6-K - SU - Equibles

FORM 6-K

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

Report of Foreign Private Issuer

Pursuant to Rule 13a - 16 or 15d - 16 of

the Securities Exchange Act of 1934

For the month of: May 2025	Commission File Number: 1-12384

SUNCOR ENERGY INC.

(Name of registrant)

150 – 6th Avenue S.W.

P.O. Box 2844

Calgary, Alberta

Canada, T2P 3E3

Indicate by check mark whether the registrant files or will file annual reports under cover of Form 20-F or Form 40-F:

Form 20-F         ¨                        Form 40-F         x

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

		SUNCOR ENERGY INC.
Date:	May 6 , 2025	By:	“Shawn Poirier”
			Shawn Poirier <br><br>Assistant Corporate Secretary

EXHIBIT INDEX

Exhibit	Description of Exhibit
99.1	News Release dated May 6, 2025, Suncor Energy reports first quarter 2025 results
99.2	Report to Shareholders for the first quarter ended March 31, 2025

Exhibit 99.1

Suncor Energy reports first quarter 2025 results

Unless otherwise noted, all financial figures are unaudited, presentedin Canadian dollars (Cdn$), and derived from the company’s condensed consolidated financial statements which are based on Canadiangenerally accepted accounting principles (GAAP), specifically International Financial Reporting Standards (IFRS) as issued by the InternationalAccounting Standards Board (IASB), and are prepared in accordance with International Accounting Standard (IAS) 34 Interim Financial Reporting.Production volumes are presented on a working-interest basis, before royalties, except for production values from the company's Libyaoperations, which are presented on an economic basis. Certain financial measures referred to in this news release (adjusted funds fromoperations, adjusted operating earnings, free funds flow and net debt) are not prescribed by Canadian generally accepted accounting principles(GAAP). See the Non-GAAP Financial Measures section of this news release. References to Oil Sands operations exclude Suncor Energy Inc.’sownership of Fort Hills and interest in Syncrude.

Calgary, Alberta (May 6, 2025)

First Quarter Highlights

·	Generated over $3.0 billion in adjusted funds from operations and $1.9 billion in free funds flow.
·	Returned $1.5 billion to shareholders, with $750 million in share repurchases and $705 million in dividends.
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·	Upstream production of 853,000 barrels per day (bbls/d), the highest first quarter in company history.
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·	Refining throughput of 483,000 bbls/d, the highest first quarter in company history.
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·	Refined product sales of 605,000 bbls/d, the highest first quarter in company history.
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·	Exceptional asset utilization with upgraders at 102% and refineries at 104%.
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“Our strong first quarter financial and operating performance maintained the momentum established in 2024, as we remain laser focused on continuing to deliver safe, reliable, and cost-effective operations. Our results demonstrate this commitment, as represented by record performance across both the upstream and downstream,” said Rich Kruger, Suncor’s President and Chief Executive Officer. “Our focus on the fundamentals, integrated business model, and continually improving cost structure enable us to deliver free funds flow and shareholder value despite the current volatile business environment.”

Suncor Energy<br><br> <br>150 6 Avenue S.W. Calgary,<br> Alberta T2P 3E3<br><br> <br>suncor.com

First Quarter Results

Financial Highlights	Q1		Q4		Q1
($ millions, unless otherwise noted)	2025		2024		2024
Net earnings		1 689		818		1 610
Per common share^(1)^ (dollars)		1.36		0.65		1.25
Adjusted operating earnings^(2)^		1 629		1 566		1 817
Per common share^(1)(2)^ (dollars)		1.31		1.25		1.41
Adjusted funds from operations^(2)^		3 045		3 493		3 169
Per common share^(1)(2)^ (dollars)		2.46		2.78		2.46
Cash flow provided by operating activities		2 156		5 083		2 787
Per common share^(1)^ (dollars)		1.74		4.05		2.16
Capital and exploration expenditures^(3)^		1 087		1 498		1 237
Free funds flow^(2)^		1 900		1 923		1 858
Dividend per common share^(1)^ (dollars)		0.57		0.57		0.55
Share repurchases per common share^(4)^ (dollars)		0.61		0.80		0.23
Returns to shareholders^(5)^		1 455		1 713		995
Operating, selling and general (OS&G) expenses		3 297		3 411		3 440
Net debt^(2)(6)^		7 559		6 861		9 552
	Q1		Q4		Q1
---	---	---	---	---	---	---
Operating Highlights	2025		2024		2024
Total upstream production (mbbls/d)		853.2		875.0		835.3
Refinery utilization (%)		104		104		98
(1)	Presented on a basic per share basis.
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(2)	Non-GAAP financial measures or contains non-GAAP financial measures. See the Non-GAAP Financial Measures section of this news release.
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(3)	Excludes capitalized interest.
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(4)	Calculated as the cost of share repurchases, excluding taxes paid on share repurchases, divided by the weighted average number of<br>shares outstanding.
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(5)	Includes dividends paid on common shares and repurchases of common shares; excludes taxes paid on common share repurchases.
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(6)	Beginning in the second quarter of 2024, the company revised the definition of net debt to exclude lease liabilities to better align<br>with how management and industry monitor capital structure. Prior period comparatives have been restated to reflect this change.
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Financial Results

Adjusted Operating Earnings Reconciliation^(1)^

	Q1			Q4			Q1
($ millions)	2025			2024			2024
Net earnings		1 689			818			1 610
Unrealized foreign exchange (gain) loss on U.S. dollar denominated debt		(14	)		514			220
Unrealized gain on risk management activities		(60	)		(16	)		(2	)
Loss on early repayment of long-term debt		—			144			—
Asset impairment and derecognition		—			212			—
Income tax expense (recovery) on adjusted operating earnings adjustments		14			(106	)		(11	)
Adjusted operating earnings		1 629			1 566			1 817
(1)	Non-GAAP financial measure. All reconciling items are presented on a before-tax basis and adjusted for income taxes in the income<br>tax expense (recovery) on adjusted operating earnings adjustments line. See the Non GAAP Financial Measures section of this news release.
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·	Suncor’s adjusted operating earnings were $1.629 billion ($1.31 per common share) in the first quarter of 2025, compared to<br>$1.817 billion ($1.41 per common share) in the prior year quarter, with the decrease primarily as a result of lower upstream sales volumes<br>due to a build in inventory as production remained strong in the quarter, partially offset by higher refined products sales volumes with<br>record first quarter refining throughput. Higher Oil Sands price realizations, which benefited from narrower differentials compared to<br>the prior year quarter, were mostly offset by lower downstream benchmark crack spreads. The Canadian dollar also weakened against the<br>U.S. dollar in the current quarter, resulting in a foreign exchange loss on working capital items compared to a larger gain in the prior<br>year quarter, but a benefit to upstream price realizations.
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·	Net earnings were $1.689 billion ($1.36 per common share) in the first quarter of 2025, compared to $1.610 billion ($1.25 per common<br>share) in the prior year quarter. In addition to the factors impacting adjusted operating earnings, net earnings for the first quarter<br>of 2025 and the prior year quarter were impacted by the reconciling items shown in the table above.
---	---
·	Adjusted funds from operations were $3.045 billion ($2.46 per common share) in the first quarter of 2025, compared to $3.169 billion<br>($2.46 per common share) in the prior year quarter, and were primarily influenced by the same factors impacting adjusted operating earnings,<br>excluding depreciation, depletion and amortization (DD&A) expense.
---	---
o	Oil Sands adjusted funds from operations increased by $367 million compared to the prior year quarter, primarily due to higher price<br>realizations and strong production, partially offset by a build of inventory in the latter part of the quarter.
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o	Exploration and production (E&P) adjusted funds from operations decreased by $137 million compared to the prior year quarter,<br>primarily due to an inventory build related to the timing of cargo sales as production increased compared to the prior year quarter.
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o	Refining and Marketing (R&M) adjusted funds from operations decreased by $404 million compared to the prior year quarter, primarily<br>due to lower benchmark crack spreads, partially offset by increased refinery production and sales volumes.
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·	Cash flow provided by operating activities, which includes changes in non-cash working capital, decreased to $2.156 billion ($1.74<br>per common share) in the first quarter of 2025, compared to $2.787 billion ($2.16 per common share) in the prior year quarter.
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·	Operating, selling and general (OS&G) expenses decreased to $3.297 billion in the first quarter of 2025, compared to $3.440 billion<br>in the prior year quarter, primarily due to lower upstream sales volumes and a corresponding decrease in operating expenses as inventory<br>was built in the latter part of the quarter, partially offset by increased mining and maintenance activity, and higher commodity input<br>volumes
---	---

