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ETR · Entergy

34 filings

10-K

ETR 10-K Annual Reports

Entergy - 34 annual reports

Filing record · 2016–202610-K1110-Q338-K146

2025
Entergy Annual Report, Year Ended Dec 31, 2025
Entergy (ETR) reported 2025 net income attributable to the company of $1.76 billion, or $3.91 diluted EPS, up from $1.06 billion ($2.45) in 2024, which was depressed by a $320 million non-cash pension settlement charge and about $151 million in Louisiana formula-rate-plan regulatory charges. Utility net income rose to $2.29 billion from $1.83 billion, driven by higher volume/weather, retail pricing, and capital-investment-driven returns. Operating revenues grew 9% to $12.9 billion on 3% higher electric sales, led by industrial load growth, including large data-center-related demand. The effective tax rate fell to 21.9% from 26.4%. The main investor story is the scale of the capital plan and the financing it requires. Planned construction and capital investment totals roughly $11.6 billion in 2026 and $13.0 billion in 2027, with generation the largest category. Long-term debt rose to about $30.3 billion, and debt-to-capital was 64.3% at year-end. Entergy is funding this partly through equity, including forward sale agreements and about $4.4 billion of expected issuances through 2029, which raises dilution risk. The company also flagged Winter Storm Fern costs of roughly $460–560 million, most of it capital, with recovery expected through established regulatory mechanisms. Regulatory and commercial risk is elevated. Several large projects depend on data-center customers and pending approvals, including Louisiana's Meta-linked generation, the Arkansas Jefferson and Cypress Solar filings, and the Entergy Texas Legend Power Station build-to-suit lease. Other items include the Entergy Arkansas opportunity-sales loss, the OBBBA's effect on clean-energy tax credits, and potential exposure to the corporate alternative minimum tax in 1 to 3 years.
Feb 19, 2026
2024
Entergy Annual Report, Year Ended Dec 31, 2024
Entergy Corporation (ETR) reported 2024 consolidated net income attributable to Entergy of $1.06 billion, down from $2.36 billion in 2023, which benefited from a one-time $843 million income tax reduction tied to the resolution of the 2016-2018 IRS audit. Utility segment net income fell to $1.83 billion from $2.51 billion on the same basis, and Parent & Other posted a larger loss driven mainly by a $320 million non-cash pension settlement charge. Operating revenues were roughly flat at $11.9 billion, with Utility retail electric price increases offset by lower fuel and purchased power pass-through revenues. Capital intensity is rising sharply. Planned construction and capital investments total $8.4 billion in 2025, $9.6 billion in 2026, and $8.8 billion in 2027, driven by generation for large data-center customers in Louisiana and Mississippi, solar build-outs, and transmission. Long-term debt rose to about $28 billion from $25 billion, the debt-to-capital ratio reached 65.3%, and Entergy expects to issue about $4.7 billion of equity through 2028. Management highlights regulatory risks (rate cases, MISO market changes, nuclear fuel and waste costs), the litigation loss on Entergy Arkansas's opportunity sales proceeding ($131.8 million write-off), and the dependence of growth plans on a small number of large data-center customers. For investors, the key tension is between strong rate base growth and credit and equity dilution pressure. The filing also discloses a $12 million SEC settlement regarding materials and supplies accounting controls, and a planned sale of the New Orleans and Louisiana natural gas distribution businesses pending regulatory approval.
Feb 18, 2025
2023
Entergy Annual Report, Year Ended Dec 31, 2023
Entergy Corporation (NYSE: ETR) reported a strong 2023 under its combined Form 10-K filed February 23, 2024, with consolidated net income attributable to Entergy of $2.36 billion ($11.10 diluted EPS), up from $1.10 billion ($5.37) in 2022. The improvement was driven mainly by a $842 million income-tax benefit tied to the resolution of the 2016-2018 IRS audit, the Entergy Louisiana Hurricane Ida securitization, and the absence of the 2022 $551 million System Energy regulatory charge. Operating revenue was $12.1 billion, down from $13.8 billion, reflecting lower fuel and purchased-power pass-throughs, while the Utility segment earned $2.51 billion. Balance-sheet leverage improved: debt-to-capital fell to 63.8% from 66.9%, and the company issued equity through its at-the-market program. Entergy plans capital expenditures of $5.9 billion in 2024, rising to $7.3 billion in 2026, focused on generation (including solar additions), transmission, and distribution. Management expects to pay about $270 million into qualified pensions in 2024 and expects to issue roughly $1.4 billion of equity through 2026. Key risks include pending rate cases and formula-rate-plan proceedings, including Entergy Louisiana's 2023 rate-extension request, and a large set of FERC complaints against System Energy over Grand Gulf. Aggregate refund claims in those proceedings exceed System Energy's net book value, so an adverse outcome could require new financing. The company also faces possible corporate alternative minimum tax exposure within two to four years and ongoing storm-cost and nuclear decommissioning and spent-fuel matters.
Feb 23, 2024
2022
Entergy Annual Report, Year Ended Dec 31, 2022
Entergy Corporation (NYSE: ETR) filed its combined 2022 Form 10-K on February 24, 2023, covering the parent and six registrant subsidiaries (Entergy Arkansas, Louisiana, Mississippi, New Orleans, Texas, and System Energy). Entergy reported 2022 consolidated net income attributable to Entergy of $1,103 million (basic EPS $5.40, diluted $5.37), versus $1,118 million ($5.54 diluted) in 2021, with operating revenues rising to $13.8 billion from $11.7 billion, driven primarily by higher Utility electric prices, volume/weather, and fuel pass-through revenues. Results were held back by a $551 million pre-tax regulatory charge (about $413 million after tax) tied to System Energy's settlement with the Mississippi Public Service Commission and potential FERC refunds, plus a $224 million charge tied to the Louisiana storm securitization, partly offset by a $283 million income tax benefit from that securitization and a $166 million gain on the Palisades sale. The company completed its multi-year exit from merchant nuclear generation with the June 2022 sale of Palisades, and Entergy Wholesale Commodities ceases to be a reportable segment from January 1, 2023, leaving a regulated Utility-focused business. Capital plans for 2023 through 2025 total roughly $15.9 billion (about $3.9 billion in 2023, rising to $6.6 billion in 2025), concentrated in generation (including solar and the Orange County Advanced Power Station), transmission, and distribution. Debt to capital was 66.9% at year-end 2022 (66.6% excluding securitization bonds), down from 69.5%, aided by about $870 million of equity forward settlements. The filing also flags substantial open risks: a FERC-pending System Energy refund exposure that the City Council estimates at about $493 million beyond amounts already paid, and the possibility of CAMT tax exposure within two to three years.
