed its first annual update to the strategic investment recovery rider, requesting recovery of $110.4 million of financing costs during construction of generation and transmission strategic investments related to Ironwood Power Station, Jefferson Power Station, and the Arkansas Cypress Solar facility. The revised rates are requested to be effective for bills rendered on the first billing cycle of June 2026. In April 2026 the APSC general staff filed testimony arguing that the APSC had not issued an order designating Ironwood Power Station as a strategic investment and that related costs should therefore be removed from the annual update. Also in April 2026, Entergy Arkansas filed testimony asserting that the APSC general staff’s position is contrary to the plain language of the statute, which includes an exception for facilities like Ironwood Power Station that were certified by the APSC within a certain timeframe. A hearing was held in April 2026.

Production Tax Credit Tariff

As discussed in Note 3 to the financial statements in the Form 10-K, in January 2026 the APSC opened a docket to investigate the sale of Entergy Arkansas’s nuclear production tax credits and the appropriate ratemaking treatment of production tax credits for all of Entergy Arkansas’s eligible resources, including how the proceeds of any sales should flow through to customers. As directed by the APSC, in February 2026, Entergy Arkansas submitted a compliance filing to the APSC verifying the status of the solar production tax credits. The filing also verified that the net proceeds from the sale of the nuclear production tax credits were recorded in FERC accounts that are accruing a return for customers’ benefit at a rate that is above the customer deposit rate. Subsequently, in March 2026, Entergy Arkansas filed testimony setting forth its proposal for the solar production tax credits. Specifically, Entergy Arkansas requested the same ratemaking treatment for all of the solar facilities that the APSC already approved for Walnut Bend (i.e., the total net monetized proceeds from production tax credits expected to be

generated over the first ten years of a solar facility’s operation are estimated and then amortized over the expected useful life of the asset, which is typically 30 years). Additionally, consistent with prior orders for these resources, the deferred tax asset balances associated with both the production tax credits and the tax gross-up of the regulatory liability will be recognized as a reduction to the overall accumulated deferred income tax liability balance in Entergy Arkansas’s calculation of its weighted average cost of capital providing a return on the unamortized balance for the benefit of customers. Further, Entergy Arkansas proposes to flow the benefits of the solar production tax credits to customers through Entergy Arkansas’s formula rate plan, effective with the formula rate plan rates that will go into effect January 1, 2027. Entergy Arkansas’s proposal would result in the benefits of the production tax credits being passed through to customers, if approved, as reductions in revenue requirement evenly over the life of the assets, rather than only during the 10-year period in which the production tax credits are generated. In April 2026 the APSC general staff filed testimony proposing an amortization period of no more than 15 years for the monetized proceeds for the tax credits associated with the West Memphis Solar and Driver Solar facilities. An evidentiary hearing is scheduled for July 2026.

Special Rate Contract and Arkansas Cypress Solar

As discussed in the Form 10-K, in September 2025, Entergy Arkansas filed an application with the APSC seeking a certificate of environmental compatibility and public need for the construction and operation of the Arkansas Cypress Solar facility, a planned 600 MW solar photovoltaic array with a 350 MW battery energy storage system and associated transmission facilities interconnecting at Entergy Arkansas’s White Bluff substation. The estimated cost of the project is $1,602 million. In March 2026 the APSC approved the Arkansas Cypress Solar facility and Entergy Arkansas’s recovery of the costs of the facility through the Generating Arkansas Jobs Act rider. The APSC also ordered implementation of an independent monitor to oversee costs. In April 2026, Entergy Arkansas filed with the APSC its proposal for an independent monitor to oversee the reasonableness of costs. In April 2026 the APSC issued an order consolidating Entergy Arkansas’s cost independent monitor proposals for three pending resources, including the Arkansas Cypress Solar facility, into a single docket and directing parties with full intervention status to respond to the proposals and recommend independent monitor candidates. The facility is expected to be in service by the end of 2028.

Filings with the LPSC (Entergy Louisiana)

Retail Rates

Resilience Plan Cost Recovery Rider

In December 2022, Entergy Louisiana filed an application with the LPSC seeking a public interest finding regarding Phase I of Entergy Louisiana’s Future Ready resilience plan and approval of a rider mechanism to recover the program’s costs. Phase I in the December 2022 application reflected the first five years of a ten-year resilience plan and included investment of approximately $5 billion, including hardening investment, transmission dead-end structures, enhanced vegetation management, and telecommunications improvement. In April 2024 the LPSC approved a framework which includes an initial five-year resilience plan providing for an investment of approximately $1.9 billion with cost recovery via a forward-looking rider with semi-annual true-ups. The plan is subject to specified reporting requirements and includes a performance review of the hardened assets. The LPSC order approving the framework does not include any restrictions on Entergy Louisiana’s ability to file applications for approval of additional investments in resilience.