Operating Results

	Q1			Q4			Q1
(mbbls/d, unless otherwise noted)	2025			2024			2024
Upstream
Total Oil Sands bitumen production		937.3			951.5			932.1
SCO and diesel production		567.3			572.5			572.5
Inter-asset transfers and consumption		(30.7	)		(28.9	)		(27.5	)
Upgraded production – net SCO and diesel		536.6			543.6			545.0
Bitumen production		341.7			342.6			297.9
Inter-asset transfers		(87.4	)		(68.7	)		(57.9	)
Non-upgraded bitumen production		254.3			273.9			240.0
Total Oil Sands production		790.9			817.5			785.0
Exploration and Production		62.3			57.5			50.3
Total upstream production		853.2			875.0			835.3
Upstream sales		828.4			865.4			847.4
Downstream
Refinery utilization (%)		104			104			98
Refinery crude oil processed		482.7			486.2			455.3
Refined product sales		604.9			613.3			581.0
·	Total Oil Sands bitumen production increased to 937,300<br>bbls/d in the first quarter of 2025, compared to 932,100 bbls/d in the prior year quarter, and included record first quarter Firebag production.
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·	The company’s net synthetic crude oil (SCO) production<br>was 536,600 bbls/d in the first quarter of 2025, compared to an all-time record of 545,000 bbls/d in the prior year quarter and included<br>the second highest ever quarterly upgrader utilization of 103% at Oil Sands Base and record first quarter upgrader utilization of 100%<br>at Syncrude.
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·	Non-upgraded bitumen production increased to 254,300 bbls/d<br>in the first quarter of 2025, compared to 240,000 bbls/d in the prior year quarter, primarily due to higher upgrader availability in the<br>prior year quarter.
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·	E&P production increased to 62,300 bbls/d in the first<br>quarter of 2025, compared to 50,300 bbls/d in the prior year quarter, primarily due to increased production at Terra Nova and Hebron.
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·	Strong downstream operating performance resulted in record<br>first quarter refinery throughput of 482,700 bbls/d and refinery utilization of 104%, compared to 455,300 bbls/d and 98%, respectively,<br>in the prior year quarter, which was also impacted by higher planned maintenance activities.
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·	Downstream achieved record first quarter refined product<br>sales of 604,900 bbls/d in the first quarter of 2025, compared to 581,000 bbls/d in the prior year quarter, with the increase primarily<br>due to higher refinery throughput and the benefit of the company’s extensive sales and retail network.
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Corporate and Strategy Updates

·	Production resumes at White Rose. Production safely<br>restarted at White Rose in the first quarter, with production returning to normal levels in the second quarter.

Corporate Guidance Updates

There have been no changes to the 2025 corporate guidance ranges previously issued on December 12, 2024.

For further details and advisories regarding Suncor’s 2025 corporate guidance, see www.suncor.com/guidance.

Non-GAAP Financial Measures

Certain financial measures in this news release – namely adjusted funds from operations, adjusted operating earnings, free funds flow and net debt, and related per share or per barrel amounts – 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

Adjusted operating earnings is a non-GAAP financial measure that adjusts net earnings for significant items that are not indicative of operating performance. Management uses adjusted operating earnings to evaluate operating performance because management believes it provides better comparability between periods. Adjusted operating earnings are reconciled to net earnings in the news release above.

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 believe reduces comparability between periods.

Three months ended March 31	Oil Sands						Exploration <br><br>and<br> Production						Refining and <br><br> Marketing						Corporate and<br><br> Eliminations						Income Taxes						Total
($ millions)	2025			2024			2025			2024			2025			2024			2025			2024			2025			2024			2025			2024
Earnings<br> (loss) before income taxes		1 675			1<br> 371			158			274			672			1<br> 114			(215	)		(539	)		—			—			2 290			2<br> 220
Adjustments<br> for:
Depreciation,<br> depletion, amortization and impairment		1 199			1<br> 185			171			170			257			244			36			29			—			—			1 663			1<br> 628
Accretion		124			126			16			16			3			3			—			—			—			—			143			145
Unrealized<br> foreign exchange (gain) loss on U.S. dollar denominated debt		—			—			—			—			—			—			(14	)		220			—			—			(14	)		220
Change in<br> fair value of financial instruments and trading inventory		(68	)		2			(6	)		3			17			25			—			—			—			—			(57	)		30
Gain on<br> disposal of assets		—			—			—			—			—			—			—			(3	)		—			—			—			(3	)
Share-based<br>compensation		(86	)		(171	)		(6	)		3			(40	)		(78	)		(171	)		(128	)		—			—			(303	)		(374	)
Settlement<br> of decommissioning and restoration liabilities		(79	)		(112	)		(3	)		(2	)		(12	)		(9	)		—			—			—			—			(94	)		(123	)
Other		45			42			—			3			5			7			15			23			—			—			65			75
Current<br> income tax expense		—			—			—			—			—			—			—			—			(648	)		(649	)		(648	)		(649	)
Adjusted<br> funds from (used in) operations		2 810			2<br> 443			330			467			902			1<br> 306			(349	)		(398	)		(648	)		(649	)		3 045			3<br> 169
Change in<br> non-cash working capital																																(889	)		(382	)
Cash flow<br> provided by operating activities																																2 156			2<br> 787

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 March 31	Oil Sands						Exploration <br><br>and<br><br><br> Production						Refining and <br><br> Marketing						Corporate and<br><br> Eliminations						Income Taxes						Total
($ millions)	2025			2024			2025			2024			2025			2024			2025			2024			2025			2024			2025		2024
Adjusted<br> funds from (used in) operations		2 810			2<br> 443			330			467			902			1<br> 306			(349	)		(398	)		(648	)		(649	)		3 045		3<br> 169
Capital<br> expenditures including capitalized interest		(749	)		(995	)		(209	)		(142	)		(180	)		(168	)		(7	)		(6	)		—			—			(1145)		(1<br> 311)
Free funds<br> flow (deficit)		2 061			1<br> 448			121			325			722			1<br> 138			(356	)		(404	)		(648	)		(649	)		1 900		1<br> 858

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 and long-term debt (all of which are GAAP measures). Net debt is equal to total debt less cash and cash equivalents (a GAAP measure).