Feb 24, 2023
2021
Entergy Annual Report, Year Ended Dec 31, 2021
Entergy Corporation (NYSE: ETR) reported 2021 consolidated net income attributable to Entergy of $1.118 billion, or $5.54 diluted EPS, down from $1.388 billion ($6.90) in 2020, driven largely by a $340 million charge (about $268 million after tax) tied to the May 2021 sale of Indian Point, a lower-earning Entergy Wholesale Commodities segment, and the 2020 IRS audit resolution benefit that did not recur. Operating revenues rose 16% to $11.74 billion, led by the Utility segment (94% of revenue), which benefited from higher retail rates and volume. Utility fuel and purchased power costs rose sharply, including Winter Storm Uri, and Hurricane Ida restoration costs are estimated at about $2.7 billion for Entergy Louisiana and Entergy New Orleans, with roughly $1.1 billion booked as regulatory assets. Balance sheet leverage is elevated: the debt-to-capital ratio rose to 69.5% from 68.3%, and long-term debt grew to about $24.8 billion. Management expects to issue roughly $700 million of equity through 2024 under an at-the-market program, and projects capital investment of $3.7 billion in 2022 rising to $4.3 billion in 2024, plus $885 million of Hurricane Ida spending in 2022. Cash flow from operations fell to $2.3 billion from $2.7 billion, while investing outflows reached $6.2 billion. Entergy is also winding down its merchant nuclear business, with the Palisades plant expected to shut down by May 2022 and be sold to Holtec in mid-2022. For investors, the key questions are whether Entergy can recover storm costs through securitization and rate mechanisms, how quickly it can fund its large capital plan without further dilution or credit pressure, and whether pending FERC proceedings against System Energy (Grand Gulf) produce material refunds. The filing also flags a $712 million net unrecognized tax benefit and ongoing regulatory challenges to the Unit Power Sales Agreement.
Feb 25, 2022
2020
Entergy Annual Report, Year Ended Dec 31, 2020
Entergy Corporation's 2020 Form 10-K (filed February 26, 2021) reports consolidated net income of $1.41 billion and net income attributable to Entergy of $1.39 billion, up from $1.24 billion in 2019, with basic EPS of $6.94 versus $6.36. The Utility segment generated roughly 91% of revenue and 96% of total assets, and drove the improvement, while Entergy Wholesale Commodities (EWC) posted a loss of about $65 million as it winds down its merchant nuclear fleet. Operating revenues declined to $10.11 billion from $10.88 billion, largely due to COVID-19-related sales declines, Hurricanes Laura, Delta and Zeta, and lower wholesale output, but these were offset by a $230 million reduction in deferred tax expense from the resolution of the 2014-2015 IRS audit. The balance sheet and financing needs are the main investor focus. Total assets rose to $58.2 billion, and the debt-to-capital ratio climbed to 68.3% from 65.5%, with net debt to net capital excluding securitization bonds at 66.4%. Entergy's capital expenditure plan totals roughly $3.5 billion in 2021 and $4.6 billion in 2023, and management expects to issue about $2.5 billion of equity through 2024, including a new at-the-market program authorized in January 2021. Estimated restoration costs for the 2020 hurricanes are about $2.4 billion, and recovery through regulatory mechanisms or securitization remains subject to approval and is not yet assured. Key risks include regulatory outcomes (formula rate plan extensions, storm cost recovery, and FERC proceedings on System Energy's return on equity and Grand Gulf), the planned shutdown and sale of the remaining EWC nuclear plants by mid-2022, and the February 2021 winter storm, which drove Entergy's estimated natural gas purchases to about $510 million and restoration costs to roughly $125-140 million. Entergy's 2020 results were achieved despite these headwinds, and the filing notes that the outcome of these proceedings cannot be predicted.
Feb 26, 2021
2019
Entergy Annual Report, Year Ended Dec 31, 2019
Entergy Corporation's FY2019 10-K shows a company in transition: consolidated net income rose to $1.258 billion (EPS $6.30 diluted) from $863 million in 2018, driven largely by the absence of 2018's $532 million Entergy Wholesale Commodities impairment and by favorable tax items. The Utility segment, now 88% of revenue and 96% of assets, earned $1.426 billion, while the merchant nuclear business (Entergy Wholesale Commodities) contributed $149 million, helped by a $156 million tax benefit from an internal restructuring. The company is executing a planned exit from merchant power, with Indian Point 2 and 3 and Palisades to be shut down by 2022 and sold to Holtec, and it recorded a $190 million loss on the August 2019 Pilgrim sale. Investors should weigh a heavy capital program and leverage. Planned construction spending is about $4.1 billion in 2020 and declining thereafter, while operating cash flow was $2.8 billion, so the company continues to depend on debt and equity issuance. Debt to capital stood at 65.5% (about 64.6% net of cash, excluding securitization bonds), near the 65% covenant ceiling in the $3.5 billion credit facility. Entergy also faces open regulatory risk, including the FERC return-on-equity proceeding for System Energy and litigation over the Grand Gulf sale-leaseback, with refund claims in the hundreds of millions of dollars. The filing also flags a $1.5 billion net unrecognized tax benefit, a $1.7 billion regulatory liability for income taxes that is being returned to customers, and an unusually low 2019 effective tax rate of (15.6%). Earnings quality in 2019 therefore depends partly on tax and restructuring items rather than purely on recurring utility margins.
Feb 21, 2020
2018
Entergy Annual Report, Year Ended Dec 31, 2018
Entergy Corporation's 2018 combined Form 10-K (filed February 26, 2019) covers the parent and six Registrant Subsidiaries. Consolidated net income attributable to Entergy rose to $848.7 million (diluted EPS $4.63) from $411.6 million (EPS $2.28) in 2017, but the increase was flattered by large one-time items: a 2017 tax-reform charge and a 2018 income tax benefit of roughly $1.0 billion, which produced a negative effective tax rate of 595% for the year. Operating income fell to $469 million from $1.36 billion in 2017, largely because of $532 million of impairment charges tied to the planned exit from merchant nuclear generation. The strategic story is the wind-down of Entergy Wholesale Commodities. Vermont Yankee was sold to NorthStar in January 2019, Pilgrim is set to shut down May 31, 2019 (with a pending sale to Holtec and an expected roughly $120 million loss), Indian Point 2 and 3 are slated to close in 2020 and 2021, and Palisades in 2022. Entergy has already sold 98% of 2019 planned nuclear output forward, but forward coverage declines sharply in later years, so merchant exposure is shrinking and so is that segment's revenue (down to $1.47 billion from $1.66 billion). The Utility segment, which provides roughly 87% of revenue and 93% of assets, carries the growth plan: 2019-2021 planned capital spending of about $4.6 billion, $3.5 billion, and $3.8 billion, including new gas plants (St. Charles, Lake Charles, Montgomery County) and the Choctaw acquisition. Balance-sheet and cash-flow pressure is the key investor watch item. Operating cash flow fell to $2.39 billion from $2.62 billion, mainly because of returns of excess deferred taxes to customers, while investing outflows were $4.1 billion. Debt to capital is about 66.7%, and the parent's credit facility includes a 65% consolidated debt covenant. Management says it is in compliance. Common dividends were $3.58 per share, and remaining forward equity sales (8.45 million shares) are due by June 2019.
