EX-99.1 2 tm2319211d1_ex99-1.htm EXHIBIT 99.1 tm2319211-1_nonfiling_DIV_02-mda - none - 10.640672s
 Exhibit 99.1​
MANAGEMENT’S DISCUSSION AND ANALYSIS
August 14, 2023
Suncor Energy Inc. (Suncor or the company) is an integrated energy company headquartered in Calgary, Alberta, Canada. Suncor’s operations include oil sands development, production and upgrading; offshore oil and gas; petroleum refining in Canada and the U.S.; and the company’s Petro-Canada™ retail and wholesale distribution networks (including Canada’s Electric Highway™, a coast-to-coast network of fast-charging electric vehicle stations). Suncor is developing petroleum resources while advancing the transition to a low-emissions future through investments in power and renewable fuels. Suncor also conducts energy trading activities focused principally on marketing and trading crude oil, natural gas, byproducts, refined products and power. Suncor has been recognized for its performance and transparent reporting on the Dow Jones Sustainability North American Index, FTSE4Good Index and CDP. Suncor’s common shares (symbol: SU) are listed on the Toronto Stock Exchange (TSX) and the New York Stock Exchange (NYSE).
For a description of Suncor’s segments, refer to Suncor’s Management’s Discussion and Analysis (MD&A) for the year ended December 31, 2022, dated March 6, 2023 (the 2022 annual MD&A).
This MD&A, for the three and six months ended June 30, 2023, should be read in conjunction with Suncor’s unaudited interim Consolidated Financial Statements for the three and six months ended June 30, 2023, Suncor’s audited Consolidated Financial Statements for the year ended December 31, 2022, and the 2022 annual MD&A.
Additional information about Suncor filed with Canadian securities regulatory authorities and the United States Securities and Exchange Commission (SEC), including quarterly and annual reports and Suncor’s Annual Information Form dated March 6, 2023 (the 2022 AIF), which is also filed with the SEC under cover of Form 40-F, is available online at www.sedarplus.ca, www.sec.gov and on our website at www.suncor.com. Information contained in or otherwise accessible through our website does not form part of this MD&A, and is not incorporated into this document by reference.
Suncor Energy Inc. has numerous direct and indirect subsidiaries, partnerships and joint arrangements (collectively, affiliates), which own and operate assets and conduct activities in different jurisdictions. The terms “we”, “our”, “Suncor” or “the company” are used herein for simplicity of communication and only mean there is an affiliation with Suncor Energy Inc., without necessarily identifying the specific nature of the affiliation. The use of such terms in any statement herein does not mean they apply to Suncor Energy Inc. or any particular affiliate, and does not waive the corporate separateness of any affiliate. For further clarity, Suncor Energy Inc. does not directly operate or own assets in the U.S.
Basis of Presentation
Unless otherwise noted, all financial information is derived from the company’s condensed consolidated financial statements which are based on Canadian generally accepted accounting principles (GAAP), specifically International Financial Reporting Standards (IFRS) as issued by the International Accounting Standards Board, and are prepared in accordance with International Accounting Standard (IAS) 34 Interim Financial Reporting.
All financial information is reported in Canadian dollars, unless otherwise noted. Production volumes are presented on a working-interest basis, before royalties, except for production volumes from the company’s Libya operations, which are presented on an economic basis.
References to Oil Sands operations exclude Suncor’s interests in Fort Hills and Syncrude.
Common Abbreviations
For a list of abbreviations that may be used in this MD&A, refer to the Common Abbreviations section of this MD&A.
Table of Contents
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2023 Second Quarter   Suncor Energy Inc.   5
MANAGEMENT’S DISCUSSION AND ANALYSIS
1. Second Quarter Highlights
•
Second quarter financial results. Suncor’s adjusted funds from operations(1) were $2.655 billion ($2.03 per common share) in the second quarter of 2023, including a $275 million before-tax restructuring charge related to the company’s workforce reduction plans, compared to $5.345 billion ($3.80 per common share) in the prior year quarter. Adjusted operating earnings(1) were $1.253 billion ($0.96 per common share) in the second quarter of 2023, compared to $3.814 billion ($2.71 per common share) in the prior year quarter.
​
•
Maximized returns to shareholders. Suncor returned $1.4 billion of value to shareholders in the second quarter of 2023, through $684 million in share repurchases and the payment of $679 million of dividends. As at August 11, 2023, since the start of the year, the company has repurchased approximately $1.6 billion of Suncor’s common shares, representing approximately 38.5 million common shares at an average price of $42.29 per common share, or the equivalent of 2.9% of its common shares as at December 31, 2022.
​
•
Reduced net debt. As at June 30, 2023, Suncor’s net debt(1) was $14.394 billion, a reduction of $1.320 billion compared to March 31, 2023, with the decrease in net debt primarily due to an increase in cash and cash equivalents, which included the proceeds from the sale of the company’s U.K. Exploration and Production (E&P) portfolio.
​
•
Maximized Oil Sands value through regional integration. Total Oil Sands production was 679,100 bbls/d in the second quarter, compared to 641,500 bbls/d in the prior year quarter, with the increase due to lower maintenance activities in the current period, the company’s increased working interest in Fort Hills, strong upgrader utilizations outside of planned maintenance activities and continued strong performance from the company’s In Situ assets. To mitigate the impacts of planned maintenance during the quarter and maximize value, the company leveraged its regional asset connectivity through increased internal transfers between assets.
​
•
Driving fit and focus of asset portfolio. During the second quarter of 2023, Suncor completed the sale of its U.K. E&P portfolio for gross proceeds of $1.1 billion, before closing adjustments and other closing costs, resulting in a gain on sale of $607 million ($607 million after-tax).
​
•
Refineries are well positioned for strong second half of 2023. The company completed major planned turnaround maintenance at each of its refineries in the second quarter of 2023, positioning the company’s refineries for a strong second half of 2023.
​
•
Update on acquisition of TotalEnergies’ Canadian operations. Following ConocoPhillips Canada exercising its pre-emptive right to purchase the 50% working interest in the Surmont in situ asset, Suncor is continuing to evaluate the transaction to acquire the remainder of TotalEnergies’ Canadian operations, including the remaining 31.23% working interest in Fort Hills.
​
(1)
Non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A and the Adjusted Operating Earnings Reconciliation below for a reconciliation of net earnings to adjusted operating earnings.
​
6   2023 Second Quarter   Suncor Energy Inc.
2. CONSOLIDATED FINANCIAL AND OPERATING INFORMATION
Financial Highlights
​ ​ ​ ​
Three months ended
June 30
​ ​
Six months ended
June 30
​
​
($ millions)
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ Earnings (loss) before income taxes ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Oil Sands
​ ​ ​
​
1 267
​ ​ ​ ​ ​ 2 892 ​ ​ ​ ​
​
2 744
 ​ ​ ​ ​ ​ 5 201 ​ ​
​
​
Exploration and Production
​ ​ ​
​
956
​ ​ ​ ​ ​ 1 361 ​ ​ ​ ​
​
1 331
 ​ ​ ​ ​ ​ 2 006 ​ ​
​
​
Refining and Marketing
​ ​ ​
​
518
​ ​ ​ ​ ​ 2 007 ​ ​ ​ ​
​
1 511
 ​ ​ ​ ​ ​ 3 424 ​ ​
​
​
Corporate and Eliminations
​ ​ ​
​
(390)
​ ​ ​ ​ ​ (851) ​ ​ ​ ​
​
(521)
 ​ ​ ​ ​ ​ (1 374) ​ ​
​
​ Income tax expense ​ ​ ​
​
(472)
​ ​ ​ ​ ​ (1 413) ​ ​ ​ ​
​
(1 134)
 ​ ​ ​ ​ ​ (2 312) ​ ​
​ Net earnings ​ ​ ​
​
1 879
​ ​ ​ ​ ​ 3 996 ​ ​ ​ ​
​
3 931
 ​ ​ ​ ​ ​ 6 945 ​ ​
​ Adjusted operating earnings (loss)(1) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Oil Sands
​ ​ ​
​
1 281
​ ​ ​ ​ ​ 2 872 ​ ​ ​ ​
​
2 771
 ​ ​ ​ ​ ​ 5 128 ​ ​
​
​
Exploration and Production
​ ​ ​
​
349
​ ​ ​ ​ ​ 716 ​ ​ ​ ​
​
724
 ​ ​ ​ ​ ​ 1 361 ​ ​
​
​
Refining and Marketing
​ ​ ​
​
494
​ ​ ​ ​ ​ 2 008 ​ ​ ​ ​
​
1 492
 ​ ​ ​ ​ ​ 3 403 ​ ​
​
​
Corporate and Eliminations
​ ​ ​
​
(359)
​ ​ ​ ​ ​ (499) ​ ​ ​ ​
​
(789)
 ​ ​ ​ ​ ​ (1 168) ​ ​
​
​
Income tax expense included in adjusted operating earnings
​ ​ ​
​
(512)
​ ​ ​ ​ ​ (1 283) ​ ​ ​ ​
​
(1 136)
 ​ ​ ​ ​ ​ (2 155) ​ ​
​ Total ​ ​ ​
​
1 253
​ ​ ​ ​ ​ 3 814 ​ ​ ​ ​
​
3 062
 ​ ​ ​ ​ ​ 6 569 ​ ​
​ Adjusted funds from (used in) operations(1) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Oil Sands
​ ​ ​
​
2 557
​ ​ ​ ​ ​ 4 231 ​ ​ ​ ​
​
5 145
 ​ ​ ​ ​ ​ 7 645 ​ ​
​
​
Exploration and Production
​ ​ ​
​
521
​ ​ ​ ​ ​ 841 ​ ​ ​ ​
​
1 012
 ​ ​ ​ ​ ​ 1 565 ​ ​
​
​
Refining and Marketing
​ ​ ​
​
781
​ ​ ​ ​ ​ 2 127 ​ ​ ​ ​
​
1 975
 ​ ​ ​ ​ ​ 3 724 ​ ​
​
​
Corporate and Eliminations
​ ​ ​
​
(655)
​ ​ ​ ​ ​ (402) ​ ​ ​ ​
​
(1 188)
 ​ ​ ​ ​ ​ (1 067) ​ ​
​
​
Current income tax expense
​ ​ ​
​
(549)
​ ​ ​ ​ ​ (1 452) ​ ​ ​ ​
​
(1 287)
 ​ ​ ​ ​ ​ (2 428) ​ ​
​ Total ​ ​ ​
​
2 655
​ ​ ​ ​ ​ 5 345 ​ ​ ​ ​
​
5 657
 ​ ​ ​ ​ ​ 9 439 ​ ​
​
Change in non-cash working capital
​ ​ ​
​
148
​ ​ ​ ​ ​ (1 110) ​ ​ ​ ​
​
(1 815)
 ​ ​ ​ ​ ​ (2 132) ​ ​
​
​ Cash flow provided by operating activities ​ ​ ​
​
2 803
​ ​ ​ ​ ​ 4 235 ​ ​ ​ ​
​
3 842
 ​ ​ ​ ​ ​ 7 307 ​ ​
​ Capital and exploration expenditures(2)(3) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Asset sustainment and maintenance
​ ​ ​
​
1 047
​ ​ ​ ​ ​ 899 ​ ​ ​ ​
​
1 637
 ​ ​ ​ ​ ​ 1 411 ​ ​
​
​
Economic investment
​ ​ ​
​
504
​ ​ ​ ​ ​ 352 ​ ​ ​ ​
​
942
 ​ ​ ​ ​ ​ 814 ​ ​
​ Total ​ ​ ​
​
1 551
​ ​ ​ ​ ​ 1 251 ​ ​ ​ ​
​
2 579
 ​ ​ ​ ​ ​ 2 225 ​ ​
​ Free funds flow(1) ​ ​ ​
​
1 042
​ ​ ​ ​ ​ 4 050 ​ ​ ​ ​
​
2 958
 ​ ​ ​ ​ ​ 7 133 ​ ​
​
(1)
Non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.
​
(2)
Excludes capitalized interest of  $62 million and $120 million in the second quarter and first six months of 2023, respectively, compared to $44 million and $81 million in the second quarter and first six months of 2022, respectively.
​
(3)
Excludes capital expenditures related to assets previously held for sale of  $66 million and $108 million in the second quarter and first six months of 2023, respectively, compared to $36 million and $55 million in the second quarter and first six months of 2022, respectively.
​
2023 Second Quarter   Suncor Energy Inc.   7
MANAGEMENT’S DISCUSSION AND ANALYSIS
Operating Highlights
​ ​ ​ ​
Three months ended
June 30
​ ​
Six months ended
June 30
​
​ ​ ​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ Production volumes ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Oil Sands – Upgraded – net SCO and diesel (mbbls/d)
​ ​ ​
​
505.0
​ ​ ​ ​ ​ 483.0 ​ ​ ​ ​
​
501.5
 ​ ​ ​ ​ ​ 498.9 ​ ​
​
​
Oil Sands – Non-upgraded bitumen (mbbls/d)
​ ​ ​
​
174.1
​ ​ ​ ​ ​ 158.5 ​ ​ ​ ​
​
175.6
 ​ ​ ​ ​ ​ 164.4 ​ ​
​ Total Oil Sands production volumes (mbbls/d) ​ ​ ​
​
679.1
​ ​ ​ ​ ​ 641.5 ​ ​ ​ ​
​
677.1
 ​ ​ ​ ​ ​ 663.3 ​ ​
​
Exploration and Production (mboe/d)
​ ​ ​
​
62.8
​ ​ ​ ​ ​ 78.7 ​ ​ ​ ​
​
64.9
 ​ ​ ​ ​ ​ 79.5 ​ ​
​ Total upstream production (mboe/d) ​ ​ ​
​
741.9
​ ​ ​ ​ ​ 720.2 ​ ​ ​ ​
​
742.0
 ​ ​ ​ ​ ​ 742.8 ​ ​
​ Refinery utilization (%) ​ ​ ​
​
85
​ ​ ​ ​ ​ 84 ​ ​ ​ ​
​
82
 ​ ​ ​ ​ ​ 89 ​ ​
​
​ Refinery crude oil processed (mbbls/d) ​ ​ ​
​
394.4
​ ​ ​ ​ ​ 389.3 ​ ​ ​ ​
​
381.1
 ​ ​ ​ ​ ​ 412.7 ​ ​
Financial Results
Net Earnings
Suncor’s consolidated net earnings for the second quarter of 2023 were $1.879 billion, compared to $3.996 billion in the prior year quarter. Net earnings were primarily influenced by the same factors that impacted adjusted operating earnings noted below.
Other items affecting net earnings over these periods included:
•
An unrealized foreign exchange gain on the revaluation of U.S. dollar denominated debt of $244 million recorded in financing expenses in the Corporate and Eliminations segment in the second quarter of 2023, compared to a loss of $352 million in the second quarter of 2022.
​
•
An unrealized gain on risk management activities of $10 million recorded in other income (loss) in the second quarter of 2023, compared to $19 million in the second quarter of 2022.
​
•
During the second quarter of 2023, Suncor recorded a gain of $607 million on the sale of its U.K. E&P portfolio, which was completed in the second quarter of 2023.
​
•
In the second quarter of 2023, the company recorded a restructuring charge of $275 million in operating, selling and general (OS&G) expenses in the Corporate and Eliminations segment, related to the company’s workforce reduction plans.
​
•
During the second quarter of 2022, as a result of the decision to restart the West White Rose Project, the company recorded a non-cash impairment reversal of $715 million on its share of the White Rose assets, in the E&P segment. Also, during the second quarter of 2022, due to the company’s sale of its E&P assets in Norway, the company recorded a non-cash impairment of $70 million against its share of its assets in Norway.
​
•
An income tax recovery related to the items noted above of $40 million in the second quarter of 2023, compared to an expense of $130 million in the second quarter of 2022.
​
Adjusted Operating Earnings Reconciliation(1)
​ ​ ​ ​
Three months ended
June 30
​ ​
Six months ended
June 30
​
​
($ millions)
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ Net earnings ​ ​ ​
​
1 879
​ ​ ​ ​ ​ 3 996 ​ ​ ​ ​
​
3 931
 ​ ​ ​ ​ ​ 6 945 ​ ​
​
​
Unrealized foreign exchange (gain) loss on U.S. dollar denominated debt
​ ​ ​
​
(244)
​ ​ ​ ​ ​ 352 ​ ​ ​ ​
​
(241)
 ​ ​ ​ ​ ​ 206 ​ ​
​
​
Unrealized (gain) loss on risk management activities
​ ​ ​
​
(10)
​ ​ ​ ​ ​ (19) ​ ​ ​ ​
​
8
 ​ ​ ​ ​ ​ (94) ​ ​
​
​
Gain on significant disposal
​ ​ ​
​
(607)
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
(909)
 ​ ​ ​ ​ ​ — ​ ​
​
​
Restructuring charge
​ ​ ​
​
275
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
275
 ​ ​ ​ ​ ​ — ​ ​
​
​
Asset impairment (reversal)
​ ​ ​
​
—
​ ​ ​ ​ ​ (645) ​ ​ ​ ​
​
—
 ​ ​ ​ ​ ​ (645) ​ ​
​
​
Income tax (recovery) expense on adjusted operating earnings adjustments
​ ​ ​
​
(40)
​ ​ ​ ​ ​ 130 ​ ​ ​ ​
​
(2)
 ​ ​ ​ ​ ​ 157 ​ ​
​ Adjusted operating earnings(1) ​ ​ ​
​
1 253
​ ​ ​ ​ ​ 3 814 ​ ​ ​ ​
​
3 062
 ​ ​ ​ ​ ​ 6 569 ​ ​
​
(1)
Non-GAAP financial measure. All reconciling items are presented on a before-tax basis and adjusted for income taxes in the income tax (recovery) expense excluded from adjusted operating earnings line. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.
​
8   2023 Second Quarter   Suncor Energy Inc.
Bridge Analysis of Adjusted Operating Earnings ($ millions)(1)
[MISSING IMAGE: bc_financial-pn.jpg]
(1)
For an explanation of this bridge analysis, see the Non-GAAP and Other Financial Measures Advisory section of this MD&A.
​
Suncor’s adjusted operating earnings were $1.253 billion ($0.96 per common share) in the second quarter of 2023, compared to $3.814 billion ($2.71 per common share) in the prior year quarter, primarily due to decreased crude oil and refined product realizations reflecting a weaker business environment in the current quarter, and a first-in, first-out (FIFO) inventory valuation loss in the current quarter compared to a gain in the prior year quarter, partially offset by lower royalties and income taxes.
Adjusted Funds from Operations and Cash Flow Provided by Operating Activities
Adjusted funds from operations were $2.655 billion ($2.03 per common share) in the second quarter of 2023, compared to $5.345 billion ($3.80 per common share) in the prior year quarter, and were influenced by the same factors impacting adjusted operating earnings, as well as a restructuring charge related to workforce reduction plans recorded in the current quarter.
Cash flow provided by operating activities, which includes changes in non-cash working capital, was $2.803 billion ($2.14 per common share) in the second quarter of 2023, compared to $4.235 billion ($3.01 per common share) in the prior year quarter. In addition to the factors impacting adjusted funds from operations, cash flow provided by operating activities was impacted by a source of cash associated with the company’s working capital balances in the current quarter compared to a use of cash in the prior year quarter. The source of cash in the second quarter of 2023 was primarily due to a decrease in benchmark commodity prices during the quarter resulting in a decrease in accounts receivables and inventory balances, partially offset by a decrease in accounts payable and accrued liabilities.
2023 Second Quarter   Suncor Energy Inc.   9
MANAGEMENT’S DISCUSSION AND ANALYSIS
Operating, Selling and General Expenses
​ ​ ​ ​
Three months ended
June 30
​ ​
Six months ended
June 30
​
​
($ millions)
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ Operations, selling and corporate costs ​ ​ ​
​
2 678
​ ​ ​ ​ ​ 2 348 ​ ​ ​ ​
​
5 404
 ​ ​ ​ ​ ​ 4 681 ​ ​
​
​ Commodities ​ ​ ​
​
418
​ ​ ​ ​ ​ 537 ​ ​ ​ ​
​
969
 ​ ​ ​ ​ ​ 1 035 ​ ​
​
​ Share-based compensation and other(1) ​ ​ ​
​
344
​ ​ ​ ​ ​ 203 ​ ​ ​ ​
​
491
 ​ ​ ​ ​ ​ 460 ​ ​
​ Total operating, selling and general (OS&G) expenses ​ ​ ​
​
3 440
​ ​ ​ ​ ​ 3 088 ​ ​ ​ ​
​
6 864
 ​ ​ ​ ​ ​ 6 176 ​ ​
​
(1)
In the second quarter of 2023, share-based compensation expense of  $22 million included a $21 million expense recorded in the Oil Sands segment, a $1 million expense recorded in the E&P segment, a $8 million expense recorded in the Refining and Marketing (R&M) segment and a $8 million recovery recorded in the Corporate and Eliminations segment. The second quarter of 2022 share-based compensation expense of $140 million included $53 million recorded in the Oil Sands segment, $4 million recorded in the E&P segment, $20 million recorded in the R&M segment and $63 million recorded in the Corporate and Eliminations segment. Other primarily includes costs associated with investments in the company’s digital transformation and net-zero greenhouse gas objective, and a $275 million restructuring charge related to workforce reduction plans recorded in the second quarter of 2023.
​
The increase in OS&G expenses in the second quarter of 2023 compared to the prior year quarter was primarily due to a $275 million restructuring charge related to the company’s workforce reduction plans, increased mining activity, the company’s increased working interest in Fort Hills, increased maintenance costs and the impact of inflation. This was partially offset by a decrease in share-based compensation expense and decreased commodity input costs primarily due to lower natural gas prices. The company’s exposure to commodity costs are partially mitigated by revenue from power sales that are recorded in operating revenues.
