Imperial announces first quarter 2024 financial and operating results
- Quarterly net income of $1,195 million
- Cash flows from operating activities of $1,076 million and cash flows from operating activities excluding working capital1 of $1,521 million
- Upstream production of 421,000 gross oil-equivalent barrels per day
- Highest ever first quarter production at Kearl of 277,000 total gross oil-equivalent barrels per day (196,000 barrels Imperial’s share)
- Further progressed Cold Lake Grand Rapids, consistent with plan to ramp up production in coming weeks
- Strong Downstream operating performance with refinery capacity utilization of 94 percent and highest ever first quarter throughput at Nanticoke
- Esso brand achieved No.1 retail market share in Canada in 20232
- Initial regulatory applications filed for Pathways Alliance carbon capture and storage project
- Declared quarterly dividend of 60 cents per share
CALGARY, Alberta–(BUSINESS WIRE)–Imperial (TSE: IMO) (NYSE American: IMO):
|
|
First quarter |
||
|
millions of Canadian dollars, unless noted |
2024 |
2023 |
∆ |
|
Net income (loss) (U.S. GAAP) |
1,195 |
1,248 |
(53) |
|
Net income (loss) per common share, assuming dilution (dollars) |
2.23 |
2.13 |
+0.10 |
|
Capital and exploration expenditures |
496 |
429 |
+67 |
Imperial reported estimated net income in the first quarter of $1,195 million, compared to net income of $1,365 million in the fourth quarter of 2023, reflecting an expected seasonal decrease in Upstream production volume. Quarterly cash flows from operating activities was $1,076 million, compared to $1,311 million generated in the fourth quarter of 2023. Excluding the impact of working capital1, cash flows from operating activities was $1,521 million, compared to $1,799 million in the fourth quarter of 2023.
“Imperial’s first quarter financial results reflect the strength of our integrated business model as we delivered record first quarter production from Kearl and continued to deliver high utilization rates across our refining network,” said Brad Corson, chairman, president and chief executive officer. “In addition, we progressed key projects such as our Strathcona Renewable Diesel Facility and Cold Lake Grand Rapids, that support both volume growth and lower emissions to meet Canada’s energy needs.”
Upstream production in the first quarter averaged 421,000 gross oil-equivalent barrels per day. At Kearl, quarterly total gross production averaged 277,000 barrels per day (196,000 barrels Imperial’s share), the highest ever first quarter production in the asset’s history. At Cold Lake, quarterly production averaged 142,000 gross barrels per day. The Grand Rapids Phase 1 project continued to progress steam injection throughout the quarter, consistent with plans to begin ramping up production in the coming weeks. The project is expected to achieve 15,000 gross barrels at full production rates and also reduce greenhouse gas emissions intensity by up to 40 percent compared to existing steam processes.
In the Downstream, quarterly throughput averaged 407,000 barrels per day, which included the highest ever first quarter throughput at Nanticoke, with overall refinery capacity utilization of 94 percent and petroleum product sales of 450,000 barrels per day. Based on retail market share data published in the first quarter, the Esso brand has now achieved the No.1 market share position in Canada on a stand-alone basis2, building on the company’s previous No.1 market share position when combining both Esso and Mobil brands. Throughout the quarter, the company continued to advance work on Canada’s largest renewable diesel facility at its Strathcona refinery, with construction activity now underway on a number of units and progressing on plan. When complete, the project is expected to be able to produce more than one billion litres of renewable diesel annually, primarily from locally sourced and grown feedstocks, and support Canada’s ambition to achieve net-zero by 2050.
During the quarter, Imperial returned $278 million to shareholders through dividend payments and declared a second quarter dividend of 60 cents per share. “A reliable and growing dividend is the foundation of our shareholder returns program, and with our first quarter increase, we are now positioned to deliver 30 consecutive years of dividend growth,” said Corson.
In March, regulatory filings began for the proposed Pathways Alliance carbon capture and storage project, starting with transportation network applications. Pathways Alliance members have been working together to develop and prepare these applications while discussing the project with Indigenous groups, local communities, landowners and governments. “The regulatory applications represent an important milestone,” said Corson. “Our industry has an important role to play in the energy transition, and Imperial remains well positioned to continue pursuing strategic opportunities to reduce emissions, provide economic benefits for local and Indigenous communities and deliver value for our shareholders.”
