Imperial Oil Limited — 2023 Form 10-K
Reporting period: Fiscal year ended December 31, 2023. The filing is an annual report, not a standalone fourth-quarter report. Amounts are Canadian dollars unless otherwise stated; financial statements use U.S. GAAP.
Business context
Imperial is an integrated Canadian energy company with Upstream, Downstream and Chemical operations. ExxonMobil owns approximately 69.6% of its common shares. Its businesses span oil sands production, refining and marketing, and petrochemicals, with investments and goals related to lower-emission technologies and fuels.
Financial and operating performance
| Metric | 2023 | 2022 |
|---|---|---|
| Revenue | $50.702 billion | $59.413 billion |
| Net income | $4.889 billion | $7.340 billion |
| Diluted earnings per share | $8.49 | $11.44 |
| Cash flow from operating activities | $3.734 billion | $10.482 billion |
| Free cash flow (non-GAAP) | $2.040 billion | Not stated in the supplied comparison |
| Cash and cash equivalents at year-end | $864 million | $3.749 billion |
| Total debt at year-end | $4.132 billion | $4.155 billion |
| Debt-to-capital ratio | 16% | 16% |
| Capital and exploration expenditures | $1.778 billion | $1.490 billion |
Net income by segment was $2.512 billion for Upstream, $2.301 billion for Downstream and $164 million for Chemical; Corporate and other was a loss of $88 million. Consolidated return on average capital employed was 18.7%, versus 27.6% in 2022. The filing does not provide a single consolidated operating-margin figure in the supplied text.
- Cash and liquidity: Operating cash flow fell substantially, primarily reflecting a $2.1 billion income-tax catch-up payment, unfavorable working-capital effects, lower Upstream realizations and lower Downstream margins. Operating cash flow excluding working capital, a non-GAAP measure, was $6.435 billion. Imperial had $500 million of undrawn committed credit facilities.
- Debt: Long-term debt was $4.011 billion, including a $3.447 billion variable-rate loan from an ExxonMobil affiliate; total debt also includes short-term borrowings and finance leases. Debt-related interest incurred was $203 million, and the weighted-average debt interest rate was 4.9%, both higher than in 2022.
- Shareholder returns: Imperial paid $1.103 billion in dividends and repurchased $3.800 billion of shares in 2023. Declared dividends were $1.94 per share, up from $1.46. The $1.5 billion substantial issuer bid bought back 19.1 million shares at $78.50 each.
- Production and costs: Gross Upstream production averaged 413,000 oil-equivalent barrels per day, compared with 416,000 in 2022; net production rose to 360,000 from 349,000. Kearl production improved, while Cold Lake volumes declined. Total oil-equivalent unit production costs fell to $38.51 per barrel from $44.02.
- Prices and refining: Average bitumen realization fell to $67.42 per barrel from $84.67 and synthetic crude oil realization to $105.57 from $125.46. Refinery throughput was 407,000 barrels per day at 94% utilization, versus 418,000 and 98%; planned turnarounds reduced 2023 throughput. Refining margins remained strong but were below 2022 levels.
Material changes versus 2022
- Revenue declined approximately 15% and net income approximately 33%, as commodity realizations and Downstream margins eased from elevated 2022 levels.
- Operating cash flow dropped by $6.748 billion, with the $2.1 billion tax catch-up payment and working-capital impacts important contributors.
- Upstream results were also affected by lower volumes, including Cold Lake steam-cycle timing and the absence of production from assets sold in the XTO Energy Canada transaction. Kearl’s improved reliability and productivity partly offset these pressures.
- Downstream earnings were reduced by weaker market conditions and about $340 million of higher turnaround impacts. Chemical earnings declined to $164 million from $204 million, with polyethylene oversupply and planned maintenance affecting results and sales volumes.
- Capital and exploration expenditures rose by $288 million. Cash declined, while total debt was broadly stable; Imperial continued substantial shareholder distributions.
Outlook, risks and contingencies
- Guidance: 2024 capital and exploration expenditures are expected to be approximately $1.7 billion, including $686 million of firm commitments for 2024. The filing does not provide clear numerical guidance for 2024 earnings or production.
- Projects: Strathcona’s renewable diesel facility is under construction, with production expected to begin in 2025. Cold Lake’s Leming SAGD project is planned to start up in 2025. Grand Rapids Phase 1 began steam injection in December 2023, with production expected to ramp up in 2024. The Aspen project remains on hold pending evaluation of market uncertainty; its EBRT field pilot is being developed for planned startup by 2027.
- Climate and environmental matters: Imperial targets a 30% reduction in operated oil sands Scope 1 and 2 emissions intensity by 2030 against 2016 levels and company-wide net-zero Scope 1 and 2 emissions from operated assets by 2050, contingent on technology development and policy support. The company reported approximately $1.7 billion in 2023 environmental capital and operating expenditures and expects approximately $1.9 billion in 2024.
- Operational and regulatory risks: Commodity-price and refining-margin volatility, Western Canadian crude differentials and transportation constraints, inflation, currency movements, project execution, environmental regulation and carbon costs could affect results. Imperial described off-lease seepage at Kearl and its monitoring, interception, collection and community-engagement response; the board oversaw the response to a Kearl environmental protection order.
- Policy and litigation: The Supreme Court of Canada ruled the federal Impact Assessment Act unconstitutional in part in October 2023; amendments and their effects remain uncertain. Management stated that pending lawsuits and performance guarantees were not expected to have a material adverse effect. The filing notes no material fixed-quantity oil or gas delivery commitments.
- Controls and audit: Management and PwC concluded that internal control over financial reporting was effective at year-end. PwC identified proved developed oil and gas reserve estimates’ effect on Upstream property, plant and equipment and depreciation as a critical audit matter.
Important facts for investors to verify
- Whether the sharp decline in reported operating cash flow reverses, particularly after the tax catch-up payment and working-capital changes.
- Whether commodity realizations, refining margins and segment earnings stabilize or continue to weaken, and how much the integrated business offsets price and differential movements.
- Execution, cost and timing of the Strathcona renewable diesel, Leming and Grand Rapids projects, including permitting, feedstock availability and expected returns.
- Developments and potential financial or operating consequences related to Kearl seepage, the environmental protection order, tailings management and regulatory requirements.
- Capital allocation after the 2023 buybacks: the company says it will evaluate renewal of its share-purchase program in June 2024; confirm subsequent decisions and the effect of Canadian taxes on share repurchases.
- Terms and refinancing or repayment plans for the $3.447 billion ExxonMobil-affiliate loan, whose agreement is effective until June 30, 2025 and may be cancellable with required notice.
- Reserve assumptions and revisions: the standardized measure of discounted future cash flows fell to $14.002 billion from $25.554 billion, a measure the company cautions is sensitive to prescribed price assumptions and is not its estimate of asset value.