Imperial announces second quarter 2024 financial and operating results
- Quarterly net income of $1,133 million
- Cash flows from operating activities of $1,629 million and cash flows from operating activities excluding working capital1 of $1,508 million
- Upstream production of 404,000 gross oil-equivalent barrels per day, highest second quarter in over 30 years when adjusted for divestment of XTO Energy Canada
- Matched highest-ever second quarter production at Kearl of 255,000 total gross oil-equivalent barrels per day (181,000 barrels Imperial’s share)
- Strong performance at Cold Lake with production of 147,000 barrels per day and first oil at Grand Rapids
- Achieved refinery capacity utilization of 89 percent while successfully completing turnarounds at Strathcona and Sarnia
- Renewed annual normal course issuer bid to repurchase up to 5 percent of outstanding common shares; plan to accelerate purchases to complete the program prior to year end
- Declared quarterly dividend of 60 cents per share
CALGARY, Alberta–(BUSINESS WIRE)–Imperial (TSE: IMO) (NYSE American: IMO):
|
|
Second quarter |
Six months |
||||
|
millions of Canadian dollars, unless noted |
2024 |
2023 |
∆ |
2024 |
2023 |
∆ |
|
Net income (loss) (U.S. GAAP) |
1,133 |
675 |
+458 |
2,328 |
1,923 |
+405 |
|
Net income (loss) per common share, assuming dilution (dollars) |
2.11 |
1.15 |
+0.96 |
4.34 |
3.29 |
+1.05 |
|
Capital and exploration expenditures |
462 |
493 |
(31) |
958 |
922 |
+36 |
Imperial reported estimated net income in the second quarter of $1,133 million, compared to net income of $1,195 million in the first quarter of 2024, reflecting lower refinery margins, and significant turnaround activity partly offset by stronger upstream realizations. Quarterly cash flows from operating activities were $1,629 million, up from $1,076 million generated in the first quarter of 2024. Excluding the impact of working capital1, cash flows from operating activities were $1,508 million, compared to $1,521 million in the first quarter of 2024.
“Imperial’s second quarter results are underpinned by strong operations across our businesses, including the safe and successful completion of several major turnarounds,” said Brad Corson, chairman, president and chief executive officer. “With the majority of upstream turnaround activity behind us, we are well positioned for strong production in the second half of the year.”
Upstream production in the second quarter averaged 404,000 gross oil-equivalent barrels per day, the highest second quarter production in over 30 years when adjusting for the divestment of XTO Energy Canada. At Kearl, quarterly total gross production averaged 255,000 barrels per day (181,000 barrels Imperial’s share), matching the asset’s second quarter production record and achieving record first half production. Kearl also successfully completed its annual turnaround in record time during the quarter. At Cold Lake, quarterly gross production averaged 147,000 barrels per day, including about 3,000 barrels per day from Grand Rapids Phase 1 (GRP1). The production at GRP1 continues to ramp up, producing about 8,000 gross barrels per day in June, and is expected to achieve 15,000 gross barrels per day at full production rates. This project also lowers unit cash cost1 and reduces greenhouse gas intensity compared to legacy processes. During the quarter, Syncrude completed its annual coker turnaround, with the company’s share of quarterly production averaging 66,000 gross barrels per day.
“Grand Rapids Phase 1 is the first solvent assisted SAGD operation in the industry, highlighting Imperial’s continued focus on leveraging technology to profitably grow production while reducing greenhouse gas intensity,” said Corson.
In the Downstream, major turnarounds were successfully completed at the Strathcona and Sarnia refineries. Quarterly throughput averaged 387,000 barrels per day, with overall refinery capacity utilization of 89 percent, reflecting strong operations and high reliability, particularly at the Nanticoke refinery. Petroleum product sales averaged 470,000 barrels per day. Throughout the quarter, the company continued to advance work on Canada’s largest renewable diesel facility at its Strathcona refinery. When completed, the project is expected to have a capacity of more than one billion litres of renewable diesel annually.