	March 31		December 31
($ millions, except as noted)	2025		2024
Short-term debt		—		—
Current portion of long-term debt		997		997
Long-term debt		9 335		9<br> 348
Total debt^(1)^		10 332		10<br> 345
Less: Cash and cash equivalents		2 773		3<br> 484
Net debt ^(1)^		7 559		6<br> 861
Shareholders’ equity		44 834		44<br> 514
Total debt plus shareholders’ equity		55 166		54<br> 859
Total debt to total debt plus shareholders’ equity^(1)^ (%)		18.7		18.9
Net debt to net debt plus shareholders’ equity^(1)^ (%)		14.4		13.4
(1)	Beginning in the second quarter of 2024, the company revised the definition of net debt and total debt to exclude lease liabilities<br>to better align with how management and industry monitor capital structure. Prior period comparatives have been restated to reflect this<br>change.
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Legal Advisory – Forward-Looking Information

This news release contains certain forward-looking information andforward-looking statements (collectively referred to herein as “forward-looking statements”) and other information based onSuncor’s current expectations, estimates, projections and assumptions that were made by the company in light of information availableat the time the statement was made and consider Suncor’s experience and its perception of historical trends, including expectationsand assumptions concerning: the accuracy of reserves estimates; commodity prices and interest and foreign exchange rates; the performanceof assets and equipment; uncertainty related to geopolitical conflict; capital efficiencies and cost savings; applicable laws and governmentpolicies; future production rates; the sufficiency of budgeted capital expenditures in carrying out planned activities; the availabilityand cost of labour, services and infrastructure; the satisfaction by third parties of their obligations to Suncor; the development andexecution of projects; and the receipt, in a timely manner, of regulatory and third-party approvals. All statements and information thataddress expectations or projections about the future, and other statements and information about Suncor’s strategy for growth, expectedand 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-lookingstatements 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-lookingstatements in this news release include references to: Suncor's strategy, focus, goals and priorities and the expected benefits therefrom,and the anticipated return to normal production at White Rose in in the second quarter. In addition, all other statements and informationabout Suncor’s strategy for growth, expected and future expenditures or investment decisions, commodity prices, costs, schedules,production volumes, operating and financial results and the expected impact of future commitments are forward-looking statements. Someof the forward-looking statements and information 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” and similar expressions.

Forward-looking statements are based on Suncor’s current expectations,estimates, projections and assumptions that were made by the company in light of its information available at the time the statement wasmade 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;capital efficiencies and cost savings; applicable laws and government policies; future production rates; the sufficiency of budgeted capitalexpenditures in carrying out planned activities; the availability and cost of labour, services and infrastructure; the satisfaction bythird parties of their obligations to Suncor; the development and execution of projects; and the receipt, in a timely manner, of regulatoryand third-party approvals.

Forward-looking statements and information are not guarantees offuture performance and involve a number of risks and uncertainties, some that are similar to other oil and gas companies and some thatare 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.

Suncor’s Annual InformationForm, Annual Report to Shareholders and Form 40-F, each dated February 26, 2025, Suncor’s Report to Shareholders for theFirst Quarter of 2025 dated May 6, 2025, and other documents it files from time to time with securities regulatory authorities describethe risks, uncertainties, material assumptions and other factors that could influence actual results and such factors are incorporatedherein by reference. Copies of these documents are available by referring to suncor.com/FinancialReportsor on SEDAR+ at sedarplus.ca or EDGAR at sec.gov. Except as requiredby applicable securities laws, Suncor disclaims any intention or obligation to publicly update or revise any forward-looking statements,whether as a result of new information, future events or otherwise.

To view a full copy of Suncor’s first quarter 2025 Report to Shareholders and the financial statements and notes (unaudited), visit Suncor's profile on sedarplus.ca or sec.gov or visit Suncor’s website at suncor.com/financialreports.

To listen to the conference call discussing Suncor's first quarter results, visit suncor.com/webcasts.

Suncor Energy is Canada's leading integrated energy company. Suncor'soperations include oil sands development, production and upgrading; offshore oil production; petroleum refining in Canada and the U.S.;and the company’s Petro-Canada^TM^ retail and wholesale distribution networks (including Canada’s Electric Highway^TM^,a coast-to-coast network of fast-charging EV stations). Suncor is developing petroleum resources while advancing the transition to a lower-emissionsfuture through investments in lower emissions intensity power, renewable feedstock fuels and projects targeting emissions intensity. Suncoralso conducts energy trading activities focused primarily on the marketing and trading of crude oil, natural gas, byproducts, refinedproducts and power. Suncor's common shares (symbol: SU) are listed on the Toronto and New York stock exchanges.

For more information about Suncor, visit our web site at suncor.com

Media inquiries:

833-296-4570

media@suncor.com

Investor inquiries:

invest@suncor.com

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TABLE OF CONTENTS

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Exhibit 99.2

All financial figures are unaudited and presented in Canadian dollars unless noted otherwise. Production volumes are presented on a working-interest basis, before royalties, except for production volumes from Suncor Energy Inc.’s (Suncor or the company) Libya operations, which are presented on an economic basis. Certain financial measures in this document are not prescribed by Canadian generally accepted accounting principles (GAAP). For a description of these non-GAAP financial measures, see the Non-GAAP and Other Financial Measures Advisory section of Suncor’s Management Discussion and Analysis (MD&A) dated May 6, 2025. See also the Advisories section of the MD&A. References to Oil Sands operations exclude Suncor’s ownership of Fort Hills and interest in Syncrude.

First Quarter Highlights

•

Generated over $3.0 billion in adjusted funds from operations(1) and $1.9 billion in free funds flow(1).

•

Returned $1.5 billion to shareholders, with $750 million in share repurchases and $705 million in dividends.

•

Upstream production of 853,000 barrels per day (bbls/d), the highest first quarter in company history.

•

Refining throughput of 483,000 bbls/d, the highest first quarter in company history.

•

Refined product sales of 605,000 bbls/d, the highest first quarter in company history.

•

Exceptional asset utilization with upgraders at 102%(2) and refineries at 104%.

First Quarter Results

	Financial Highlights<br><br> <br>($ millions, unless otherwise noted)			Q1<br> <br><br> 2025						Q4<br> <br><br> 2024						Q1<br> <br><br> 2024
	Net earnings					1 689						818						1 610
	Per common share(1) (dollars)					1.36						0.65						1.25
	Adjusted operating earnings(2)					1 629						1 566						1 817
	Per common share(1)(2) (dollars)					1.31						1.25						1.41
	Adjusted funds from operations(2)					3 045						3 493						3 169
	Per common share(1)(2) (dollars)					2.46						2.78						2.46
	Cash flow provided by operating activities					2 156						5 083						2 787
	Per common share(1) (dollars)					1.74						4.05						2.16
	Capital and exploration expenditures(3)					1 087						1 498						1 237
	Free funds flow(2)					1 900						1 923						1 858
	Dividend per common share(1) (dollars)					0.57						0.57						0.55
	Share repurchases per common share(4) (dollars)					0.61						0.80						0.23
	Returns to shareholders(5)					1 455						1 713						995
	Operating, selling and general (OS&G) expenses					3 297						3 411						3 440
	Net debt(2)(6)					7 559						6 861						9 552
	Operating Highlights			Q1<br> <br><br> 2025						Q4<br> <br><br> 2024						Q1<br> <br><br> 2024
---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---
	Total upstream production (mbbls/d)					853.2						875.0						835.3
	Refinery utilization (%)					104						104						98

(1)

Presented on a basic per share basis.