10   2023 Second Quarter   Suncor Energy Inc.
Business Environment
Commodity prices, refining crack spreads and foreign exchange rates are important factors that affect the results of Suncor’s operations. Commodity market volatility increased during the second quarter of 2023, due to economic concerns regarding rising interest rates, inflationary pressures and future economic growth. For additional details see the Financial Information section of the 2022 annual MD&A.
​ ​ ​ ​ ​ ​ ​
Average for the
three months ended
June 30
​ ​
Average for the
six months ended
June 30
​
​ ​ ​ ​ ​ ​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ WTI crude oil at Cushing ​ ​
US$/bbl
​ ​ ​
​
73.75
 ​ ​ ​ ​ ​ 108.40 ​ ​ ​ ​
​
74.90
 ​ ​ ​ ​ ​ 101.45 ​ ​
​
​ Dated Brent crude ​ ​
US$/bbl
​ ​ ​
​
78.35
 ​ ​ ​ ​ ​ 113.75 ​ ​ ​ ​
​
79.80
 ​ ​ ​ ​ ​ 107.70 ​ ​
​
​
Dated Brent/Maya crude oil FOB price differential
​ ​
US$/bbl
​ ​ ​
​
14.75
 ​ ​ ​ ​ ​ 11.65 ​ ​ ​ ​
​
16.55
 ​ ​ ​ ​ ​ 13.05 ​ ​
​
​ MSW at Edmonton ​ ​
Cdn$/bbl
​ ​ ​
​
95.10
 ​ ​ ​ ​ ​ 137.80 ​ ​ ​ ​
​
97.05
 ​ ​ ​ ​ ​ 126.85 ​ ​
​
​ WCS at Hardisty ​ ​
US$/bbl
​ ​ ​
​
58.70
 ​ ​ ​ ​ ​ 95.60 ​ ​ ​ ​
​
55.05
 ​ ​ ​ ​ ​ 87.75 ​ ​
​
​ WTI-WCS light/heavy differential ​ ​
US$/bbl
​ ​ ​
​
(15.05)
 ​ ​ ​ ​ ​ (12.80) ​ ​ ​ ​
​
(19.85)
 ​ ​ ​ ​ ​ (13.70) ​ ​
​
​ SYN-WTI differential ​ ​
US$/bbl
​ ​ ​
​
2.90
 ​ ​ ​ ​ ​ 6.05 ​ ​ ​ ​
​
2.50
 ​ ​ ​ ​ ​ 2.40 ​ ​
​
​ Condensate at Edmonton ​ ​
US$/bbl
​ ​ ​
​
72.35
 ​ ​ ​ ​ ​ 108.35 ​ ​ ​ ​
​
76.10
 ​ ​ ​ ​ ​ 102.30 ​ ​
​
​
Natural gas (Alberta spot) at AECO
​ ​
Cdn$/GJ
​ ​ ​
​
2.35
 ​ ​ ​ ​ ​ 6.90 ​ ​ ​ ​
​
2.70
 ​ ​ ​ ​ ​ 5.70 ​ ​
​
​ Alberta Power Pool Price ​ ​
Cdn$/MWh
​ ​ ​
​
159.80
 ​ ​ ​ ​ ​ 122.45 ​ ​ ​ ​
​
150.95
 ​ ​ ​ ​ ​ 106.30 ​ ​
​
​ New York Harbor 2-1-1 crack(1) ​ ​
US$/bbl
​ ​ ​
​
32.30
 ​ ​ ​ ​ ​ 60.05 ​ ​ ​ ​
​
34.50
 ​ ​ ​ ​ ​ 44.20 ​ ​
​
​ Chicago 2-1-1 crack(1) ​ ​
US$/bbl
​ ​ ​
​
28.60
 ​ ​ ​ ​ ​ 49.40 ​ ​ ​ ​
​
30.05
 ​ ​ ​ ​ ​ 34.90 ​ ​
​
​ Portland 2-1-1 crack(1) ​ ​
US$/bbl
​ ​ ​
​
37.30
 ​ ​ ​ ​ ​ 63.45 ​ ​ ​ ​
​
37.35
 ​ ​ ​ ​ ​ 48.70 ​ ​
​
​ Gulf Coast 2-1-1 crack(1) ​ ​
US$/bbl
​ ​ ​
​
29.15
 ​ ​ ​ ​ ​ 52.55 ​ ​ ​ ​
​
33.40
 ​ ​ ​ ​ ​ 39.75 ​ ​
​
​
U.S. Renewable Volume Obligation
​ ​
US$/bbl
​ ​ ​
​
7.70
 ​ ​ ​ ​ ​ 7.80 ​ ​ ​ ​
​
7.95
 ​ ​ ​ ​ ​ 7.15 ​ ​
​
​ Suncor custom 5-2-2-1 index(2) ​ ​
US$/bbl
​ ​ ​
​
34.20
 ​ ​ ​ ​ ​ 51.45 ​ ​ ​ ​
​
38.55
 ​ ​ ​ ​ ​ 41.90 ​ ​
​
​ Exchange rate ​ ​
US$/Cdn$
​ ​ ​
​
0.74
 ​ ​ ​ ​ ​ 0.78 ​ ​ ​ ​
​
0.74
 ​ ​ ​ ​ ​ 0.79 ​ ​
​
​ Exchange rate (end of period) ​ ​
US$/Cdn$
​ ​ ​
​
0.76
 ​ ​ ​ ​ ​ 0.78 ​ ​ ​ ​
​
0.76
 ​ ​ ​ ​ ​ 0.78 ​ ​
​
(1)
2-1-1 crack spreads are indicators of the refining margin generated by converting two barrels of WTI into one barrel of gasoline and one barrel of diesel. The crack spreads presented here generally approximate the regions into which the company sells refined products through retail and wholesale channels.
​
(2)
Suncor has developed an indicative 5-2-2-1 index based on publicly available pricing data to more accurately reflect the company’s realized refining and marketing gross margin. For more details, including how the custom index is calculated, see Suncor’s 2022 annual MD&A.
​
2023 Second Quarter   Suncor Energy Inc.   11
MANAGEMENT’S DISCUSSION AND ANALYSIS
3. SEGMENT RESULTS AND ANALYSIS
OIL SANDS
Financial Highlights
​ ​ ​ ​
Three months ended
June 30
​ ​
Six months ended
June 30
​
​
($ millions)
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ Operating revenues ​ ​ ​
​
6 178
​ ​ ​ ​ ​ 8 762 ​ ​ ​ ​
​
12 245
 ​ ​ ​ ​ ​ 16 232 ​ ​
​
​ Less: Royalties ​ ​ ​
​
(599)
​ ​ ​ ​ ​ (1 487) ​ ​ ​ ​
​
(871)
 ​ ​ ​ ​ ​ (2 472) ​ ​
​ Operating revenues, net of royalties ​ ​ ​
​
5 579
​ ​ ​ ​ ​ 7 275 ​ ​ ​ ​
​
11 374
 ​ ​ ​ ​ ​ 13 760 ​ ​
​ Earnings before income taxes ​ ​ ​
​
1 267
​ ​ ​ ​ ​ 2 892 ​ ​ ​ ​
​
2 744
 ​ ​ ​ ​ ​ 5 201 ​ ​
​ Adjusted for: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Unrealized loss (gain) on risk management activities
​ ​ ​
​
14
​ ​ ​ ​ ​ (20) ​ ​ ​ ​
​
27
 ​ ​ ​ ​ ​ (73) ​ ​
​ Adjusted operating earnings(1) ​ ​ ​
​
1 281
​ ​ ​ ​ ​ 2 872 ​ ​ ​ ​
​
2 771
 ​ ​ ​ ​ ​ 5 128 ​ ​
​ Adjusted funds from operations(1) ​ ​ ​
​
2 557
​ ​ ​ ​ ​ 4 231 ​ ​ ​ ​
​
5 145
 ​ ​ ​ ​ ​ 7 645 ​ ​
​ Free funds flow(1) ​ ​ ​
​
1 514
​ ​ ​ ​ ​ 3 326 ​ ​ ​ ​
​
3 292
 ​ ​ ​ ​ ​ 6 072 ​ ​
​
(1)
Non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.
​
Oil Sands segment adjusted operating earnings were $1.281 billion in the second quarter of 2023, compared to $2.872 billion in the prior year quarter, with the decrease primarily due to lower realized crude oil prices, partially offset by decreased royalties and increased sales volumes.
Production Volumes(1)
​ ​ ​ ​
Three months ended
June 30
​ ​
Six months ended
June 30
​
​
(mbbls/d)
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ Total Oil Sands bitumen production ​ ​ ​
​
814.3
​ ​ ​ ​ ​ 760.7 ​ ​ ​ ​
​
812.8
 ​ ​ ​ ​ ​ 794.0 ​ ​
​
SCO and diesel production(2)
​ ​ ​
​
521.6
​ ​ ​ ​ ​ 497.1 ​ ​ ​ ​
​
519.6
 ​ ​ ​ ​ ​ 513.9 ​ ​
​
​
Internally consumed diesel and internal transfers(3)(4)
​ ​ ​
​
(16.6)
​ ​ ​ ​ ​ (14.1) ​ ​ ​ ​
​
(18.1)
 ​ ​ ​ ​ ​ (15.0) ​ ​
​ Upgraded production – net SCO and diesel ​ ​ ​
​
505.0
​ ​ ​ ​ ​ 483.0 ​ ​ ​ ​
​
501.5
 ​ ​ ​ ​ ​ 498.9 ​ ​
​
Bitumen production
​ ​ ​
​
200.2
​ ​ ​ ​ ​ 163.3 ​ ​ ​ ​
​
194.9
 ​ ​ ​ ​ ​ 168.3 ​ ​
​
​
Internal bitumen transfers(5)(6)
​ ​ ​
​
(26.1)
​ ​ ​ ​ ​ (4.8) ​ ​ ​ ​
​
(19.3)
 ​ ​ ​ ​ ​ (3.9) ​ ​
​ Non-upgraded bitumen production ​ ​ ​
​
174.1
​ ​ ​ ​ ​ 158.5 ​ ​ ​ ​
​
175.6
 ​ ​ ​ ​ ​ 164.4 ​ ​
​ Total Oil Sands production ​ ​ ​
​
679.1
​ ​ ​ ​ ​ 641.5 ​ ​ ​ ​
​
677.1
 ​ ​ ​ ​ ​ 663.3 ​ ​
​
(1)
Bitumen production from Oil Sands Base is upgraded, while bitumen production from In Situ operations is either upgraded or sold directly to customers, including Suncor’s own refineries, with SCO and diesel yields of approximately 79% of bitumen feedstock input. Fort Hills bitumen is either sold directly to customers as finished bitumen, including Suncor’s own refineries, or to Oil Sands Base for upgrading. Nearly all the bitumen produced at Syncrude is upgraded to sweet SCO and a small amount of diesel, at an approximate yield of 85%.
​
(2)
Upgrader utilization rates are calculated using total upgraded production, inclusive of internally consumed diesel and internal transfers.
​
(3)
Both Oil Sands operations and Syncrude produce diesel, which is internally consumed in mining operations, and Fort Hills and Syncrude use internally produced diesel from Oil Sands Base within their mining operations. In the second quarter of 2023, Oil Sands operations production volumes included 10,900 bbls/d of internally consumed diesel, of which 6,800 bbls/d was consumed at Oil Sands Base, 2,900 bbls/d was consumed at Fort Hills and 1,200 bbls/d was consumed at Syncrude. Syncrude production volumes included 2,700 bbls/d of internally consumed diesel.
​
(4)
Internal feedstock transfers between Oil Sands operations and Syncrude through the interconnecting pipelines are included in gross SCO production volumes. In the second quarter of 2023, Oil Sands operations production included 3,000 bbls/d of SCO that was transferred to Suncor’s share of Syncrude through the interconnecting pipelines.
​
(5)
Internal feedstock transfers between Oil Sands operations and Syncrude through the interconnecting pipelines are included in gross bitumen production volumes. In the second quarter of 2023, Oil Sands operations production included 11,600 bbls/d of bitumen that was transferred to Suncor’s share of Syncrude through the interconnecting pipelines. Syncrude production included 100 bbls/d of bitumen that was transferred to Oil Sands Base through the interconnecting pipelines.
​
(6)
Internal feedstock transfers from Fort Hills to Oil Sands operations through the paraffinic froth treatment hot bitumen transfer piping are included in gross bitumen production volumes. In the second quarter of 2023, Fort Hills production included 14,400 bbls/d of bitumen that was transferred to Oil Sands Base.
​
12   2023 Second Quarter   Suncor Energy Inc.
Total Oil Sands bitumen production increased in the second quarter of 2023 compared to the prior year quarter, due to lower maintenance activities in the current period, excluding at Syncrude, which was impacted by planned turnaround activities, and the company’s increased working interest in Fort Hills.
The company’s net SCO production increased to 505,000 bbls/d in the second quarter of 2023, compared to 483,000 bbls/d in the prior year quarter, reflecting lower planned maintenance activities in the current period and strong upgrader utilizations outside of planned maintenance activities. Upgrader utilization at Oil Sands Base in the second quarter of 2023 was 100%, reflecting strong upgrader performance outside of the planned annual coker maintenance at Upgrader 1, compared to 87% in the prior year quarter, reflecting annual coker maintenance at Upgrader 2 and unplanned maintenance. At Syncrude, upgrader utilization was 83% in the second quarter of 2023, compared to 93% in the prior year quarter, with the decrease due to the timing of planned turnaround activities.
The company’s saleable non-upgraded bitumen production increased to 174,100 bbls/d in the second quarter of 2023, compared to 158,500 bbls/d in the prior year quarter, reflecting strong performance from the company’s In Situ assets and increased working interest from Fort Hills. Total production from the company’s In Situ assets increased in the current quarter, reflecting strong production compared to the prior year quarter, which was impacted by the major planned turnaround at Firebag and unplanned maintenance at MacKay River. Saleable non-upgraded bitumen production is impacted by total bitumen production less volumes which are diverted to upgrading to maximize higher-value SCO production. To mitigate the impacts of planned maintenance during the quarter, the company leveraged its regional asset connectivity through increased internal transfers between assets.
Sales Volumes
​ ​ ​ ​
Three months ended
June 30
​ ​
Six months ended
June 30
​
​
(mbbls/d)
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ Upgraded – net SCO and diesel ​ ​ ​
​
511.5
​ ​ ​ ​ ​ 489.4 ​ ​ ​ ​
​
507.8
 ​ ​ ​ ​ ​ 503.4 ​ ​
​
​ Non-upgraded bitumen ​ ​ ​
​
163.6
​ ​ ​ ​ ​ 162.7 ​ ​ ​ ​
​
168.8
 ​ ​ ​ ​ ​ 158.2 ​ ​
​ Total ​ ​ ​
​
675.1
​ ​ ​ ​ ​ 652.1 ​ ​ ​ ​
​
676.6
 ​ ​ ​ ​ ​ 661.6 ​ ​
SCO and diesel sales volumes increased to 511,500 bbls/d in the second quarter of 2023, compared to 489,400 bbls/d in the prior year quarter, primarily due to the increase in production volumes in the current quarter.
Non-upgraded bitumen sales volumes increased to 163,600 bbls/d in the second quarter of 2023, compared to 162,700 bbls/d in the prior year quarter, primarily due to the increase in production volumes in the current quarter, partially offset by a build of inventory in the second quarter of 2023, compared to a draw in the prior year quarter.
Price Realizations(1)
​
Net of transportation costs, but before royalties
​ ​
Three months ended
June 30
​ ​
Six months ended
June 30
​
​
($/bbl)
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ Upgraded – net SCO and diesel ​ ​ ​
​
95.36
​ ​ ​ ​ ​ 137.17 ​ ​ ​ ​
​
97.08
 ​ ​ ​ ​ ​ 125.57 ​ ​
​
​ Non-upgraded bitumen ​ ​ ​
​
69.91
​ ​ ​ ​ ​ 113.41 ​ ​ ​ ​
​
60.47
 ​ ​ ​ ​ ​ 105.24 ​ ​
​
​ Average crude ​ ​ ​
​
89.19
​ ​ ​ ​ ​ 131.28 ​ ​ ​ ​
​
87.95
 ​ ​ ​ ​ ​ 120.72 ​ ​
​
​ Average crude, relative to WTI ​ ​ ​
​
(9.86)
​ ​ ​ ​ ​ (7.10) ​ ​ ​ ​
​
(12.98)
 ​ ​ ​ ​ ​ (8.25) ​ ​
​
(1)
Contains non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.
​
Oil Sands price realizations decreased in the second quarter of 2023 from the prior year quarter, in line with the decrease in crude oil benchmark prices, the widening of heavy crude oil differentials and the impact of weaker SYN-WTI differentials in the current quarter compared to the prior year quarter, partially offset by a weaker Canadian dollar in relation to the U.S. dollar.
Royalties
Royalties for the Oil Sands segment decreased in the second quarter of 2023 compared to the prior year quarter, due to the decrease in crude oil benchmark pricing and the widening of heavy crude oil differentials in the current period compared to the prior year quarter.
Expenses and Other Factors
Total Oil Sands operating expenses increased in the second quarter of 2023 compared to the prior year quarter, primarily due to increased mining activity, the company’s increased working interest in Fort Hills, increased maintenance costs and inflationary
2023 Second Quarter   Suncor Energy Inc.   13
MANAGEMENT’S DISCUSSION AND ANALYSIS
impacts, partially offset by lower natural gas prices and a decrease in share-based compensation expense. See the Cash Operating Costs section for additional details regarding cash operating costs and a breakdown of non-production costs by asset.
In the second quarter of 2023, depreciation, depletion and amortization (DD&A) expense was lower compared to the prior year quarter, primarily due to higher derecognition charges of property, plant and equipment in the prior year quarter.
Cash Operating Costs
​ ​ ​ ​
Three months ended
June 30
​ ​
Six months ended
June 30
​
​
($ millions, except as noted)
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ Oil Sands operating, selling and general expense (OS&G)(1) ​ ​ ​
​
2 299
​ ​ ​ ​ ​ 2 169 ​ ​ ​ ​
​
4 720
 ​ ​ ​ ​ ​ 4 381 ​ ​
​ Oil Sands operations cash operating costs(2) reconciliation ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Oil Sands operations OS&G
​ ​ ​
​
1 257
​ ​ ​ ​ ​ 1 342 ​ ​ ​ ​
​
2 629
 ​ ​ ​ ​ ​ 2 654 ​ ​
​
​
Non-production costs(3)
​ ​ ​
​
(10)
​ ​ ​ ​ ​ (93) ​ ​ ​ ​
​
(61)
 ​ ​ ​ ​ ​ (185) ​ ​
​
​
Excess power capacity and other(4)
​ ​ ​
​
(81)
​ ​ ​ ​ ​ (101) ​ ​ ​ ​
​
(223)
 ​ ​ ​ ​ ​ (210) ​ ​
​
Oil Sands operations cash operating costs(2)
​ ​ ​
​
1 166
​ ​ ​ ​ ​ 1 148 ​ ​ ​ ​
​
2 345
 ​ ​ ​ ​ ​ 2 259 ​ ​
​
​
Oil Sands operations production volumes (mbbls/d)
​ ​ ​
​
440.1
​ ​ ​ ​ ​ 376.5 ​ ​ ​ ​
​
441.3
 ​ ​ ​ ​ ​ 403.2 ​ ​
​
​
Oil Sands operations cash operating costs(2) ($/bbl)
​ ​ ​
​
29.10
​ ​ ​ ​ ​ 33.50 ​ ​ ​ ​
​
29.35
 ​ ​ ​ ​ ​ 30.95 ​ ​
​ Fort Hills cash operating costs(2) reconciliation ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Fort Hills OS&G
​ ​ ​
​
372
​ ​ ​ ​ ​ 289 ​ ​ ​ ​
​
721
 ​ ​ ​ ​ ​ 555 ​ ​
​
​
Non-production costs(3)
​ ​ ​
​
(41)
​ ​ ​ ​ ​ (40) ​ ​ ​ ​
​
(95)
 ​ ​ ​ ​ ​ (70) ​ ​
​
​
Excess power capacity(4)
​ ​ ​
​
(16)
​ ​ ​ ​ ​ (8) ​ ​ ​ ​
​
(33)
 ​ ​ ​ ​ ​ (16) ​ ​
​
Fort Hills cash operating costs(2)
​ ​ ​
​
315
​ ​ ​ ​ ​ 241 ​ ​ ​ ​
​
593
 ​ ​ ​ ​ ​ 469 ​ ​
​
​
Fort Hills production volumes (mbbls/d)
​ ​ ​
​
110.2
​ ​ ​ ​ ​ 87.4 ​ ​ ​ ​
​
92.5
 ​ ​ ​ ​ ​ 87.4 ​ ​
​
​
Fort Hills cash operating costs(2) ($/bbl)
​ ​ ​
​
31.40
​ ​ ​ ​ ​ 30.20 ​ ​ ​ ​
​
35.45
 ​ ​ ​ ​ ​ 29.60 ​ ​
​ Syncrude cash operating costs(2) reconciliation ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Syncrude OS&G
​ ​ ​
​
724
​ ​ ​ ​ ​ 721 ​ ​ ​ ​
​
1 475
 ​ ​ ​ ​ ​ 1 397 ​ ​
​
​
Non-production costs(3)
​ ​ ​
​
(53)
​ ​ ​ ​ ​ (65) ​ ​ ​ ​
​
(111)
 ​ ​ ​ ​ ​ (152) ​ ​
​
​
Excess power capacity(4)
​ ​ ​
​
(6)
​ ​ ​ ​ ​ (5) ​ ​ ​ ​
​
(10)
 ​ ​ ​ ​ ​ (10) ​ ​
​
Syncrude cash operating costs(2)
​ ​ ​
​
665
​ ​ ​ ​ ​ 651 ​ ​ ​ ​
​
1 354
 ​ ​ ​ ​ ​ 1 235 ​ ​
​
​
Syncrude production volumes (mbbls/d)
​ ​ ​
​
171.5
​ ​ ​ ​ ​ 196.5 ​ ​ ​ ​
​
180.7
 ​ ​ ​ ​ ​ 191.6 ​ ​
​
​
Syncrude cash operating costs(2) ($/bbl)
​ ​ ​
​
42.60
​ ​ ​ ​ ​ 36.40 ​ ​ ​ ​
​
41.35
 ​ ​ ​ ​ ​ 35.65 ​ ​
​
(1)
Oil Sands inventory changes and internal transfers are presented on an aggregate basis and reflect: i) the impacts of changes in inventory levels and valuations, such that the company is able to present cost information based on production volumes and ii) adjustments for internal diesel sales between assets. In the second quarter and first six months of 2023, Oil Sands OS&G includes ($54) million and ($105) million, respectively, of inventory changes and internal transfers. In the second quarter and first six months of 2022, Oil Sands OS&G includes ($183) million and ($225) million, respectively, of inventory changes and internal transfers.