Imperial returned $321 million to shareholders through dividend payments during the second quarter and has declared a third quarter dividend of 60 cents per share. In June, Imperial renewed its annual normal course issuer bid program (NCIB), allowing the repurchase of up to five percent of its outstanding shares over a 12-month period.
“Consistent with our continued commitment to return surplus cash to shareholders, I am pleased to announce our plan to accelerate our NCIB share repurchases with a target of completing the program prior to year end,” said Corson.
Second quarter highlights
- Net income of $1,133 million or $2.11 per share on a diluted basis, up from $675 million or $1.15 per share in the second quarter of 2023.
- Cash flows from operating activities of $1,629 million, up from cash flows from operating activities of $885 million in the second quarter of 2023. Cash flows from operating activities excluding working capital1 of $1,508 million, up from $1,136 million in the same period of 2023.
- Capital and exploration expenditures totaled $462 million, compared to $493 million in the second quarter of 2023.
- The company returned $321 million to shareholders in the second quarter of 2024 through dividends paid.
- Renewed share repurchase program, enabling the purchase of up to five percent of common shares outstanding, a maximum of 26,791,840 shares, during the 12-month period commencing June 29, 2024. Consistent with the company’s commitment to return surplus cash to shareholders, Imperial plans to accelerate its share purchases under the NCIB program and anticipates repurchasing all remaining allowable shares prior to the end of 2024. Purchase plans may be modified at any time without prior notice.
- Production averaged 404,000 gross oil-equivalent barrels per day, the highest second quarter production in over 30 years when adjusting for the divestment of XTO Energy Canada, up from 363,000 gross oil-equivalent barrels per day in the same period of 2023.
- Total gross bitumen production at Kearl averaged 255,000 barrels per day (181,000 barrels Imperial’s share), matching the second quarter production record and achieving record first half production. This is up from 217,000 barrels per day (154,000 barrels Imperial’s share) in the second quarter of 2023.
- Gross bitumen production at Cold Lake averaged 147,000 barrels per day, up from 132,000 barrels per day in the second quarter of 2023, primarily driven by production and steam cycle timing, and Grand Rapids Phase 1 (GRP1) production.
- Achieved first oil at Grand Rapids Phase 1, consistent with plan and continuing to ramp up production. GRP1 is the first solvent-assisted SAGD project in the industry and will lower unit cash cost1 and reduce greenhouse gas intensity compared to legacy processes. This project is expected to achieve 15,000 gross barrels per day of production at full rates.
- Commenced module fabrication on Leming SAGD redevelopment project, work on site continues to progress. The project is on track for a 2025 start up with peak production anticipated to be around 9,000 gross barrels per day.
- The company’s share of gross production from Syncrude averaged 66,000 barrels per day, consistent with 66,000 barrels per day in the second quarter of 2023. Syncrude completed its annual coker turnaround in late May.
- Refinery throughput averaged 387,000 barrels per day, compared to 388,000 barrels per day in the second quarter of 2023. Capacity utilization was 89 percent, compared to 90 percent in the second quarter of 2023. This reflects the strong operations and high reliability this quarter, including the successful turnarounds at Sarnia and Strathcona.
- Petroleum product sales were 470,000 barrels per day, compared to 475,000 barrels per day in the second quarter of 2023.
- Successfully completed proactive replacement of a section from the Winnipeg Products Pipeline, restoring pipeline fuel supply in the region.
- Continued to advance work on Canada’s largest renewable diesel facility at the Strathcona refinery, with the main reactor now installed. When completed, the project is expected to have a capacity of more than one billion litres of renewable diesel annually.
- Further developed network of renewable diesel blending and offloading distribution terminals. Completion of the Calgary terminal further expands our capability to supply lower emission fuel options to our customers.
- Chemical net income of $65 million in the quarter, compared to $71 million in the second quarter of 2023.