(2)

Non-GAAP financial measures or contains non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of the MD&A.

(3)

Excludes capitalized interest.

(4)

Calculated as the cost of share repurchases, excluding taxes paid on share repurchases, divided by the weighted average number of shares outstanding.

(5)

Includes dividends paid on common shares and repurchases of common shares; excludes taxes paid on common share repurchases.

(6)

Beginning in the second quarter of 2024, the company revised the definition of net debt to exclude lease liabilities to better align with how management and industry monitor capital structure. Prior period comparatives have been restated to reflect this change.

(1)

Non-GAAP financial measure. See the Non-GAAP and Other Financial Measures Advisory section of the MD&A.

(2)

Upgrader utilization is calculated using gross upgraded production, inclusive of internally consumed products and inter-asset transfers, and gross upgrader nameplate capacities, on an average basis of Oil Sands Base and Syncrude.

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Financial Results

Adjusted Operating Earnings Reconciliation(1)

($ millions)
Net earnings	1 689	818	1 610
Unrealized foreign exchange (gain) loss on U.S. dollar denominated debt	(14)	514	220
Unrealized gain on risk management activities	(60)	(16)	(2)
Loss on early repayment of long-term debt	—	144	—
Asset impairment and derecognition	—	212	—
Income tax expense (recovery) on adjusted operating earnings adjustments	14	(106)	(11)
Adjusted operating earnings(1)	1 629	1 566	1 817

(1)

Non-GAAP financial measure. All reconciling items are presented on a before-tax basis and adjusted for income taxes in the income tax expense (recovery) on adjusted operating earnings adjustments line. See the Non-GAAP and Other Financial Measures Advisory section of the MD&A.

•

Suncor’s adjusted operating earnings were $1.629 billion ($1.31 per common share) in the first quarter of 2025, compared to $1.817 billion ($1.41 per common share) in the prior year quarter, with the decrease primarily as a result of lower upstream sales volumes due to a build in inventory as production remained strong in the quarter, partially offset by higher refined products sales volumes with record first quarter refining throughput. Higher Oil Sands price realizations, which benefited from narrower differentials compared to the prior year quarter, were mostly offset by lower downstream benchmark crack spreads. The Canadian dollar also weakened against the U.S. dollar in the current quarter, resulting in a foreign exchange loss on working capital items compared to a larger gain in the prior year quarter, but a benefit to upstream price realizations.

•

Net earnings were $1.689 billion ($1.36 per common share) in the first quarter of 2025, compared to $1.610 billion ($1.25 per common share) in the prior year quarter. In addition to the factors impacting adjusted operating earnings, net earnings for the first quarter of 2025 and the prior year quarter were impacted by the reconciling items shown in the table above.

•

Adjusted funds from operations were $3.045 billion ($2.46 per common share) in the first quarter of 2025, compared to $3.169 billion ($2.46 per common share) in the prior year quarter, and were primarily influenced by the same factors impacting adjusted operating earnings, excluding depreciation, depletion and amortization (DD&A) expense.

•

Oil Sands adjusted funds from operations increased by $367 million compared to the prior year quarter, primarily due to higher price realizations and strong production, partially offset by a build of inventory in the latter part of the quarter.

•

Exploration and production (E&P) adjusted funds from operations decreased by $137 million compared to the prior year quarter, primarily due to an inventory build related to the timing of cargo sales as production increased compared to the prior year quarter.

•

Refining and Marketing (R&M) adjusted funds from operations decreased by $404 million compared to the prior year quarter, primarily due to lower benchmark crack spreads, partially offset by increased refinery production and sales volumes.

•

Cash flow provided by operating activities, which includes changes in non-cash working capital, decreased to $2.156 billion ($1.74 per common share) in the first quarter of 2025, compared to $2.787 billion ($2.16 per common share) in the prior year quarter.

•

Operating, selling and general (OS&G) expenses decreased to $3.297 billion in the first quarter of 2025, compared to $3.440 billion in the prior year quarter, primarily due to lower upstream sales volumes and a corresponding decrease in operating expenses as inventory was built in the latter part of the quarter, partially offset by increased mining and maintenance activity, and higher commodity input volumes.

2 2025 First Quarter Suncor Energy Inc.

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Operating Results

(mbbls/d, unless otherwise noted)
Upstream
Total Oil Sands bitumen production	937.3	951.5	932.1
SCO and diesel production	567.3	572.5	572.5
Inter-asset transfers and consumption	(30.7)	(28.9)	(27.5)
Upgraded production – net SCO and diesel	536.6	543.6	545.0
Bitumen production	341.7	342.6	297.9
Inter-asset transfers	(87.4)	(68.7)	(57.9)
Non-upgraded bitumen production	254.3	273.9	240.0
Total Oil Sands production	790.9	817.5	785.0
Exploration and Production	62.3	57.5	50.3
Total upstream production	853.2	875.0	835.3
Upstream sales	828.4	865.4	847.4
Downstream
Refinery utilization (%)	104	104	98
Refinery crude oil processed	482.7	486.2	455.3
Refined product sales	604.9	613.3	581.0

•

Total Oil Sands bitumen production increased to 937,300 bbls/d in the first quarter of 2025, compared to 932,100 bbls/d in the prior year quarter, and included record first quarter Firebag production.

•

The company’s net synthetic crude oil (SCO) production was 536,600 bbls/d in the first quarter of 2025, compared to an all-time record of 545,000 bbls/d in the prior year quarter and included the second highest ever quarterly upgrader utilization of 103% at Oil Sands Base and record first quarter upgrader utilization of 100% at Syncrude.

•

Non-upgraded bitumen production increased to 254,300 bbls/d in the first quarter of 2025, compared to 240,000 bbls/d in the prior year quarter, primarily due to higher upgrader availability in the prior year quarter.

•

E&P production increased to 62,300 bbls/d in the first quarter of 2025, compared to 50,300 bbls/d in the prior year quarter, primarily due to increased production at Terra Nova and Hebron.

•

Strong downstream operating performance resulted in record first quarter refinery throughput of 482,700 bbls/d and refinery utilization of 104%, compared to 455,300 bbls/d and 98%, respectively, in the prior year quarter, which was also impacted by higher planned maintenance activities.

•

Downstream achieved record first quarter refined product sales of 604,900 bbls/d in the first quarter of 2025, compared to 581,000 bbls/d in the prior year quarter, with the increase primarily due to higher refinery throughput and the benefit of the company’s extensive sales and retail network.

Corporate and Strategy Updates

•

Production resumes at White Rose. Production safely restarted at White Rose in the first quarter, with production returning to normal levels in the second quarter.

Corporate Guidance Updates

There have been no changes to the 2025 corporate guidance ranges previously issued on December 12, 2024.