​
(2)
Non-GAAP financial measures. Related per barrel amounts contain non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.
​
(3)
Non-production costs include, but are not limited to, share-based compensation adjustments, research costs, project startup costs and adjustments to reflect the cost of internal transfers in the receiving asset at the cost of production versus the cost of purchase. Non-production costs at Fort Hills and Syncrude also include, but are not limited to, an adjustment to reflect internally produced diesel from Oil Sands operations at the cost of production.
​
(4)
Represents excess power revenue from cogeneration units that is recorded in operating revenues. Oil Sands operations excess power capacity and other also includes, but is not limited to, the natural gas expense recorded as part of a non-monetary arrangement involving a third-party processor.
​
Oil Sands operations cash operating costs per barrel(1) were $29.10 in the second quarter of 2023, compared to $33.50 in the prior year quarter, with the decrease primarily due to increased production, lower natural gas prices and an increase in excess power revenues resulting from higher power prices, partially offset by increased maintenance costs.
(1)
Contains non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.
​
14   2023 Second Quarter   Suncor Energy Inc.
Fort Hills cash operating costs per barrel(1) were $31.40 in the second quarter of 2023, compared to $30.20 in the prior year quarter, with the increase due to increased mining activity associated with the mine improvement plan, partially offset by lower natural gas prices and an increase in excess power revenues resulting from higher power prices.
Syncrude cash operating costs per barrel(1) were $42.60 in the second quarter of 2023, compared to $36.40 in the prior year quarter, with the increase primarily due to decreased production, as a result of planned turnaround activities.
Results for the First Six Months of 2023
Oil Sands earnings before income taxes for the first six months of 2023 were $2.744 billion, compared to $5.201 billion in the prior year period. In addition to the factors impacting adjusted operating earnings, earnings before income taxes for the first six months of 2023 included a $27 million unrealized loss on risk management activities, compared to a $73 million unrealized gain in the prior year period.
Oil Sands adjusted operating earnings for the first six months of 2023 were $2.771 billion, compared to $5.128 billion in the prior year period, primarily due to lower realized crude oil prices and increased operating expenses, partially offset by lower royalties.
Oil Sands adjusted funds from operations for the first six months of 2023 were $5.145 billion, compared to $7.645 billion in the prior year period, with the decrease primarily due to the same factors that influenced adjusted operating earnings.
Oil Sands operations cash operating costs per barrel averaged $29.35 for the first six months of 2023, a decrease compared to an average of $30.95 for the first six months of 2022, with the decrease due to increased production, lower natural gas prices and an increase in excess power revenues resulting from higher power prices, partially offset by increased maintenance costs.
Fort Hills cash operating costs per barrel averaged $35.45 for the first six months of 2023, compared to $29.60 in the first six months of 2022, with the increase due to increased mining activity associated with the mine improvement plan, partially offset by an increase in excess power revenues resulting from higher power prices.
Syncrude cash operating costs per barrel averaged $41.35 for the first six months of 2023, compared to $35.65 in the first six months of 2022, with the increase primarily due to decreased production volumes, due to the timing of planned turnaround activities, and increased maintenance costs.
Planned Maintenance Update
Significant planned turnaround activities at Oil Sands Base Upgrader 2 are scheduled to commence in the third quarter of 2023 and are anticipated be completed in the fourth quarter of 2023. At Fort Hills, the first full plant turnaround commenced subsequent to the second quarter, and is anticipated to be completed within the third quarter of 2023. Additional planned maintenance activities are scheduled to commence at Firebag and Syncrude in the third quarter of 2023 and are anticipated to be completed in the fourth quarter of 2023. Additionally, planned maintenance activities at MacKay River are scheduled in the third quarter of 2023. The anticipated impact of these maintenance events has been reflected in the company’s 2023 guidance.
Asset Transactions
In the second quarter of 2023, Suncor entered into an agreement to purchase TotalEnergies’ Canadian operations through the acquisition of TotalEnergies Canada, which held a 31.23% working interest in Fort Hills, a 50% working interest in the Surmont in situ asset (Surmont), as well as certain other associated assets. The agreement was conditional upon ConocoPhillips Canada waiving its right of first refusal in respect of the Surmont working interest, which ConocoPhillips Canada elected to exercise in the second quarter. As a result, Suncor is continuing to evaluate the transaction to acquire the remainder of TotalEnergies’ Canadian operations, including the remaining working interest in Fort Hills.
(1)
Contains non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.
​
2023 Second Quarter   Suncor Energy Inc.   15
MANAGEMENT’S DISCUSSION AND ANALYSIS
EXPLORATION AND PRODUCTION
Financial Highlights
​ ​ ​ ​
Three months ended
June 30
​ ​
Six months ended
June 30
​
​
($ millions)
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ Operating revenues(1) ​ ​ ​
​
813
​ ​ ​ ​ ​ 1 219 ​ ​ ​ ​
​
1 547
 ​ ​ ​ ​ ​ 2 234 ​ ​
​
​ Less: Royalties(1) ​ ​ ​
​
(116)
​ ​ ​ ​ ​ (193) ​ ​ ​ ​
​
(202)
 ​ ​ ​ ​ ​ (340) ​ ​
​ Operating revenues, net of royalties ​ ​ ​
​
697
​ ​ ​ ​ ​ 1 026 ​ ​ ​ ​
​
1 345
 ​ ​ ​ ​ ​ 1 894 ​ ​
​ Earnings before income taxes ​ ​ ​
​
956
​ ​ ​ ​ ​ 1 361 ​ ​ ​ ​
​
1 331
 ​ ​ ​ ​ ​ 2 006 ​ ​
​
Gain on significant disposal
​ ​ ​
​
(607)
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
(607)
 ​ ​ ​ ​ ​ — ​ ​
​
​
Asset impairment (reversal)
​ ​ ​
​
—
​ ​ ​ ​ ​ (645) ​ ​ ​ ​
​
—
 ​ ​ ​ ​ ​ (645) ​ ​
​ Adjusted operating earnings(2) ​ ​ ​
​
349
​ ​ ​ ​ ​ 716 ​ ​ ​ ​
​
724
 ​ ​ ​ ​ ​ 1 361 ​ ​
​ Adjusted funds from operations(2) ​ ​ ​
​
521
​ ​ ​ ​ ​ 841 ​ ​ ​ ​
​
1 012
 ​ ​ ​ ​ ​ 1 565 ​ ​
​ Free funds flow(2) ​ ​ ​
​
339
​ ​ ​ ​ ​ 726 ​ ​ ​ ​
​
692
 ​ ​ ​ ​ ​ 1 367 ​ ​
​
(1)
Production from the company’s Libya operations has been presented in the E&P section of this MD&A on an economic basis. Revenue and royalties from the company’s Libya operations are presented under the working-interest basis, which is required for presentation purposes in the company’s financial statements. In the second quarter of 2023, revenue included a gross-up amount of  $108 million, with an offsetting amount of  $48 million in royalties in the E&P segment and $60 million in income tax expense recorded at the consolidated level. In the first six months of 2023, revenue included a gross-up amount of  $175 million, with an offsetting amount of  $83 million in royalties in the E&P segment and $92 million in income tax expense reported at the consolidated level. In the second quarter of 2022, revenue included a gross-up amount of  $113 million, with an offsetting amount of  $87 million in royalties in the E&P segment and $26 million in income tax expense reported at the consolidated level. In the first six months of 2022, revenue included a gross-up amount of  $251 million, with an offsetting amount of  $147 million in royalties in the E&P segment and $104 million in income tax expense reported at the consolidated level.
​
(2)
Non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.
​
Adjusted operating earnings for the E&P segment in the second quarter of 2023 were $349 million, compared to $716 million in the prior year quarter, with the decrease primarily due to lower realized crude prices and decreased sales volumes.
Volumes
​ ​ ​ ​
Three months ended
June 30
​ ​
Six months ended
June 30
​
​ ​ ​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ E&P Canada (mbbls/d) ​ ​ ​
​
45.9
​ ​ ​ ​ ​ 52.9 ​ ​ ​ ​
​
46.3
 ​ ​ ​ ​ ​ 52.1 ​ ​
​
​ E&P International (mboe/d) ​ ​ ​
​
16.9
​ ​ ​ ​ ​ 25.8 ​ ​ ​ ​
​
18.6
 ​ ​ ​ ​ ​ 27.4 ​ ​
​ Total production (mboe/d) ​ ​ ​
​
62.8
​ ​ ​ ​ ​ 78.7 ​ ​ ​ ​
​
64.9
 ​ ​ ​ ​ ​ 79.5 ​ ​
​ Total sales volumes (mboe/d) ​ ​ ​
​
71.6
​ ​ ​ ​ ​ 86.7 ​ ​ ​ ​
​
70.2
 ​ ​ ​ ​ ​ 83.1 ​ ​
Production volumes for E&P Canada were 45,900 bbls/d in the second quarter of 2023, compared to 52,900 bbls/d in the prior year quarter, primarily due to natural declines and maintenance.
At Terra Nova, restart preparation and commissioning activities are ongoing on the Floating, Production, Storage and Offloading unit.
Production volumes for E&P International were 16,900 boe/d in the second quarter of 2023, compared to 25,800 boe/d in the prior year quarter, primarily due to natural declines and the divestment of the company’s Norway assets in the third quarter of 2022.
Total E&P sales volumes were 71,600 boe/d in the second quarter of 2023, compared to 86,700 boe/d in the prior year quarter, primarily due to the same factors that impacted production volumes.
16   2023 Second Quarter   Suncor Energy Inc.
Price Realizations(1)
​ ​ ​ ​
Three months ended
June 30
​ ​
Six months ended
June 30
​
​
Net of transportation costs, but before royalties
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ E&P Canada ($/bbl) ​ ​ ​
​
105.81
​ ​ ​ ​ ​ 140.24 ​ ​ ​ ​
​
103.63
 ​ ​ ​ ​ ​ 132.05 ​ ​
​
​ E&P International(2) ($/boe) ​ ​ ​
​
102.44
​ ​ ​ ​ ​ 127.84 ​ ​ ​ ​
​
109.01
 ​ ​ ​ ​ ​ 120.58 ​ ​
​
(1)
Contains non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.
​
(2)
E&P International price realizations exclude Libya.
​
E&P price realizations decreased in the second quarter of 2023 from the prior year quarter, in line with the decrease in benchmark prices for Brent crude, partially offset by weaker foreign exchange rates.
Royalties
E&P royalties in the second quarter of 2023 were lower compared to the prior year quarter primarily due to the decrease in price realizations.
Expenses and Other Factors
Operating and transportation expenses increased in the second quarter of 2023 compared to the prior year quarter primarily due to increased commissioning costs related to the Terra Nova Asset Life Extension Project.
DD&A and exploration expense for the second quarter of 2023 was comparable to the prior year quarter, excluding the impacts of impairments and impairment reversals.
Financing and other expenses decreased in the second quarter of 2023 compared to the prior year quarter, due to decreased accretion expense resulting from asset sales.
Results for the First Six Months of 2023
Earnings before income taxes for E&P for the first six months of 2023 were $1.331 billion, compared to $2.006 billion in the prior year period. In addition to the factors impacting adjusted operating earnings, earnings before income taxes for the first six months of 2023 included a gain of $607 million on the sale of the company’s U.K. portfolio, which was completed in the second quarter of 2023. For the first six months of 2022, earnings before income taxes included a non-cash impairment reversal of $715 million on the company’s share of the White Rose assets and a non-cash impairment of $70 million against the company’s share of its assets in Norway.
Adjusted operating earnings for E&P for the first six months of 2023 were $724 million, compared to $1.361 billion for the first six months of 2022, with the decrease primarily due to lower realized crude prices, decreased sales volumes and the recognition of contingent consideration in the first quarter of 2022 related to the company’s sale of the Golden Eagle Area Development.
Adjusted funds from operations for the first six months of 2023 were $1.012 billion, compared to $1.565 billion for the first six months of 2022, due to the same factors that influenced adjusted operating earnings.
Planned Maintenance Update for Operated Assets
There are no significant planned maintenance events scheduled for the third quarter of 2023.
Asset Transaction
During the second quarter of 2023, the company completed the sale of its U.K. E&P portfolio for gross proceeds of $1.1 billion, before closing adjustments and other closing costs, resulting in a gain on sale of $607 million ($607 million after-tax).
2023 Second Quarter   Suncor Energy Inc.   17
MANAGEMENT’S DISCUSSION AND ANALYSIS
REFINING AND MARKETING
Financial Highlights
​ ​ ​ ​
Three months ended
June 30
​ ​
Six months ended
June 30
​
​
($ millions)
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ Operating revenues ​ ​ ​
​
7 272
​ ​ ​ ​ ​ 10 239 ​ ​ ​ ​
​
14 445
 ​ ​ ​ ​ ​ 18 094 ​ ​
​ Earnings before income taxes ​ ​ ​
​
518
​ ​ ​ ​ ​ 2 007 ​ ​ ​ ​
​
1 511
 ​ ​ ​ ​ ​ 3 424 ​ ​
​ Adjusted for: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Unrealized (gain) loss on risk management activities
​ ​ ​
​
(24)
​ ​ ​ ​ ​ 1 ​ ​ ​ ​
​
(19)
 ​ ​ ​ ​ ​ (21) ​ ​
​ Adjusted operating earnings(1) ​ ​ ​
​
494
​ ​ ​ ​ ​ 2 008 ​ ​ ​ ​
​
1 492
 ​ ​ ​ ​ ​ 3 403 ​ ​
​ Adjusted funds from operations(1) ​ ​ ​
​
781
​ ​ ​ ​ ​ 2 127 ​ ​ ​ ​
​
1 975
 ​ ​ ​ ​ ​ 3 724 ​ ​
​ Free funds flow(1) ​ ​ ​
​
404
​ ​ ​ ​ ​ 1 866 ​ ​ ​ ​
​
1 473
 ​ ​ ​ ​ ​ 3 331 ​ ​
​
(1)
Non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.
​
R&M adjusted operating earnings in the second quarter of 2023 were $494 million, compared to $2.008 billion in the prior year quarter. The decrease in adjusted operating earnings was primarily due to a decrease in refining and marketing benchmark crack spreads in the current quarter compared to the prior year quarter, a FIFO inventory valuation loss of $116 million in the current quarter compared to a gain of $525 million in the prior year quarter, and increased operating and transportation expenses, which was partially offset by increased refinery production and refined product sales in the current period.
Volumes
​ ​ ​ ​
Three months ended
June 30
​ ​
Six months ended
June 30
​
​ ​ ​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ Crude oil processed (mbbls/d) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Eastern North America
​ ​ ​
​
212.3
​ ​ ​ ​ ​ 191.4 ​ ​ ​ ​
​
208.1
 ​ ​ ​ ​ ​ 200.4 ​ ​
​
​
Western North America
​ ​ ​
​
182.1
​ ​ ​ ​ ​ 197.9 ​ ​ ​ ​
​
173.0
 ​ ​ ​ ​ ​ 212.3 ​ ​
​ Total ​ ​ ​
​
394.4
​ ​ ​ ​ ​ 389.3 ​ ​ ​ ​
​
381.1
 ​ ​ ​ ​ ​ 412.7 ​ ​
​ Refinery utilization(1) (%) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Eastern North America
​ ​ ​
​
96
​ ​ ​ ​ ​ 86 ​ ​ ​ ​
​
94
 ​ ​ ​ ​ ​ 90 ​ ​
​
​
Western North America
​ ​ ​
​
75
​ ​ ​ ​ ​ 81 ​ ​ ​ ​
​
71
 ​ ​ ​ ​ ​ 87 ​ ​
​ Total ​ ​ ​
​
85
​ ​ ​ ​ ​ 84 ​ ​ ​ ​
​
82
 ​ ​ ​ ​ ​ 89 ​ ​
​ Refined product sales (mbbls/d) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Gasoline
​ ​ ​
​
220.1
​ ​ ​ ​ ​ 218.0 ​ ​ ​ ​
​
214.3
 ​ ​ ​ ​ ​ 222.0 ​ ​
​
​
Distillate
​ ​ ​
​
244.4
​ ​ ​ ​ ​ 229.9 ​ ​ ​ ​
​
238.6
 ​ ​ ​ ​ ​ 242.0 ​ ​
​
​
Other
​ ​ ​
​
82.5
​ ​ ​ ​ ​ 89.0 ​ ​ ​ ​
​
78.1
 ​ ​ ​ ​ ​ 80.4 ​ ​
​ Total ​ ​ ​
​
547.0
​ ​ ​ ​ ​ 536.9 ​ ​ ​ ​
​
531.0
 ​ ​ ​ ​ ​ 544.4 ​ ​
​ Refinery production(2) (mbbls) ​ ​ ​
​
38 214
​ ​ ​ ​ ​ 37 517 ​ ​ ​ ​
​
73 797
 ​ ​ ​ ​ ​ 79 828 ​ ​
​
Refining and marketing gross margin – FIFO(3) ($/bbl)
​ ​ ​
​
38.10
​ ​ ​ ​ ​ 76.85 ​ ​ ​ ​
​
46.45
 ​ ​ ​ ​ ​ 64.30 ​ ​
​
​
Refining and marketing gross margin – LIFO(3) ($/bbl)
​ ​ ​
​
41.10
​ ​ ​ ​ ​ 62.85 ​ ​ ​ ​
​
49.80
 ​ ​ ​ ​ ​ 48.60 ​ ​
​
​
Refining operating expense(3) ($/bbl)
​ ​ ​
​
7.95
​ ​ ​ ​ ​ 7.15 ​ ​ ​ ​
​
8.05
 ​ ​ ​ ​ ​ 6.70 ​ ​
​
(1)
Refinery utilization is the amount of crude oil and natural gas plant liquids run through crude distillation units, expressed as a percentage of the capacity of these units.
​
(2)
Refinery production is the output of the refining process, and differs from crude oil processed as a result of volumetric adjustments for non-crude feedstock, volumetric gain associated with the refining process and changes in unfinished product inventories.
​
(3)
Contains non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.
​
18   2023 Second Quarter   Suncor Energy Inc.
Refinery crude throughput was 394,400 bbls/d and refinery utilization was 85% in the second quarter of 2023, compared to 389,300 bbls/d and 84% in the prior year quarter, reflecting planned turnaround activities in both periods.
Refined product sales in the second quarter of 2023 were 547,000 bbls/d, compared to 536,900 bbls/d in the prior year quarter, primarily due to the company leveraging its extensive domestic sales network and export channels, partially offset by a build of refined product inventory in the current period, compared to a draw in the prior year quarter.
Refining and Marketing Gross Margins(1)
Refining and marketing gross margins were influenced by the following:
•
On a last in, first out (LIFO)(2) basis, Suncor’s refining and marketing gross margin decreased to $41.10/bbl in the second quarter of 2023, from $62.85/bbl in the prior year quarter. The decrease was due to lower gasoline and distillate benchmark crack spreads, which was partially offset by strong location and quality differentials from regional benchmarks to the company’s local markets. On a LIFO basis, Suncor’s refining and marketing gross margin represents 89% margin capture compared to Suncor’s 5-2-2-1 index in the second quarter of 2023.
​
•
On a FIFO basis, Suncor’s refining and marketing gross margin decreased to $38.10/bbl in the second quarter of 2023, from $76.85/bbl in the prior year quarter, due to the same factors noted above, in addition to FIFO inventory valuation impacts. In the second quarter of 2023, the FIFO method of inventory valuation, relative to an estimated LIFO(2) accounting method, including the impact of commodity risk management activities, resulted in a loss of $116 million on the decrease in crude oil benchmarks. In the prior year quarter, FIFO, including the impact of commodity risk management activities, resulted in a gain of $525 million, for an unfavourable quarter-over-quarter impact of $641 million.
​
Expenses and Other Factors
Operating and transportation expenses in the second quarter of 2023 increased compared to the prior year quarter, primarily due to increased maintenance costs, inflationary impacts, and increased transportation costs associated with higher sales volumes, partially offset by lower commodity input costs, primarily natural gas prices, and reduced share-based compensation expenses.
Refining operating expense per barrel(1) was $7.95 in the second quarter of 2023, compared to $7.15 in the prior year quarter, primarily due to increased maintenance, including inflationary impacts, partially offset by lower natural gas prices and higher refinery production.
