Business context and reporting period
Entergy Texas, Inc. (ETI) filed this Form 10-K for the fiscal year ended December 31, 2023; it is an annual report, not a standalone fourth-quarter report. ETI is a regulated electric utility serving approximately 512,000 customers in eastern Texas. It reported 3,234 MW of owned and leased generating capability. Its rates and cost recovery are principally overseen by the Public Utility Commission of Texas (PUCT), with wholesale and transmission matters subject to FERC and MISO rules.
Figures below are for ETI and its subsidiaries, not Entergy Corporation consolidated, and dollar amounts are in millions unless stated otherwise.
Financial performance and liquidity
| Metric | 2023 | 2022 | Change / context |
|---|---|---|---|
| Operating revenue | $2,028.6 | $2,288.9 | Down $260.3 (about 11%) |
| Operating income | $429.7 | $433.8 | Down $4.1 |
| Net income | $291.3 | $303.3 | Down $12.1 (about 4%) |
| Operating cash flow | $641.7 | $409.4 | Up $232.3 |
| Net cash used in investing | ($1,125.9) | ($764.1) | Higher investment outflow, principally capital spending |
| Net cash from financing | $502.7 | $358.1 | Higher, including debt issuance and a $150 million parent contribution |
| Cash and cash equivalents at year-end | $22.0 | $3.5 | Increased, but remains modest relative to planned investment |
| Total assets | $8,056.6 | $7,044.0 | Increased by about $1,012.6 |
Operating cash flow improved mainly from lower fuel costs and the timing of fuel and purchased-power cost recovery, partially offset by lower customer collections and higher interest and tax payments. Operating cash flow did not cover 2023 construction expenditures of $946.5 million. Retail electric sales were 21,146 GWh, down 1% from 21,380 GWh in 2022.
Long-term debt was $3,225.1 million at year-end, including $260.8 million of ETI securitization bonds. The reported debt-to-capital ratio was 50.9%; excluding non-recourse securitization bonds it was 48.8%, and net debt-to-net capital excluding those bonds was 48.6%. ETI had no borrowings under its $150 million revolving credit facility; $1.1 million of letters of credit were outstanding against it. Separately, $76.5 million of letters of credit were issued under its $80 million uncommitted facility supporting MISO and other obligations.
Deferred fuel costs stood at $139.0 million at December 31, 2023, compared with $258.1 million a year earlier, subject to regulatory review and recovery mechanisms. No standalone gross-profit or EBITDA measure is presented in the supplied filing text.
Material changes versus the prior comparable period
- Revenue fell primarily because fuel, rider, and other pass-through revenues declined $331.8 million and system-restoration carrying-cost revenues declined $21.7 million. These amounts generally have offsetting expenses and do not materially affect net income.
- Higher retail electric prices added $58.2 million to the year-over-year revenue comparison, reflecting the 2023 base-rate increase and realignment of certain cost-recovery riders into base rates. Volume/weather added $8.4 million.
- The 2022 comparison included $26.6 million of revenue reductions from returning unprotected excess deferred taxes to customers; there was no such return in 2023.
- Net income declined despite higher retail pricing, mainly reflecting increased depreciation and amortization, higher taxes other than income taxes, and higher interest expense. The 2023 effective income tax rate was 17.8%, versus 14.3% in 2022.
- Capital spending rose, including investment in the Orange County Advanced Power Station. ETI’s utility plant net of accumulated depreciation increased to $6,425.1 million from $5,613.2 million.
Outlook, management commentary, risks and unusual items
- Capital plan: ETI plans construction and capital investment of $1.29 billion in 2024, $1.63 billion in 2025, and $1.98 billion in 2026. The filing does not provide a clear ETI-specific earnings or revenue forecast.
- Orange County Advanced Power Station: The 1,215 MW combined-cycle project is under construction and expected in service by mid-2026, subject to permits. A fixed-price option was estimated at approximately $1.55 billion; the PUCT approved the project without a cost-recovery cap and without the proposed hydrogen co-firing investment, subject to conditions including weatherization and customer receipt of certain contractual benefits.
- Rates and fuel recovery: The 2022 base-rate case settlement produced a $54 million annual base-rate increase, implemented on an interim basis in June 2023 and approved in August 2023. A roughly $24.1 million relate-back surcharge was approved for collection over six months beginning January 2024, with related depreciation adjustments expected to offset the net-income effect. A separate electric-vehicle charging infrastructure proceeding remained pending, with a hearing scheduled for April 2024. Fuel recovery balances and related costs remain subject to regulatory review.
- Storm securitization: ETI issued $290.85 million of non-recourse system-restoration bonds in 2022 for storm costs. Customer system-restoration charges service the bonds and may remain in effect for up to 15 years. The outstanding ETI securitization balance was $260.8 million at year-end 2023.
- Execution and regulatory risks: The filing highlights uncertainty around timely recovery of utility costs, fuel and purchased-power prices, storm restoration costs, MISO capacity accreditation and transmission costs, and the timing and cost of generation and grid projects. Severe weather, supply-chain constraints, inflation, higher interest rates, environmental requirements, and cyber or physical security events may affect operations, liquidity, or investment plans.
- Audit and controls: Deloitte issued an unqualified opinion on ETI’s financial statements. Management concluded internal control over financial reporting was effective; ETI is a non-accelerated filer and did not receive a separate auditor attestation on internal controls.
Most important facts for investors to verify
- Whether the Orange County project remains on schedule for mid-2026 and within its expected cost, and how regulators treat any cost changes.
- How quickly ETI recovers its $139 million year-end deferred fuel balance and any new fuel or storm costs through customer rates.
- Whether planned capital spending can be financed while preserving credit metrics and liquidity, given modest year-end cash and substantial investment needs.
- The outcome of the pending electric-vehicle infrastructure proceeding and the implementation of the 2023 base-rate settlement and 2024 relate-back surcharge.
- Future MISO resource-adequacy and transmission rules, and their potential effect on capacity procurement, costs, and reliability.