For further details and advisories regarding Suncor’s 2025 corporate guidance, see www.suncor.com/guidance.

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Management’s Discussion and Analysis

May 6, 2025

Suncor Energy is Canada’s leading integrated energy company. Suncor’s operations include oil sands development, production and upgrading; offshore oil production; 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 EV stations). Suncor is developing petroleum resources while advancing the transition to a lower-emissions future through investments in lower emissions intensity power, renewable feedstock fuels and projects targeting emissions intensity. Suncor also conducts energy trading activities focused primarily on the marketing and trading of crude oil, natural gas, byproducts, refined products and power. 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, 2024, dated February 26, 2025 (the 2024 annual MD&A).

This MD&A, for the three months ended March 31, 2025, should be read in conjunction with Suncor’s unaudited interim Consolidated Financial Statements for the three months ended March 31, 2025, Suncor’s audited Consolidated Financial Statements for the year ended December 31, 2024, and the 2024 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 February 26, 2025 (the 2024 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 MD&A by reference.

References to “we”, “our”, “Suncor”, “Suncor Energy” or “the company” means Suncor Energy Inc., its subsidiaries, partnerships and joint arrangements, unless otherwise specified or the context otherwise requires.

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 ownership of Fort Hills and interest in Syncrude.

Common Abbreviations

For a list of the abbreviations that may be used in this MD&A, please refer to the Common Abbreviations section of this MD&A.

Table of Contents

	1.<br><br> <br>First Quarter Highlights<br><br> <br>					5
	2.<br><br> <br>Consolidated Financial and Operating Information<br><br> <br>					6
	3.<br><br> <br>Segment Results and Analysis<br><br> <br>					10
	4.<br><br> <br>Income Tax<br><br> <br>					18
	5.<br><br> <br>Capital Investment Update<br><br> <br>					19
	6.<br><br> <br>Financial Condition and Liquidity<br><br> <br>					20
	7.<br><br> <br>Quarterly Financial Data<br><br> <br>					23
	8.<br><br> <br>Other Items<br><br> <br>					25
	9.<br><br> <br>Non-GAAP and Other Financial Measures Advisory<br><br> <br>					26
	10.<br><br> <br>Common Abbreviations<br><br> <br>					33
	11.<br><br> <br>Advisories<br><br> <br>					34

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FIRST QUARTER HIGHLIGHTS

•

Financial results. Adjusted funds from operations(1) were $3.045 billion ($2.46 per common share), compared to $3.169 billion ($2.46 per common share) in the prior year quarter. Adjusted operating earnings(1) were $1.629 billion ($1.31 per common share), compared to $1.817 billion ($1.41 per common share) in the prior year quarter.

•

Returned value to shareholders. Suncor returned approximately $1.5 billion of value to shareholders in the quarter with $750 million in share repurchases(2) and $705 million in dividends.

•

Record first quarter upstream production. Total upstream production was 853,200 bbls/d, the highest first quarter upstream production in company history, and included record first quarter production at Firebag.

•

Second highest ever Oil Sands production. Oil Sands production was 790,900 bbls/d and upgrader utilization(3) was 102%, the second highest ever in company history. The company maximized higher value SCO production through the second highest quarterly utilization ever of 103% at Oil Sands Base and first quarter record utilization of 100% at Syncrude.

•

Record first quarter refining throughput. Refining throughput was 482,700 bbls/d with refinery utilization of 104%, a first quarter record.

•

Record first quarter refined product sales. Refined product sales were 604,900 bbls/d, a first quarter record, reflecting increased refinery throughput and the benefit of the company’s extensive sales and retail network.

•

Production resumes at White Rose. Production safely restarted at White Rose in the first quarter, with production returning to normal levels in the second quarter.

(1)

Non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.

(2)

Excludes taxes paid on share repurchases.

(3)

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First Quarter Discussion

CONSOLIDATED FINANCIAL AND OPERATING INFORMATION

Financial Highlights

	Three months ended<br> <br><br> March 31
($ millions)	2025		2024
Earnings (loss) before income taxes
Oil Sands		1 675		1 371
Exploration and Production		158		274
Refining and Marketing		672		1 114
Corporate and Eliminations		(215)		(539)
Income tax expense		(601)		(610)
Net earnings		1 689		1 610
Adjusted operating earnings (loss)(1)
Oil Sands		1 620		1 365
Exploration and Production		158		274
Refining and Marketing		667		1 118
Corporate and Eliminations		(229)		(319)
Income tax expense included in adjusted operating earnings		(587)		(621)
Total		1 629		1 817
Adjusted funds from (used in) operations(1)
Oil Sands		2 810		2 443
Exploration and Production		330		467
Refining and Marketing		902		1 306
Corporate and Eliminations		(349)		(398)
Current income tax expense		(648)		(649)
Total		3 045		3 169
Change in non-cash working capital		(889)		(382)
Cash flow provided by operating activities		2 156		2 787
Capital and exploration expenditures(2)
Asset sustainment and maintenance		498		574
Economic investment		589		663
Total		1 087		1 237
Free funds flow(1)		1 900		1 858

(1)

Non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.

(2)

Excludes capitalized interest of $58 million in the first quarter of 2025, compared to $74 million in the first quarter of 2024.

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Operating Highlights

	Three months ended<br> <br><br> March 31
(mbbls/d, unless otherwise noted)	2025		2024
Upstream
Production volumes
Oil Sands – Upgraded – net SCO and diesel		536.6		545.0
Oil Sands – Non-upgraded bitumen		254.3		240.0
Total Oil Sands production volumes		790.9		785.0
Exploration and Production		62.3		50.3
Total upstream production		853.2		835.3
Upstream sales		828.4		847.4
Downstream
Refinery utilization (%)		104		98
Refinery crude oil processed		482.7		455.3
Refined product sales		604.9		581.0

Financial Results

Net Earnings and Adjusted Operating Earnings

Adjusted Operating Earnings Reconciliation(1)

	Three months ended<br> <br><br> March 31
($ millions)	2025		2024
Net earnings		1 689		1 610
Unrealized foreign exchange (gain) loss on U.S. dollar denominated debt		(14)		220
Unrealized gain on risk management activities		(60)		(2)
Income tax expense (recovery) on adjusted operating earnings adjustments		14		(11)
Adjusted operating earnings(1)		1 629		1 817

(1)

Suncor’s consolidated net earnings for the first quarter of 2025 were $1.689 billion, compared to $1.610 billion in the prior year quarter. Net earnings were primarily influenced by the same factors that impacted adjusted operating earnings discussed 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 $14 million recorded in financing expenses in the Corporate and Eliminations segment in the first quarter of 2025, compared to a loss of $220 million in the first quarter of 2024.

•

An unrealized gain on risk management activities of $60 million recorded in other income in the first quarter of 2025, compared to an unrealized gain of $2 million in the first quarter of 2024.

•

An income tax expense related to the items noted above of $14 million in the first quarter of 2025, compared to a recovery of $11 million in the first quarter of 2024.

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First Quarter Discussion

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.