Results for the First Six Months of 2023
R&M’s earnings before income taxes were $1.511 billion for the first six months of 2023, compared to $3.424 billion in the prior year period. In addition to the factors impacting adjusted operating earnings, earnings before income taxes for the first six months of 2023 included a $19 million unrealized gain on risk management activities, compared to $21 million in the prior year period.
Adjusted operating earnings for R&M in the first six months of 2023 were $1.492 billion, compared to $3.403 billion in the first six months of 2022, with the decrease primarily due to a FIFO inventory valuation loss in the current period due to a decline in crude oil and refined product benchmarks, compared to a significant gain in the prior year period, increased operating and transportation expenses and decreased refinery production and refined product sales in the current period, partially offset by stronger location and quality differentials from regional benchmarks to the company’s local markets. For the first six months of 2023, the impact of the FIFO method of inventory valuation, relative to an estimated LIFO method, had a negative impact to adjusted operating earnings and adjusted funds from operations of $247 million, compared to a positive impact of $1.254 billion in the first six months of 2022.
R&M’s adjusted funds from operations in the first six months of 2023 were $1.975 billion, compared to $3.724 billion in the first six months of 2022, with the decrease primarily due to the same factors that influenced adjusted operating earnings.
Planned Maintenance
Planned maintenance activities are scheduled at the company’s Edmonton and Montreal refineries during the third quarter of 2023, with both events expected to be completed early in the fourth quarter of 2023. The anticipated impact of these maintenance events has been reflected in the company’s 2023 guidance.
(1)
Contains non-GAAP financial measures. See the non-GAAP and Other Financial Measures Advisory section of this MD&A.
​
(2)
The estimated impact of the LIFO method is a non-GAAP financial measure. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.
​
2023 Second Quarter   Suncor Energy Inc.   19
MANAGEMENT’S DISCUSSION AND ANALYSIS
CORPORATE AND ELIMINATIONS
Financial Highlights
​ ​ ​ ​
Three months ended
June 30
​ ​
Six months ended
June 30
​
​
($ millions)
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ Loss before income taxes ​ ​ ​
​
(390)
​ ​ ​ ​ ​ (851) ​ ​ ​ ​
​
(521)
 ​ ​ ​ ​ ​ (1 374) ​ ​
​ Adjusted for: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Unrealized foreign exchange (gain) loss on U.S. dollar denominated debt
​ ​ ​
​
(244)
​ ​ ​ ​ ​ 352 ​ ​ ​ ​
​
(241)
 ​ ​ ​ ​ ​ 206 ​ ​
​
​
Restructuring charge
​ ​ ​
​
275
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
275
 ​ ​ ​ ​ ​ — ​ ​
​
​
Gain on significant disposal(1)
​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
(302)
 ​ ​ ​ ​ ​ — ​ ​
​ Adjusted operating loss(2) ​ ​ ​
​
(359)
​ ​ ​ ​ ​ (499) ​ ​ ​ ​
​
(789)
 ​ ​ ​ ​ ​ (1 168) ​ ​
​
​
Corporate and Renewables
​ ​ ​
​
(324)
 ​ ​ ​ ​
​
(358)
 ​ ​ ​ ​
​
(761)
 ​ ​ ​ ​
​
(746)
 ​ ​
​
​
Eliminations – Intersegment profit eliminated
​ ​ ​
​
(35)
 ​ ​ ​ ​ ​ (141) ​ ​ ​ ​
​
(28)
 ​ ​ ​ ​ ​ (422) ​ ​
​ Adjusted funds used in operations(2) ​ ​ ​
​
(655)
​ ​ ​ ​ ​ (402) ​ ​ ​ ​
​
(1 188)
 ​ ​ ​ ​ ​ (1 067) ​ ​
​ Free funds flow(2) ​ ​ ​
​
(666)
​ ​ ​ ​ ​ (416) ​ ​ ​ ​
​
(1 212)
 ​ ​ ​ ​ ​ (1 209) ​ ​
​
(1)
During the first quarter of 2023, the company recorded a gain of  $302 million on the sale of its wind and solar assets.
​
(2)
Non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.
​
Corporate incurred an adjusted operating loss of $324 million in the second quarter of 2023, compared to $358 million in the prior year quarter. The decreased loss was attributable to lower OS&G expenses in the current quarter, due to reduced share-based compensation and employee benefit expenses as a result of the company’s workforce reduction plans and a decrease in share price during the quarter, and a net decrease in interest expense in the current quarter as a result of debt reductions in 2022. The decreased loss in the second quarter of 2023 was partially offset by an operational foreign exchange loss in the current quarter, compared to a gain in the prior year quarter. Suncor capitalized $62 million of its borrowing costs in the second quarter of 2023, as part of the cost of major development assets and construction projects in progress, compared to $44 million in the prior year quarter.
Eliminations reflect the deferral or realization of profit or loss on crude oil sales from Oil Sands to Suncor’s refineries. Consolidated profits and losses are only realized when the refined products produced from internal purchases of crude feedstock have been sold to third parties. During the second quarter of 2023, the company deferred $35 million of intersegment profit, compared to $141 million in the prior year quarter. The deferral of intersegment profit in the second quarter of 2023 was primarily driven by an increase in intersegment inventory volumes, versus the prior year quarter, which was driven by the increase in Oil Sands price realizations over the previous quarter, as lower margin crude refinery feedstock sourced internally from Oil Sands was sold and replaced by higher margin crude inventory.
Corporate and Eliminations adjusted funds used in operations were $655 million for the second quarter of 2023, compared to $402 million in the second quarter of 2022, and were influenced by the same factors impacting adjusted operating loss, excluding the impact of share-based compensation expense. Adjusted funds used in operations in the second quarter of 2023 were also impacted by a restructuring charge related to the company’s workforce reduction plans.
The company experienced a cybersecurity incident in late June. Upon learning of the incident, Suncor took immediate action and activated its business continuity plans, engaged leading IT and cybersecurity experts, and notified the appropriate authorities. The incident did not impact the safety or reliability of the company’s field operations but did impact some business operations and services at the end of the quarter. The cybersecurity incident is not expected to have a material impact on the company’s 2023 financial results.
20   2023 Second Quarter   Suncor Energy Inc.
Results for the First Six Months of 2023
Corporate and Eliminations loss before income taxes was $521 million for the first six months of 2023, compared to $1.374 billion in the prior year period. In addition to the factors impacting adjusted operating loss, the loss before income taxes for the first six months of 2023 included a $241 million unrealized foreign exchange gain on the revaluation of U.S. dollar denominated debt, a restructuring charge of $275 million related to workforce reduction plans recorded in the second quarter of 2023 and a $302 million gain on the sale of the company’s wind and solar assets in the first quarter of 2023. Corporate and Eliminations loss before income taxes in the prior year period included a $206 million unrealized foreign exchange loss on the revaluation of U.S. dollar denominated debt.
The adjusted operating loss for Corporate and Eliminations for the first six months of 2023 was $789 million, compared to $1.168 billion in the first six months of 2022. The decreased loss was attributed to a smaller deferral of intersegment profit in the current year period compared to the prior year period, decreased share-based compensation and employee benefit expenses in the first six months of 2023, as compared to the first six months of 2022, and a net decrease in interest expense in the current period as a result of debt reductions in 2022. The decreased loss was partially offset by an operational foreign exchange loss in the current period, compared to a gain in the prior year period, and an unrealized gain on investment recorded in the first quarter of 2022. The company capitalized $120 million of its borrowing costs in the first six months of 2023, compared with $81 million in the first six months of 2022.
Corporate and Eliminations adjusted funds used in operations for the first six months of 2023 were $1.188 billion, compared to $1.067 billion in the prior year period, and were influenced by the same factors impacting adjusted operating loss, excluding the impact of share-based compensation and the unrealized gain on investment recorded in the first quarter of 2022. Adjusted funds used in operations in the first six months of 2023 were also impacted by a restructuring charge related to the company’s workforce reduction plans recorded in the second quarter of 2023.
2023 Second Quarter   Suncor Energy Inc.   21
MANAGEMENT’S DISCUSSION AND ANALYSIS
4. INCOME TAX
​ ​ ​ ​
Three months ended
June 30
​ ​
Six months ended
June 30
​
​
($ millions)
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ Current income tax expense ​ ​ ​
​
549
​ ​ ​ ​ ​ 1 452 ​ ​ ​ ​
​
1 287
 ​ ​ ​ ​ ​ 2 428 ​ ​
​
​ Deferred income tax recovery ​ ​ ​
​
(77)
​ ​ ​ ​ ​ (39) ​ ​ ​ ​
​
(153)
 ​ ​ ​ ​ ​ (116) ​ ​
​ Income tax expense included in net earnings ​ ​ ​
​
472
​ ​ ​ ​ ​ 1 413 ​ ​ ​ ​
​
1 134
 ​ ​ ​ ​ ​ 2 312 ​ ​
​
​
Less: Income tax (recovery) expense on adjusted operating earnings adjustments
​ ​ ​
​
(40)
​ ​ ​ ​ ​ 130 ​ ​ ​ ​
​
(2)
 ​ ​ ​ ​ ​ 157 ​ ​
​
Income tax expense included in adjusted operating earnings
​ ​ ​
​
512
​ ​ ​ ​ ​ 1 283 ​ ​ ​ ​
​
1 136
 ​ ​ ​ ​ ​ 2 155 ​ ​
​ Effective tax rate ​ ​ ​
​
20.1%
​ ​ ​ ​ ​ 26.1% ​ ​ ​ ​
​
22.4%
 ​ ​ ​ ​ ​ 25.0% ​ ​
The provision for income taxes in the second quarter and first six months of 2023 decreased compared to the prior year periods, primarily due to decreased earnings. In the second quarter and first six months of 2023, the company’s effective tax rate on net earnings decreased compared to the prior year periods, primarily due to the non-taxable gain on the disposition of the company’s U.K. E&P portfolio, non-taxable foreign exchange gains and losses on the revaluation of U.S. dollar denominated debt, lower income earned in foreign jurisdictions with higher statutory tax rates, and other permanent items impacting total tax expense.
22   2023 Second Quarter   Suncor Energy Inc.
5. CAPITAL INVESTMENT UPDATE
Capital and Exploration Expenditures by Type, Excluding Capitalized Interest
​ ​ ​ ​
Three months ended
​ ​
Six months ended
​
​ ​ ​ ​
June 30,
2023
 ​ ​
June 30,
2022
​ ​
June 30,
2023
 ​ ​
June 30,
2022
​
​
($ millions)
​ ​
Asset
Sustainment
and
Maintenance(1)
​ ​
Economic
Investment(2)
​ ​
Total
 ​ ​
Total
​ ​
Asset
Sustainment
and
Maintenance(1)
​ ​
Economic
Investment(2)
​ ​
Total
 ​ ​
Total
​
​ Oil Sands ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Oil Sands Base
​ ​ ​
​
300
 ​ ​ ​ ​
​
157
 ​ ​ ​ ​
​
457
 ​ ​ ​ ​
​
414
 ​ ​ ​ ​
​
479
 ​ ​ ​ ​
​
280
 ​ ​ ​ ​
​
759
 ​ ​ ​ ​
​
721
 ​ ​
​
​
In Situ
​ ​ ​
​
25
 ​ ​ ​ ​
​
84
 ​ ​ ​ ​
​
109
 ​ ​ ​ ​
​
196
 ​ ​ ​ ​
​
55
 ​ ​ ​ ​
​
180
 ​ ​ ​ ​
​
235
 ​ ​ ​ ​
​
329
 ​ ​
​
​
Fort Hills
​ ​ ​
​
96
 ​ ​ ​ ​
​
—
 ​ ​ ​ ​
​
96
 ​ ​ ​ ​
​
90
 ​ ​ ​ ​
​
186
 ​ ​ ​ ​
​
—
 ​ ​ ​ ​
​
186
 ​ ​ ​ ​
​
158
 ​ ​
​
​
Syncrude
​ ​ ​
​
271
 ​ ​ ​ ​
​
57
 ​ ​ ​ ​
​
328
 ​ ​ ​ ​
​
173
 ​ ​ ​ ​
​
442
 ​ ​ ​ ​
​
126
 ​ ​ ​ ​
​
568
 ​ ​ ​ ​
​
306
 ​ ​
​
​ Exploration and Production(3) ​ ​ ​
​
—
​ ​ ​ ​
​
174
 ​ ​ ​ ​
​
174
 ​ ​ ​ ​ ​ 108 ​ ​ ​ ​
​
—
 ​ ​ ​ ​
​
306
 ​ ​ ​ ​
​
306
 ​ ​ ​ ​ ​ 185 ​ ​
​
​ Refining and Marketing ​ ​ ​
​
345
​ ​ ​ ​
​
31
 ​ ​ ​ ​
​
376
 ​ ​ ​ ​ ​ 261 ​ ​ ​ ​
​
459
 ​ ​ ​ ​
​
42
 ​ ​ ​ ​
​
501
 ​ ​ ​ ​ ​ 393 ​ ​
​
​ Corporate and Eliminations(4) ​ ​ ​
​
10
​ ​ ​ ​
​
1
 ​ ​ ​ ​
​
11
 ​ ​ ​ ​ ​ 9 ​ ​ ​ ​
​
16
 ​ ​ ​ ​
​
8
 ​ ​ ​ ​
​
24
 ​ ​ ​ ​ ​ 133 ​ ​
​ ​ ​ ​ ​ ​ 1 047 ​ ​ ​ ​ ​ 504 ​ ​ ​ ​ ​ 1 551 ​ ​ ​ ​
​
1 251
 ​ ​ ​ ​ ​ 1 637 ​ ​ ​ ​ ​ 942 ​ ​ ​ ​ ​ 2 579 ​ ​ ​ ​
​
2 225
 ​ ​
​ Capitalized interest on debt ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
62
 ​ ​ ​ ​ ​ 44 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
120
 ​ ​ ​ ​ ​ 81 ​ ​
​
Total capital and exploration expenditures
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
1 613
 ​ ​ ​ ​ ​ 1 295 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
2 699
 ​ ​ ​ ​ ​ 2 306 ​ ​
​
(1)
Asset sustainment and maintenance capital expenditures include capital investments that deliver on existing value by ensuring compliance or maintaining relations with regulators and other stakeholders, maintaining current processing capacity and delivering existing developed reserves.
​
(2)
Economic investment capital expenditures include capital investments that result in an increase in value through adding reserves or improving processing capacity, utilization, cost or margin, including associated infrastructure.
​
(3)
Excludes capital expenditures related to assets previously held for sale of  $66 million and $108 million in the second quarter and first six months of 2023, respectively, compared to $15 million and $34 million in the second quarter and first six months of 2022, respectively.
​
(4)
Excludes capital expenditures related to assets previously held for sale of  $21 million in the second quarter and first six months of 2022.
​
During the second quarter of 2023, the company spent $1.551 billion on capital expenditures, excluding capitalized interest, compared to $1.251 billion in the prior year quarter. The increase was primarily due to increased expenditures at Syncrude, due to the timing of planned turnaround activities and expenditures related to the Mildred Lake West Extension mining project, increased maintenance in R&M, and increased E&P expenditures, primarily due to the ramp up of development work at the West White Rose Project in the current period, partially offset by lower expenditures at In Situ in the current quarter, due to the major planned turnaround at Firebag in the second quarter of 2022.
Activity in the second quarter of 2023 is summarized by business unit below.
Oil Sands
Oil Sands Base capital expenditures were $457 million in the second quarter of 2023 and were primarily focused on planned annual coker maintenance at Upgrader 1 as well as tailings development. Economic investment expenditures were primarily focused on progressing the investment in low-carbon power cogeneration by replacing the coke-fired boilers with a new cogeneration facility.
In Situ capital expenditures were $109 million in the second quarter of 2023 and were primarily directed towards economic investment activities focused on the ongoing design and construction of well pads to develop additional reserves that are expected to maintain existing production levels.
Fort Hills capital expenditures were $96 million in the second quarter of 2023 and were directed towards mine and tailings development to support ongoing operations, including expenditures aligned with the execution of the mine improvement plan as well as planned maintenance.
Syncrude capital expenditures were $328 million in the second quarter of 2023 and were primarily directed towards planned turnaround activities. Economic investment expenditures were directed towards progressing the Mildred Lake West Extension mining project.
2023 Second Quarter   Suncor Energy Inc.   23
MANAGEMENT’S DISCUSSION AND ANALYSIS
Exploration and Production
E&P capital and exploration expenditures were $174 million in the second quarter of 2023 and were focused on economic investment projects, primarily development work on the West White Rose Project and the Terra Nova Asset Life Extension Project.
Refining and Marketing
R&M capital expenditures were $376 million in the second quarter of 2023 and were primarily related to the company’s planned maintenance program. Economic investment capital expenditures in the second quarter of 2023 were focused on enhancing the company’s sales and marketing business, including the optimization of its retail operations.
Corporate and Eliminations
Corporate and Eliminations capital expenditures were $11 million in the second quarter of 2023 and were primarily directed towards investment in digital technologies.
24   2023 Second Quarter   Suncor Energy Inc.
6. FINANCIAL CONDITION AND LIQUIDITY
Indicators
​ ​ ​ ​
Twelve months ended
June 30
​
​ ​ ​ ​
2023
 ​ ​
2022
​
​ Return on capital employed (ROCE)(1)(2) (%) ​ ​ ​
​
12.8
​ ​ ​ ​ ​ 19.4 ​ ​
​ Net debt to adjusted funds from operations(1) (times) ​ ​ ​
​
1.0
​ ​ ​ ​ ​ 1.0 ​ ​
​ Total debt to total debt plus shareholders’ equity(1) (%) ​ ​ ​
​
29.4
​ ​ ​ ​ ​ 30.4 ​ ​
​ Net debt to net debt plus shareholders’ equity(1) (%) ​ ​ ​
​
26.1
​ ​ ​ ​ ​ 28.3 ​ ​
​ Net debt to net debt plus shareholders’ equity – excluding leases(1) (%) ​ ​ ​
​
21.5
​ ​ ​ ​ ​ 24.3 ​ ​
​
(1)
Non-GAAP financial measures or contains non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.
​
(2)
ROCE would have been 16.3% for the twelve months ended June 30, 2023, excluding the impact of the impairment of  $3.397 billion ($2.586 billion after-tax) in the third quarter of 2022. ROCE would have been 18.2% for the twelve months ended June 30, 2022, excluding the impact of the impairment reversal of  $715 million ($542 million after-tax) and impairment of  $70 million ($47 million after-tax) in the second quarter of 2022 and the impact of the impairment reversal of  $221 million ($168 million after-tax) in the third quarter of 2021.
​
Capital Resources
Suncor’s capital resources consist primarily of cash flow provided by operating activities, cash and cash equivalents, and available lines of credit. Suncor’s management believes the company will have the capital resources required to fund its planned 2023 capital spending program of $5.4 billion to $5.8 billion and to meet current and future working capital requirements, through cash and cash equivalents balances, cash flow provided by operating activities, available committed credit facilities, issuing commercial paper and, if needed, accessing capital markets. The company’s cash flow provided by operating activities depends on several factors, including commodity prices, production and sales volumes, refining and marketing gross margins, operating expenses, taxes, royalties and foreign exchange rates.
The company has invested cash in short-term financial instruments that are presented as cash and cash equivalents. The objectives of the company’s short-term investment portfolio are to ensure the preservation of capital, maintain adequate liquidity to meet Suncor’s cash flow requirements and deliver competitive returns derived from the quality and diversification of investments within acceptable risk parameters. The maximum weighted average term to maturity of the short-term investment portfolio is not expected to exceed six months, and all investments are with counterparties with investment grade debt ratings.
Available Sources of Liquidity
For the three months ended June 30, 2023, cash and cash equivalents increased to $2.610 billion from $1.128 billion at March 31, 2023, due to the company’s cash flow provided by operating activities, proceeds from the sale of its U.K. E&P portfolio and increases in short-term indebtedness exceeding its capital and exploration expenditures, the repurchase of Suncor’s common shares under its normal course issuer bid (NCIB) and the payment of dividends.
For the six months ended June 30, 2023, cash and cash equivalents increased to $2.610 billion from $1.980 billion at December 31, 2022, due to the company’s cash flow provided by operating activities, proceeds from the sale of its U.K. E&P portfolio, and its wind and solar assets, and increases in short-term indebtedness exceeding its capital and exploration expenditures, the repurchase of Suncor’s common shares under its NCIB, the payment of dividends and the acquisition of an additional 14.65% working interest in Fort Hills in the first quarter of 2023.
As at June 30, 2023, the weighted average days to maturity of the company’s short-term investment portfolio was approximately 42 days.
As at June 30, 2023, available credit facilities for liquidity purposes were $1.289 billion, compared to $2.900 billion at December 31, 2022. The decrease in available credit facilities was due to an increase in short-term indebtedness and a reduction in the size of the company’s syndicated credit facilities. In the second quarter of 2023, the company extended the maturity of its syndicated credit facilities from June 2024 and June 2025 to June 2026, and reduced the size of its $3.0 billion tranche by $200 million, to $2.8 billion.
Financing Activities
Management of debt levels and liquidity continues to be a priority for Suncor given the company’s long-term plans and future expected volatility in the business environment. Suncor believes a phased and flexible approach to existing and future projects should assist the company in maintaining its ability to manage project costs and debt levels.
2023 Second Quarter   Suncor Energy Inc.   25
MANAGEMENT’S DISCUSSION AND ANALYSIS
Total Debt to Total Debt Plus Shareholders’ Equity
Suncor is subject to financial and operating covenants related to its bank debt and public market debt. Failure to meet the terms of one or more of these covenants may constitute an “event of default” as defined in the respective debt agreements, potentially resulting in accelerated repayment of one or more of the debt obligations. The company is in compliance with its financial covenant that requires total debt to not exceed 65% of its total debt plus shareholders’ equity. As at June 30, 2023, total debt to total debt plus shareholders’ equity was 29.4% (December 31, 2022 – 28.4%). The company also continues to be in compliance with all operating covenants under its debt agreements.