- Pathways Alliance continued to file regulatory applications with the Alberta Energy Regulator for the proposed carbon capture and storage project, while progressing front end engineering and design on the proposed transportation pipeline as well as drilling plans for additional evaluation wells. Completion of the project is contingent on fiscal support and regulatory approvals.
Recent business environment
In the first half of 2024, the price of crude oil remained relatively flat compared to the fourth quarter of 2023. The Canadian WTI/WCS spread continued to narrow in the second quarter, primarily due to additional pipeline capacity coming online. Refining margins fell as increasing supply more than met growing demand and geopolitical trade-flow disruptions lessened.
Operating results
Second quarter 2024 vs. second quarter 2023
|
|
Second Quarter |
|
|
millions of Canadian dollars, unless noted |
2024 |
2023 |
|
Net income (loss) (U.S. GAAP) |
1,133 |
675 |
|
Net income (loss) per common share, assuming dilution (dollars) |
2.11 |
1.15 |
Upstream
Net income (loss) factor analysis
millions of Canadian dollars
|
2023 |
Price |
Volumes |
Royalty |
Other |
2024 |
|
384 |
300 |
280 |
(180) |
15 |
799 |
Price – Average bitumen realizations increased by $14.38 per barrel, primarily driven by higher marker prices and the narrowing of the WTI/WCS spread. Synthetic crude oil realizations increased by $10.64 per barrel, generally in line with WTI.
Volumes – Higher volumes were primarily driven by higher mine fleet productivity and optimized turnaround at Kearl, production and steam cycle timing and GRP1 production at Cold Lake.
Royalty – Higher royalties were primarily driven by improved commodity prices.
Marker prices and average realizations
|
|
Second Quarter |
|
|
Canadian dollars, unless noted |
2024 |
2023 |
|
West Texas Intermediate (US$ per barrel) |
80.63 |
73.56 |
|
Western Canada Select (US$ per barrel) |
67.03 |
58.49 |
|
WTI/WCS Spread (US$ per barrel) |
13.60 |
15.07 |
|
Bitumen (per barrel) |
83.02 |
68.64 |
|
Synthetic crude oil (per barrel) |
111.56 |
100.92 |
|
Average foreign exchange rate (US$) |
0.73 |
0.74 |
Production
|
|
Second Quarter |
|
|
thousands of barrels per day |
2024 |
2023 |
|
Kearl (Imperial’s share) |
181 |
154 |
|
Cold Lake |
147 |
132 |
|
Syncrude (a) |
66 |
66 |
|
|
|
|
|
Kearl total gross production (thousands of barrels per day) |
255 |
217 |
| (a) | In the second quarter of 2024, Syncrude gross production included about 2 thousand barrels per day of bitumen and other products (2023 – 0 thousand barrels per day) that were exported to the operator’s facilities using an existing interconnect pipeline. |
Higher production at Kearl was primarily driven by higher mine fleet productivity and optimized turnaround.
Higher production at Cold Lake was primarily driven by production and steam cycle timing, and GRP1 production.
Downstream
Net income (loss) factor analysis
millions of Canadian dollars
|
2023 |
Margins |
Other |
2024 |
|
250 |
(90) |
134 |
294 |
Margins – Lower margins primarily reflect weaker market conditions.
Other – Primarily due to lower turnaround impacts of about $140 million.
Refinery utilization and petroleum product sales
|
|
Second Quarter |
|
|
thousands of barrels per day, unless noted |
2024 |
2023 |
|
Refinery throughput |
387 |
388 |
|
Refinery capacity utilization (percent) |
89 |
90 |
|
Petroleum product sales |
470 |
475 |
Refinery throughput in the second quarter of 2024 reflects the impact of turnaround activities at the Sarnia and Strathcona refineries. Refinery throughput in the second quarter of 2023 reflected the impact of turnaround activities at the Strathcona refinery.