Adjusted Funds from Operations and Cash Flow Provided by Operating Activities

Cash flow provided by operating activities, which includes changes in non-cash working capital, was $2.156 billion ($1.74 per common share) in the first quarter of 2025, compared to $2.787 billion ($2.16 per common share) in the prior year quarter. In addition to the factors impacting adjusted funds from operations, cash flow provided by operating activities were impacted by a larger use of cash associated with the company’s working capital balances in the first quarter of 2025 compared to the prior year quarter. Working capital is subject to fluctuations based on commodity prices, the timing of transactions and seasonal factors. The use of cash in the first quarter of 2025 was primarily due to a build of inventory related to decreased upstream sales volumes and the timing of cargo sales and a decrease in accounts payable and accrued liabilities.

Operating, Selling and General Expenses

	Three months ended<br> <br><br> March 31
($ millions)	2025		2024
Operations, selling and corporate costs		2 666		2 815
Commodities		486		466
Share-based compensation(1)		145		159
Total operating, selling and general (OS&G) expenses		3 297		3 440

(1)

In the first quarter of 2025, share-based compensation expense of $145 million included $47 million in the Oil Sands segment, $2 million in the E&P segment, $25 million in the R&M segment and $71 million in the Corporate and Eliminations segment. In the first quarter of 2024, share-based compensation expense of $159 million included $51 million in the Oil Sands segment, $5 million in the E&P segment, $25 million in the R&M segment and $78 million in the Corporate and Eliminations segment.

OS&G expenses decreased in the first quarter of 2025, compared to the prior year quarter, primarily due to lower upstream sales volumes and a corresponding decrease in operating expenses as inventory was built in the latter part of the quarter, partially offset by increased mining and maintenance activity and higher commodity input volumes. The company’s exposure to commodity costs is partially mitigated by revenue from power sales that are recorded in operating revenues.

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Business Environment

Commodity prices, refining crack spreads and foreign exchange rates are important factors that affect the results of Suncor’s operations. For additional details, see the Financial Information section of the 2024 annual MD&A.

		Average for the<br> <br><br> three months ended<br> <br><br> March 31
		2025		2024
WTI crude oil at Cushing	US$/bbl		71.40		76.95
Dated Brent crude	US$/bbl		75.70		83.25
Dated Brent/Maya crude oil FOB price differential	US$/bbl		11.10		14.10
MSW at Edmonton	Cdn$/bbl		95.30		92.20
WCS at Hardisty	US$/bbl		58.75		57.60
WCS-WTI heavy/light differential	US$/bbl		(12.65)		(19.35)
SYN-WTI differential	US$/bbl		(2.35)		(7.40)
Condensate at Edmonton	US$/bbl		69.90		72.80
Natural gas (Alberta spot) at AECO	Cdn$/GJ		2.05		2.20
Alberta Power Pool Price	Cdn$/MWh		39.80		99.30
New York Harbor 2-1-1 crack(1)	US$/bbl		21.05		27.05
Chicago 2-1-1 crack(1)	US$/bbl		14.65		19.80
Portland 2-1-1 crack(1)	US$/bbl		22.30		26.85
Gulf Coast 2-1-1 crack(1)	US$/bbl		20.85		27.95
U.S. Renewable Volume Obligation	US$/bbl		4.75		3.70
Suncor custom 5-2-2-1 index(2)	US$/bbl		26.80		35.95
Exchange rate (average)	US$/Cdn$		0.70		0.74
Exchange rate (end of period)	US$/Cdn$		0.69		0.74

(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 5-2-2-1 index is calculated, see Suncor’s 2024 annual MD&A.

2025 First Quarter Suncor Energy Inc. 9

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First Quarter Discussion

SEGMENT RESULTS AND ANALYSIS

OIL SANDS

Financial Highlights

	Three months ended<br> <br><br> March 31
($ millions)	2025		2024
Operating revenues		7 141		6 922
Less: Royalties		(815)		(782)
Operating revenues, net of royalties		6 326		6 140
Earnings before income taxes		1 675		1 371
Adjusted for:
Unrealized gain on risk management activities		(55)		(6)
Adjusted operating earnings(1)		1 620		1 365
Adjusted funds from operations(1)		2 810		2 443
Free funds flow(1)		2 061		1 448

(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 increased to $1.620 billion in the first quarter of 2025, compared to $1.365 billion in the prior year quarter, primarily due to narrower heavy crude oil and SYN-WTI differentials, the favourable impact of foreign exchange rates on benchmark pricing and decreased operating expenses as inventory was built in the latter part of the quarter, partially offset by lower sales volumes.

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Production Volumes

	Three months ended<br> <br><br> March 31
(mbbls/d)	2025		2024
Oil Sands bitumen
Upgrader bitumen throughput		683.0		692.1
Non-upgraded bitumen production		254.3		240.0
Total Oil Sands bitumen production		937.3		932.1
Upgraded – net SCO and diesel
Oil Sands operations(1)		361.3		374.6
Syncrude(1)		206.0		197.9
Inter-asset transfers and consumption(2)(3)		(30.7)		(27.5)
Upgraded – net SCO and diesel production		536.6		545.0
Non-upgraded bitumen
Oil Sands operations		165.3		120.3
Fort Hills		176.4		177.6
Syncrude		—		—
Inter-asset transfers(4)		(87.4)		(57.9)
Non-upgraded bitumen production		254.3		240.0
Oil Sands production volumes to market
Upgraded – net SCO and diesel		536.6		545.0
Non-upgraded bitumen		254.3		240.0
Total Oil Sands production volumes		790.9		785.0

(1)

Oil Sands Base upgrader yields are approximately 80% of bitumen throughput and Syncrude upgrader yield is approximately 85% of bitumen throughput. Upgrader utilization rates are calculated using total upgraded production, inclusive of internally consumed products and inter-asset transfers.

(2)

Both Oil Sands operations and Syncrude produce diesel and other products, which are internally consumed in operations. In the first quarter of 2025, Oil Sands operations produced 17,700 bbls/d of internally consumed products, of which 10,900 bbls/d was consumed at Oil Sands operations, 5,700 bbls/d was consumed at Fort Hills and 1,100 bbls/d was consumed at Syncrude. Syncrude produced 3,700 bbls/d of internally consumed products.

(3)

In the first quarter of 2025, upgraded inter-asset transfers consist of 9,300 bbls/d of sour SCO that was transferred from Oil Sands operations to Syncrude.

(4)

In the first quarter of 2025, non-upgraded inter-asset transfers consist of 62,000 bbls/d of bitumen that was transferred from Fort Hills to Oil Sands Base and 25,400 bbls/d of bitumen that was transferred from Firebag to Syncrude.

Total Oil Sands bitumen production increased to 937,300 bbls/d in the first quarter of 2025, compared to 932,100 bbls/d in the prior year quarter, as record first quarter Firebag production more than offset slightly lower mining production.

The company’s net SCO production was 536,600 bbls/d in the first quarter of 2025, compared to 545,000 bbls/d in the prior year quarter and included upgrader utilization of 103% at Oil Sands Base and 100% at Syncrude, compared to 107% and 96%, respectively, in the prior year quarter. The decrease was primarily due to fewer maintenance activities in the prior year quarter, which was an all-time record for net SCO production.

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First Quarter Discussion

Sales Volumes

	Three months ended<br> <br><br> March 31
(mbbls/d)	2025		2024
Upgraded – net SCO and diesel		528.5		550.3
Non-upgraded bitumen		244.9		233.8
Total		773.4		784.1

SCO and diesel sales volumes decreased to 528,500 bbls/d in the first quarter of 2025, compared to 550,300 bbls/d in the prior year quarter, primarily due to the decrease in SCO production volumes and a build of inventory in the first quarter of 2025 compared to a draw of inventory in the prior year quarter.