Change in Debt
​ ​ ​ ​
Three months ended
​ ​
Six months ended
​
​
($ millions)
​ ​
June 30, 2023
​ ​
June 30, 2023
​
​
Total debt(1) – beginning of period
​ ​ ​ ​ 16 842 ​ ​ ​ ​ ​ 15 619 ​ ​
​
​ Decrease in long-term debt ​ ​ ​
​
—
​ ​ ​ ​
​
(5)
 ​ ​
​
​
Increase in short-term debt
​ ​ ​ ​ 446 ​ ​ ​ ​ ​ 1 408 ​ ​
​
​ Increase in lease liability ​ ​ ​
​
38
​ ​ ​ ​
​
384
 ​ ​
​
​ Lease payments ​ ​ ​
​
(82)
​ ​ ​ ​
​
(164)
 ​ ​
​
​ Foreign exchange on debt, and other ​ ​ ​
​
(240)
​ ​ ​ ​
​
(238)
 ​ ​
​
Total debt(1) – June 30, 2023
​ ​ ​ ​ 17 004 ​ ​ ​ ​ ​ 17 004 ​ ​
​
​
Less: Cash and cash equivalents – June 30, 2023
​ ​ ​ ​ 2 610 ​ ​ ​ ​ ​ 2 610 ​ ​
​
Net debt(1) – June 30, 2023
​ ​ ​ ​ 14 394 ​ ​ ​ ​ ​ 14 394 ​ ​
​
(1)
Non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.
​
The company’s total debt increased in the second quarter of 2023 primarily due to an increase in short-term indebtedness and net leases entered into during the period, partially offset by favourable foreign exchange rates on U.S. dollar denominated debt compared to March 31, 2023, and principal lease payments made during the second quarter of 2023.
The company’s total debt increased in the first six months of 2023 primarily due to an increase in short-term indebtedness and net leases entered into, and assumed with the Fort Hills acquisition, during the period, partially offset by favourable foreign exchange rates on U.S. dollar denominated debt compared to December 31, 2022, and principal lease payments made during the first six months of 2023.
As at June 30, 2023, Suncor’s net debt was $14.394 billion, compared to $15.714 billion at March 31, 2023, and $13.639 billion at December 31, 2022. The change in net debt was primarily due to the factors listed above, and the impacts of an increase in cash and cash equivalents.
Common Shares
​ ​ ​ ​
June 30,
​
​
(thousands)
​ ​
2023
​
​
Common shares
​ ​ ​ ​ 1 302 117 ​ ​
​
​ Common share options – exercisable ​ ​ ​
​
17 124
​ ​
​
​ Common share options – non-exercisable ​ ​ ​
​
3 357
 ​ ​
As at August 11, 2023, the total number of common shares outstanding was 1,300,418,024 and the total number of exercisable and non-exercisable common share options outstanding was 20,295,918. Once vested, each outstanding common share option is exercisable for one common share.
26   2023 Second Quarter   Suncor Energy Inc.
Share Repurchases
During the first quarter of 2023, the TSX accepted a notice filed by Suncor to renew its NCIB to purchase the company’s common shares through the facilities of the TSX, NYSE and/or alternative trading systems. The notice provides that, beginning February 17, 2023, and ending February 16, 2024, Suncor may purchase for cancellation up to 132,900,000 common shares, which is equal to approximately 10% of Suncor’s public float (as defined in the TSX Company Manual) as at February 3, 2023. On February 3, 2023, Suncor had 1,330,006,760 common shares issued and outstanding.
Between February 17, 2023, and August 11, 2023, pursuant to Suncor’s NCIB, Suncor repurchased 30,168,097 common shares on the open market, representing the equivalent of 2.3% of its common shares as at February 3, 2023, for $1.264 billion, at a weighted average price of $41.89 per share.
The actual number of common shares that may be purchased under the NCIB and the timing of any such purchases will be determined by Suncor. Suncor believes that, depending on the trading price of its common shares and other relevant factors, purchasing its own shares represents an attractive investment opportunity and is in the best interests of the company and its shareholders. The company does not expect the decision to allocate cash to repurchase shares will affect its long-term strategy.
​ ​ ​ ​
Three months ended
June 30
​ ​
Six months ended
June 30
​
​
($ millions, except as noted)
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ Share repurchase activities (thousands of common shares) ​ ​ ​
​
16 804
​ ​ ​ ​ ​ 53 513 ​ ​ ​ ​
​
36 740
 ​ ​ ​ ​ ​ 75 212 ​ ​
​
​
Weighted average repurchase price per share (dollars per share)
​ ​ ​
​
40.71
​ ​ ​ ​ ​ 47.70 ​ ​ ​ ​
​
42.41
 ​ ​ ​ ​ ​ 44.94 ​ ​
​
​ Share repurchase cost ​ ​ ​
​
684
​ ​ ​ ​ ​ 2 553 ​ ​ ​ ​
​
1 558
 ​ ​ ​ ​ ​ 3 380 ​ ​
Contractual Obligations, Commitments, Guarantees and Off-Balance Sheet Arrangements
In the normal course of business, the company is obligated to make future payments, including contractual obligations and non-cancellable commitments. Suncor has included these items in the Financial Condition and Liquidity section of the 2022 annual MD&A, with no material updates to note during the six months ended June 30, 2023, with the exception of an increase in commitments related to the company’s increased working interest in Fort Hills during the first quarter of 2023. Suncor does not believe it has any guarantees or off-balance sheet arrangements that have, or are reasonably likely to have, a current or future material effect on the company’s financial performance or financial condition, results of operations, liquidity or capital expenditures.
2023 Second Quarter   Suncor Energy Inc.   27
MANAGEMENT’S DISCUSSION AND ANALYSIS
7. QUARTERLY FINANCIAL DATA
Trends in Suncor’s quarterly revenue, earnings and adjusted funds from operations are driven primarily by production volumes, which can be significantly impacted by major maintenance events, changes in commodity prices and crude differentials, refining crack spreads, foreign exchange rates and other significant events impacting operations, such as operational incidents and the impacts of the COVID-19 pandemic.
Financial Summary
​
Three months ended
($ millions, unless otherwise noted)
​ ​
Jun 30
2023
 ​ ​
Mar 31
2023
​ ​
Dec 31
2022
​ ​
Sep 30
2022
​ ​
Jun 30
2022
​ ​
Mar 31
2022
​ ​
Dec 31
2021
​ ​
Sep 30
2021
​
​ Total production (mboe/d) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Oil Sands
​ ​ ​
​
679.1
​ ​ ​ ​ ​ 675.1 ​ ​ ​ ​ ​ 688.1 ​ ​ ​ ​ ​ 646.0 ​ ​ ​ ​ ​ 641.5 ​ ​ ​ ​ ​ 685.7 ​ ​ ​ ​ ​ 665.9 ​ ​ ​ ​ ​ 605.1 ​ ​
​
​
Exploration and Production
​ ​ ​
​
62.8
​ ​ ​ ​ ​ 67.0 ​ ​ ​ ​ ​ 75.0 ​ ​ ​ ​ ​ 78.1 ​ ​ ​ ​ ​ 78.7 ​ ​ ​ ​ ​ 80.4 ​ ​ ​ ​ ​ 77.4 ​ ​ ​ ​ ​ 93.5 ​ ​
​ Total upstream production ​ ​ ​
​
741.9
​ ​ ​ ​ ​ 742.1 ​ ​ ​ ​ ​ 763.1 ​ ​ ​ ​ ​ 724.1 ​ ​ ​ ​ ​ 720.2 ​ ​ ​ ​ ​ 766.1 ​ ​ ​ ​ ​ 743.3 ​ ​ ​ ​ ​ 698.6 ​ ​
​ Revenues and other income ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Gross revenues(1)
​ ​ ​
​
12 434
​ ​ ​ ​ ​ 12 272 ​ ​ ​ ​ ​ 14 754 ​ ​ ​ ​ ​ 15 869 ​ ​ ​ ​ ​ 17 815 ​ ​ ​ ​ ​ 14 469 ​ ​ ​ ​ ​ 11 897 ​ ​ ​ ​ ​ 10 758 ​ ​
​
​
Royalties
​ ​ ​
​
(715)
​ ​ ​ ​ ​ (358) ​ ​ ​ ​ ​ (834) ​ ​ ​ ​ ​ (925) ​ ​ ​ ​ ​ (1 680) ​ ​ ​ ​ ​ (1 132) ​ ​ ​ ​ ​ (748) ​ ​ ​ ​ ​ (613) ​ ​
​
Operating revenues, net of royalties(1)
​ ​ ​
​
11 719
​ ​ ​ ​ ​ 11 914 ​ ​ ​ ​ ​ 13 920 ​ ​ ​ ​ ​ 14 944 ​ ​ ​ ​ ​ 16 135 ​ ​ ​ ​ ​ 13 337 ​ ​ ​ ​ ​ 11 149 ​ ​ ​ ​ ​ 10 145 ​ ​
​
​
Other (loss) income
​ ​ ​
​
(3)
​ ​ ​ ​ ​ 342 ​ ​ ​ ​ ​ (65) ​ ​ ​ ​ ​ 113 ​ ​ ​ ​ ​ 69 ​ ​ ​ ​ ​ 14 ​ ​ ​ ​ ​ 10 ​ ​ ​ ​ ​ 68 ​ ​
​ ​ ​ ​ ​
​
11 716
​ ​ ​ ​ ​ 12 256 ​ ​ ​ ​ ​ 13 855 ​ ​ ​ ​ ​ 15 057 ​ ​ ​ ​ ​ 16 204 ​ ​ ​ ​ ​ 13 351 ​ ​ ​ ​ ​ 11 159 ​ ​ ​ ​ ​ 10 213 ​ ​
​ Net earnings (loss) ​ ​ ​
​
1 879
​ ​ ​ ​ ​ 2 052 ​ ​ ​ ​ ​ 2 741 ​ ​ ​ ​ ​ (609) ​ ​ ​ ​ ​ 3 996 ​ ​ ​ ​ ​ 2 949 ​ ​ ​ ​ ​ 1 553 ​ ​ ​ ​ ​ 877 ​ ​
​
​
Per common share – basic (dollars)
​ ​ ​
​
1.44
​ ​ ​ ​ ​ 1.54 ​ ​ ​ ​ ​ 2.03 ​ ​ ​ ​ ​ (0.45) ​ ​ ​ ​ ​ 2.84 ​ ​ ​ ​ ​ 2.06 ​ ​ ​ ​ ​ 1.07 ​ ​ ​ ​ ​ 0.59 ​ ​
​
​
Per common share – diluted (dollars)
​ ​ ​
​
1.43
​ ​ ​ ​ ​ 1.54 ​ ​ ​ ​ ​ 2.03 ​ ​ ​ ​ ​ (0.45) ​ ​ ​ ​ ​ 2.83 ​ ​ ​ ​ ​ 2.06 ​ ​ ​ ​ ​ 1.07 ​ ​ ​ ​ ​ 0.59 ​ ​
​ Adjusted operating earnings(2) ​ ​ ​
​
1 253
​ ​ ​ ​ ​ 1 809 ​ ​ ​ ​ ​ 2 432 ​ ​ ​ ​ ​ 2 565 ​ ​ ​ ​ ​ 3 814 ​ ​ ​ ​ ​ 2 755 ​ ​ ​ ​ ​ 1 294 ​ ​ ​ ​ ​ 1 043 ​ ​
​
​
Per common share(3)(4) (dollars)
​ ​ ​
​
0.96
​ ​ ​ ​ ​ 1.36 ​ ​ ​ ​ ​ 1.81 ​ ​ ​ ​ ​ 1.88 ​ ​ ​ ​ ​ 2.71 ​ ​ ​ ​ ​ 1.92 ​ ​ ​ ​ ​ 0.89 ​ ​ ​ ​ ​ 0.71 ​ ​
​ Adjusted funds from operations(2) ​ ​ ​
​
2 655
​ ​ ​ ​ ​ 3 002 ​ ​ ​ ​ ​ 4 189 ​ ​ ​ ​ ​ 4 473 ​ ​ ​ ​ ​ 5 345 ​ ​ ​ ​ ​ 4 094 ​ ​ ​ ​ ​ 3 144 ​ ​ ​ ​ ​ 2 641 ​ ​
​
​
Per common share(3)(4) (dollars)
​ ​ ​
​
2.03
​ ​ ​ ​ ​ 2.26 ​ ​ ​ ​ ​ 3.11 ​ ​ ​ ​ ​ 3.28 ​ ​ ​ ​ ​ 3.80 ​ ​ ​ ​ ​ 2.86 ​ ​ ​ ​ ​ 2.17 ​ ​ ​ ​ ​ 1.79 ​ ​
​ Cash flow provided by operating activities ​ ​ ​
​
2 803
​ ​ ​ ​ ​ 1 039 ​ ​ ​ ​ ​ 3 924 ​ ​ ​ ​ ​ 4 449 ​ ​ ​ ​ ​ 4 235 ​ ​ ​ ​ ​ 3 072 ​ ​ ​ ​ ​ 2 615 ​ ​ ​ ​ ​ 4 718 ​ ​
​
​
Per common share(4) (dollars)
​ ​ ​
​
2.14
​ ​ ​ ​ ​ 0.78 ​ ​ ​ ​ ​ 2.91 ​ ​ ​ ​ ​ 3.26 ​ ​ ​ ​ ​ 3.01 ​ ​ ​ ​ ​ 2.14 ​ ​ ​ ​ ​ 1.80 ​ ​ ​ ​ ​ 3.19 ​ ​
​ ROCE(3) (%) for the twelve months ended ​ ​ ​
​
12.8
​ ​ ​ ​ ​ 17.8 ​ ​ ​ ​ ​ 19.4 ​ ​ ​ ​ ​ 17.5 ​ ​ ​ ​ ​ 19.4 ​ ​ ​ ​ ​ 12.7 ​ ​ ​ ​ ​ 8.6 ​ ​ ​ ​ ​ 4.5 ​ ​
​
ROCE excluding impairments and impairment reversals(3) (%) for the twelve months ended
​ ​ ​
​
16.3
​ ​ ​ ​ ​ 21.6 ​ ​ ​ ​ ​ 22.9 ​ ​ ​ ​ ​ 21.0 ​ ​ ​ ​ ​ 18.2 ​ ​ ​ ​ ​ 12.4 ​ ​ ​ ​ ​ 8.2 ​ ​ ​ ​ ​ 4.9 ​ ​
​ Common share information (dollars) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Dividend per common share
​ ​ ​
​
0.52
​ ​ ​ ​ ​ 0.52 ​ ​ ​ ​ ​ 0.52 ​ ​ ​ ​ ​ 0.47 ​ ​ ​ ​ ​ 0.47 ​ ​ ​ ​ ​ 0.42 ​ ​ ​ ​ ​ 0.42 ​ ​ ​ ​ ​ 0.21 ​ ​
​
​
Share price at the end of trading
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Toronto Stock Exchange (Cdn$)
​ ​ ​
​
38.86
​ ​ ​ ​ ​ 41.96 ​ ​ ​ ​ ​ 42.95 ​ ​ ​ ​ ​ 38.90 ​ ​ ​ ​ ​ 45.16 ​ ​ ​ ​ ​ 40.70 ​ ​ ​ ​ ​ 31.65 ​ ​ ​ ​ ​ 26.26 ​ ​
​
​
New York Stock Exchange (US$)
​ ​ ​
​
29.32
​ ​ ​ ​ ​ 31.05 ​ ​ ​ ​ ​ 31.73 ​ ​ ​ ​ ​ 28.15 ​ ​ ​ ​ ​ 35.07 ​ ​ ​ ​ ​ 32.59 ​ ​ ​ ​ ​ 25.03 ​ ​ ​ ​ ​ 20.74 ​ ​
​
(1)
The company revised certain gross revenues and purchases of crude oil and products to align with the current period presentation. For the three months ended March 31, 2022, gross revenues and purchases of crude oil and products were decreased by $150 million, with no effect on net earnings.
​
(2)
Non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A. Adjusted operating earnings (loss) for each quarter are defined in the Non-GAAP and Other Financial Measures Advisory section and reconciled to GAAP measures in the Consolidated Financial Information and Segment Results and Analysis sections of each Quarterly Report to Shareholders issued by Suncor (Quarterly Reports) in respect of the relevant quarter. Adjusted funds from operations for each quarter are defined and reconciled to GAAP measures in the Non-GAAP and Other Financial Measures Advisory section of each Quarterly Report in respect of the relevant quarter, with such information being incorporated by reference herein and available on SEDAR+ at www.sedarplus.ca.
​
(3)
Contains non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A. Non-GAAP measures included in ROCE and ROCE excluding impairments and impairment reversals are defined and reconciled to GAAP measures in the Non-GAAP and Other Financial Measures Advisory section of each Quarterly Report in respect of the relevant quarter, with such information being incorporated by reference herein and available on SEDAR+ at www.sedarplus.ca.
​
(4)
Represented on a basic per share basis.
​
28   2023 Second Quarter   Suncor Energy Inc.
Business Environment
​
(average for the three months ended)
​ ​ ​ ​ ​
Jun 30
2023
 ​ ​
Mar 31
2023
​ ​
Dec 31
2022
​ ​
Sep 30
2022
​ ​
Jun 30
2022
​ ​
Mar 31
2022
​ ​
Dec 31
2021
​ ​
Sep 30
2021
​
​ WTI crude oil at Cushing ​ ​ US$/bbl ​ ​ ​
​
73.75
​ ​ ​ ​ ​ 76.10 ​ ​ ​ ​ ​ 82.65 ​ ​ ​ ​ ​ 91.65 ​ ​ ​ ​ ​ 108.40 ​ ​ ​ ​ ​ 94.40 ​ ​ ​ ​ ​ 77.15 ​ ​ ​ ​ ​ 70.55 ​ ​
​
​ Dated Brent crude ​ ​ US$/bbl ​ ​ ​
​
78.35
​ ​ ​ ​ ​ 81.25 ​ ​ ​ ​ ​ 88.65 ​ ​ ​ ​ ​ 100.95 ​ ​ ​ ​ ​ 113.75 ​ ​ ​ ​ ​ 101.50 ​ ​ ​ ​ ​ 79.70 ​ ​ ​ ​ ​ 73.45 ​ ​
​
​
Dated Brent/Maya FOB price differential
​ ​ US$/bbl ​ ​ ​
​
14.75
​ ​ ​ ​ ​ 18.40 ​ ​ ​ ​ ​ 17.70 ​ ​ ​ ​ ​ 17.95 ​ ​ ​ ​ ​ 11.65 ​ ​ ​ ​ ​ 14.30 ​ ​ ​ ​ ​ 8.60 ​ ​ ​ ​ ​ 7.80 ​ ​
​
​ MSW at Edmonton ​ ​ Cdn$/bbl ​ ​ ​
​
95.10
​ ​ ​ ​ ​ 99.05 ​ ​ ​ ​ ​ 110.05 ​ ​ ​ ​ ​ 116.85 ​ ​ ​ ​ ​ 137.80 ​ ​ ​ ​ ​ 115.75 ​ ​ ​ ​ ​ 93.25 ​ ​ ​ ​ ​ 83.75 ​ ​
​
​ WCS at Hardisty ​ ​ US$/bbl ​ ​ ​
​
58.70
​ ​ ​ ​ ​ 51.35 ​ ​ ​ ​ ​ 57.00 ​ ​ ​ ​ ​ 71.75 ​ ​ ​ ​ ​ 95.60 ​ ​ ​ ​ ​ 79.80 ​ ​ ​ ​ ​ 62.50 ​ ​ ​ ​ ​ 56.95 ​ ​
​
​ WTI-WCS light/heavy differential ​ ​ US$/bbl ​ ​ ​
​
(15.05)
​ ​ ​ ​ ​ (24.75) ​ ​ ​ ​ ​ (25.65) ​ ​ ​ ​ ​ (19.90) ​ ​ ​ ​ ​ (12.80) ​ ​ ​ ​ ​ (14.60) ​ ​ ​ ​ ​ (14.65) ​ ​ ​ ​ ​ (13.60) ​ ​
​
​ SYN-WTI (differential) premium ​ ​ US$/bbl ​ ​ ​
​
2.90
​ ​ ​ ​ ​ 2.10 ​ ​ ​ ​ ​ 4.15 ​ ​ ​ ​ ​ 8.80 ​ ​ ​ ​ ​ 6.05 ​ ​ ​ ​ ​ (1.30) ​ ​ ​ ​ ​ (1.80) ​ ​ ​ ​ ​ (1.60) ​ ​
​
​ Condensate at Edmonton ​ ​ US$/bbl ​ ​ ​
​
72.35
​ ​ ​ ​ ​ 79.85 ​ ​ ​ ​ ​ 83.40 ​ ​ ​ ​ ​ 87.35 ​ ​ ​ ​ ​ 108.35 ​ ​ ​ ​ ​ 96.15 ​ ​ ​ ​ ​ 79.10 ​ ​ ​ ​ ​ 69.20 ​ ​
​
​ Natural gas (Alberta spot) at AECO ​ ​ Cdn$/GJ ​ ​ ​
​
2.35
​ ​ ​ ​ ​ 3.05 ​ ​ ​ ​ ​ 4.90 ​ ​ ​ ​ ​ 4.15 ​ ​ ​ ​ ​ 6.90 ​ ​ ​ ​ ​ 4.50 ​ ​ ​ ​ ​ 4.45 ​ ​ ​ ​ ​ 3.40 ​ ​
​
​ Alberta Power Pool Price ​ ​ Cdn$/MWh ​ ​ ​
​
159.80
​ ​ ​ ​ ​ 142.00 ​ ​ ​ ​ ​ 213.95 ​ ​ ​ ​ ​ 221.40 ​ ​ ​ ​ ​ 122.45 ​ ​ ​ ​ ​ 90.00 ​ ​ ​ ​ ​ 107.30 ​ ​ ​ ​ ​ 100.35 ​ ​
​
​ New York Harbor 2-1-1 crack(1) ​ ​ US$/bbl ​ ​ ​
​
32.30
​ ​ ​ ​ ​ 36.70 ​ ​ ​ ​ ​ 52.75 ​ ​ ​ ​ ​ 46.70 ​ ​ ​ ​ ​ 60.05 ​ ​ ​ ​ ​ 28.25 ​ ​ ​ ​ ​ 20.65 ​ ​ ​ ​ ​ 20.90 ​ ​
​
​ Chicago 2-1-1 crack(1) ​ ​ US$/bbl ​ ​ ​
​
28.60
​ ​ ​ ​ ​ 31.55 ​ ​ ​ ​ ​ 39.20 ​ ​ ​ ​ ​ 43.30 ​ ​ ​ ​ ​ 49.40 ​ ​ ​ ​ ​ 20.20 ​ ​ ​ ​ ​ 16.90 ​ ​ ​ ​ ​ 20.45 ​ ​
​
​ Portland 2-1-1 crack(1) ​ ​ US$/bbl ​ ​ ​
​
37.30
​ ​ ​ ​ ​ 37.40 ​ ​ ​ ​ ​ 50.70 ​ ​ ​ ​ ​ 57.30 ​ ​ ​ ​ ​ 63.45 ​ ​ ​ ​ ​ 33.80 ​ ​ ​ ​ ​ 25.35 ​ ​ ​ ​ ​ 26.70 ​ ​
​
​ Gulf Coast 2-1-1 crack(1) ​ ​ US$/bbl ​ ​ ​
​
29.15
​ ​ ​ ​ ​ 37.65 ​ ​ ​ ​ ​ 40.20 ​ ​ ​ ​ ​ 41.85 ​ ​ ​ ​ ​ 52.55 ​ ​ ​ ​ ​ 26.80 ​ ​ ​ ​ ​ 19.65 ​ ​ ​ ​ ​ 19.55 ​ ​
​
​ U.S. Renewable Volume Obligation ​ ​ US$/bbl ​ ​ ​
​
7.70
​ ​ ​ ​ ​ 8.20 ​ ​ ​ ​ ​ 8.55 ​ ​ ​ ​ ​ 8.10 ​ ​ ​ ​ ​ 7.80 ​ ​ ​ ​ ​ 6.45 ​ ​ ​ ​ ​ 6.10 ​ ​ ​ ​ ​ 7.35 ​ ​
​
​ Suncor custom 5-2-2-1 index(2) ​ ​ US$/bbl ​ ​ ​
​
34.20
​ ​ ​ ​ ​ 42.80 ​ ​ ​ ​ ​ 51.90 ​ ​ ​ ​ ​ 45.45 ​ ​ ​ ​ ​ 51.45 ​ ​ ​ ​ ​ 32.25 ​ ​ ​ ​ ​ 28.05 ​ ​ ​ ​ ​ 27.60 ​ ​
​
​ Exchange rate ​ ​ US$/Cdn$ ​ ​ ​
​
0.74
​ ​ ​ ​ ​ 0.74 ​ ​ ​ ​ ​ 0.74 ​ ​ ​ ​ ​ 0.77 ​ ​ ​ ​ ​ 0.78 ​ ​ ​ ​ ​ 0.79 ​ ​ ​ ​ ​ 0.79 ​ ​ ​ ​ ​ 0.79 ​ ​
​
​ Exchange rate (end of period) ​ ​ US$/Cdn$ ​ ​ ​
​
0.76
​ ​ ​ ​ ​ 0.74 ​ ​ ​ ​ ​ 0.74 ​ ​ ​ ​ ​ 0.73 ​ ​ ​ ​ ​ 0.78 ​ ​ ​ ​ ​ 0.80 ​ ​ ​ ​ ​ 0.79 ​ ​ ​ ​ ​ 0.78 ​ ​
​
(1)
2-1-1 crack spreads are indicators of the refining margin generated by converting two barrels of WTI into one barrel of gasoline and one barrel of diesel. The crack spreads presented here generally approximate the regions into which the company sells refined products through retail and wholesale channels.
