Business context and reporting period
Constellation Energy Corporation (CEG) filed this unaudited Form 10-Q for the quarter and nine months ended September 30, 2022. CEG is a clean-energy producer and energy-products supplier, with generation primarily from nuclear, wind, solar, natural gas and hydroelectric assets. Exelon completed the spin-off on February 1, 2022; the filing presents CEG Parent and Constellation Energy Generation, LLC financial information. Prior-period comparisons include pre-separation affiliate activity, so they are not fully like-for-like.
Key financial metrics
Amounts are in millions, except per-share data. CEG Parent consolidated results:
| Metric | Q3 2022 | Q3 2021 | Nine months 2022 | Nine months 2021 |
|---|---|---|---|---|
| Operating revenue | $6,051 | $4,406 | $17,107 | $14,117 |
| Operating income (loss) | $(41) | $1,006 | $667 | $(344) |
| Net income (loss) attributable to common shareholders | $(188) | $607 | $(194) | $(247) |
| Diluted EPS | $(0.57) | Not applicable in filing | $(0.59) | Not applicable in filing |
| Adjusted EBITDA (non-GAAP) | $592 | $967 | $2,062 | $1,158 |
| Revenue less purchased power and fuel expense (RNF; non-GAAP segment measure) | $1,356 | $2,860 | $5,353 | $6,014 |
Revenue rose 37.3% in the quarter and 21.2% year to date, but purchased power and fuel costs rose faster. Q3 operating margin was approximately negative 0.7%, versus positive 22.8% a year earlier; nine-month operating margin was approximately 3.9%, versus negative 2.4%. These are calculated from reported operating income and revenue. RNF and Adjusted EBITDA are non-GAAP measures and should be considered alongside GAAP results.
Operating cash flow was $69 million for CEG Parent for the first nine months, down from $974 million. Capital expenditures were $1.09 billion. Investing cash flow was $1.87 billion provided, while financing used $1.21 billion. The filing attributes operating cash flow movements in part to collateral, working capital and other asset and liability changes.
At September 30, cash and restricted cash totaled $1.303 billion. Short-term borrowings were $693 million; long-term debt, including amounts due within one year, totaled approximately $4.661 billion, for total borrowings of approximately $5.354 billion. CEG reported $5.8 billion of aggregate bank commitments and $2.293 billion of available capacity, alongside $493 million of commercial paper outstanding. Management said liquidity was sufficient for expected needs. Debt covenants were reported in compliance.
Material changes versus the prior comparable period
- Q3 common-shareholder results swung to a $188 million loss from $607 million of income. Management cited unfavorable derivative mark-to-market activity, NDT investment results, labor and materials costs, lower capacity revenues and portfolio optimization.
- For the first nine months, the common-shareholder loss narrowed by $53 million. Prior-year Texas winter-storm impacts, asset impairments and accelerated retirement-related depreciation were absent, while higher realized energy prices helped; these benefits were partly offset by unfavorable mark-to-market and NDT results, lower capacity revenues, higher costs and outages.
- Q3 derivative commodity mark-to-market losses were $520 million, compared with gains of $755 million a year earlier. Nine-month losses were $567 million, compared with gains of $1.248 billion. Such valuation changes can make reported earnings volatile.
- Revenue growth reflected higher energy and natural-gas prices, while purchased power and fuel expense rose substantially. Q3 RNF declined to $1.356 billion from $2.860 billion.
- The nuclear fleet capacity factor was 96.4% in Q3 and 94.5% year to date, modestly below the respective prior-year reported levels of 97.7% and 95.3%.
Outlook, commentary, risks and unusual items
- No specific near-term earnings or revenue guidance is provided in the supplied filing text. Management expects that federal Inflation Reduction Act credits, including a nuclear production tax credit of up to $15/MWh from 2024 through 2032, will support continued operation of many nuclear assets through the credit period. The company also plans license-extension applications for eligible units.
- Management said it expects cash flows, credit-market access and facilities to meet operating, financing and capital needs. A downgrade below investment grade was estimated to require about $3.1 billion of incremental collateral; reported available capacity and cash were approximately $2.2 billion and $1.2 billion, respectively.
- Market exposure remains significant despite hedging: expected generation for the Mid-Atlantic, Midwest, New York and ERCOT segments was 97%–100% hedged for 2022 and 92%–95% for 2023. The filing describes a sensitivity of about $32 million lower pretax income in 2023 for a $2.50/MWh decrease in annual average energy prices, based on September 30 market conditions and hedge positions.
- Management is monitoring Russia-Ukraine-related nuclear-fuel supply risks. About 55% of uranium concentrate requirements for 2022–2026 were supplied by three suppliers; no delivery or non-performance issues had been experienced as of the filing.
- Texas winter-storm litigation includes numerous lawsuits; CEG disputes liability and recorded no loss contingency because losses were not considered probable or reasonably estimable. Other exposures include environmental remediation, with $122 million of accrued environmental liabilities, and ERCOT market-participant defaults, for which the company recorded an estimated $16 million obligation.
- Mystic cost-of-service proceedings and remanded issues could have a material financial impact over the agreement term; outcomes were not predictable. Peach Bottom’s subsequent license renewals remained in effect, but expiration dates had reverted to 2033 and 2034 pending further environmental review; management expected restoration to 2053 and 2054.
- Unusual accounting and separation items include a $226 million benefit in operating and maintenance expense from 2022 nuclear decommissioning obligation updates and a $50 million reversal of a prior merger-commitment loss contingency. NDT funds declined from $16.064 billion at year-end 2021 to $13.546 billion at September 30, 2022, reflecting market and investment activity.
Important facts for investors to verify
- Review the reconciliation and drivers of Adjusted EBITDA and RNF, and distinguish recurring operating performance from derivative mark-to-market and NDT valuation effects.
- Assess liquidity under stress, especially collateral calls after a credit downgrade, the availability and terms of credit facilities, and commercial-paper refinancing needs.
- Track nuclear policy support, unit license extensions and operating performance, including resolution of Peach Bottom and Mystic proceedings.
- Monitor legal and environmental contingencies, including Texas winter-storm cases, ERCOT defaults and remediation liabilities; outcomes and potential additional costs remain uncertain.
- Account for the February 2022 separation when comparing periods, including changed affiliate relationships, pension accounting, separation expenses and TSA arrangements.