Cheniere Energy, Inc. — FY2023 Form 10-K
Reporting period: Fiscal year ended December 31, 2023. This is an annual filing; it does not provide a standalone fourth-quarter financial summary. Cheniere operates LNG export facilities at Sabine Pass, Louisiana, and Corpus Christi, Texas. The filing reports consolidated results, including its publicly traded subsidiary CQP.
Business context
Cheniere reported approximately 45 mtpa of operational LNG production capacity at year-end: about 30 mtpa at Sabine Pass and 15 mtpa at Corpus Christi. The Corpus Christi Stage 3 expansion—seven midscale trains expected to add more than 10 mtpa—was 51.4% complete at December 31, 2023. Cheniere said approximately 95% of anticipated production was contracted through the mid-2030s, with approximately 16 years of weighted-average remaining contract life, subject to the exclusions described in the filing.
Key financial metrics
| Metric | FY2023 | FY2022 |
|---|---|---|
| Total revenue | $20.394 billion | $33.428 billion |
| Income from operations | $15.489 billion | $4.559 billion |
| Net income attributable to common stockholders | $9.881 billion | $1.428 billion |
| Diluted earnings per share | $40.72 | $5.64 |
| Net cash provided by operating activities | $8.418 billion | $10.523 billion |
| Net cash used in investing activities | $2.202 billion | $1.844 billion |
| Net cash used in financing activities | $4.180 billion | $8.014 billion |
| Cash and cash equivalents at year-end | $4.066 billion | $1.353 billion |
| Restricted cash at year-end | $459 million | $1.134 billion |
| Total debt principal at year-end | $23.9 billion | $25.1 billion |
Reported operating income and net income rose sharply, but earnings were substantially affected by derivative fair-value movements. Cheniere reported a $7.0 billion gain in 2023 versus a $5.0 billion loss in 2022 on changes in fair value of IPM agreements; much of the change was non-cash. LNG revenue fell 38.5%, while volumes recognized increased to 2,318 TBtu from 2,288 TBtu. The filing does not present a single normalized earnings or operating-margin measure that removes these effects.
Year-end available credit commitments were $7.575 billion, bringing reported total liquidity, including cash and restricted cash, to $12.1 billion. Cash and credit availability are not fully interchangeable: some cash is restricted, and subsidiaries have independent capital structures and limits on distributions. Senior notes had a 4.73% weighted-average contractual interest rate. Cash paid for interest, net of capitalized amounts, was $1.032 billion.
Material changes versus FY2022
- Revenue declined $13.0 billion, primarily reflecting lower Henry Hub-indexed LNG prices, lower marketing revenues as international prices and short-term sales volumes declined, and lower regasification revenue following the prior-year recognition of a Chevron termination fee.
- Operating cash flow decreased $2.1 billion, mainly due to lower LNG sale receipts, partly offset by reduced feed-gas cash outflows.
- Derivative results improved significantly: derivative fair-value changes and settlements contributed a favorable year-over-year variance of $14.4 billion before tax and non-controlling interests. Lower LNG margins, higher taxes and increased income attributable to non-controlling interests partly offset this benefit.
- Cheniere prepaid $1.2 billion of consolidated debt, issued $1.4 billion of CQP notes and used the proceeds, with cash on hand, to redeem SPL notes. It repurchased approximately 9.5 million shares for $1.5 billion and paid $1.62 per share in dividends.
- Restricted cash declined by $675 million, while unrestricted cash increased by $2.713 billion. Total stockholders’ equity increased to $9.020 billion from a $171 million deficit.
Outlook, commentary, risks and contingencies
- Projects and contracting: Management described continued LNG demand and long-term contracting as supportive of growth, but gave no consolidated earnings or revenue guidance in the supplied filing text. Cheniere expected a similar level of capital expenditures in the upcoming year as Corpus Christi Stage 3 construction progressed. The Stage 3 EPC contract was approximately $5.7 billion, with about $2.9 billion of remaining obligations at year-end; stated substantial-completion timing ranged from the second/third quarter of 2025 to the second half of 2026.
- Expansion proposals and approvals: CCL Midscale Trains 8 & 9 (approximately 3 mtpa) was under FERC review and had FTA export authorization; non-FTA export approval remained pending. The SPL Expansion Project, with potential capacity of up to approximately 20 mtpa including estimated debottlenecking, was in FERC pre-filing. Both projects require acceptable commercial and financing arrangements before a positive FID. The January 2024 federal pause on pending non-FTA export decisions was not expected by management to materially affect the business.
- Cash commitments and financing: Estimated consideration under executed SPAs was $299.3 billion through the contracts’ terms, including variable fees based on assumptions about deliveries and future prices. Separately, the filing reported $69.3 billion of estimated payments under specified executed operating and capital contracts, and $30.3 billion of scheduled debt principal and interest payments. These estimates are not equivalent to fixed, immediately payable liabilities. Debt agreements, project funding needs and subsidiary distribution restrictions may constrain access to cash.
- Market and operating risks: LNG and natural-gas prices, demand, shipping availability and pipeline supply can be volatile. Other risks include severe weather, construction delays or cost increases, contractor performance, customer default, cyberattacks, and changes in regulation or environmental requirements. The filing identifies potential cash-tax volatility from the corporate alternative minimum tax (CAMT); Cheniere expected to be an applicable corporation beginning in 2024.
- Derivatives and taxes: Level 3 liquefaction-supply derivatives were a net liability of $2.178 billion at year-end, down from $9.924 billion. Their valuations use significant unobservable assumptions, and management said material changes in estimated fair value could occur. The effective tax rate was 17.3%, versus 14.8%; federal and state NOL carryforwards were approximately $4.3 billion and $2.2 billion, respectively, but their use may be limited by tax rules or an ownership change.
- Legal and audit matters: Subsidiaries were discussing an LDEQ compliance order concerning formaldehyde standards at Sabine Pass. Test results filed in December 2023 indicated all 44 turbines met the relevant standard for the initial compliance period; management did not expect any ultimate penalty to have a material financial impact. KPMG issued unqualified opinions on the financial statements and internal control over financial reporting; the critical audit matter concerned valuation of Level 3 liquefaction-supply derivatives.
Important facts for investors to verify
- How much of FY2023 reported earnings and future reported results reflects derivative fair-value changes rather than realized operating cash flows; review the Level 3 valuation assumptions and sensitivity disclosures.
- Current Corpus Christi Stage 3 cost, schedule, remaining funding needs and construction progress, including any changes from the year-end estimates.
- Whether expected operating cash flows, debt reduction and shareholder returns remain consistent with the capital allocation plan, considering restricted cash, subsidiary covenants and CQP distributions.
- The status of non-FTA export approvals and FERC permits for proposed expansions, and whether commercial contracts and financing support a positive FID.
- The potential cash-tax impact and timing of CAMT, NOL utilization and tax depreciation as projects enter service.
- Developments in the LDEQ matter and any changes to the stated assessment of its potential financial impact.