​
(2)
Suncor has developed an indicative 5-2-2-1 index based on publicly available pricing data to more accurately reflect the company’s realized refining and marketing gross margin. For more details, including how the custom index is calculated, see Suncor’s 2022 annual MD&A.
​
2023 Second Quarter   Suncor Energy Inc.   29
MANAGEMENT’S DISCUSSION AND ANALYSIS
8. OTHER ITEMS
Accounting Policies and New IFRS Standards
Suncor’s significant accounting policies and a summary of recently announced accounting standards are described in the Accounting Policies and Critical Accounting Estimates section of Suncor’s 2022 annual MD&A and in notes 3 and 5 of Suncor’s audited Consolidated Financial Statements for the year ended December 31, 2022.
Critical Accounting Estimates
The preparation of financial statements in accordance with GAAP requires management to make estimates, judgments and assumptions that affect reported assets, liabilities, revenues and expenses, gains and losses, and disclosures of contingencies. These estimates and assumptions are subject to change based on experience and new information. Critical accounting estimates are those that require management to make assumptions about matters that are highly uncertain at the time the estimate is made. Critical accounting estimates are also those estimates that, where a different estimate could have been used or where changes in the estimate that are reasonably likely to occur, would have a material impact on the company’s financial condition, changes in financial condition or financial performance. Critical accounting estimates and judgments are reviewed annually by the Audit Committee of the Board of Directors. A detailed description of Suncor’s critical accounting estimates is provided in note 4 to the audited Consolidated Financial Statements for the year ended December 31, 2022, and in the Accounting Policies and Critical Accounting Estimates section of Suncor’s 2022 annual MD&A.
Financial Instruments
Suncor periodically enters into derivative contracts such as forwards, futures, swaps, options and costless collars to manage exposure to fluctuations in commodity prices and foreign exchange rates, and to optimize the company’s position with respect to interest payments. The company also uses physical and financial energy derivatives to earn trading profits. For more information on Suncor’s financial instruments and the related financial risk factors, see note 27 of the audited Consolidated Financial Statements for the year ended December 31, 2022, note 9 to the unaudited interim Consolidated Financial Statements for the three and six months ended June 30, 2023, and the Financial Condition and Liquidity section of the 2022 annual MD&A.
Control Environment
Based on their evaluation as at June 30, 2023, Suncor’s Chief Executive Officer and Chief Financial Officer concluded that the company’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the United States Securities Exchange Act of 1934, as amended (the Exchange Act)), are effective to ensure that information required to be disclosed by the company in reports that are filed or submitted to Canadian and U.S. securities authorities is recorded, processed, summarized and reported within the time periods specified in Canadian and U.S. securities laws. In April 2022, the company implemented a new enterprise resource planning (ERP) system across the entire organization; accordingly, the company has modified and added a number of internal controls, including verifications and testing to ensure data integrity. Additionally, on June 25, 2023, the company confirmed that it had experienced a cybersecurity incident that resulted in a breach of customer data from the Petro-Points program and impacted certain transactional systems for a short period following the incident. The company has taken actions to monitor and maintain appropriate internal controls during the period following the cybersecurity incident and, accordingly, has implemented interim, or modified certain existing, internal controls. There were no other changes in the internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) that occurred during the three-month period ended June 30, 2023, that have materially affected, or are reasonably likely to materially affect, the company’s internal control over financial reporting. Management will continue to periodically evaluate the company’s disclosure controls and procedures and internal control over financial reporting and will make any modifications from time to time as deemed necessary.
Based on their inherent limitations, disclosure controls and procedures and internal control over financial reporting may not prevent or detect misstatements, and even those controls determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.
Corporate Guidance
There have been no changes to Suncor’s previously announced 2023 corporate guidance ranges (which was originally disclosed via press release on November 29, 2022, and updated via Suncor’s press releases dated February 14, 2023, and May 8, 2023), a copy of which is available on www.sedarplus.ca.
30   2023 Second Quarter   Suncor Energy Inc.
9. NON-GAAP AND OTHER FINANCIAL MEASURES ADVISORY
Certain financial measures in this MD&A – namely adjusted operating earnings (loss), adjusted funds from (used in) operations, measures contained in ROCE and ROCE excluding impairments and impairment reversals, price realizations, free funds flow, Oil Sands operations cash operating costs, Fort Hills cash operating costs, Syncrude cash operating costs, refining and marketing gross margin, refining operating expense, net debt, total debt, LIFO inventory valuation methodology and related per share or per barrel amounts or metrics that contain such measures – are not prescribed by GAAP. These non-GAAP financial measures are included because management uses the information to analyze business performance, leverage and liquidity, as applicable, and it may be useful to investors on the same basis. These non-GAAP financial measures do not have any standardized meaning and, therefore, are unlikely to be comparable to similar measures presented by other companies. Therefore, these non-GAAP financial measures should not be considered in isolation or as a substitute for measures of performance prepared in accordance with GAAP. Except as otherwise indicated, these non-GAAP financial measures are calculated and disclosed on a consistent basis from period to period. Specific adjusting items may only be relevant in certain periods.
Adjusted Operating Earnings (Loss)
Adjusted operating earnings (loss) is a non-GAAP financial measure that adjusts net earnings (loss) for significant items that are not indicative of operating performance. Management uses adjusted operating earnings (loss) to evaluate operating performance because management believes it provides better comparability between periods. Adjusted operating earnings (loss) is reconciled to net earnings (loss) in the Consolidated Financial Information and Segment Results and Analysis sections of this MD&A.
Bridge Analyses of Adjusted Operating Earnings (Loss)
Within this MD&A, the company presents a chart that illustrates the change in adjusted operating earnings (loss) from the comparative period through key variance factors. These factors are analyzed in the Adjusted Operating Earnings (Loss) narratives following the bridge analyses in particular sections of this MD&A. This bridge analysis is presented because management uses this presentation to evaluate performance. All reconciling items are presented on a before-tax basis and adjusted for income taxes in the Income Tax bridge factor.
•
The factor for Sales Volumes and Mix is calculated based on sales volumes and mix for the Oil Sands and E&P segments and refinery production volumes for the R&M segment.
​
•
The factor for Price, Margin and Other Revenue includes upstream price realizations before royalties, with the exception of Libya, which is net of royalties, and realized commodity risk management activities. Also included are refining and marketing gross margins, other operating revenue and the net impacts of sales and purchases of third-party crude, including product purchased for use as diluent in the company’s Oil Sands operations and subsequently sold as part of diluted bitumen.
​
•
The factor for Royalties excludes the impact of Libya, as royalties in Libya are included in Price, Margin and Other Revenue as described above.
​
•
The factor for Inventory Valuation is comprised of changes in the FIFO inventory valuation and the realized portion of commodity risk management activities reported in the R&M segment, as well as the impact of the deferral or realization of profit or loss on crude oil sales from the Oil Sands segment to Suncor’s refineries reported in the Corporate and Eliminations segment.
​
•
The factor for Operating and Transportation Expense includes project startup costs, OS&G expense and transportation expense.
​
•
The factor for Financing Expense and Other includes financing expenses, other income, operational foreign exchange gains and losses and changes in gains and losses on disposal of assets that are not adjusted operating earnings (loss) adjustments.
​
•
The factor for DD&A and Exploration Expense includes depreciation, depletion and amortization expense, and exploration expense.
​
•
The factor for Income Tax includes the company’s current and deferred income tax expense on adjusted operating earnings, changes in statutory income tax rates and other income tax adjustments.
​
2023 Second Quarter   Suncor Energy Inc.   31
MANAGEMENT’S DISCUSSION AND ANALYSIS
Return on Capital Employed (ROCE) and ROCE Excluding Impairments and Impairment Reversals
ROCE is a non-GAAP ratio that management uses to analyze operating performance and the efficiency of Suncor’s capital allocation process. ROCE is calculated using the non-GAAP financial measures adjusted net earnings and average capital employed. Adjusted net earnings are calculated by taking net earnings (loss) and adjusting after-tax amounts for unrealized foreign exchange on U.S. dollar denominated debt and net interest expense. Average capital employed is calculated as a twelve-month average of the capital employed balance at the beginning of the twelve-month period and the month-end capital employed balances throughout the remainder of the twelve-month period. Figures for capital employed at the beginning and end of the twelve-month period are presented to show the changes in the components of the calculation over the twelve-month period.
​
For the twelve months ended June 30
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
($ millions, except as noted)
​ ​ ​ ​ ​ ​ ​ ​
2023
 ​ ​
2022
​
​ Adjustments to net earnings ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Net earnings
​ ​ ​ ​ ​ ​ ​ ​ ​
​
6 063
​ ​ ​ ​ ​ 9 375 ​ ​
​
​
Add after-tax amounts for:
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Unrealized foreign exchange loss on U.S. dollar denominated debt
​ ​ ​ ​ ​ ​ ​ ​ ​
​
269
​ ​ ​ ​ ​ 426 ​ ​
​
​
Net interest expense
​ ​ ​ ​ ​ ​ ​ ​ ​
​
590
​ ​ ​ ​ ​ 638 ​ ​
​ Adjusted net earnings(1) ​ ​ ​ ​ A ​ ​ ​ ​
​
6 922
​ ​ ​ ​ ​ 10 439 ​ ​
​ Capital employed – beginning of twelve-month period ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Net debt(2)
​ ​ ​ ​ ​ ​ ​ ​ ​
​
15 699
​ ​ ​ ​ ​ 18 681 ​ ​
​
​
Shareholders’ equity
​ ​ ​ ​ ​ ​ ​ ​ ​
​
39 765
​ ​ ​ ​ ​ 36 209 ​ ​
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 55 464 ​ ​ ​ ​
​
54 890
 ​ ​
​ Capital employed – end of twelve-month period ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Net debt(2)
​ ​ ​ ​ ​ ​ ​ ​ ​
​
14 394
​ ​ ​ ​ ​ 15 699 ​ ​
​
​
Shareholders’ equity
​ ​ ​ ​ ​ ​ ​ ​ ​
​
40 819
​ ​ ​ ​ ​ 39 765 ​ ​
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 55 213 ​ ​ ​ ​
​
55 464
 ​ ​
​ Average capital employed ​ ​ ​ ​ B ​ ​ ​ ​
​
54 273
​ ​ ​ ​ ​ 53 812 ​ ​
​ ROCE (%)(3) ​ ​ ​ ​ A/B ​ ​ ​ ​
​
12.8
​ ​ ​ ​ ​ 19.4 ​ ​
​
(1)
Total before-tax impact of adjustments is $1.060 billion for the twelve months ended June 30, 2023, and $1.305 billion for the twelve months ended June 30, 2022.
​
(2)
Net debt is a non-GAAP financial measure.
​
(3)
ROCE would have been 16.3% for the twelve months ended June 30, 2023, excluding the impact of the impairment of  $3.397 billion ($2.586 billion after-tax) in the third quarter of 2022. ROCE would have been 18.2% for the twelve months ended June 30, 2022, excluding the impact of the impairment reversal of  $715 million ($542 million after-tax) and impairment of  $70 million ($47 million after-tax) in the second quarter of 2022 and the impact of the impairment reversal of  $221 million ($168 million after-tax) in the third quarter of 2021.
​
32   2023 Second Quarter   Suncor Energy Inc.
Adjusted Funds From (Used In) Operations
Adjusted funds from (used in) operations is a non-GAAP financial measure that adjusts a GAAP measure – cash flow provided by operating activities – for changes in non-cash working capital, which management uses to analyze operating performance and liquidity. Changes to non-cash working capital can be impacted by, among other factors, commodity price volatility, the timing of offshore feedstock purchases and payments for commodity and income taxes, the timing of cash flows related to accounts receivable and accounts payable, and changes in inventory, which management believes reduces comparability between periods.
Adjusted funds from (used in) operations for each quarter are separately defined and reconciled to the cash flow provided by the operating activities measure in the Non-GAAP and Other Financial Measures Advisory section of each respective MD&A or quarterly report to shareholders, as applicable, for the related quarter, with such information being incorporated by reference herein and available on SEDAR+ at www.sedarplus.ca.
​
Three months ended June 30
​ ​
Oil Sands
​ ​
Exploration and
Production
​ ​
Refining and
Marketing
​ ​
Corporate and
Eliminations
​ ​
Income
Taxes
​ ​
Total
​
​
($ millions)
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​
Earnings (loss) before income taxes
​ ​ ​
​
1 267
​ ​ ​ ​ ​ 2 892 ​ ​ ​ ​
​
956
​ ​ ​ ​ ​ 1 361 ​ ​ ​ ​
​
518
​ ​ ​ ​ ​ 2 007 ​ ​ ​ ​
​
(390)
​ ​ ​ ​ ​ (851) ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
2 351
 ​ ​ ​ ​ ​ 5 409 ​ ​
​
​ Adjustments for: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Depreciation, depletion, amortization and impairment
​ ​ ​
​
1 183
​ ​ ​ ​ ​ 1 279 ​ ​ ​ ​
​
142
​ ​ ​ ​ ​ (505) ​ ​ ​ ​
​
224
​ ​ ​ ​ ​ 199 ​ ​ ​ ​
​
28
​ ​ ​ ​ ​ 25 ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
1 577
 ​ ​ ​ ​ ​ 998 ​ ​
​
​
Accretion
​ ​ ​
​
115
​ ​ ​ ​ ​ 58 ​ ​ ​ ​
​
18
​ ​ ​ ​ ​ 16 ​ ​ ​ ​
​
1
​ ​ ​ ​ ​ 2 ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
134
 ​ ​ ​ ​ ​ 76 ​ ​
​
​
Unrealized foreign exchange (gain) loss on U.S. dollar denominated debt
​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
(244)
​ ​ ​ ​ ​ 352 ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
(244)
 ​ ​ ​ ​ ​ 352 ​ ​
​
​
Change in fair value of financial instruments and trading inventory
​ ​ ​
​
18
​ ​ ​ ​ ​ (22) ​ ​ ​ ​
​
12
​ ​ ​ ​ ​ (22) ​ ​ ​ ​
​
16
​ ​ ​ ​ ​ (89) ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
46
 ​ ​ ​ ​ ​ (133) ​ ​
​
​
(Gain) loss on disposal of assets
​ ​ ​
​
—
​ ​ ​ ​ ​ 1 ​ ​ ​ ​
​
(607)
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
(7)
​ ​ ​ ​ ​ (11) ​ ​ ​ ​
​
(18)
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
(632)
 ​ ​ ​ ​ ​ (10) ​ ​
​
​
Share-based compensation
​ ​ ​
​
23
​ ​ ​ ​ ​ 53 ​ ​ ​ ​
​
1
​ ​ ​ ​ ​ 3 ​ ​ ​ ​
​
8
​ ​ ​ ​ ​ 21 ​ ​ ​ ​
​
(13)
​ ​ ​ ​ ​ 57 ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
19
 ​ ​ ​ ​ ​ 134 ​ ​
​
​
Settlement of decommissioning and restoration liabilities
​ ​ ​
​
(65)
​ ​ ​ ​ ​ (59) ​ ​ ​ ​
​
(2)
​ ​ ​ ​ ​ (18) ​ ​ ​ ​
​
(5)
​ ​ ​ ​ ​ (3) ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
(72)
 ​ ​ ​ ​ ​ (80) ​ ​
​
​
Other
​ ​ ​
​
16
​ ​ ​ ​ ​ 29 ​ ​ ​ ​
​
1
​ ​ ​ ​ ​ 6 ​ ​ ​ ​
​
26
​ ​ ​ ​ ​ 1 ​ ​ ​ ​
​
(18)
​ ​ ​ ​ ​ 15 ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
25
 ​ ​ ​ ​ ​ 51 ​ ​
​
​
Current income tax expense
​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
(549)
​ ​ ​ ​ ​ (1 452) ​ ​ ​ ​
​
(549)
 ​ ​ ​ ​ ​ (1 452) ​ ​
​
Adjusted funds from (used in) operations
​ ​ ​
​
2 557
​ ​ ​ ​ ​ 4 231 ​ ​ ​ ​
​
521
​ ​ ​ ​ ​ 841 ​ ​ ​ ​
​
781
​ ​ ​ ​ ​ 2 127 ​ ​ ​ ​
​
(655)
​ ​ ​ ​ ​ (402) ​ ​ ​ ​
​
(549)
​ ​ ​ ​ ​ (1 452) ​ ​ ​ ​
​
2 655
 ​ ​ ​ ​ ​ 5 345 ​ ​
​
​
Change in non-cash working capital
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
148
 ​ ​ ​ ​ ​ (1 110) ​ ​
​
Cash flow provided by operating activities
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
2 803
 ​ ​ ​ ​ ​ 4 235 ​ ​
2023 Second Quarter   Suncor Energy Inc.   33
MANAGEMENT’S DISCUSSION AND ANALYSIS
​
Six months ended June 30
​ ​
Oil Sands
​ ​
Exploration and
Production
​ ​
Refining and
Marketing
​ ​
Corporate and
Eliminations
​ ​
Income
Taxes
​ ​
Total
​
​
($ millions)
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ Earnings (loss) before income
taxes 		​ ​ ​
​
2 744
​ ​ ​ ​ ​ 5 201 ​ ​ ​ ​
​
1 331
​ ​ ​ ​ ​ 2 006 ​ ​ ​ ​
​
1 511
​ ​ ​ ​ ​ 3 424 ​ ​ ​ ​
​
(521)
​ ​ ​ ​ ​ (1 374) ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
5 065
 ​ ​ ​ ​ ​ 9 257 ​ ​
​
​ Adjustments for: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Depreciation, depletion, amortization and impairment
​ ​ ​
​
2 321
​ ​ ​ ​ ​ 2 384 ​ ​ ​ ​
​
269
​ ​ ​ ​ ​ (376) ​ ​ ​ ​
​
444
​ ​ ​ ​ ​ 411 ​ ​ ​ ​
​
59
​ ​ ​ ​ ​ 50 ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
3 093
 ​ ​ ​ ​ ​ 2 469 ​ ​
​
​
Accretion
​ ​ ​
​
229
​ ​ ​ ​ ​ 121 ​ ​ ​ ​
​
35
​ ​ ​ ​ ​ 30 ​ ​ ​ ​
​
3
​ ​ ​ ​ ​ 3 ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
267
 ​ ​ ​ ​ ​ 154 ​ ​
​
​
Unrealized foreign
exchange (gain) loss on U.S.