Feb 26, 2019
2017
Entergy Annual Report, Year Ended Dec 31, 2017
Entergy Corporation's FY2017 Form 10-K (filed February 26, 2018) reports a year shaped by a strategic exit from merchant nuclear generation and the enactment of the Tax Cuts and Jobs Act. Consolidated revenue was $11.07 billion (up from $10.85 billion), and consolidated net income attributable to Entergy was $411.6 million, or $2.28 diluted EPS, compared with a 2016 loss of $583.6 million. The swing reflects the absence of 2016's $2.8 billion of impairments, partially offset by 2017's own $538 million of impairment charges at Entergy Wholesale Commodities (EWC) and a $526 million charge tied to the tax law change. The effective tax rate was 56.1%, distorted by the one-time effects of the tax reform and a $373 million tax benefit from reclassifying EWC nuclear entities. The Utility segment, which generates about 85% of revenue and 92% of assets, remains the core earnings driver, with net income of $773 million. Its net revenue rose on retail price increases and the Union Power Station purchase, though weather was unfavorable. EWC's net loss widened to $172 million as the merchant fleet shrinks: FitzPatrick was sold to Exelon in March 2017, and Pilgrim, Indian Point 2 and 3, and Palisades are scheduled to shut by mid-2022. Entergy's capital plan calls for $4.2 billion in 2018 and about $3.3 billion by 2020, with the Utility funding new generation such as St. Charles and Lake Charles. Leverage is elevated, with debt to capital at 67.1% (66.3% excluding securitization bonds), up from 64.8%, driven largely by commercial paper. For investors, the central questions are the pace of EWC's wind-down and the regulatory treatment of roughly $3.7 billion of excess deferred taxes returned to customers, which management expects to reduce operating cash flow. Operating cash flow fell to $2.62 billion from $3.00 billion. The dividend was raised to $0.89 per quarter, and the company retains a $350 million buyback authorization.
Feb 26, 2018
2016
Entergy Annual Report, Year Ended Dec 31, 2016
Entergy Corporation's 2016 Form 10-K reports a consolidated net loss of $564.5 million (EPS of -$3.26), driven primarily by $2.84 billion in pre-tax impairment and related charges at its merchant nuclear business, Entergy Wholesale Commodities (EWC). The charges wrote down Palisades, Indian Point 2, and Indian Point 3 following the company's decision to exit merchant power generation. The Utility segment remained the earnings engine, contributing $1.15 billion of net income and generating 83% of revenue, while total revenue declined to $10.85 billion from $11.51 billion. Management is executing a planned exit from merchant generation: FitzPatrick is slated for sale to Exelon in 2017, Vermont Yankee for sale to NorthStar, Palisades is to shut in October 2018 after a $172 million PPA termination payment, Pilgrim is to close in 2019, and a January 2017 settlement with New York State commits to shutting Indian Point 2 and 3 by 2020 and 2021. Entergy expects cessation of all merchant nuclear generation by 2021. On the Utility side, the company plans roughly $3.4-3.8 billion of annual capital spending for 2017-2019, including the St. Charles, Lake Charles, and Montgomery County gas plants, and it acquired the Union Power Station for about $949 million in 2016. Investors should weigh the strong regulated base against balance-sheet pressure: debt-to-capital rose to 64.8% from 59.1%, and operating cash flow fell to $3.0 billion. Ongoing regulatory items, including a January 2017 FERC complaint seeking a lower System Energy return on equity and open System Agreement proceedings, add uncertainty. The dividend was raised to $0.87 per quarter.
Feb 24, 2017
2015
Entergy Annual Report, Year Ended Dec 31, 2015
Entergy Corporation's FY2015 10-K (combined filing with its utility subsidiaries) reports a consolidated net loss of $156.7 million, or $(0.99) per share, versus net income of $960.3 million ($5.22 diluted EPS) in 2014. The swing is driven almost entirely by $2.04 billion ($1.32 billion after tax) of impairment and related charges at the Entergy Wholesale Commodities (EWC) nuclear fleet: FitzPatrick and Pilgrim, which Entergy decided in October 2015 to close, and Palisades. Consolidated operating revenues fell about 8% to $11.5 billion, while the Utility segment, which generates about 82% of revenue and 86% of assets, earned $1.11 billion. Management also cites a lower effective tax rate tied to the Louisiana business combination and a 2015 Louisiana regulatory charge. The company's own figures show weaker wholesale power prices, with realized EWC nuclear revenue per MWh down to $51.49 from $60.35. The balance sheet and cash flow remain sizable but are under pressure. Operating cash flow was $3.29 billion (down from $3.89 billion), and capital spending is planned at $3.8 billion for 2016, $3.25 billion for 2017, and $3.26 billion for 2018, mainly for generation, transmission and distribution, plus the pending Union Power Station acquisition (about $948 million base price). Debt to capital rose to 59.1% from 57.4%, and the common dividend is $0.85 per quarter ($3.40 annualized). Key forward risks include the EWC plant closures, Indian Point license renewal and state proceedings, the System Agreement termination effective August 31, 2016, ANO's elevated NRC oversight (Column 4, with about $50 million expected in 2016), and the tax and nuclear decommissioning matters. For investors, the central question is whether the Utility franchise can carry the group while EWC is wound down. The Utility's earnings growth and rate-case outcomes are the main positives; the merchant nuclear exposure and litigation/regulatory uncertainty are the main negatives.
Feb 26, 2016
2014
Entergy Annual Report, Year Ended Dec 31, 2014
Entergy Corporation's 2014 Form 10-K (filed February 26, 2015) reports a year of strong earnings recovery. Consolidated net income rose to $960.3 million from $730.6 million in 2013, and earnings per diluted share reached $5.22 versus $3.99. Operating revenues grew 9.7% to $12.5 billion, with the Utility segment producing $846.5 million of net income and Entergy Wholesale Commodities (EWC) contributing $294.5 million, up from $43.0 million, driven mainly by higher realized nuclear prices in the Northeast, mark-to-market gains, and fewer unplanned outage days. The filing also highlights meaningful risks. EWC's nuclear fleet faces a challenging long-term price environment: Entergy has sold forward 86% of 2015 planned nuclear output at about $48/MWh, but only 39% of 2017 output, and four of five operating plants sit in low-priced New York and New England markets. Vermont Yankee ceased operations in December 2014, and the Indian Point 2 and 3 license renewals remain contested. The Utility faces regulatory uncertainty around the System Agreement exit, the pending Entergy Louisiana/Entergy Gulf States Louisiana business combination, and ANO stator-related NRC findings, including multiple 'yellow' findings that could increase operating costs. Balance sheet metrics are stable. Debt to capital was 57.6% (53.4% net of cash and excluding securitization bonds), cash on hand rose to $1.42 billion, and a $3.5 billion credit facility had $2.8 billion of capacity available. The company maintained its $0.83 quarterly dividend ($3.32 annually), and planned 2015-2017 capital expenditures total about $9.0 billion, led by the Union Power Station acquisition and Ninemile 6, which entered service in December 2014.