Chemicals
Net income (loss) factor analysis
millions of Canadian dollars
|
2023 |
Margins |
Other |
2024 |
|
71 |
(10) |
4 |
65 |
Corporate and other
|
|
Second Quarter |
|
|
millions of Canadian dollars |
2024 |
2023 |
|
Net income (loss) (U.S. GAAP) |
(25) |
(30) |
Liquidity and capital resources
|
|
Second Quarter |
|
|
millions of Canadian dollars |
2024 |
2023 |
|
Cash flows from (used in): |
|
|
|
Operating activities |
1,629 |
885 |
|
Investing activities |
(456) |
(489) |
|
Financing activities |
(329) |
(263) |
|
Increase (decrease) in cash and cash equivalents |
844 |
133 |
|
|
|
|
|
Cash and cash equivalents at period end |
2,020 |
2,376 |
Cash flows from operating activities primarily reflect higher Upstream realizations and volumes, and favourable working capital impacts.
Cash flows used in investing activities primarily reflect lower additions to property, plant and equipment.
Cash flows used in financing activities primarily reflect:
|
|
Second Quarter |
|
|
millions of Canadian dollars, unless noted |
2024 |
2023 |
|
Dividends paid |
321 |
257 |
|
Per share dividend paid (dollars) |
0.60 |
0.44 |
|
Share repurchases (a) |
— |
— |
|
Number of shares purchased (millions) (a) |
— |
— |
| (a) | The company did not purchase any shares during the second quarter of 2024 and 2023. |
On June 24, 2024, the company announced by news release that it had received final approval from the Toronto Stock Exchange for a new normal course issuer bid and will continue its existing share purchase program. Shareholders may obtain a copy of the Notice of Intention to Make a Normal Course Issuer Bid approved by the TSX without charge by contacting the company. The program enables the company to purchase up to a maximum of 26,791,840 common shares during the period June 29, 2024 to June 28, 2025. This maximum includes shares purchased under the normal course issuer bid from Exxon Mobil Corporation. As in the past, Exxon Mobil Corporation has advised the company that it intends to participate to maintain its ownership percentage at approximately 69.6 percent. The program will end should the company purchase the maximum allowable number of shares or otherwise on June 28, 2025. Imperial plans to accelerate its share purchases under the normal course issuer bid program, and anticipates repurchasing all remaining allowable shares prior to year end. Purchase plans may be modified at any time without prior notice.
Six months 2024 vs. six months 2023
|
|
Six Months |
|
|
millions of Canadian dollars, unless noted |
2024 |
2023 |
|
Net income (loss) (U.S. GAAP) |
2,328 |
1,923 |
|
Net income (loss) per common share, assuming dilution (dollars) |
4.34 |
3.29 |
Upstream
Net income (loss) factor analysis
millions of Canadian dollars
|
2023 |
Price |
Volumes |
Royalty |
Other |
2024 |
|
714 |
630 |
310 |
(300) |
3 |
1,357 |
Price – Average bitumen realizations increased by $15.76 per barrel, primarily driven by higher marker prices and the narrowing WTI/WCS spread. Synthetic crude oil realizations increased by $0.37 per barrel, primarily driven by higher WTI, partly offset by a weaker Synthetic/WTI spread.
Volumes – Higher volumes were primarily driven by higher mine fleet productivity and optimized turnaround at Kearl, production and steam cycle timing and GRP1 production at Cold Lake.
Royalty – Higher royalties were primarily driven by improved commodity prices.
Other – Includes lower operating expenses of about $120 million, primarily from lower energy prices, partially offset by lower electricity sales at Cold Lake due to lower prices.