First quarter highlights
- Net income of $1,195 million or $2.23 per share on a diluted basis, compared to $1,248 million or $2.13 per share in the first quarter of 2023.
- Cash flows from operating activities of $1,076 million, up from cash flows used in operating activities of $821 million in the first quarter of 2023. Cash flows from operating activities excluding working capital1 of $1,521 million, compared to $1,554 million in the same period of 2023.
- Capital and exploration expenditures totaled $496 million, up from $429 million in the first quarter of 2023.
- The company returned $278 million to shareholders in the first quarter of 2024 through dividends paid.
- Production averaged 421,000 gross oil-equivalent barrels per day, up from 413,000 gross oil-equivalent barrels per day in the same period of 2023.
- Total gross bitumen production at Kearl averaged 277,000 barrels per day (196,000 barrels Imperial’s share), the highest first quarter production in the asset’s history, up from 259,000 barrels per day (184,000 barrels Imperial’s share) in the first quarter of 2023, primarily driven by strong mine and plant performance.
- Gross bitumen production at Cold Lake averaged 142,000 barrels per day, up from 141,000 barrels per day in the first quarter of 2023.
- Further progressed steam injection at the Grand Rapids Phase 1 (GRP1) project, consistent with plans to begin ramping up production in the coming weeks. GRP1 will be the first solvent-assisted SAGD project in the industry and is expected to achieve 15,000 gross barrels per day of production at full rates while also reducing greenhouse gas emissions intensity by up to 40 percent compared to existing cyclic steam stimulation technology.
- The company’s share of gross production from Syncrude averaged 73,000 barrels per day, compared to 76,000 barrels per day in the first quarter of 2023. Syncrude began its annual planned coker turnaround in late March, which is expected to be completed in the second quarter.
- Refinery throughput averaged 407,000 barrels per day, including highest ever first quarter throughput at Nanticoke, compared to 417,000 barrels per day in the first quarter of 2023. Capacity utilization was 94 percent, compared to 96 percent in the first quarter of 2023.
- Petroleum product sales were 450,000 barrels per day, compared to 455,000 barrels per day in the first quarter of 2023.
- Continued to advance work on the Strathcona Renewable Diesel facility, with construction activity now underway on a number of units and progressing on-plan. When complete the project is expected to produce more than one billion litres of renewable diesel annually, from locally sourced and grown feedstocks, and support Canada’s ambition to achieve net-zero by 2050.
- Esso brand has achieved the No.1 market share position in Canada in 2023 on a stand-alone basis according to retail market share data published in the first quarter2. This builds on the company’s previous position holding the No.1 retail market share position in Canada when combining the Esso and Mobil brands.
- Following a proactive decision to conduct preventative maintenance on the Winnipeg Products Pipeline, regular fuel supply into the region is being maintained through temporary transportation networks.
- Chemical net income of $57 million in the quarter, up from $53 million in the first quarter of 2023.
- Pathways Alliance files regulatory applications with the Alberta Energy Regulator for proposed carbon capture and storage project. Pathways Alliance has set goals to reduce emissions from oil sands operations (scope 1 and 2), working towards a goal of net zero from oil sands operations by 2050.
Recent business environment
During the first quarter of 2024, the price of crude oil remained relatively flat with the fourth quarter of 2023, as markets continued to be reasonably balanced on higher inventory levels. The Canadian WTI/WCS spread began to narrow in the first quarter, but remained in line with the 2023 full year average. Refining margins improved in the first quarter of 2024 primarily driven by industry downtime and supply disruptions.
Operating results
First quarter 2024 vs. first quarter 2023
|
|
First Quarter |
|
|
millions of Canadian dollars, unless noted |
2024 |
2023 |
|
Net income (loss) (U.S. GAAP) |
1,195 |
1,248 |
|
Net income (loss) per common share, assuming dilution (dollars) |
2.23 |
2.13 |
Upstream
Net income (loss) factor analysis
millions of Canadian dollars
|
2023 |
Price |
Volumes |
Royalty |
Other |
2024 |
|
330 |
310 |
60 |
(120) |
(22) |
558 |
Price – Average bitumen realizations increased by $16.23 per barrel, primarily driven by higher marker prices and the narrowing of the WTI/WCS spread. Synthetic crude oil realizations decreased by $8.94 per barrel, due to a weaker Synthetic/WTI spread.