Non-upgraded bitumen sales volumes increased to 244,900 bbls/d in the first quarter of 2025, compared to 233,800 bbls/d in the prior year quarter, primarily due to the increase in non-upgraded bitumen production volumes, partially offset by a larger build of inventory in the first quarter of 2025 compared to the prior year quarter.

Price Realizations(1)

Net of transportation costs, but before royalties	Three months ended<br> <br><br> March 31
($/bbl)	2025		2024
Upgraded – net SCO and diesel		96.24		90.97
Non-upgraded bitumen		71.13		65.11
Weighted average		88.28		83.24
Weighted average crude, relative to WTI		(14.18)		(20.55)

(1)

Contains non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.

Oil Sands price realizations increased in the first quarter of 2025 compared to the prior year quarter, primarily due to narrower heavy crude oil and SYN-WTI differentials and the favourable impact of foreign exchange rates on benchmark pricing.

Royalties

Royalties for the Oil Sands segment increased in the first quarter of 2025 compared to the prior year quarter, primarily due to higher bitumen pricing.

Expenses and Other Factors

Total Oil Sands operating expenses decreased in the first quarter of 2025, compared to the prior year quarter, primarily due to lower sales volumes and a corresponding decrease in operating expenses as inventory was built in the latter part of the quarter, partially offset by increased mining activity, increased maintenance costs and higher commodity input volumes.

DD&A expense increased slightly in the first quarter of 2025, compared to the prior year quarter, primarily due to the commissioning of new assets and new leases entered into during the quarter, partially offset by decreased depreciation related to the company’s asset retirement obligation assets.

Financing expense and other, which includes other income, increased in the first quarter of 2025 compared to the prior year quarter, primarily due to increased interest related to leases.

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Cash Operating Costs

	Three months ended<br> <br><br> March 31
($ millions, except as noted)	2025		2024
Oil Sands OS&G(1)		2 392		2 482
Oil Sands operations cash operating costs reconciliation
Oil Sands operations OS&G		1 286		1 278
Non-production costs(3)		126		37
Excess power capacity and other(4)		(95)		(105)
Oil Sands operations cash operating costs(2)		1 317		1 210
Oil Sands operations production volumes (mbbls/d)		526.6		494.9
Oil Sands operations cash operating costs(2) ($/bbl)		27.80		26.85
Fort Hills cash operating costs reconciliation
Fort Hills OS&G		617		613
Non-production costs(3)		(74)		(67)
Excess power capacity(4)		(5)		(15)
Fort Hills cash operating costs(2)		538		531
Fort Hills production volumes (mbbls/d)		176.4		177.6
Fort Hills cash operating costs(2) ($/bbl)		33.85		32.85
Syncrude cash operating costs reconciliation
Syncrude OS&G		659		656
Non-production costs(3)		14		(6)
Excess power capacity(4)		(3)		(8)
Syncrude cash operating costs(2)		670		642
Syncrude production volumes (mbbls/d)		206.0		197.9
Syncrude cash operating costs(2) ($/bbl)		36.10		35.70

(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 first quarter of 2025, Oil Sands OS&G included ($170) million of inventory changes and internal transfers, compared to ($65) million in the prior year quarter.

(2)

Non-GAAP financial measures. Related per barrel amounts contain on-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 $27.80 in the first quarter of 2025, compared to $26.85 in the prior year quarter, with the increase primarily due to a higher proportion of Fort Hills bitumen being directed to upgrading at Oil Sands Base, increased mining activity, and higher natural gas volumes related to increased consumption at the new co-generation facility, partially offset by increased production volumes and increased power sales.

Fort Hills cash operating costs per barrel(1) were $33.85 in the first quarter of 2025, compared to $32.85 in the prior year quarter, with the increase primarily due to the timing of maintenance activities and a decrease in excess power revenues resulting from lower power prices, partially offset by lower natural gas prices.

Syncrude cash operating costs per barrel(1) were $36.10 in the first quarter of 2025, compared to $35.70 in the prior year quarter, with the increase primarily due to increased mining and maintenance activity, partially offset by increased production volumes.

(1)

Contains non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.

2025 First Quarter Suncor Energy Inc. 13

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First Quarter Discussion

Planned Maintenance Update

The anticipated impact of these maintenance activities has been reflected in the company’s 2025 guidance.

•

Maintenance at Oil Sands Base Upgrader 1 relating to the coke drum integrity project commenced subsequent to the first quarter, with completion expected in the third quarter.

•

The maintenance at Fort Hills commenced subsequent to the first quarter, with completion expected in the second quarter.

•

The turnaround at Firebag is commencing in the second quarter with completion expected in the third quarter.

EXPLORATION AND PRODUCTION

Financial Highlights

	Three months ended<br> <br><br> March 31
($ millions)	2025		2024
Operating revenues(1)		729		765
Less: Royalties(1)		(192)		(142)
Operating revenues, net of royalties		537		623
Earnings before income taxes		158		274
Adjusted operating earnings(2)		158		274
Adjusted funds from operations(2)		330		467
Free funds flow(2)		121		325

(1)

(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 first quarter of 2025 were $158 million, compared to $274 million in the prior year quarter, with the decrease primarily due to lower sales volumes, increased exploration expense and lower realized crude prices, partially offset by decreased operating expenses.

Volumes

	Three months ended<br> <br><br> March 31
(mbbls/d)	2025		2024
E&P Canada		55.6		46.7
E&P International		6.7		3.6
Total production		62.3		50.3
Total sales volumes		55.0		63.3

E&P production increased to 62,300 bbls/d in the first quarter of 2025, compared to 50,300 bbls/d in the prior year quarter, primarily due to increased production at Terra Nova and Hebron.

Total E&P sales volumes decreased to 55,000 bbls/d in the first quarter of 2025, compared to 63,300 bbls/d in the prior year quarter, primarily due to the timing of cargo sales in E&P Canada.

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Price Realizations(1)

	Net of transportation costs, but before royalties			Three months ended<br> <br><br> March 31
	($/bbl)			2025						2024
	E&P Canada					103.82						107.52

(1)

Contains non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.

E&P price realizations decreased in the first quarter of 2025 compared to the prior year quarter, in line with the decrease in benchmark prices for Brent crude.

Royalties

In the first quarter of 2025, E&P royalties, excluding the impact of Libya, were higher compared to the prior year quarter, primarily due to higher royalty rates.

Expenses and Other Factors

Operating expenses decreased in the first quarter of 2025 compared to the prior year quarter, primarily due to lower costs related to improved reliability at Terra Nova following a full year of production.

DD&A and exploration expense for the first quarter of 2025 increased compared to the prior year quarter, primarily due to the relinquishment of E&P Canada exploration commitments.

Planned Maintenance Update for Operated Assets

There are no significant planned maintenance events for the E&P segment scheduled for the second quarter of 2025.