In January 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $40.4 million, or $38.9 million in incremental annual revenues from Entergy Louisiana’s first semi-annual filing in July 2024, for projects expected to be placed in service during the rate-effective period of March 2025 through August 2025. In February 2025 the LPSC staff reviewed the filed rider rates and identified no material issues.

In July 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $50.2 million, or $9.8 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of September 2025 through February 2026. Additionally, Entergy Louisiana’s true-up filing included an under-recovery totaling $5.6 million to be implemented in the January 2026 semi-annual filing. In August 2025 the LPSC staff reviewed the filed rider rates and identified no material issues.

In January 2026, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $101.8 million, or $51.6 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of March 2026 through August 2026. Additionally, Entergy Louisiana’s true-up filing included an over-recovery totaling $16.6 million to be implemented in the July 2026 semi-annual filing. In February 2026 the LPSC staff reviewed the filed rider rates and identified no material issues.

Filings with the MPSC (Entergy Mississippi)

Retail Rates

2026 Formula Rate Plan Filing

In February 2026, Entergy Mississippi submitted its formula rate plan 2026 test year filing and 2025 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2025 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2026 calendar year to also be within the formula rate plan bandwidth. The 2026 test year filing resulted in an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2025 look-back filing compared actual 2025 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 $293 thousand to reflect one outside-the-bandwidth change, a true-up of demand side management costs. A final order is expected in second quarter 2026.

Filings with the City Council (Entergy New Orleans)

Retail Rates

2026 Formula Rate Plan Filing

In April 2026, Entergy New Orleans submitted to the City Council its formula rate plan 2025 test year filing. The 2025 evaluation report produced an earned return on equity of 7.55% compared to the authorized return on equity of 9.35%. Without adjustments, this would result in an increase in rates of $16.6 million. The increase in rates is driven, in part, by an increase in plant in service, as well as the cost of known and measurable capital additions. The increase is also driven by a decrease in total revenues due to a decline in kWh sales. The filing is subject to a 75-day review and discovery period followed by a 25-day period to resolve any disputes among the parties. For any disputed items, the City Council would set a procedural schedule to resolve such disputes. Resulting rates will be effective with the first billing cycle of September 2026 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 2026, 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 $112.5 million annually, or $20.4 million

in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between July 1, 2025 and December 31, 2025.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2025, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $30.3 million annually, or $20.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2024 and June 30, 2025 and changes in other transmission charges. In April 2026 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 6, 2026.

Generation Cost Recovery Rider

In March 2026, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its capital investment in the Orange County Advanced Power Station. The proposed generation cost recovery rider, which includes Entergy Texas’s capital invested in generation for the Orange County Advanced Power Station through December 31, 2025, is designed to collect approximately $150.4 million annually from Entergy Texas’s retail customers. By statute, the proposed generation cost recovery rider rates are to become effective when the Orange County Advanced Power Station is placed into service, which is expected in third quarter 2026.

Entergy Arkansas Opportunity Sales Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints.

Unit Power Sales Agreement

See Note 2 to the financial statements in the Form 10-K for discussion of the Unit Power Sales Agreement.

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.

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.

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 2026, 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 $0.01333 per kWh to $0.01508 per kWh. The primary reason for the rate increase was an under-recovered balance as a result of higher natural gas prices in 2025. Based on circumstances related to ANO 2’s refueling outage, Entergy Arkansas made an adjustment to projected energy costs to phase-in the rate increase gradually. The redetermined rate of $0.01508 per kWh became effective with the first billing cycle in April 2026 through the normal operation of the tariff.

Entergy Louisiana

As discussed in the Form 10-K, in June 2025 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings (for Entergy Louisiana’s gas operations). The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from January 2023 through June 2025. The LPSC staff issued its audit report in March 2026, and although certain internal record keeping recommendations were made, the LPSC staff did not recommend any disallowances. The next step is for the LPSC to issue its final report, but there is no deadline or timing requirement associated with the issuance of the final report.

In February 2026, Entergy Louisiana, in its monthly filing to update its fuel adjustment clause, requested to defer approximately $141.9 million of fuel costs incurred in January 2026 that were primarily attributable to the effects of Winter Storm Fern, consistent with the LPSC’s general order approved at its February 2026 meeting

permitting temporary modifications to the LPSC’s fuel adjustment clause general order. The filing proposes to defer the recovery of these fuel costs over a four-month period from March 2026 through June 2026 to mitigate the customer bill impacts of these fuel costs.