Volumes – Higher volumes were primarily driven by strong mine and plant performance at Kearl.
Royalty – Higher royalties were primarily driven by improved commodity prices.
Marker prices and average realizations
|
|
First Quarter |
|
|
Canadian dollars, unless noted |
2024 |
2023 |
|
West Texas Intermediate (US$ per barrel) |
76.86 |
75.98 |
|
Western Canada Select (US$ per barrel) |
57.50 |
51.42 |
|
WTI/WCS Spread (US$ per barrel) |
19.36 |
24.56 |
|
Bitumen (per barrel) |
66.56 |
50.33 |
|
Synthetic crude oil (per barrel) |
93.51 |
102.45 |
|
Average foreign exchange rate (US$) |
0.74 |
0.74 |
Production
|
|
First Quarter |
|
|
thousands of barrels per day |
2024 |
2023 |
|
Kearl (Imperial’s share) |
196 |
184 |
|
Cold Lake |
142 |
141 |
|
Syncrude (a) |
73 |
76 |
|
|
|
|
|
Kearl total gross production (thousands of barrels per day) |
277 |
259 |
| (a) | In the first quarter of 2023, Syncrude gross production included about 2 thousand barrels per day of bitumen and other products that were exported to the operator’s facilities using an existing interconnect pipeline. |
Higher production at Kearl was primarily driven by strong mine and plant performance.
Downstream
Net income (loss) factor analysis
millions of Canadian dollars
|
2023 |
Margins |
Other |
2024 |
|
870 |
(190) |
(49) |
631 |
Margins – Lower margins primarily reflect weaker market conditions.
Refinery utilization and petroleum product sales
|
|
First Quarter |
|
|
thousands of barrels per day, unless noted |
2024 |
2023 |
|
Refinery throughput |
407 |
417 |
|
Refinery capacity utilization (percent) |
94 |
96 |
|
Petroleum product sales |
450 |
455 |
Lower refinery throughput was primarily driven by minor maintenance activities.
Chemicals
Net income (loss) factor analysis
millions of Canadian dollars
|
2023 |
Margins |
Other |
2024 |
|
53 |
— |
4 |
57 |
Corporate and other
|
|
First Quarter |
|
|
millions of Canadian dollars |
2024 |
2023 |
|
Net income (loss) (U.S. GAAP) |
(51) |
(5) |
Liquidity and capital resources
|
|
First Quarter |
|
|
millions of Canadian dollars |
2024 |
2023 |
|
Cash flows from (used in): |
|
|
|
Operating activities |
1,076 |
(821) |
|
Investing activities |
(481) |
(414) |
|
Financing activities |
(283) |
(271) |
|
Increase (decrease) in cash and cash equivalents |
312 |
(1,506) |
|
|
|
|
|
Cash and cash equivalents at period end |
1,176 |
2,243 |
Cash flows from operating activities primarily reflect the absence of unfavourable working capital impacts 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:
|
|
First Quarter |
|
|
millions of Canadian dollars, unless noted |
2024 |
2023 |
|
Dividends paid |
278 |
266 |
|
Per share dividend paid (dollars) |
0.50 |
0.44 |
|
Share repurchases (a) |
— |
— |
|
Number of shares purchased (millions) (a) |
— |
— |
| (a) | The company did not purchase any shares in the first quarter of 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, the impact and timing of the Cold Lake Grand Rapids Phase 1 project, including expected production 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, feedstock sources, expected production, and reduction to greenhouse gas emissions; other references to the company’s operations helping to reduce emissions, providing economic benefits, delivering shareholder value and helping meet Canada’s energy needs and ambitions; the timing of the Syncrude coker turnaround; references to the company’s shareholder returns program and future potential dividend growth; and progress and goals of the Pathways Alliance carbon capture and storage project.
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 and the Strathcona renewable diesel project; for shareholder returns, assumptions such as cash flow forecasts, financing sources and capital structure; 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; 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; 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; the results of research programs and new technologies, the ability to bring new technologies to commercial scale on a cost-competitive basis, and the competitiveness of alternative energy and other emission reduction technologies; 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; political or regulatory events, including changes in law or government policy, applicable royalty rates, and tax laws including taxes on share repurchases; 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 Oil Limited’s most recent annual report on Form 10-K.