Marker prices and average realizations
|
|
Six Months |
|
|
Canadian dollars, unless noted |
2024 |
2023 |
|
West Texas Intermediate (US$ per barrel) |
78.77 |
74.77 |
|
Western Canada Select (US$ per barrel) |
62.34 |
54.92 |
|
WTI/WCS Spread (US$ per barrel) |
16.43 |
19.85 |
|
Bitumen (per barrel) |
74.70 |
58.94 |
|
Synthetic crude oil (per barrel) |
102.10 |
101.73 |
|
Average foreign exchange rate (US$) |
0.74 |
0.74 |
Production
|
|
Six Months |
|
|
thousands of barrels per day |
2024 |
2023 |
|
Kearl (Imperial’s share) |
189 |
169 |
|
Cold Lake |
144 |
137 |
|
Syncrude (a) |
70 |
71 |
|
|
|
|
|
Kearl total gross production (thousands of barrels per day) |
266 |
238 |
| (a) | In 2024, Syncrude gross production included about 1 thousand barrels per day of bitumen and other products (2023 – 1 thousand barrels per day) that were exported to the operator’s facilities using an existing interconnect pipeline. |
Higher production at Kearl was primarily driven by higher mine fleet productivity and optimized turnaround.
Downstream
Net income (loss) factor analysis
millions of Canadian dollars
|
2023 |
Margins |
Other |
2024 |
|
1,120 |
(280) |
85 |
925 |
Margins – Lower margins primarily reflect weaker market conditions.
Other – Primarily due to lower turnaround impacts of about $150 million.
Refinery utilization and petroleum product sales
|
|
Six Months |
|
|
thousands of barrels per day, unless noted |
2024 |
2023 |
|
Refinery throughput |
397 |
403 |
|
Refinery capacity utilization (percent) |
92 |
93 |
|
Petroleum product sales |
460 |
465 |
Refinery throughput in 2024 reflects the impact of turnaround activities at the Sarnia and Strathcona refineries. Refinery throughput in 2023 reflected the impact of turnaround activities at the Strathcona refinery.
Chemicals
Net income (loss) factor analysis
millions of Canadian dollars
|
2023 |
Margins |
Other |
2024 |
|
124 |
(10) |
8 |
122 |
Corporate and other
|
|
Six Months |
|
|
millions of Canadian dollars |
2024 |
2023 |
|
Net income (loss) (U.S. GAAP) |
(76) |
(35) |
Liquidity and capital resources
|
|
Six Months |
|
|
millions of Canadian dollars |
2024 |
2023 |
|
Cash flows from (used in): |
|
|
|
Operating activities |
2,705 |
64 |
|
Investing activities |
(937) |
(903) |
|
Financing activities |
(612) |
(534) |
|
Increase (decrease) in cash and cash equivalents |
1,156 |
(1,373) |
Cash flows from operating activities primarily reflect the absence of unfavourable working capital impacts mainly related to an income tax catch-up payment of $2.1 billion in the prior year.
Cash flows used in investing activities primarily reflect higher additions to property, plant and equipment.
Cash flows used in financing activities primarily reflect:
|
|
Six Months |
|
|
millions of Canadian dollars, unless noted |
2024 |
2023 |
|
Dividends paid |
599 |
523 |
|
Per share dividend paid (dollars) |
1.10 |
0.88 |
|
Share repurchases (a) |
— |
— |
|
Number of shares purchased (millions) (a) |
— |
— |
| (a) | The company did not purchase any shares during the six months ended June 30, 2024 and 2023. |
Key financial and operating data follow.
Forward-looking statements
Statements of future events or conditions in this report, including projections, targets, expectations, estimates, and business plans, are forward-looking statements. Similarly, discussion of roadmaps or future plans related to carbon capture, transportation and storage, biofuel, hydrogen, and other future plans to reduce emissions and emission intensity of the company, its affiliates and third parties are dependent on future market factors, such as continued technological progress, policy support and timely rule-making and permitting, and represent forward-looking statements. Forward-looking statements can be identified by words such as believe, anticipate, intend, propose, plan, goal, seek, estimate, expect, future, continue, likely, may, should, will and similar references to future periods. Forward-looking statements in this report include, but are not limited to, references to the company’s commitment to return surplus cash to shareholders and shareholder returns programs, including purchases under the normal course issuer bid and plans to accelerate purchases to complete the program prior to year end; the impact and timing of the Cold Lake Grand Rapids Phase 1 project, including expected production, cost reductions and reductions to greenhouse gas emissions intensity, and the timing of production ramp-up for such project; the company’s Strathcona renewable diesel project, including timing and expected capacity; the company’s Leming SAGD redevelopment project, including timing and anticipated production; the company’s focus on leveraging technology to profitably grow production while reducing greenhouse gas intensity; company performance in the second half of the year; progress and conditions of the Pathways Alliance carbon capture and storage project; and impact of the Calgary renewable diesel blending and offloading distribution terminal.