In April 2026 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment clause for the period from 2023 through 2025.

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

2026 Base Rate Case

In February 2026, Entergy Arkansas filed with the APSC a general change in rates, charges, and tariffs. The filing requested a base rate increase to recover a base rate revenue deficiency of $44.6 million and notified the APSC of Entergy Arkansas’s intent to implement a forward test year formula rate plan pursuant to Arkansas legislation passed in 2015. The primary drivers of the revenue deficiency were increased depreciation expense and the impact of net capital additions. Additionally, the filing requested a 9.90% return on common equity and increased depreciation rates as the result of a depreciation study. In March 2026 the APSC issued an order suspending the proposed rates and tariffs filed by Entergy Arkansas and will establish a procedural schedule by subsequent order.

Generating Arkansas Jobs Act Rider

In March 2026, Entergy Arkansas filed its first annual update to the strategic investment recovery rider, requesting recovery of $110.4 million of financing costs during construction of generation and transmission strategic investments related to Ironwood Power Station, Jefferson Power Station, and the Arkansas Cypress Solar facility. The revised rates are requested to be effective for bills rendered on the first billing cycle of June 2026. In April 2026 the APSC general staff filed testimony arguing that the APSC had not issued an order designating Ironwood Power Station as a strategic investment and that related costs should therefore be removed from the annual update. Also in April 2026, Entergy Arkansas filed testimony asserting that the APSC general staff’s position is contrary to the plain language of the statute, which includes an exception for facilities like Ironwood Power Station that were certified by the APSC within a certain timeframe. A hearing was held in April 2026.

Production Tax Credit Tariff

As discussed in Note 3 to the financial statements in the Form 10-K, in January 2026 the APSC opened a docket to investigate the sale of Entergy Arkansas’s nuclear production tax credits and the appropriate ratemaking treatment of production tax credits for all of Entergy Arkansas’s eligible resources, including how the proceeds of any sales should flow through to customers. As directed by the APSC, in February 2026, Entergy Arkansas submitted a compliance filing to the APSC verifying the status of the solar production tax credits. The filing also verified that the net proceeds from the sale of the nuclear production tax credits were recorded in FERC accounts that are accruing a return for customers’ benefit at a rate that is above the customer deposit rate. Subsequently, in March 2026, Entergy Arkansas filed testimony setting forth its proposal for the solar production tax credits. Specifically, Entergy Arkansas requested the same ratemaking treatment for all of the solar facilities that the APSC already approved for Walnut Bend (i.e., the total net monetized proceeds from production tax credits expected to be

generated over the first ten years of a solar facility’s operation are estimated and then amortized over the expected useful life of the asset, which is typically 30 years). Additionally, consistent with prior orders for these resources, the deferred tax asset balances associated with both the production tax credits and the tax gross-up of the regulatory liability will be recognized as a reduction to the overall accumulated deferred income tax liability balance in Entergy Arkansas’s calculation of its weighted average cost of capital providing a return on the unamortized balance for the benefit of customers. Further, Entergy Arkansas proposes to flow the benefits of the solar production tax credits to customers through Entergy Arkansas’s formula rate plan, effective with the formula rate plan rates that will go into effect January 1, 2027. Entergy Arkansas’s proposal would result in the benefits of the production tax credits being passed through to customers, if approved, as reductions in revenue requirement evenly over the life of the assets, rather than only during the 10-year period in which the production tax credits are generated. In April 2026 the APSC general staff filed testimony proposing an amortization period of no more than 15 years for the monetized proceeds for the tax credits associated with the West Memphis Solar and Driver Solar facilities. An evidentiary hearing is scheduled for July 2026.

Special Rate Contract and Arkansas Cypress Solar

As discussed in the Form 10-K, in September 2025, Entergy Arkansas filed an application with the APSC seeking a certificate of environmental compatibility and public need for the construction and operation of the Arkansas Cypress Solar facility, a planned 600 MW solar photovoltaic array with a 350 MW battery energy storage system and associated transmission facilities interconnecting at Entergy Arkansas’s White Bluff substation. The estimated cost of the project is $1,602 million. In March 2026 the APSC approved the Arkansas Cypress Solar facility and Entergy Arkansas’s recovery of the costs of the facility through the Generating Arkansas Jobs Act rider. The APSC also ordered implementation of an independent monitor to oversee costs. In April 2026, Entergy Arkansas filed with the APSC its proposal for an independent monitor to oversee the reasonableness of costs. In April 2026 the APSC issued an order consolidating Entergy Arkansas’s cost independent monitor proposals for three pending resources, including the Arkansas Cypress Solar facility, into a single docket and directing parties with full intervention status to respond to the proposals and recommend independent monitor candidates. The facility is expected to be in service by the end of 2028.