Forward-looking statements are not guarantees of future performance and involve a number of risks and uncertainties, some that are similar to other oil and gas companies and some that are unique to Imperial Oil Limited. Imperial’s actual results may differ materially from those expressed or implied by its forward-looking statements and readers are cautioned not to place undue reliance on them. Imperial undertakes no obligation to update any forward-looking statements contained herein, except as required by applicable law.
Forward-looking and other statements regarding Imperial’s environmental, social and other sustainability efforts and aspirations are not an indication that these statements are material to investors or require disclosure in the company’s filings with securities regulators. In addition, historical, current and forward-looking environmental, social and sustainability-related statements may be based on standards for measuring progress that are still developing, internal controls and processes that continue to evolve, and assumptions that are subject to change in the future, including future rule-making. Individual projects or opportunities may advance based on a number of factors, including availability of supportive policy, technology for cost-effective abatement, company planning process, and alignment with our partners and other stakeholders.
In this release all dollar amounts are expressed in Canadian dollars unless otherwise stated. This release should be read in conjunction with Imperial’s most recent Form 10-K. Note that numbers may not add due to rounding.
The term “project” as used in this release can refer to a variety of different activities and does not necessarily have the same meaning as in any government payment transparency reports.
|
|
Attachment I |
|
|
|
|
|
|
|
|
|
|
|
Three Months |
|
|
millions of Canadian dollars, unless noted |
2024 |
2023 |
|
|
|
|
|
Net income (loss) (U.S. GAAP) |
|
|
|
Total revenues and other income |
12,283 |
12,121 |
|
Total expenses |
10,711 |
10,476 |
|
Income (loss) before income taxes |
1,572 |
1,645 |
|
Income taxes |
377 |
397 |
|
Net income (loss) |
1,195 |
1,248 |
|
|
|
|
|
Net income (loss) per common share (dollars) |
2.23 |
2.14 |
|
Net income (loss) per common share – assuming dilution (dollars) |
2.23 |
2.13 |
|
|
|
|
|
Other financial data |
|
|
|
Gain (loss) on asset sales, after tax |
2 |
8 |
|
|
|
|
|
Total assets at March 31 |
42,513 |
42,115 |
|
|
|
|
|
Total debt at March 31 |
4,127 |
4,149 |
|
|
|
|
|
Shareholders’ equity at March 31 |
23,112 |
23,435 |
|
|
|
|
|
Capital employed at March 31 |
27,264 |
27,610 |
|
|
|
|
|
Dividends declared on common stock |
|
|
|
Total |
321 |
257 |
|
Per common share (dollars) |
0.60 |
0.44 |
|
|
|
|
|
Millions of common shares outstanding |
|
|
|
At March 31 |
535.8 |
584.2 |
|
Average – assuming dilution |
536.9 |
585.4 |
|
|
|
|
|
|
Attachment II |
|
|
|
|
|
|
|
|
|
|
|
Three Months |
|
|
millions of Canadian dollars |
2024 |
2023 |
|
|
|
|
|
Total cash and cash equivalents at period end |
1,176 |
2,243 |
|
|
|
|
|
Operating activities |
|
|
|
Net income (loss) |
1,195 |
1,248 |
|
Adjustments for non-cash items: |
|
|
|
Depreciation and depletion |
490 |
490 |
|
(Gain) loss on asset sales |
(2) |
(9) |
|
Deferred income taxes and other |
(164) |
(56) |
|
Changes in operating assets and liabilities |
(445) |
(2,375) |
|
All other items – net |
2 |
(119) |
|
Cash flows from (used in) operating activities |
1,076 |
(821) |
|
|
|
|
|
Investing activities |
|
|
|
Additions to property, plant and equipment |