Feb 26, 2015
2013
Entergy Annual Report, Year Ended Dec 31, 2013
Entergy Corporation's 2013 Form 10-K, filed February 27, 2014, covers a combined report for the parent and its seven Registrant Subsidiaries. Consolidated 2013 net income was $730.6 million, with net income attributable to Entergy of $711.9 million, or $3.99 per diluted share, down from $4.76 in 2012. Revenue rose to $11.39 billion from $10.30 billion. The decline in earnings was driven mainly by $321.5 million ($202.2 million after tax) of impairment and related charges tied to the planned shutdown of Vermont Yankee, and by roughly $110 million of human capital management restructuring costs. Operating cash flow improved to $3.19 billion from $2.94 billion. The Utility segment generated about 80% of revenue and 116% of net income, while Entergy Wholesale Commodities (EWC), the merchant nuclear business, contributed 20% of revenue and only 6% of net income. EWC faces structural pressure from low natural gas and wholesale power prices, with realized nuclear revenue of $50.15 per MWh and 74% of 2014 planned output sold forward at an expected $50 per MWh. Management has signaled that unfavorable economics could trigger further impairments at other plants. The 2013 MISO RTO integration was completed on December 19, 2013, and the proposed ITC transmission spin-merge was terminated after the Mississippi PSC denied the joint application. Balance sheet metrics were stable. Debt to capital (excluding securitization bonds) was 56.3%, and net debt to net capital was 54.8%. Liquidity included $739 million of cash and a $3.5 billion revolving credit facility with $3.2 billion available. The board declared a $0.83 quarterly dividend, and $350 million remained on the $500 million buyback authorization. Management expects 2014 pension contributions of about $400 million, and planned capital spending is $2.3 billion for 2014.
Feb 27, 2014
2012
Entergy Annual Report, Year Ended Dec 31, 2012
Entergy's FY2012 10-K (combined filing with its six utility registrant subsidiaries and System Energy) reports a sharp earnings decline driven primarily by a $355.5 million ($223.5 million after-tax) impairment of Vermont Yankee and related assets, plus large swings in income tax items. Consolidated net income fell to $868.4 million from $1,367.4 million in 2011, and diluted EPS from continuing operations dropped to $4.76 from $7.55. Operating revenues declined about 8% to $10.3 billion, with lower fuel and purchased power pass-throughs, lower Entergy Wholesale Commodities realized nuclear prices ($50.29/MWh vs. $54.73), and weather-driven volume declines. The effective tax rate was only 3.4%, reflecting IRS settlements and the reversal of uncertain tax positions, which flattered 2012 results but are non-recurring in nature. For investors, the most important forward-looking items are the planned spin-off and merger of the Utility's transmission business with ITC Holdings (targeted for completion in 2013, subject to regulatory and shareholder approvals), the planned move of the Utility operating companies into the MISO RTO by December 2013, and the outlook for the nuclear fleet, where 85% of 2013 planned output is sold forward at about $46/MWh and 73% of 2014 output at about $45/MWh. Liquidity remained adequate, with $2.7 billion of undrawn capacity on the $3.5 billion credit facility and cash of $533 million, while total debt to capital rose to 58.7%. Dividends were held at $0.83 per quarter ($3.32 annually), and the board retained a $350 million remaining repurchase authority. Key risks include Indian Point license renewal and cooling-water litigation, the Vermont Yankee regulatory and legal challenges, uncertainties in System Agreement cost allocation and FERC proceedings, Hurricane Isaac restoration cost recovery (estimated at about $370 million, with roughly $120 million recorded as regulatory assets), and continued pressure on nuclear realized prices and capacity factors.
Feb 27, 2013
2011
Entergy Annual Report, Year Ended Dec 31, 2011
Entergy's 2011 combined Form 10-K (filed February 28, 2012, covering Entergy Corporation and six Registrant Subsidiaries) reports consolidated net income of $1.37 billion and earnings per diluted share from continuing operations of $7.55, up from $6.66 in 2010, on operating revenues of $11.23 billion, down slightly from $11.49 billion. The improvement was driven largely by a $422 million income tax benefit from a 2011 IRS settlement on the mark-to-market tax treatment of power purchase contracts, of which a $199 million regulatory charge at Entergy Louisiana will be shared with customers. Excluding that one-time item, earnings were weaker: Entergy Wholesale Commodities net revenue fell 7% to $2.04 billion on lower realized nuclear power prices ($54.73/MWh versus $59.16), and the company's effective tax rate was 17.3% against the 35% statutory rate. The Utility segment remains the core business, serving about 2.8 million customers in Arkansas, Louisiana, Mississippi and Texas, with a 2012 to 2014 capital plan of roughly $2.9 billion, $2.1 billion and $2.1 billion. Major projects include the Ninemile 6 gas plant, acquisitions of the Hinds and Hot Spring facilities, the Waterford 3 steam generator replacement (about $687 million), and the Grand Gulf uprate (about $754 million). The company also plans to transfer transmission assets to MISO and to spin off its transmission business into a merger with ITC Holdings, targeted for completion in 2013. Entergy's pending exit from the System Agreement and ongoing FERC cost-allocation litigation add regulatory uncertainty. Balance-sheet leverage is high, with debt to capital at 57.3% (about 55% excluding securitization bonds), and the company repurchased $236 million of stock in 2011 while paying $590 million in dividends. Key risks include nuclear license renewal challenges at Indian Point, Pilgrim and Vermont Yankee, the Entergy Wholesale Commodities price exposure from forward contracts at declining prices, and litigation in Texas and Mississippi.
Feb 28, 2012
2010
Entergy Annual Report, Year Ended Dec 31, 2010
Entergy Corporation's 2010 Form 10-K (filed February 28, 2011) reports consolidated net income of $1.27 billion, up from $1.25 billion in 2009, on operating revenues of $11.49 billion (up 6.9% from $10.75 billion). Earnings per diluted share from continuing operations were $6.66, up from $6.30. The Utility segment drove results, with net income of $829.7 million versus $708.9 million in 2009, helped by higher retail rates, favorable weather and volume, and the Act 55 storm cost financings. Entergy Wholesale Commodities (EWC) earnings fell to $489.4 million from $641.1 million, mainly because nuclear realized prices declined to $59.16/MWh from $61.07/MWh and nuclear volumes dropped with a 90% capacity factor versus 93%. The company's cash flow from operations rose to $3.93 billion from $2.93 billion, aided by $703 million received from the Louisiana Utilities Restoration Corporation. Entergy returned capital to shareholders through $604 million in common dividends and $879 million in share repurchases. The Board raised the quarterly dividend to $0.83 per share from $0.75 starting in 2010. Liquidity remains solid, with $1.29 billion of cash and a $3.5 billion revolving credit facility of which $1.8 billion was available at year-end. Key risks include the EWC nuclear fleet's exposure to lower market power prices (96% of 2011 planned output is sold forward at about $53/MWh, but only 40% of 2013 output is sold), the planned unwinding of the non-utility nuclear spin-off (which produced $64 million in write-offs), the Waterford 3 steam generator replacement delay, the System Agreement litigation and the planned exit of Entergy Arkansas and Entergy Mississippi, the Vermont Yankee operating-license uncertainty, and a potential Department of Justice civil investigation.