Filings with the LPSC (Entergy Louisiana)

Retail Rates

Resilience Plan Cost Recovery Rider

In December 2022, Entergy Louisiana filed an application with the LPSC seeking a public interest finding regarding Phase I of Entergy Louisiana’s Future Ready resilience plan and approval of a rider mechanism to recover the program’s costs. Phase I in the December 2022 application reflected the first five years of a ten-year resilience plan and included investment of approximately $5 billion, including hardening investment, transmission dead-end structures, enhanced vegetation management, and telecommunications improvement. In April 2024 the LPSC approved a framework which includes an initial five-year resilience plan providing for an investment of approximately $1.9 billion with cost recovery via a forward-looking rider with semi-annual true-ups. The plan is subject to specified reporting requirements and includes a performance review of the hardened assets. The LPSC order approving the framework does not include any restrictions on Entergy Louisiana’s ability to file applications for approval of additional investments in resilience.

In January 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $40.4 million, or $38.9 million in incremental annual revenues from Entergy Louisiana’s first semi-annual filing in July 2024, for projects expected to be placed in service during the rate-effective period of March 2025 through August 2025. In February 2025 the LPSC staff reviewed the filed rider rates and identified no material issues.

In July 2025, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $50.2 million, or $9.8 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of September 2025 through February 2026. Additionally, Entergy Louisiana’s true-up filing included an under-recovery totaling $5.6 million to be implemented in the January 2026 semi-annual filing. In August 2025 the LPSC staff reviewed the filed rider rates and identified no material issues.

In January 2026, Entergy Louisiana’s semi-annual filing sought to collect from Entergy Louisiana’s retail customers approximately $101.8 million, or $51.6 million in incremental annual revenues, for projects expected to be placed in service during the rate-effective period of March 2026 through August 2026. Additionally, Entergy Louisiana’s true-up filing included an over-recovery totaling $16.6 million to be implemented in the July 2026 semi-annual filing. In February 2026 the LPSC staff reviewed the filed rider rates and identified no material issues.

Filings with the MPSC (Entergy Mississippi)

Retail Rates

2026 Formula Rate Plan Filing

In February 2026, Entergy Mississippi submitted its formula rate plan 2026 test year filing and 2025 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2025 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2026 calendar year to also be within the formula rate plan bandwidth. The 2026 test year filing resulted in an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2025 look-back filing compared actual 2025 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 $293 thousand to reflect one outside-the-bandwidth change, a true-up of demand side management costs. A final order is expected in second quarter 2026.

Filings with the City Council (Entergy New Orleans)

Retail Rates

2026 Formula Rate Plan Filing

In April 2026, Entergy New Orleans submitted to the City Council its formula rate plan 2025 test year filing. The 2025 evaluation report produced an earned return on equity of 7.55% compared to the authorized return on equity of 9.35%. Without adjustments, this would result in an increase in rates of $16.6 million. The increase in rates is driven, in part, by an increase in plant in service, as well as the cost of known and measurable capital additions. The increase is also driven by a decrease in total revenues due to a decline in kWh sales. The filing is subject to a 75-day review and discovery period followed by a 25-day period to resolve any disputes among the parties. For any disputed items, the City Council would set a procedural schedule to resolve such disputes. Resulting rates will be effective with the first billing cycle of September 2026 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 2026, 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 $112.5 million annually, or $20.4 million

in incremental annual revenues beyond Entergy Texas’s currently effective DCRF rider based on its capital invested in distribution between July 1, 2025 and December 31, 2025.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2025, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $30.3 million annually, or $20.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2024 and June 30, 2025 and changes in other transmission charges. In April 2026 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 6, 2026.

Generation Cost Recovery Rider

In March 2026, Entergy Texas filed an application to establish a generation cost recovery rider to begin recovering a return of and on its capital investment in the Orange County Advanced Power Station. The proposed generation cost recovery rider, which includes Entergy Texas’s capital invested in generation for the Orange County Advanced Power Station through December 31, 2025, is designed to collect approximately $150.4 million annually from Entergy Texas’s retail customers. By statute, the proposed generation cost recovery rider rates are to become effective when the Orange County Advanced Power Station is placed into service, which is expected in third quarter 2026.

Entergy Arkansas Opportunity Sales Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints.

Unit Power Sales Agreement

See Note 2 to the financial statements in the Form 10-K for discussion of the Unit Power Sales Agreement.

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.

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.