dollar denominated debt
​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
(241)
​ ​ ​ ​ ​ 206 ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
(241)
 ​ ​ ​ ​ ​ 206 ​ ​
​
​
Change in fair value of financial instruments and trading inventory
​ ​ ​
​
45
​ ​ ​ ​ ​ (43) ​ ​ ​ ​
​
(13)
​ ​ ​ ​ ​ (39) ​ ​ ​ ​
​
44
​ ​ ​ ​ ​ (125) ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
76
 ​ ​ ​ ​ ​ (207) ​ ​
​
​
(Gain) loss on disposal of assets
​ ​ ​
​
—
​ ​ ​ ​ ​ (1) ​ ​ ​ ​
​
(608)
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
(18)
​ ​ ​ ​ ​ (11) ​ ​ ​ ​
​
(320)
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
(946)
 ​ ​ ​ ​ ​ (12) ​ ​
​
​
Share-based compensation
​ ​ ​
​
(37)
​ ​ ​ ​ ​ 81 ​ ​ ​ ​
​
2
​ ​ ​ ​ ​ 2 ​ ​ ​ ​
​
(19)
​ ​ ​ ​ ​ 26 ​ ​ ​ ​
​
(130)
​ ​ ​ ​ ​ 81 ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
(184)
 ​ ​ ​ ​ ​ 190 ​ ​
​
​
Settlement of decommissioning and restoration liabilities
​ ​ ​
​
(189)
​ ​ ​ ​ ​ (147) ​ ​ ​ ​
​
(4)
​ ​ ​ ​ ​ (18) ​ ​ ​ ​
​
(12)
​ ​ ​ ​ ​ (5) ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ (1) ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
(205)
 ​ ​ ​ ​ ​ (171) ​ ​
​
​
Other
​ ​ ​
​
32
​ ​ ​ ​ ​ 49 ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ (40) ​ ​ ​ ​
​
22
​ ​ ​ ​ ​ 1 ​ ​ ​ ​
​
(35)
​ ​ ​ ​ ​ (29) ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
19
 ​ ​ ​ ​ ​ (19) ​ ​
​
​
Current income tax expense
​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
(1 287)
​ ​ ​ ​ ​ (2 428) ​ ​ ​ ​
​
(1 287)
 ​ ​ ​ ​ ​ (2 428) ​ ​
​ Adjusted funds from (used in)
operations 		​ ​ ​
​
5 145
​ ​ ​ ​ ​ 7 645 ​ ​ ​ ​
​
1 012
​ ​ ​ ​ ​ 1 565 ​ ​ ​ ​
​
1 975
​ ​ ​ ​ ​ 3 724 ​ ​ ​ ​
​
(1 188)
​ ​ ​ ​ ​ (1 067) ​ ​ ​ ​
​
(1 287)
​ ​ ​ ​ ​ (2 428) ​ ​ ​ ​
​
5 657
 ​ ​ ​ ​ ​ 9 439 ​ ​
​
​
Change in non-cash working capital
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
(1 815)
 ​ ​ ​ ​ ​ (2 132) ​ ​
​
Cash flow provided by operating activities
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
3 842
 ​ ​ ​ ​ ​ 7 307 ​ ​
34   2023 Second Quarter   Suncor Energy Inc.
Free Funds Flow
Free funds flow is a non-GAAP financial measure that is calculated by taking adjusted funds from operations and subtracting capital expenditures, including capitalized interest. Free funds flow reflects cash available for increasing distributions to shareholders and reducing debt. Management uses free funds flow to measure the capacity of the company to increase returns to shareholders and to grow Suncor’s business.
​
Three months ended June 30
​ ​
Oil Sands
​ ​
Exploration and
Production
​ ​
Refining and
Marketing
​ ​
Corporate and
Eliminations
​ ​
Income
Taxes
​ ​
Total
​
​
($ millions)
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ Adjusted funds from
(used in) operations 		​ ​ ​
​
2 557
​ ​ ​ ​ ​ 4 231 ​ ​ ​ ​
​
521
​ ​ ​ ​ ​ 841 ​ ​ ​ ​
​
781
​ ​ ​ ​ ​ 2 127 ​ ​ ​ ​
​
(655)
​ ​ ​ ​ ​ (402) ​ ​ ​ ​
​
(549)
​ ​ ​ ​ ​ (1 452) ​ ​ ​ ​
​
2 655
 ​ ​ ​ ​ ​ 5 345 ​ ​
​
​ Capital expenditures
including capitalized
interest(1) 		​ ​ ​
​
(1 043)
​ ​ ​ ​ ​ (905) ​ ​ ​ ​
​
(182)
​ ​ ​ ​ ​ (115) ​ ​ ​ ​
​
(377)
​ ​ ​ ​ ​ (261) ​ ​ ​ ​
​
(11)
​ ​ ​ ​ ​ (14) ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
(1 613)
 ​ ​ ​ ​ ​ (1 295) ​ ​
​ Free funds flow ​ ​ ​
​
1 514
​ ​ ​ ​ ​ 3 326 ​ ​ ​ ​
​
339
​ ​ ​ ​ ​ 726 ​ ​ ​ ​
​
404
​ ​ ​ ​ ​ 1 866 ​ ​ ​ ​
​
(666)
​ ​ ​ ​ ​ (416) ​ ​ ​ ​
​
(549)
​ ​ ​ ​ ​ (1 452) ​ ​ ​ ​
​
1 042
 ​ ​ ​ ​ ​ 4 050 ​ ​
​
Six months ended June 30
​ ​
Oil Sands
​ ​
Exploration and
Production
​ ​
Refining and
Marketing
​ ​
Corporate and
Eliminations
​ ​
Income
Taxes
​ ​
Total
​
​
($ millions)
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ Adjusted funds from
(used in) operations 		​ ​ ​
​
5 145
​ ​ ​ ​ ​ 7 645 ​ ​ ​ ​
​
1 012
​ ​ ​ ​ ​ 1 565 ​ ​ ​ ​
​
1 975
​ ​ ​ ​ ​ 3 724 ​ ​ ​ ​
​
(1 188)
​ ​ ​ ​ ​ (1 067) ​ ​ ​ ​
​
(1 287)
​ ​ ​ ​ ​ (2 428) ​ ​ ​ ​
​
5 657
 ​ ​ ​ ​ ​ 9 439 ​ ​
​
​ Capital expenditures
including capitalized
interest(1) 		​ ​ ​
​
(1 853)
​ ​ ​ ​ ​ (1 573) ​ ​ ​ ​
​
(320)
​ ​ ​ ​ ​ (198) ​ ​ ​ ​
​
(502)
​ ​ ​ ​ ​ (393) ​ ​ ​ ​
​
(24)
​ ​ ​ ​ ​ (142) ​ ​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​ ​ ​
​
(2 699)
 ​ ​ ​ ​ ​ (2 306) ​ ​
​ Free funds flow ​ ​ ​
​
3 292
​ ​ ​ ​ ​ 6 072 ​ ​ ​ ​
​
692
​ ​ ​ ​ ​ 1 367 ​ ​ ​ ​
​
1 473
​ ​ ​ ​ ​ 3 331 ​ ​ ​ ​
​
(1 212)
​ ​ ​ ​ ​ (1 209) ​ ​ ​ ​
​
(1 287)
​ ​ ​ ​ ​ (2 428) ​ ​ ​ ​
​
2 958
 ​ ​ ​ ​ ​ 7 133 ​ ​
​
(1)
Excludes capital expenditures related to assets previously held for sale of  $66 million and $108 million in the second quarter and first six months of 2023, respectively, compared to $36 million and $55 million in the second quarter and first six months of 2022, respectively.
​
Oil Sands Operations, Fort Hills and Syncrude Cash Operating Costs
Cash operating costs are calculated by adjusting Oil Sands segment OS&G expense for non-production costs and excess power capacity. Significant non-production costs include, but are not limited to, share-based compensation adjustments, research costs, project startup costs and adjustments to reflect the cost of internal transfers in the receiving asset at the cost of production versus the cost of purchase. Non-production costs at Fort Hills and Syncrude also include, but are not limited to, an adjustment to reflect internally produced diesel from Oil Sands operations at the cost of production. Excess power capacity represents excess power revenue from cogeneration units that is recorded in operating revenues. Oil Sands operations excess power capacity and other also includes, but is not limited to, the natural gas expense recorded as part of a non-monetary arrangement involving a third-party processor. Oil Sands operations, Fort Hills and Syncrude production volumes are gross of internally consumed diesel and feedstock transfers between assets. Oil Sands operations, Fort Hills and Syncrude cash operating costs are reconciled in the Segment Results and Analysis – Oil Sands section of this MD&A. Management uses cash operating costs to measure operating performance.
2023 Second Quarter   Suncor Energy Inc.   35
MANAGEMENT’S DISCUSSION AND ANALYSIS
Refining and Marketing Gross Margin and Refining Operating Expense
Refining and marketing gross margins and refining operating expense are non-GAAP financial measures. Refining and marketing gross margin, on a FIFO basis, is calculated by adjusting R&M segment operating revenue, other income and purchases of crude oil and products (all of which are GAAP measures) for intersegment marketing fees recorded in intersegment revenues. Refining and marketing gross margin, on a LIFO basis, is further adjusted for the impacts of FIFO inventory valuation recorded in purchases of crude oil and products and risk management activities recorded in other income (loss). Refinery operating expense is calculated by adjusting R&M segment OS&G for i) non-refining costs pertaining to the company’s supply, marketing and ethanol businesses; and ii) non-refining costs that management believes do not relate to the production of refined products, including, but not limited to, share-based compensation and enterprise shared service allocations. Management uses refining and marketing gross margin and refining operating expense to measure operating performance on a production barrel basis.
​ ​ ​ ​
Three months ended
June 30
​ ​
Six months ended
June 30
​
​
($ millions, except as noted)
​ ​
2023
 ​ ​
2022
​ ​
2023
 ​ ​
2022
​
​ Refining and marketing gross margin reconciliation ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Operating revenues
​ ​ ​
​
7 272
​ ​ ​ ​ ​ 10 239 ​ ​ ​ ​
​
14 445
 ​ ​ ​ ​ ​ 18 094 ​ ​
​
​
Purchases of crude oil and products
​ ​ ​
​
(5 797)
​ ​ ​ ​ ​ (7 385) ​ ​ ​ ​
​
(11 151)
 ​ ​ ​ ​ ​ (12 867) ​ ​
​ ​ ​ ​ ​
​
1 475
​ ​ ​ ​ ​ 2 854 ​ ​ ​ ​
​
3 294
 ​ ​ ​ ​ ​ 5 227 ​ ​
​
​
Other (loss) income
​ ​ ​
​
13
​ ​ ​ ​ ​ 35 ​ ​ ​ ​
​
169
 ​ ​ ​ ​ ​ (75) ​ ​
​
​
Non-refining and marketing margin
​ ​ ​
​
(33)
​ ​ ​ ​ ​ (6) ​ ​ ​ ​
​
(35)
 ​ ​ ​ ​ ​ (19) ​ ​
​
Refining and marketing gross margin – FIFO
​ ​ ​
​
1 455
​ ​ ​ ​ ​ 2 883 ​ ​ ​ ​
​
3 428
 ​ ​ ​ ​ ​ 5 133 ​ ​
​
​
Refinery production(1) (mbbls)
​ ​ ​
​
38 214
​ ​ ​ ​ ​ 37 517 ​ ​ ​ ​
​
73 797
 ​ ​ ​ ​ ​ 79 828 ​ ​
​
Refining and marketing gross margin – FIFO ($/bbl)
​ ​ ​
​
38.10
​ ​ ​ ​ ​ 76.85 ​ ​ ​ ​
​
46.45
 ​ ​ ​ ​ ​ 64.30 ​ ​
​
FIFO and risk management activities adjustment
​ ​ ​
​
116
​ ​ ​ ​ ​ (525) ​ ​ ​ ​
​
247
 ​ ​ ​ ​ ​ (1 254) ​ ​
​
Refining and marketing gross margin – LIFO
​ ​ ​
​
1 571
​ ​ ​ ​ ​ 2 358 ​ ​ ​ ​
​
3 675
 ​ ​ ​ ​ ​ 3 879 ​ ​
​
Refining and marketing gross margin – LIFO ($/bbl)
​ ​ ​
​
41.10
​ ​ ​ ​ ​ 62.85 ​ ​ ​ ​
​
49.80
 ​ ​ ​ ​ ​ 48.60 ​ ​
​ Refining operating expense reconciliation ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
​
Operating, selling and general expense
​ ​ ​
​
604
​ ​ ​ ​ ​ 592 ​ ​ ​ ​
​
1 254
 ​ ​ ​ ​ ​ 1 151 ​ ​
​
​
Non-refining costs
​ ​ ​
​
(300)
​ ​ ​ ​ ​ (323) ​ ​ ​ ​
​
(660)
 ​ ​ ​ ​ ​ (617) ​ ​
​
Refining operating expense
​ ​ ​
​
304
​ ​ ​ ​ ​ 269 ​ ​ ​ ​
​
594
 ​ ​ ​ ​ ​ 534 ​ ​
​
​
Refinery production(1) (mbbls)
​ ​ ​
​
38 214
​ ​ ​ ​ ​ 37 517 ​ ​ ​ ​
​
73 797
 ​ ​ ​ ​ ​ 79 828 ​ ​
​
Refining operating expense ($/bbl)
​ ​ ​
​
7.95
​ ​ ​ ​ ​ 7.15 ​ ​ ​ ​
​
8.05
 ​ ​ ​ ​ ​ 6.70 ​ ​
​
(1)
Refinery production is the output of the refining process, and differs from crude oil processed as a result of volumetric adjustments for non-crude feedstock, volumetric gain associated with the refining process and changes in unfinished product inventories.
​
36   2023 Second Quarter   Suncor Energy Inc.
Impact of First-in, First-out (FIFO) Inventory Valuation on Refining and Marketing Net Earnings (Loss)
GAAP requires the use of a FIFO inventory valuation methodology. For Suncor, this results in a disconnect between the sales prices for refined products, which reflect current market conditions, and the amount recorded as the cost of sale for the related refinery feedstock, which reflects market conditions at the time the feedstock was purchased. This lag between purchase and sale can be anywhere from several weeks to several months, and is influenced by the time to receive crude after purchase (which can be several weeks for foreign offshore crude purchases), regional crude inventory levels, the completion of refining processes, transportation time to distribution channels and regional refined product inventory levels.
Suncor prepares and presents an estimate of the impact of using a FIFO inventory valuation methodology compared to a LIFO methodology, because management uses the information to analyze operating performance and compare itself against refining peers that are permitted to use LIFO inventory valuation under U.S. GAAP.
The company’s estimate is not derived from a standardized calculation and, therefore, may not be directly comparable to similar measures presented by other companies, and should not be considered in isolation or as a substitute for measures of performance prepared in accordance with GAAP or U.S. GAAP.
Net Debt and Total Debt
Net debt and total debt are non-GAAP financial measures that management uses to analyze the financial condition of the company. Total debt includes short-term debt, current portion of long-term debt, current portion of long-term lease liabilities, long-term debt and long-term lease liabilities (all of which are GAAP measures). Net debt is equal to total debt less cash and cash equivalents (a GAAP measure).
​ ​ ​ ​
June 30
 ​ ​
December 31
​
​
($ millions, except as noted)
​ ​
2023
 ​ ​
2022
​
​
Short-term debt
​ ​ ​
​
4 169
​ ​ ​ ​ ​ 2 807 ​ ​
​
​
Current portion of long-term debt
​ ​ ​
​
—
​ ​ ​ ​ ​ — ​ ​
​
​
Current portion of long-term lease liabilities
​ ​ ​
​
350
​ ​ ​ ​ ​ 317 ​ ​
​
​
Long-term debt
​ ​ ​
​
9 611
​ ​ ​ ​ ​ 9 800 ​ ​
​
​
Long-term lease liabilities
​ ​ ​
​
2 874
​ ​ ​ ​ ​ 2 695 ​ ​
​ Total debt ​ ​ ​
​
17 004
​ ​ ​ ​ ​ 15 619 ​ ​
​
​
Less: Cash and cash equivalents
​ ​ ​
​
2 610
​ ​ ​ ​ ​ 1 980 ​ ​
​ Net debt ​ ​ ​
​
14 394
​ ​ ​ ​ ​ 13 639 ​ ​
​
​ Shareholders’ equity ​ ​ ​
​
40 819
​ ​ ​ ​ ​ 39 367 ​ ​
​ Total debt plus shareholders’ equity ​ ​ ​
​
57 823
​ ​ ​ ​ ​ 54 986 ​ ​
​ Total debt to total debt plus shareholders’ equity (%) ​ ​ ​
​
29.4
​ ​ ​ ​ ​ 28.4 ​ ​
​ Net debt to net debt plus shareholders’ equity (%) ​ ​ ​
​
26.1
​ ​ ​ ​ ​ 25.7 ​ ​
​ Net debt to net debt plus shareholders’ equity – excluding leases (%) ​ ​ ​
​
21.5
​ ​ ​ ​ ​ 21.3 ​ ​
2023 Second Quarter   Suncor Energy Inc.   37
MANAGEMENT’S DISCUSSION AND ANALYSIS
Price Realizations
Price realizations are a non-GAAP measure used by management to measure profitability. Oil Sands price realizations are presented on a crude product basis and are derived from the Oil Sands segmented statement of net earnings (loss), after adjusting for items not directly attributable to the revenues associated with production. E&P price realizations are presented on an asset location basis and are derived from the E&P segmented statement of net earnings (loss), after adjusting for other E&P assets, such as Libya, for which price realizations are not provided.