Forward-looking statements are based on the company’s current expectations, estimates, projections and assumptions at the time the statements are made. Actual future financial and operating results, including expectations and assumptions concerning future energy demand, supply and mix; production rates, growth and mix across various assets; project plans, timing, costs, technical evaluations and capacities and the company’s ability to effectively execute on these plans and operate its assets, including the Cold Lake Grand Rapids Phase 1 project, the Strathcona renewable diesel project and the Leming SAGD redevelopment project; for shareholder returns, assumptions such as cash flow forecasts, financing sources and capital structure, participation of the company’s majority shareholder and the results of periodic and ongoing evaluation of alternate uses of capital; the adoption and impact of new facilities or technologies on reductions to greenhouse gas emissions intensity, including but not limited to technologies using solvents to replace energy intensive steam at Cold Lake, Strathcona renewable diesel, carbon capture and storage including in connection with hydrogen for the renewable diesel project, recovery technologies and efficiency projects, and any changes in the scope, terms, or costs of such projects; the results of research programs and new technologies, including with respect to greenhouse gas emissions, and the ability to bring new technologies to scale on a commercially competitive basis, and the competitiveness of alternative energy and other emission reduction technologies; for renewable diesel, the availability and cost of locally-sourced and grown feedstock and the supply of renewable diesel to British Columbia in connection with its low-carbon fuel legislation; the amount and timing of emissions reductions, including the impact of lower carbon fuels; that any required support from policymakers and other stakeholders for various new technologies such as carbon capture and storage will be provided; receipt of regulatory approvals in a timely manner, especially with respect to large scale emissions reduction projects; performance of third-party service providers; refinery utilization; applicable laws and government policies, including with respect to climate change, greenhouse gas emissions reductions and low carbon fuels; the ability to offset any ongoing inflationary pressures; capital and environmental expenditures; cash generation, financing sources and capital structure, such as dividends and shareholder returns, including the timing and amounts of share repurchases; and commodity prices, foreign exchange rates and general market conditions, could differ materially depending on a number of factors.
These factors include global, regional or local changes in supply and demand for oil, natural gas, and petroleum and petrochemical products and resulting price, differential and margin impacts, including foreign government action with respect to supply levels and prices, and the occurrence of wars; political or regulatory events, including changes in law or government policy, applicable royalty rates, and tax laws; third-party opposition to company and service provider operations, projects and infrastructure; availability and allocation of capital; the receipt, in a timely manner, of regulatory and third-party approvals, including for new technologies that will help the company meet its lower emissions goals; failure, delay or uncertainty regarding supportive policy and market development for the adoption of emerging lower emission energy technologies and other technologies that support emissions reductions; environmental regulation, including climate change and greenhouse gas regulation and changes to such regulation; unanticipated technical or operational difficulties; project management and schedules and timely completion of projects; availability and performance of third-party service providers; environmental risks inherent in oil and gas exploration and production activities; management effectiveness and disaster response preparedness; operational hazards and risks; cybersecurity incidents; currency exchange rates; general economic conditions, including inflation and the occurrence and duration of economic recessions or downturns; and other factors discussed in Item 1A risk factors and Item 7 management’s discussion and analysis of financial condition and results of operations of Imperial’s most recent annual report on Form 10-K.
Contacts
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(587) 962-4401
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(587) 476-7010