Feb 28, 2011
2009-A
Entergy Annual Report (Amendment), Year Ended Dec 31, 2009
This excerpt is Part IV, Item 15 (Exhibits and Financial Statement Schedules) of Entergy Corporation's Form 10-K for the fiscal year ended December 31, 2009, filed February 26, 2010. It contains no financial results, balance sheet, or operating metrics. The audited financial statements, auditor's report, and financial statement schedules are incorporated by reference as "previously filed," so this section cannot support an assessment of Entergy's earnings, cash flow, or leverage. Investors would need the full filing for that analysis. The exhibit index does show the structure of Entergy's System-wide arrangements. Entergy Corporation acts as a holding company for its utility operating subsidiaries (Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy). Costs and power are shared through an Entergy System Agency Agreement, a Service Agreement with Entergy Services, a consolidated income tax allocation agreement, and System Energy's Grand Gulf availability and unit power sales arrangements. Entergy also has a $3.5 billion credit agreement dated August 2, 2007 with a syndicate of banks, plus senior note officer's certificates and a guarantee structure that supports subsidiary debt. Several filed-with-this-10-K items relate to executive compensation and governance. These include amendments to retention agreements for senior executives (J. Wayne Leonard, Leo P. Denault, and Richard J. Smith, all dated December 2009), a restricted unit agreement, a fifth amendment to the tax allocation agreement dated November 20, 2009, and amendments to the System Executive Continuity Plan effective January 1, 2010. Investors interested in governance or management retention should review these documents directly.
Feb 26, 2010
2009
Entergy Annual Report, Year Ended Dec 31, 2009
Entergy's FY2009 Form 10-K (filed February 26, 2010) reports consolidated revenues of $10.7 billion, net income attributable to Entergy of $1.23 billion (diluted EPS $6.30), and approximately 30,000 MW of generating capacity, making it the second-largest U.S. nuclear generator. The company operates through two reportable segments: a rate-regulated Utility business serving 2.7 million customers across four states, and a Non-Utility Nuclear business owning six nuclear plants. Utility net income rose to $709 million while Non-Utility Nuclear earned $631 million, down from $797 million in 2008 as realized prices gains were offset by lower volume and a planned spin-off process. The central strategic event is the proposed tax-free spin-off of Non-Utility Nuclear to shareholders through a new company, Enexus Energy Corporation, which would carry up to $4.0 billion of debt. Approval is far from assured: the New York Public Service Commission staff concluded in February 2010 that the transaction was not in the public interest and recommended a $550 million reduction in Enexus debt, and the Vermont approval is pending amid a stay request tied to tritium leaks at Vermont Yankee. Investors should weigh the spin-off's uncertain timing and conditions against the Utility's regulatory and capital-spending exposures. Other material risks include the FERC-mandated System Agreement cost reallocation (Entergy Arkansas expects roughly $70 million in 2010 payments), a Waterford 3 steam generator replacement costing about $511 million, a possible $465 million scrubber project at White Bluff, and approximately $1.5 billion in planned Utility construction capital for 2010. Liquidity appears solid, with $1.71 billion of cash on hand and $906 million of available credit under the $3.5 billion revolver.
Feb 26, 2010
2008
Entergy Annual Report, Year Ended Dec 31, 2008
Entergy Corporation's 2008 10-K filing reveals a company with two primary segments: Utility and Non-Utility Nuclear. The Utility segment, serving a four-state region including Arkansas, Mississippi, Texas, and Louisiana, experienced revenue impacts from hurricanes Gustav and Ike, leading to significant restoration costs estimated between $1.295 billion and $1.360 billion. Despite these challenges, the company continued its plan to separate the Non-Utility Nuclear business through a tax-free spin-off, creating a new entity, Enexus Energy Corporation, which would also form a joint venture, EquaGen LLC, with Entergy. This separation process faced regulatory hurdles, notably with the Nuclear Regulatory Commission (NRC) and the New York Public Service Commission. The company also reported strong performance in its Non-Utility Nuclear segment, driven by higher pricing and the acquisition of the Palisades plant, though it noted potential future pricing uncertainty due to declining natural gas prices. Financially, Entergy saw an increase in consolidated net income to $1.22 billion in 2008, compared to $1.13 billion in 2007, driven largely by the strong performance of the Non-Utility Nuclear segment. The company's liquidity remained sufficient, with $1.9 billion in cash and cash equivalents on hand as of December 31, 2008. Entergy also managed its capital structure, with the debt-to-capital ratio increasing slightly to 59.7%, in line with its financial aspirations. The report highlights the company's ongoing capital expenditure plans, focusing on maintenance and growth projects within its Utility segment, and its commitment to shareholder returns through dividends and share repurchases.
Mar 2, 2009
2007
Entergy Annual Report, Year Ended Dec 31, 2007
Entergy Corporation's (ETR) 2007 10-K filing highlights a year of operational recovery and strategic restructuring. The company reported consolidated net income of $1.135 billion, a slight increase from the previous year, driven by strong performance in its Non-Utility Nuclear segment which benefited from higher pricing and the acquisition of the Palisades plant. The Utility segment also showed resilience, with net revenue increasing despite increased operation and maintenance expenses. A significant strategic development is Entergy's plan, approved in November 2007, to spin off its Non-Utility Nuclear business into a separate, publicly traded company. This separation, along with a proposed joint venture for nuclear services, aims to allow Entergy to focus on its core Utility business. The company expects the spin-off to qualify for tax-free treatment for shareholders. Entergy also made significant progress in its liquidity and capital resources, refinancing its credit facilities and managing its debt levels, which remained within its financial aspirations. The company remains focused on environmental compliance and managing risks associated with its operations and market conditions, including the ongoing impact of Hurricanes Katrina and Rita, for which insurance claims and CDBG funding are being actively managed.