Oil Sands Price Realizations
​
For the quarter ended
​ ​
June 30, 2023
 ​ ​
June 30, 2022
​
​
($ millions, except as noted)
​ ​
Non-
Upgraded
Bitumen
 ​ ​
Upgraded – 
Net
SCO and
Diesel
 ​ ​
Average
Crude
 ​ ​
Oil
Sands
Segment
 ​ ​
Non-
Upgraded
Bitumen
​ ​
Upgraded – 
Net
SCO and
Diesel
​ ​
Average
Crude
​ ​
Oil
Sands
Segment
​
​
Operating revenues
​ ​ ​
​
1 446
​ ​ ​ ​
​
4 732
 ​ ​ ​ ​
​
6 178
 ​ ​ ​ ​
​
6 178
 ​ ​ ​ ​ ​ 2 221 ​ ​ ​ ​ ​ 6 541 ​ ​ ​ ​ ​ 8 762 ​ ​ ​ ​ ​ 8 762 ​ ​
​
​
Other (loss) income
​ ​ ​
​
26
​ ​ ​ ​
​
(31)
 ​ ​ ​ ​
​
(5)
 ​ ​ ​ ​
​
(5)
 ​ ​ ​ ​ ​ (4) ​ ​ ​ ​ ​ 20 ​ ​ ​ ​ ​ 16 ​ ​ ​ ​ ​ 16 ​ ​
​
​
Purchases of crude oil and products
​ ​ ​
​
(327)
​ ​ ​ ​
​
(34)
 ​ ​ ​ ​
​
(361)
 ​ ​ ​ ​
​
(361)
 ​ ​ ​ ​ ​ (467) ​ ​ ​ ​ ​ (94) ​ ​ ​ ​ ​ (561) ​ ​ ​ ​ ​ (561) ​ ​
​
​
Gross realization adjustment(1)
​ ​ ​
​
15
​ ​ ​ ​
​
(52)
 ​ ​ ​ ​
​
(37)
 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 27 ​ ​ ​ ​ ​ (105) ​ ​ ​ ​ ​ (78) ​ ​ ​ ​ ​ ​ ​ ​
​ Gross realization ​ ​ ​
​
1 160
​ ​ ​ ​
​
4 615
 ​ ​ ​ ​
​
5 775
 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 1 777 ​ ​ ​ ​ ​ 6 362 ​ ​ ​ ​ ​ 8 139 ​ ​ ​ ​ ​ ​ ​ ​
​ Transportation and distribution ​ ​ ​
​
(119)
​ ​ ​ ​
​
(176)
 ​ ​ ​ ​
​
(295)
 ​ ​ ​ ​
​
(295)
 ​ ​ ​ ​ ​ (97) ​ ​ ​ ​ ​ (190) ​ ​ ​ ​ ​ (287) ​ ​ ​ ​ ​ (287) ​ ​
​ Price realization ​ ​ ​
​
1 041
​ ​ ​ ​
​
4 439
 ​ ​ ​ ​
​
5 480
 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 1 680 ​ ​ ​ ​ ​ 6 172 ​ ​ ​ ​ ​ 7 852 ​ ​ ​ ​ ​ ​ ​ ​
​ Sales volumes (mbbls) ​ ​ ​
​
14 887
​ ​ ​ ​
​
46 550
 ​ ​ ​ ​
​
61 437
 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 14 808 ​ ​ ​ ​ ​ 44 992 ​ ​ ​ ​ ​ 59 800 ​ ​ ​ ​ ​ ​ ​ ​
​ Price realization per barrel ​ ​ ​
​
69.91
​ ​ ​ ​
​
95.36
 ​ ​ ​ ​
​
89.19
 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 113.41 ​ ​ ​ ​ ​ 137.17 ​ ​ ​ ​ ​ 131.28 ​ ​ ​ ​ ​ ​ ​ ​
​
For the six months ended
​ ​
June 30, 2023
 ​ ​
June 30, 2022
​
​
($ millions, except as noted)
​ ​
Non-
Upgraded
Bitumen
 ​ ​
Upgraded – 
Net
SCO and
Diesel
 ​ ​
Average
Crude
 ​ ​
Oil
Sands
Segment
 ​ ​
Non-
Upgraded
Bitumen
​ ​
Upgraded – 
Net
SCO and
Diesel
​ ​
Average
Crude
​ ​
Oil
Sands
Segment
​
​
Operating revenues
​ ​ ​
​
2 681
​ ​ ​ ​
​
9 564
 ​ ​ ​ ​
​
12 245
 ​ ​ ​ ​
​
12 245
 ​ ​ ​ ​ ​ 4 003 ​ ​ ​ ​ ​ 12 229 ​ ​ ​ ​ ​ 16 232 ​ ​ ​ ​ ​ 16 232 ​ ​
​
​
Other (loss) income
​ ​ ​
​
150
​ ​ ​ ​
​
(40)
 ​ ​ ​ ​
​
110
 ​ ​ ​ ​
​
110
 ​ ​ ​ ​ ​ (41) ​ ​ ​ ​ ​ 64 ​ ​ ​ ​ ​ 23 ​ ​ ​ ​ ​ 23 ​ ​
​
​
Purchases of crude oil and products
​ ​ ​
​
(664)
​ ​ ​ ​
​
(105)
 ​ ​ ​ ​
​
(769)
 ​ ​ ​ ​
​
(769)
 ​ ​ ​ ​ ​ (857) ​ ​ ​ ​ ​ (157) ​ ​ ​ ​ ​ (1 014) ​ ​ ​ ​ ​ (1 014) ​ ​
​
​
Gross realization adjustment(1)
​ ​ ​
​
(90)
​ ​ ​ ​
​
(160)
 ​ ​ ​ ​
​
(250)
 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 94 ​ ​ ​ ​ ​ (241) ​ ​ ​ ​ ​ (147) ​ ​ ​ ​ ​ ​ ​ ​
​ Gross realization ​ ​ ​
​
2 077
​ ​ ​ ​
​
9 259
 ​ ​ ​ ​
​
11 336
 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 3 199 ​ ​ ​ ​ ​ 11 895 ​ ​ ​ ​ ​ 15 094 ​ ​ ​ ​ ​ ​ ​ ​
​ Transportation and distribution ​ ​ ​
​
(228)
​ ​ ​ ​
​
(337)
 ​ ​ ​ ​
​
(565)
 ​ ​ ​ ​
​
(565)
 ​ ​ ​ ​ ​ (184) ​ ​ ​ ​ ​ (396) ​ ​ ​ ​ ​ (580) ​ ​ ​ ​ ​ (580) ​ ​
​ Price realization ​ ​ ​
​
1 849
​ ​ ​ ​
​
8 922
 ​ ​ ​ ​
​
10 771
 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 3 015 ​ ​ ​ ​ ​ 11 499 ​ ​ ​ ​ ​ 14 514 ​ ​ ​ ​ ​ ​ ​ ​
​ Sales volumes (mbbls) ​ ​ ​
​
30 555
​ ​ ​ ​
​
91 911
 ​ ​ ​ ​
​
122 466
 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 28 638 ​ ​ ​ ​ ​ 91 584 ​ ​ ​ ​ ​ 120 222 ​ ​ ​ ​ ​ ​ ​ ​
​ Price realization per barrel ​ ​ ​
​
60.47
​ ​ ​ ​
​
97.08
 ​ ​ ​ ​
​
87.95
 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 105.24 ​ ​ ​ ​ ​ 125.57 ​ ​ ​ ​ ​ 120.72 ​ ​ ​ ​ ​ ​ ​ ​
​
(1)
Reflects the items not directly attributed to revenues received from the sale of proprietary crude and net non-proprietary activity at its deemed point of sale.
​
38   2023 Second Quarter   Suncor Energy Inc.
E&P Price Realizations
​
For the quarter ended
​ ​
June 30, 2023
 ​ ​
June 30, 2022
​
​
($ millions, except as noted)
​ ​
E&P
International
 ​ ​
E&P
Canada
 ​ ​
Other(1)(2)
 ​ ​
E&P
Segment
 ​ ​
E&P
International
​ ​
E&P
Canada
​ ​
Other(1)(2)
​ ​
E&P
Segment
​
​ Operating revenues ​ ​ ​
​
122
​ ​ ​ ​
​
549
 ​ ​ ​ ​
​
142
 ​ ​ ​ ​
​
813
 ​ ​ ​ ​ ​ 292 ​ ​ ​ ​ ​ 776 ​ ​ ​ ​ ​ 151 ​ ​ ​ ​ ​ 1 219 ​ ​
​
​ Transportation and distribution ​ ​ ​
​
(4)
​ ​ ​ ​
​
(13)
 ​ ​ ​ ​
​
(4)
 ​ ​ ​ ​
​
(21)
 ​ ​ ​ ​ ​ (6) ​ ​ ​ ​ ​ (19) ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ (25) ​ ​
​ Price realization ​ ​ ​
​
118
​ ​ ​ ​
​
536
 ​ ​ ​ ​
​
138
 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 286 ​ ​ ​ ​ ​ 757 ​ ​ ​ ​ ​ 151 ​ ​ ​ ​ ​ ​ ​ ​
​ Sales volumes (mbbls) ​ ​ ​
​
1 155
​ ​ ​ ​
​
5 065
 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 2 240 ​ ​ ​ ​ ​ 5 404 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ Price realization per barrel ​ ​ ​
​
102.44
​ ​ ​ ​
​
105.81
 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 127.84 ​ ​ ​ ​ ​ 140.24 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
For the six months ended
​ ​
June 30, 2023
 ​ ​
June 30, 2022
​
​
($ millions, except as noted)
​ ​
International
 ​ ​
East
Coast
Canada
 ​ ​
Other(1)(2)
 ​ ​
E&P
Segment
 ​ ​
International
​ ​
East
Coast
Canada
​ ​
Other(1)(2)
​ ​
E&P
Segment
​
​ Operating revenues ​ ​ ​
​
306
​ ​ ​ ​
​
1 007
 ​ ​ ​ ​
​
234
 ​ ​ ​ ​
​
1 547
 ​ ​ ​ ​ ​ 564 ​ ​ ​ ​ ​ 1 339 ​ ​ ​ ​ ​ 331 ​ ​ ​ ​ ​ 2 234 ​ ​
​
​ Transportation and distribution ​ ​ ​
​
(9)
​ ​ ​ ​
​
(27)
 ​ ​ ​ ​
​
(6)
 ​ ​ ​ ​
​
(42)
 ​ ​ ​ ​ ​ (12) ​ ​ ​ ​ ​ (36) ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ (48) ​ ​
​ Price realization ​ ​ ​
​
297
​ ​ ​ ​
​
980
 ​ ​ ​ ​
​
228
 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 552 ​ ​ ​ ​ ​ 1 303 ​ ​ ​ ​ ​ 331 ​ ​ ​ ​ ​ ​ ​ ​
​ Sales volumes (mbbls) ​ ​ ​
​
2 729
​ ​ ​ ​
​
9 454
 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 4 576 ​ ​ ​ ​ ​ 9 864 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ Price realization per barrel ​ ​ ​
​
109.01
​ ​ ​ ​
​
103.63
 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 120.58 ​ ​ ​ ​ ​ 132.05 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​
(1)
Reflects other E&P assets, such as Libya, for which price realizations are not provided.
​
(2)
Production from the company’s Libya operations has been presented in the E&P section of this MD&A on an economic basis. Revenue and royalties from the company’s Libya operations are presented under the working-interest basis, which is required for presentation purposes in the company’s financial statements. In the second quarter of 2023, revenue included a gross-up amount of  $108 million, with an offsetting amount of  $48 million in royalties in the E&P segment and $60 million in income tax expense recorded at the consolidated level. In the first six months of 2023, revenue included a gross-up amount of  $175 million, with an offsetting amount of  $83 million in royalties in the E&P segment and $92 million in income tax expense reported at the consolidated level. In the second quarter of 2022, revenue included a gross-up amount of  $113 million, with an offsetting amount of  $87 million in royalties in the E&P segment and $26 million in income tax expense reported at the consolidated level. In the first six months of 2022, revenue included a gross-up amount of  $251 million, with an offsetting amount of  $147 million in royalties in the E&P segment and $104 million in income tax expense reported at the consolidated level.
​
2023 Second Quarter   Suncor Energy Inc.   39
MANAGEMENT’S DISCUSSION AND ANALYSIS
10. COMMON ABBREVIATIONS
The following is a list of abbreviations that may be used in this MD&A:
Measurement
​ ​
Places and Currencies
​
bbl ​ ​ barrel ​ ​ U.S. ​ ​ United States ​
bbls/d ​ ​ barrels per day ​ ​ U.K. ​ ​ United Kingdom ​
mbbls/d ​ ​ thousands of barrels per day ​ ​ ​ ​ ​ ​ ​
​ ​ ​ ​ ​ ​
$ or Cdn$
​ ​ Canadian dollars ​
boe ​ ​ barrels of oil equivalent ​ ​ US$ ​ ​ United States dollars ​
boe/d ​ ​ barrels of oil equivalent per day ​ ​ ​ ​ ​ ​ ​
mboe ​ ​ thousands of barrels of oil equivalent ​ ​ ​ ​ ​ ​ ​
mboe/d ​ ​ thousands of barrels of oil equivalent per day ​ ​
Financial and Business Environment​
​
​ ​ ​ ​ ​ ​ Q2 ​ ​ Three months ended June 30 ​
GJ ​ ​ Gigajoule ​ ​ DD&A ​ ​ Depreciation, depletion and amortization ​
​ ​ ​ ​ ​ ​ WTI ​ ​ West Texas Intermediate ​
mcf ​ ​ thousands of cubic feet of natural gas ​ ​ WCS ​ ​ Western Canadian Select ​
mcfe ​ ​ thousands of cubic feet of natural gas equivalent ​ ​ SCO ​ ​ Synthetic crude oil ​
​ ​ ​ ​ ​ ​ SYN ​ ​ Synthetic crude oil benchmark ​
MW ​ ​ megawatts ​ ​ MSW ​ ​ Mixed Sweet Blend ​
MWh ​ ​ megawatts per hour ​ ​ NYMEX ​ ​ New York Mercantile Exchange ​
​ ​ ​ ​ ​ ​ YTD ​ ​ Year to date ​
40   2023 Second Quarter   Suncor Energy Inc.
11. ADVISORIES
Measurement Conversions
Certain crude oil and natural gas liquids volumes have been converted to mcfe on the basis of one bbl to six mcf. Also, certain natural gas volumes have been converted to boe or mboe on the same basis. Any figure presented in mcfe, boe or mboe may be misleading, particularly if used in isolation. A conversion ratio of one bbl of crude oil or natural gas liquids to six mcf of natural gas is based on an energy-equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, conversion on a 6:1 basis may be misleading as an indication of value.
Forward-Looking Information
This MD&A contains certain forward-looking statements and other information based on Suncor’s current expectations, estimates, projections and assumptions that were made by the company in light of information available at the time the statement was made and consider Suncor’s experience and its perception of historical trends, including expectations and assumptions concerning: the accuracy of reserves estimates; commodity prices and interest and foreign exchange rates; the performance of assets and equipment; uncertainty related to geopolitical conflict; capital efficiencies and cost savings; applicable laws and government policies; future production rates; the sufficiency of budgeted capital expenditures in carrying out planned activities; the availability and cost of labour, services and infrastructure; the satisfaction by third parties of their obligations to Suncor; the development and execution of projects; and the receipt, in a timely manner, of regulatory and third-party approvals. All statements and information that address expectations or projections about the future, and other statements and information about Suncor’s strategy for growth, expected and future expenditures or investment decisions, commodity prices, costs, schedules, production volumes, operating and financial results, future financing and capital activities, and the expected impact of future commitments are forward-looking statements. Some of the forward-looking statements may be identified by words like “expects”, “anticipates”, “will”, “estimates”, “plans”, “scheduled”, “intends”, “believes”, “projects”, “indicates”, “could”, “focus”, “vision”, “goal”, “outlook”, “proposed”, “target”, “objective”, “continue”, “should”, “may”, “future”, “potential”, “opportunity”, “would”, “priority”, “strategy” and similar expressions. Forward-looking statements in this MD&A include references to:
•
Suncor’s strategy, focus, goals and priorities and the expected benefits therefrom;
​
•
Suncor’s belief that its indicative 5-2-2-1 index will continue to be an appropriate measure against Suncor’s actual results;
​
•
Suncor’s expectation that the cybersecurity incident will not have a material impact on the company’s 2023 financial results;
​
•
Expectations regarding planned maintenance events, including planned turnaround activities at Oil Sands Base Upgrader 2 and Fort Hills and planned maintenance activities scheduled at Firebag, MacKay River and Syncrude as well as the company’s Edmonton and Montreal refineries, and the timing and impacts thereof;
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statements regarding Suncor’s planned 2023 capital spending program of $5.4 billion to $5.8 billion, including Suncor’s management’s belief that it will have the capital resources to fund it and to meet current and future working capital requirements through cash and cash equivalents balances, cash flow provided by operating activities, available committed credit facilities, issuing commercial paper and, if needed, accessing capital markets;
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the objectives of Suncor’s short-term investment portfolio and Suncor’s expectation that the maximum weighted average term to maturity of the short-term investment portfolio will not exceed six months, and that all investments will be with counterparties with investment-grade debt ratings;
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the company’s priority regarding the management of debt levels and liquidity given the company’s long-term plans and future expected volatility in the pricing environment, Suncor’s belief that a phased and flexible approach to existing and future projects should assist Suncor in its ability to manage project costs and debt levels and Suncor’s expectation that its early debt repayments will have a significant impact on the company’s long-term debt and interest payments on long-term debt;
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the company’s belief that it does not have any guarantees or off-balance sheet arrangements that have, or are reasonably likely to have, a current or future material effect on the company’s financial performance or financial condition, results of operations, liquidity or capital expenditures; and
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statements about the NCIB, including the amount, timing and manner of purchases under the NCIB, that depending on the trading price of its common shares and other relevant factors, repurchasing its common shares represents an attractive investment opportunity and is in the best interest of the company and its shareholders and the expectation that the decision to allocate cash to repurchase shares will not affect its long-term strategy.
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MANAGEMENT’S DISCUSSION AND ANALYSIS
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 Suncor. Suncor’s actual results may differ materially from those expressed or implied by its forward-looking statements, so readers are cautioned not to place undue reliance on them. The financial and operating performance of the company’s reportable operating segments, specifically Oil Sands, E&P and R&M, may be affected by a number of factors.
Factors that affect Suncor’s Oil Sands segment include, but are not limited to, volatility in the prices for crude oil and other production, and the related impacts of fluctuating light/heavy and sweet/sour crude oil differentials; changes in the demand for refinery feedstock and diesel fuel, including the possibility that refiners that process the company’s proprietary production will be closed, experience equipment failure or other accidents; Suncor’s ability to operate its Oil Sands facilities reliably in order to meet production targets; the output of newly commissioned facilities, the performance of which may be difficult to predict during initial operations; Suncor’s dependence on pipeline capacity and other logistical constraints, which may affect the company’s ability to distribute products to market and which may cause the company to delay or cancel planned growth projects in the event of insufficient takeaway capacity; Suncor’s ability to finance Oil Sands economic investment and asset sustainment and maintenance capital expenditures; the availability of bitumen feedstock for upgrading operations, which can be negatively affected by poor ore grade quality, unplanned mine equipment and extraction plant maintenance, tailings storage, and In Situ reservoir and equipment performance, or the unavailability of third-party bitumen; changes in operating costs, including the cost of labour, natural gas and other energy sources used in oil sands processes; and the company’s ability to complete projects, including planned maintenance events, both on time and on budget, which could be impacted by competition from other projects (including other oil sands projects) for goods and services and demands on infrastructure in Alberta’s Wood Buffalo region and the surrounding area (including housing, roads and schools).
Factors that affect Suncor’s E&P segment include, but are not limited to, volatility in crude oil and natural gas prices; operational risks and uncertainties associated with oil and gas activities, including unexpected formations or pressures, premature declines of reservoirs, fires, blow-outs, equipment failures and other accidents, uncontrollable flows of crude oil, natural gas or well fluids, and pollution and other environmental risks; adverse weather conditions, which could disrupt output from producing assets or impact drilling programs, resulting in increased costs and/or delays in bringing on new production; political, economic and socioeconomic risks associated with Suncor’s foreign operations, including the unpredictability of operating in Libya due to ongoing political unrest; and market demand for mineral rights and producing properties, potentially leading to losses on disposition or increased property acquisition costs.
Factors that affect our R&M segment include, but are not limited to, fluctuations in demand and supply for refined products that impact the company’s margins; market competition, including potential new market entrants; the company’s ability to reliably operate refining and marketing facilities in order to meet production or sales targets; and risks and uncertainties affecting construction or planned maintenance schedules, including the availability of labour and other impacts of competing projects drawing on the same resources during the same time period.
Additional risks, uncertainties and other factors that could influence the financial and operating performance of all of Suncor’s operating segments and activities include, but are not limited to, changes in general economic, market and business conditions, such as commodity prices, interest rates and currency exchange rates (including as a result of demand and supply effects resulting from the COVID-19 pandemic and the actions of OPEC+); fluctuations in supply and demand for Suncor’s products; the successful and timely implementation of capital projects, including growth projects and regulatory projects; risks associated with the development and execution of Suncor’s major projects and the commissioning and integration of new facilities; the possibility that completed maintenance activities may not improve operational performance or the output of related facilities; the risk that projects and initiatives intended to achieve cash flow growth and/or reductions in operating costs may not achieve the expected results in the time anticipated or at all; competitive actions of other companies, including increased competition from other oil and gas companies or from companies that provide alternative sources of energy; labour and material shortages; actions by government authorities, including the imposition or reassessment of, or changes to, taxes, fees, royalties, duties and other government-imposed compliance costs; changes to laws and government policies that could impact the company’s business, including environmental (including climate change), royalty and tax laws and policies; the ability and willingness of parties with whom Suncor has material relationships to perform their obligations to the company; the unavailability of, or outages to, third-party infrastructure that could cause disruptions to production or prevent the company from being able to transport its products; the occurrence of a protracted operational outage, a major safety or environmental incident, or unexpected events such as fires (including forest fires), equipment failures and other similar events affecting Suncor or other parties whose operations or assets directly or indirectly affect Suncor; the potential for security breaches of Suncor’s information technology and infrastructure by malicious persons or entities, and the unavailability or failure of such systems to perform as anticipated as a result of such breaches; security threats and terrorist or activist activities; the risk that competing business objectives may exceed Suncor’s capacity to adopt and implement change; risks and uncertainties associated with obtaining regulatory, third-party and stakeholder approvals outside of Suncor’s control for the company’s operations, projects, initiatives and exploration and development activities and the satisfaction of any conditions to approvals; the potential for disruptions to operations and construction projects as a result of Suncor’s relationships with labour unions that represent employees at the company’s facilities; the company’s ability to find new oil and gas reserves that can be developed economically; the accuracy of Suncor’s reserves, resources and future production estimates; market instability affecting Suncor’s ability to borrow in the capital debt markets at acceptable rates or to issue other securities at acceptable prices; maintaining an optimal debt to cash flow ratio; the success of the company’s marketing and logistics activities using derivatives and other financial instruments; the cost of compliance with current and future environmental laws, including climate change laws; risks
42   2023 Second Quarter   Suncor Energy Inc.
relating to increased activism and public opposition to fossil fuels and oil sands; risks and uncertainties associated with closing a transaction for the purchase or sale of a business, asset or oil and gas property, including estimates of the final consideration to be paid or received; the ability of counterparties to comply with their obligations in a timely manner; risks associated with joint arrangements in which the company has an interest; risks associated with land claims and Indigenous consultation requirements; the risk that the company may be subject to litigation; the impact of technology and risks associated with developing and implementing new technologies; and the accuracy of cost estimates, some of which are provided at the conceptual or other preliminary stage of projects and prior to commencement or conception of the detailed engineering that is needed to reduce the margin of error and increase the level of accuracy. The foregoing important factors are not exhaustive.
Many of these risk factors and other assumptions related to Suncor’s forward-looking statements are discussed in further detail throughout this MD&A, and in the company’s 2022 annual MD&A, the 2022 AIF and Form 40-F on file with Canadian securities commissions at www.sedarplus.ca and the United States Securities and Exchange Commission at www.sec.gov. Readers are also referred to the risk factors and assumptions described in other MD&As that Suncor files from time to time with securities regulatory authorities. Copies of these MD&As are available without charge from the company.
The forward-looking statements contained in this MD&A are made as of the date of this MD&A. Except as required by applicable securities laws, we assume no obligation to update publicly or otherwise revise any forward-looking statements or the foregoing risks and assumptions affecting such forward-looking statements, whether as a result of new information, future events or otherwise.
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