ENTERGY CORP quarterly report, Q2 FY2022

Business context and reporting period

Entergy Corporation is an electric and natural-gas utility serving parts of Arkansas, Louisiana, Mississippi and Texas, with a legacy wholesale generation segment. This combined, unaudited Form 10-Q covers the quarter and six months ended June 30, 2022; figures below are consolidated Entergy Corporation results unless noted. The filing also reports separately for its utility subsidiaries and System Energy Resources.

Financial results and liquidity

Revenue rose 20% year over year in Q2, largely on higher utility sales, fuel/rider revenues and usage; utility retail electricity usage increased 8%. Wholesale Commodities revenue fell to $89 million from $149 million as plants shut down and realized prices declined. Approximate operating margin was 2.4% in Q2 versus 6.0% a year earlier, and 10.3% for the first half versus 11.9%. Q2 net margin attributable to Entergy was approximately 4.7%; the prior-year comparison was negative.

Q2 income before tax was a loss of $196 million, while consolidated net income was $164 million, reflecting a $360 million income-tax benefit. The tax benefit and exceptional regulatory charges make reported earnings and effective tax rates unusually volatile; the reported Q2 effective tax rate was 183.8%.

At June 30, cash and cash equivalents were $580 million, current assets $4.80 billion and current liabilities $5.54 billion (negative working capital of about $746 million). Long-term debt was $24.54 billion and current maturities $909 million; notes payable and commercial paper were $1.40 billion. Entergy’s reported debt-to-capital ratio was 69.1%, or 68.8% excluding securitization bonds; net debt-to-net capital excluding those bonds was 68.4%. The $3.5 billion parent credit facility had $3.347 billion available, and Entergy was in compliance with its debt covenant. First-half investing cash use was $3.224 billion and financing cash inflow was $2.545 billion.

Material changes and unusual items

• System Energy recorded a $551 million regulatory charge ($413 million after tax) tied to a partial settlement and offer of settlement in FERC proceedings. This was the principal reason operating income declined and System Energy reported a $380 million Q2 net loss.
• Louisiana storm-cost securitization produced a $283 million net reduction in Entergy’s income-tax expense, partly offset by a $224 million regulatory charge ($165 million after tax) for customer credits.
• Entergy sold the Palisades plant in June, recording a $166 million gain ($130 million after tax), and completed its strategy to exit merchant nuclear generation. In 2021, the Indian Point sale had resulted in a $340 million charge.
• Utility customer usage and rate changes supported results, but higher fuel and purchased-power costs, interest expense and storm spending affected cash flow and expenses. Decommissioning trust assets also fell amid market weakness; qualified pension plan assets declined 18% to $5.4 billion at June 30.

Outlook, risks and contingencies

Entergy planned capital investments of $3.875 billion in 2022, $4.090 billion in 2023 and $5.400 billion in 2024, primarily for utility generation, transmission, distribution, resilience and reliability. No consolidated earnings-per-share guidance is provided in the supplied filing text. The Board declared a $1.01-per-share quarterly dividend in July 2022.

Key uncertainties include pending FERC proceedings and potential refunds. The MPSC settlement provides for a $235 million refund, contingent on FERC approval; if other retail regulators join, total refunds could reach $588.25 million. Other FERC claims and proposed refunds remain disputed and unresolved. Entergy Louisiana also sought regulatory recovery of approximately $2.64 billion of storm restoration costs, with a hearing scheduled for December 2022; Entergy New Orleans’s storm-cost recovery requests were pending.

Management cited project execution, inflation, labor and supply constraints, solar-panel tariff investigations, regulatory approvals and cost recovery as risks to the capital plan. The proposed Orange County power station’s updated fixed-price option was $1.58 billion, above its initial $1.2 billion estimated cost; approval and permitting remained pending. The filing also discusses regulatory, nuclear safety, environmental, extreme-weather, commodity-price, interest-rate and financing risks. Management stated that disclosure controls were effective and that no material change in internal control over financial reporting occurred during the quarter.

Investor verification checklist

• Confirm FERC disposition of the System Energy settlement, the scope of any participating regulators and ultimate refund exposure.
• Assess how much Q2 and first-half earnings depended on the storm securitization tax benefit, customer-credit charge and Palisades sale gain.
• Track fuel-cost recovery, storm-cost prudence reviews and the timing and amount of customer collections.
• Review capital spending, project approvals and revised costs, especially Orange County and solar projects exposed to tariff and supply-chain issues.
• Monitor debt, cash generation, pension-asset performance and funding needs against Entergy’s elevated reported leverage.