Feb 29, 2008
2006
Entergy Annual Report, Year Ended Dec 31, 2006
This 10-K filing for Entergy Corporation and Subsidiaries as of March 1, 2007, details the company's financial performance and operations. The report highlights the significant impact of Hurricanes Katrina and Rita in 2005, which led to substantial restoration costs and damage to infrastructure, particularly affecting the Utility segment. Entergy New Orleans filed for Chapter 11 bankruptcy protection in September 2005 due to these events. The company is actively pursuing cost recovery through insurance, federal legislation, and regulatory mechanisms. Financially, the company reported consolidated net income of $1,132,602,000 for 2006, an increase from $898,331,000 in 2005, driven by improved net revenue in both Utility and Non-Utility Nuclear segments, although interest charges increased due to additional borrowing for storm restoration. The filing also addresses the company's business segments, the Utility and Non-Utility Nuclear operations, and discusses capital expenditures, liquidity, risk management, and regulatory matters across its various state jurisdictions. Key financial data points include total assets of $31,082,731,000 and long-term obligations of $8,996,620,000 as of December 31, 2006. Management expresses confidence in maintaining effective internal controls over financial reporting.
Mar 1, 2007
2005
Entergy Annual Report, Year Ended Dec 31, 2005
Entergy Corporation's (ETR) 2005 10-K filing highlights a challenging year impacted by Hurricanes Katrina and Rita, which caused significant damage to its U.S. Utility segment's infrastructure, leading to an estimated $1.5 billion in restoration costs and business continuity expenses. The company has recorded these costs as regulatory assets, assuming probable recovery through regulatory mechanisms, but acknowledges the inherent risk in the recovery process. Furthermore, Entergy New Orleans filed for Chapter 11 bankruptcy protection due to the hurricane's impact, leading to its deconsolidation from Entergy's financial statements. Despite these operational and financial headwinds, Entergy's Non-Utility Nuclear segment demonstrated strong performance with increased earnings driven by higher revenues and generation. The company implemented a new financing plan in Q4 2005, sourcing $2.5 billion through debt and equity to bolster liquidity and support its subsidiaries during the storm cost recovery period. This highlights a focus on financial resilience and operational continuity amidst significant external disruptions. Investor attention should be drawn to the company's regulatory filings for storm cost recovery, the potential impact of the Entergy New Orleans bankruptcy on overall financial health, and the performance of the stable Non-Utility Nuclear segment.
Mar 10, 2006
2004
Entergy Annual Report, Year Ended Dec 31, 2004
Entergy Corporation's (ETR) 2004 10-K filing reveals a year of mixed results across its business segments. The U.S. Utility segment showed a significant increase in earnings, driven by lower operating and maintenance expenses and the reversal of a prior year's accrual related to the River Bend plant costs. However, the Non-Utility Nuclear segment experienced a decrease in earnings, largely due to a change in accounting principle in the prior year. The Energy Commodity Services segment saw a substantial drop in earnings, primarily from a lower contribution from its investment in Entergy-Koch and an impairment charge related to the Warren Power plant. Financially, the company reported a decrease in long-term debt and a reduction in its debt-to-capital ratio. Capital expenditures were managed, with significant investments planned for maintenance and capital commitments across its segments. The company also repurchased a substantial amount of its common stock and increased its quarterly dividend. Management expressed confidence in the company's internal controls over financial reporting.
Mar 11, 2005
2003
Entergy Annual Report, Year Ended Dec 31, 2003
Entergy Corporation's 2003 10-K filing reveals a notable increase in net income to $927 million, a significant rise from $599 million in 2002. This improvement was driven by strong performance in the Non-Utility Nuclear segment, which saw earnings more than double, and a recovery in the Energy Commodity Services segment, which swung from a substantial loss in 2002 to a profit in 2003. The U.S. Utility segment, while still the largest contributor to revenue, experienced a decline in earnings due to specific accruals and severance program expenses. The company also reported progress in strengthening its capital structure, with a reduction in its net debt to net capital ratio. Key accounting changes include the adoption of SFAS 143, impacting how asset retirement obligations are recognized, and SFAS 142, related to goodwill. The filing highlights ongoing regulatory proceedings and potential impacts from utility restructuring and market reforms.
Mar 11, 2004
2002
Entergy Annual Report, Year Ended Dec 31, 2002
Entergy Corporation, a Delaware holding company, filed this combined 10-K for fiscal 2002 with six subsidiary utilities and System Energy Resources. Entergy reported 2002 consolidated operating revenues of $8.31 billion, operating income of $1.19 billion, and net income of $623.1 million, down from $750.5 million in 2001. Earnings applicable to common stock were $599.4 million, or $2.64 diluted EPS. The decline reflects a $428.5 million pre-tax ($238.3 million after-tax) charge in the Energy Commodity Services segment, tied to discontinuing greenfield power development and asset impairments in U.S. and U.K. wholesale power markets, partially offset by gains on the Damhead Creek and Spain asset sales. The U.S. Utility segment earned $583 million in 2002 versus $550 million in 2001, and Non-Utility Nuclear earnings rose to $201 million from $128 million, driven by the Indian Point 2 and Vermont Yankee acquisitions. Entergy reduced its net debt to net capital ratio to 46.3% from 49.7%, held $1.34 billion in cash at year-end, and reported cash from operations of $2.18 billion. Operating cash flow benefited from a Entergy Louisiana tax accounting election that produced a cumulative cash benefit of approximately $867 million through 2002, which the filing states is expected to reverse over 2003 through 2031. The filing also flags material forward-looking risks: pending rate proceedings (including Entergy New Orleans, whose rate case seeks a $44 million increase with an agreement in principle for $30 million), FERC proceedings on the System Agreement and Standard Market Design rulemaking, the NRC and FEMA review of Indian Point emergency plans, and the adoption of SFAS 143 in 2003, which the company expects to increase utility asset retirement obligations and to decrease Non-Utility Nuclear liabilities.
Mar 19, 2003
2000-A
Entergy Annual Report (Amendment), Year Ended Dec 31, 2000
This 10-K/A filing from Entergy Corporation, dated August 3, 2001, is an amendment to its annual report for the fiscal year ended December 31, 2000. The primary purpose of this amendment is to attach an exhibit that had previously been requested for confidential treatment, specifically the Agreement of Limited Partnership of Entergy-Koch, LP. This indicates a significant business arrangement or joint venture entered into by Entergy. While the filing primarily serves to include this exhibit, it also reiterates key information about the company's structure and outstanding securities. As of June 29, 2001, Entergy had 221,665,028 shares of common stock outstanding, with a reported market value of approximately $8.5 billion for non-affiliate shares as of the same date. The filing also lists various material contracts, credit agreements, and incentive plans, underscoring the complexity of its operations and management structure. Investors should note the formation of the Entergy-Koch, LP partnership as a material development that could impact future earnings and strategy.