(497) |
(429) |
|
Proceeds from asset sales |
4 |
14 |
|
Loans to equity companies – net |
12 |
1 |
|
Cash flows from (used in) investing activities |
(481) |
(414) |
|
Cash flows from (used in) financing activities |
(283) |
(271) |
|
|
Attachment III |
|
|
|
|
|
|
|
|
|
|
|
Three Months |
|
|
millions of Canadian dollars |
2024 |
2023 |
|
|
|
|
|
Net income (loss) (U.S. GAAP) |
|
|
|
Upstream |
558 |
330 |
|
Downstream |
631 |
870 |
|
Chemical |
57 |
53 |
|
Corporate and other |
(51) |
(5) |
|
Net income (loss) |
1,195 |
1,248 |
|
|
|
|
|
Revenues and other income |
|
|
|
Upstream |
4,168 |
3,700 |
|
Downstream |
13,639 |
13,482 |
|
Chemical |
419 |
433 |
|
Eliminations / Corporate and other |
(5,943) |
(5,494) |
|
Revenues and other income |
12,283 |
12,121 |
|
|
|
|
|
Purchases of crude oil and products |
|
|
|
Upstream |
1,813 |
1,543 |
|
Downstream |
11,591 |
11,196 |
|
Chemical |
260 |
274 |
|
Eliminations / Corporate and other |
(5,958) |
(5,535) |
|
Purchases of crude oil and products |
7,706 |
7,478 |
|
|
|
|
|
Production and manufacturing |
|
|
|
Upstream |
1,188 |
1,287 |
|
Downstream |
421 |
411 |
|
Chemical |
53 |
58 |
|
Eliminations / Corporate and other |
2 |
— |
|
Production and manufacturing |
1,664 |
1,756 |
|
|
|
|
|
Selling and general |
|
|
|
Upstream |
— |
— |
|
Downstream |
162 |
157 |
|
Chemical |
26 |
26 |
|
Eliminations / Corporate and other |
58 |
3 |
|
Selling and general |
246 |
186 |
|
|
|
|
|
Capital and exploration expenditures |
|
|
|
Upstream |
290 |
321 |
|
Downstream |
153 |
74 |
|
Chemical |
5 |
4 |
|
Corporate and other |
48 |
30 |
|
Capital and exploration expenditures |
496 |
429 |
|
Exploration expenses charged to Upstream income included above |
1 |
1 |
|
|
Attachment IV |
|
|
|
|
|
|
|
|
|
|
Operating statistics |
Three Months |
|
|
|
2024 |
2023 |
|
|
|
|
|
Gross crude oil production (thousands of barrels per day) |
|
|
|
Kearl |
196 |
184 |
|
Cold Lake |
142 |
141 |
|
Syncrude (a) |
73 |
76 |
|
Conventional |
5 |
5 |
|
Total crude oil production |
416 |
406 |
|
|
|
|
|
Gross natural gas production (millions of cubic feet per day) |
30 |
40 |
|
|
|
|
|
Gross oil-equivalent production (b) |
421 |
413 |
|
(thousands of oil-equivalent barrels per day) |
|
|
|
|
|
|
|
Net crude oil production (thousands of barrels per day) |
|
|
|
Kearl |
183 |
171 |
|
Cold Lake |
108 |
118 |
|
Syncrude (a) |
61 |
70 |
|
Conventional |
5 |
5 |
|
Total crude oil production |
357 |
364 |
|
|
|
|
|
Net natural gas production (millions of cubic feet per day) |
30 |
37 |
|
|
|
|
|
Net oil-equivalent production (b) |
362 |
370 |
|
(thousands of oil-equivalent barrels per day) |
|
|
|
|
|
|
|
Kearl blend sales (thousands of barrels per day) |
277 |
261 |
|
Cold Lake blend sales (thousands of barrels per day) |
190 |
190 |
|
|
|
|
|
Average realizations (Canadian dollars) |
|
|
|
Bitumen (per barrel) |
66.56 |
50.33 |
|
Synthetic crude oil (per barrel) |
93.51 |
102.45 |
|
Conventional crude oil (per barrel) |
52.21 |
65.02 |
|
Natural gas (per thousand cubic feet) |
0.24 |
3.05 |
|
|
|
|
|
Refinery throughput (thousands of barrels per day) |
407 |
417 |
|
Refinery capacity utilization (percent) |
94 |
96 |
|
|
|
|
|
Petroleum product sales (thousands of barrels per day) |
|
|
|
Gasolines |
215 |
213 |
|
Heating, diesel and jet fuels |
170 |
183 |
|
Lube oils and other products |
43 |
42 |
|
Heavy fuel oils |
22 |
17 |
|
Net petroleum products sales |
450 |
455 |
|
Petrochemical sales (thousands of tonnes) |
215 |
218 |
Contacts
Investor Relations
(587) 962-4401
Media Relations
(587) 476-7010