Aug 3, 2001
2000
Entergy Annual Report, Year Ended Dec 31, 2000
Entergy Corporation (ETR), a Delaware holding company, reported in its combined 2000 Form 10-K that its domestic utility companies provided 74% of 2000 revenue and 87% of net income, while its competitive businesses (power marketing and trading, global power development, and domestic non-utility nuclear) are a growing focus. Consolidated 2000 operating revenues were $10.02 billion and consolidated net income was $710.9 million, with earnings applicable to common stock of $679.3 million, or $2.97 diluted EPS, compared with $2.25 in 1999. The filing discloses that Entergy has agreed to a business combination with FPL Group, under which FPL Group shareholders would own about 57% of the new company and Entergy shareholders about 43%, with the objective of closing by late 2001 and a $215 million termination fee in certain circumstances. The company plans $8.2 billion of capital investment for 2001 through 2003, of which $2.6 billion is for the domestic utilities, $3.6 billion for global power development and $2.0 billion for the nuclear business. Major recent steps include the January 2001 formation of Entergy-Koch, L.P. with Koch Industries, the November 2000 purchase of the FitzPatrick and Indian Point 3 nuclear plants from the New York Power Authority, and a pending purchase of Indian Point 2. Risks highlighted include unresolved transition to retail competition in Arkansas, Texas and other jurisdictions, stranded cost exposure, pending FERC proceedings on the System Agreement, the December 2000 Arkansas ice storms (estimated storm costs of $195 million), and a range of litigation including a $544 million Louisiana fuel-clause claim that Entergy Louisiana has settled for about $72 million in refunds. For investors, the key questions are the timing and conditions of the FPL Group merger, the ability to fund the large capital program while managing fuel-cost recovery, and how the competitive businesses and regulatory outcomes will affect earnings.
Mar 16, 2001
1999
Entergy Annual Report, Year Ended Dec 31, 1999
Entergy Corporation's 10-K for fiscal 1999 (filed March 15, 2000) describes a holding company whose primary earnings engine is its regulated domestic utility operations, which contributed 73% of operating revenue and 93% of net income in 1999. Consolidated 1999 results were weaker than 1998: operating revenues fell to $8.77 billion from $11.49 billion, largely because London Electricity and CitiPower were sold in December 1998 and power marketing volumes declined. Net income dropped to $595 million from $786 million, and earnings applicable to common stock were $2.25 per share versus $3.00 in 1998. Lower 1999 results reflected the absence of 1998 sale gains, while the domestic utilities grew net income about 5%. The filing's most important forward-looking items are a $9.8 billion capital investment plan for 2000-2004, heavy spending on the Saltend (UK, 1,200 MW) and Damhead Creek (UK, 800 MW) merchant plants, a planned option on about $2.0 billion of GE gas turbines, and an offer to acquire NYPA's FitzPatrick and Indian Point 3 plants. Regulatory transition is a central risk: Arkansas and Texas passed retail open access laws effective January 1, 2002, creating possible stranded-cost exposure of several billion dollars and possible loss of SFAS 71 accounting. Litigation is also material, including a pending LPSC proceeding with $544 million of claimed fuel-cost damages in Louisiana, a $1.1 billion Indian arbitration claim, and an ice storm class action. For investors, the key tensions are between a solid regulated utility base and a growing, capital-intensive, more speculative merchant generation and nuclear strategy, combined with significant regulatory and litigation uncertainty. The company also repurchased stock aggressively in 1999 and maintained a dividend of $1.20 per share, which was reduced from $1.80 in 1997.
Mar 15, 2000
1998
Entergy Annual Report, Year Ended Dec 31, 1998
Entergy Corporation's 1998 Form 10-K (filed March 12, 1999) reports a year of significant strategic transformation. Consolidated net income rose to $785.6 million, or $3.00 per share, compared with $300.9 million ($1.03 per share) in 1997. The improvement was driven largely by the sale of non-regulated international businesses, most notably London Electricity and CitiPower, which generated gains and about $2.3 billion in sale proceeds. Operating revenues grew to $11.5 billion, though this was mainly due to the power marketing and trading business, which expanded sharply. Excluding special items, management states that net income would have risen roughly 20% over 1997. Following an August 1998 strategic refocus on domestic utility operations, global power development, and nuclear operations, Entergy reduced its quarterly common dividend from $0.45 to $0.30 per share in order to strengthen its balance sheet and fund future investments. Debt as a percentage of total capital fell to 48.6% from 56.5% a year earlier. The main risks for investors are regulatory and competitive. Entergy Gulf States faces pending Texas rate proceedings and a settlement that remains subject to PUCT approval, with a final decision expected in May 1999. Its River Bend recovery is still on appeal, and the Texas and Arkansas legislatures are considering retail competition. The company also carries significant nuclear and stranded-cost exposure, with roughly $1.6 billion of deregulated assets potentially subject to impairment. Several large litigation matters are outstanding, including the Panda Energy suit (approximately $4.8 billion sought), a Hindusthan arbitration seeking $1.1 billion, and the Aquila FERC complaint. Management also expects the proposed Pilgrim Nuclear acquisition to close in the second quarter of 1999.
Mar 12, 1999
1997
Entergy Annual Report, Year Ended Dec 31, 1997
Entergy Corporation's 1997 annual report (Form 10-K filed March 10, 1998) combines filings for the parent and its six registrant subsidiaries: five domestic retail utilities (Entergy Arkansas, Gulf States, Louisiana, Mississippi, New Orleans), System Energy, and Entergy London, which owns London Electricity. Consolidated 1997 operating revenues rose to $9.56 billion from $7.18 billion, but net income fell to $300.9 million from $490.6 million, and earnings applicable to common stock dropped to $247.7 million, or $1.03 per share, from $1.83 in 1996. The decline was driven largely by one-time charges: a $234 million UK windfall profits tax at London Electricity, a $227 million after-tax reserve for regulatory adjustments at Entergy Gulf States tied to Texas River Bend and rate proceedings, and write-offs of radioactive waste facility deferrals. Excluding these items, management says net income would have declined about 8%, reflecting weaker domestic regulated earnings partly offset by growth in competitive businesses. The $1.07 per share... dividend was held at $1.80 per share. The company's strategic posture shifted sharply toward international and nonregulated growth. The London Electricity acquisition for about $2.1 billion (financed with $1.7 billion of non-recourse debt) was completed in February 1997, and Entergy also acquired CitiPower in Australia and built a foreign power portfolio. Entergy's ability to invest further in exempt wholesale generators and foreign utilities is now constrained under PUHCA Rule 53 (no further investment without SEC approval or higher retained earnings), a notable limitation on growth. Gulf States' pending Texas rate settlement (a $40 million annual base rate cut, $381 million reserve) and the PUCT's January 1998 vote to disallow $1.4 billion of abeyed River Bend costs are the principal regulatory overhangs. Retail competition, the Cajun settlement (which yielded a $146 million gain), and nuclear costs (including ANO 2 steam generator replacement, estimated at about $150 million) also shape the outlook. For investors, the filing presents a company in transition: a stable core utility base facing price pressure and rate cuts, funded by a higher-risk, debt-financed international portfolio. Market value of non-affiliate common equity was $7.1 billion as of February 27, 1998, and the stock traded in a $22 to $30 range during 1997.
Mar 10, 1998
1996
Entergy Annual Report, Year Ended Dec 31, 1996
Entergy Corporation's 1996 annual report (filed March 10, 1997) covers a combined 10-K for the parent and its six registrants (Entergy Arkansas, Gulf States, Louisiana, Mississippi, New Orleans, and System Energy). Consolidated 1996 operating revenues rose to $7.16 billion from $6.29 billion, but net income fell to $420 million ($1.83 per share) from $520 million ($2.28 per share). The decline was driven mainly by a $174 million after-tax write-off of River Bend rate deferrals under SFAS 121, partly offset by a reversal of a Cajun-River Bend litigation accrual. Excluding these items, management says net income would have risen about 17%, reflecting lower O&M expense from restructuring and efficiency programs. Return on average common equity fell to 6.41% from 8.11%. The filing marks a strategic pivot toward non-utility growth. Entergy closed the $1.2 billion CitiPower acquisition (Australian electric distribution) in January 1996, agreed in February 1997 to acquire control of London Electricity plc for $2.1 billion, and built out telecom/security monitoring operations. Entergy's net investment in non-domestic-utility businesses was $812 million at year-end, and these ventures reduced 1996 consolidated net income by about $25.4 million. Much of the acquisition debt is non-recourse to the parent. The key investor risks are the River Bend litigation and the regulatory transition to competition. Texas and Louisiana regulators are still deciding how much of about $467 million of River Bend plant cost can be recovered; an adverse outcome could mean up to $278 million in additional after-tax write-offs and up to $204 million in refunds. Entergy's common dividend was held at $1.80 per share, and Entergy Gulf States has paid no common dividend since 1994. The filing also notes pending FERC matters, a $80 million IRS deficiency assertion, and tightened competitive pressures on industrial customers.
Mar 10, 1997
1995
Entergy Annual Report, Year Ended Dec 31, 1995
Entergy Corporation's 1995 combined Form 10-K (filed March 11, 1996, covering Entergy and its five operating utilities plus System Energy) shows a holding company in transition. Consolidated 1995 net income rose to $520.0 million ($2.28 per share) from $341.8 million ($1.49) in 1994, which was depressed by a $68.2 million FERC settlement charge and other write-offs. Operating revenues grew 5% to $6.27 billion, driven by higher retail sales from warmer weather and a $120.5 million System Energy FERC-related revenue item. Return on average common equity recovered to 8.11% from 5.31%, though that remains modest. Dividends were held at $1.80 per share. The filing's central investor concern is GSU's River Bend exposure. The company carries about $1.4 billion of abeyed River Bend plant costs, with a potential net-of-tax write-off of up to $289 million if the Texas PUCT rules adversely, plus a required 1996 SFAS 121 write-off of $169 million in Texas deferrals. Entergy also faces a Cajun Electric bankruptcy that threatens GSU's River Bend co-ownership economics, and a $4.8 billion Panda Energy lawsuit that management calls without merit. Dividend capacity from subsidiaries is also constrained by these matters, with GSU paying no dividends to the parent in 1995. Entergy is simultaneously expanding into nonregulated and international businesses, including the $1.2 billion CitiPower acquisition in Australia (closed January 1996, $294 million equity), Argentine and Peruvian power investments, and planned telecommunications and power marketing ventures. Management acknowledges these investments reduced 1995 net income by about $64.8 million and are unlikely to help near-term earnings. The company's competitive exposure, including retail wheeling studies and industrial cogeneration threats, is also flagged as a growing challenge to the regulated franchise.
Mar 11, 1996
1994-A
Entergy Annual Report (Amendment), Year Ended Dec 31, 1994
This document is Amendment No. 1 to the combined Form 10-K for fiscal year ended December 31, 1994, filed April 21, 1995, by Entergy Corporation and its utility subsidiaries: Arkansas Power & Light, Gulf States Utilities, Louisiana Power & Light, Mississippi Power & Light, New Orleans Public Service, and System Energy Resources. Its stated purpose is solely to add financial data schedules that were inadvertently omitted from the original filing. The excerpt provided contains only the cover page, the registrant list with commission file and IRS numbers, the amendment explanation, and the signature block. Because the excerpt contains no income statement, balance sheet, cash flow, operating metrics, regulatory developments, or risk discussion, it cannot support an analysis of Entergy's 1994 financial performance, earnings, leverage, dividend, or outlook. Any such conclusions would require the original 10-K and the financial data schedules this amendment adds. Investors should obtain the full original filing and the attached schedules before drawing conclusions about the company's financial condition. The main investor-relevant takeaway is procedural: the amendment corrects a filing omission rather than disclosing new financial information, and it is signed by Lee W. Randall, Vice President and Chief Accounting Officer, on the filing date.
Apr 21, 1995
1994
Entergy Annual Report, Year Ended Dec 31, 1994
Entergy Corporation's 1994 combined Form 10-K shows a company whose core regulated utility operations remain solid but whose 1994 earnings were severely depressed by a series of one-time charges. Consolidated net income fell to $341.8 million (EPS $1.49) from $551.9 million (EPS $3.16 including the 1993 accounting change), and return on average common equity dropped to 5.31% from 12.58%. The decline was driven primarily by the FERC settlement on System Energy's income tax allocation (about $68.2 million net reduction), a $57 million PUCT-ordered rate refund at GSU, NOPSI rate reductions and credits, Merger-related costs, and restructuring charges. Consolidated operating revenues rose to $5.96 billion from $4.49 billion, largely because GSU was consolidated for the full year following the December 31, 1993 Merger, so year-over-year comparisons are distorted by the acquisition. The most significant investor risk lies in GSU, the former Gulf States Utilities subsidiary. GSU reported a 1994 net loss of $82.8 million, and roughly $685 million of River Bend plant costs were not being recovered through rates at year-end. Management estimates a potential net-of-tax write-off of up to $293 million if the PUCT rules adversely on abeyed and disallowed River Bend costs, and the auditors (Coopers & Lybrand) flagged the uncertainty explicitly in their report. Additional exposure comes from the Cajun Electric Power Cooperative's co-ownership dispute over River Bend, including Cajun's Chapter 11 filing in December 1994. The filing warns that adverse outcomes could impair GSU's ability to continue paying dividends and could force GSU into bankruptcy if it lost the litigation and faced substantial payments. System Energy also carries covenant risk, with a waiver of its fixed charge coverage covenant running only until November 30, 1995. Offsetting these concerns, Entergy generated $1.54 billion in operating cash flow in 1994 and continues to pay a $1.80 per share dividend. The company also has ongoing nonregulated investments (roughly $150 million per year authorized), which reduced 1994 net income by about $31.7 million and are not expected to contribute positively to near-term earnings. Management expects the 1995-1997 construction program of about $1.7 billion to be funded internally, and it has requested SEC approval for a $300 million bank line of credit for share repurchases and investments. Investors should weigh the strong cash generation and regulated franchise against the large, unresolved River Bend and Cajun exposures and the sharp earnings reset.
Mar 27, 1995