REFINING AND MARKETING

Financial Highlights

	Three months ended<br> <br><br> March 31
($ millions)	2025		2024
Operating revenues		7 628		7 613
Earnings before income taxes		672		1 114
Adjusted for:
Unrealized (gain) loss on risk management activities		(5)		4
Adjusted operating earnings(1)		667		1 118
Adjusted funds from operations(1)		902		1 306
Free funds flow(1)		722		1 138

(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 first quarter of 2025 were $667 million, compared to $1.118 billion in the prior year quarter. The decrease in adjusted operating earnings was primarily due to lower benchmark crack spreads, narrower crude differentials and a first-in, first-out (FIFO) inventory valuation loss in the first quarter of 2025, compared to a gain in the prior year quarter, partially offset by increased refinery production, increased sales volumes and higher margin capture.

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First Quarter Discussion

Volumes

	Three months ended<br> <br><br> March 31
	2025		2024
Crude oil processed (mbbls/d)
Eastern North America		236.9		216.5
Western North America		245.8		238.8
Total		482.7		455.3
Refinery utilization(1) (%)
Eastern North America		107		98
Western North America		101		98
Average		104		98
Refined product sales (mbbls/d)
Gasoline		262.8		243.5
Distillate		262.6		260.1
Other		79.5		77.4
Total		604.9		581.0
Refinery production(2) (mbbls)		45 798		44 074
Refining and marketing gross margin – First-in, first-out (FIFO)(3) ($/bbl)		36.70		46.65
Refining and marketing gross margin – Last-in, first-out (LIFO)(3) ($/bbl)		38.00		45.75
Refining operating expense(3) ($/bbl)		6.75		7.15

(1)

Refinery utilization is the amount of crude oil and natural gas liquids processed by crude distillation units, expressed as a percentage of the nameplate 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.

R&M achieved record first quarter refined product sales of 604,900 bbls/d in the first quarter of 2025, compared to 581,000 bbls/d in the prior year quarter, with the increase primarily due to higher refinery throughput and the benefit of the company’s extensive sales and retail network.

Refining and Marketing Gross Margins(1)

Refining and marketing gross margins were influenced by the following:

•

On a LIFO(2) basis, Suncor’s refining and marketing gross margin decreased to $38.00/bbl in the first quarter of 2025, from $45.75/bbl in the prior year quarter, primarily due to lower benchmark crack spreads and narrower crude differentials, partially offset by higher location differentials associated with the company’s regional markets and strong branded channel performance, contributing to a 99% margin capture compared to Suncor’s 5-2-2-1 index.

•

On a FIFO basis, Suncor’s refining and marketing gross margin decreased to $36.70/bbl in the first quarter of 2025, from $46.65/bbl in the prior year quarter, due to the same factors discussed above, in addition to FIFO inventory valuation impacts. In the first quarter of 2025, the FIFO method of inventory valuation resulted in a loss of $60 million, compared to a gain of $40 million in the prior year quarter, for an unfavourable quarter-over-quarter impact of $100 million.

(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. The impact of the FIFO method of inventory valuation, relative to an estimated LIFO accounting method, also includes the impact of the realized portion of commodity risk management activities. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.

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Expenses and Other Factors

Operating expenses in the first quarter of 2025 decreased compared to the prior year quarter, primarily due to decreased maintenance costs, partially offset by increased commodity input costs. Transportation expenses increased in the first quarter of 2025 compared to the prior year quarter, primarily due to increased refined product sales volumes.

Refining operating expense per barrel(1) decreased to $6.75 in the first quarter of 2025, compared to $7.15 in the prior year quarter, primarily due to lower maintenance costs and higher refinery production, partially offset by higher commodity input costs.

Planned Maintenance

The anticipated impact of these maintenance activities has been reflected in the company’s 2025 guidance.

•

The turnaround at the Sarnia refinery commenced in the first quarter, with completion expected in the second quarter.

•

The turnaround at the Edmonton refinery commenced subsequent to the first quarter and is expected to be completed in the second quarter.

CORPORATE AND ELIMINATIONS

Financial Highlights

	Three months ended<br> <br><br> March 31
($ millions)	2025		2024
Loss before income taxes		(215)		(539)
Adjusted for:
Unrealized foreign exchange (gain) loss on U.S. dollar denominated debt		(14)		220
Adjusted operating loss(1)		(229)		(319)
Corporate		(301)		(196)
Eliminations – Intersegment profit realized (eliminated)		72		(123)
Adjusted funds used in from operations(1)		(349)		(398)
Free funds deficit(1)		(356)		(404)

(1)

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 $301 million in the first quarter of 2025, compared to a loss of $196 million in the prior year quarter. The increased loss was primarily attributable to an operational foreign exchange loss in the first quarter of 2025 compared to a gain in the prior year quarter, partially offset by a decrease in share-based compensation expense in the first quarter of 2025 compared to 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 from internal purchases have been sold to third parties. During the first quarter of 2025, the company realized $72 million of intersegment profit, compared to an elimination of $123 million in the prior year quarter. The realization of intersegment profit in the first quarter of 2025 was primarily driven by a decrease in crude feedstock costs and a decrease in intersegment inventory volumes.

Corporate and Eliminations adjusted funds used in operations were $349 million for the first quarter of 2025, compared to adjusted funds used in operations of $398 million in the prior year quarter, and were influenced by the same factors impacting adjusted operating earnings, excluding the impact of share-based compensation expense.

(1)

Contains non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.

2025 First Quarter Suncor Energy Inc. 17

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First Quarter Discussion

INCOME TAX

	Three months ended<br> <br><br> March 31
($ millions)	2025		2024
Current income tax expense		648		649
Deferred income tax recovery		(47)		(39)
Income tax expense included in net earnings		601		610
Less: Income tax expense (recovery) on adjusted operating earnings adjustments		14		(11)
Income tax expense included in adjusted operating earnings		587		621
Effective tax rate		26.2%		27.5%

The provision for income taxes in the first quarter of 2025 decreased to $601 million, compared to $610 million in the prior year quarter, primarily due to a decrease in taxable earnings. In the first quarter of 2025, the company’s effective tax rate on net earnings decreased compared to the prior year quarter, primarily due to non-taxable foreign exchange gains on the revaluation of U.S. dollar denominated debt, as well as other permanent items impacting total tax expense in the first quarter of 2025.

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CAPITAL INVESTMENT UPDATE

Capital and Exploration Expenditures by Type, Excluding Capitalized Interest

	Three months ended
	March 31,<br> <br><br> 2025						March 31,<br> <br><br> 2024
($ millions)	Asset Sustainment and<br> <br><br> Maintenance(1)		Economic<br> <br><br> Investment(2)		Total		Total
Oil Sands
Oil Sands Base		131		111		242		453
In Situ		38		104		142		119
Fort Hills		51		72		123		144
Syncrude		126		76		202		213
E&P		—		191		191		135
R&M		145		35		180		167
Corporate and Eliminations		7		—		7		6
		498		589		1 087		1 237
Capitalized interest on debt						58		74
Total capital and exploration expenditures						1 145		1 311

(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 and maintaining current processing capacity.

(2)

Economic investment capital expenditures include capital investments that result in an increase in value by adding reserves or improving processing capacity, utilization, cost or margin, including associated infrastructure.

During the first quarter of 2025, the company incurred $1.087 billion of capital expenditures, excluding capitalized interest, compared to $1.237 billion in the prior year quarter. Suncor capitalized $58 million of its borrowing costs in the first quarter of 2025, as part of the cost of major development assets and construction projects in progress, compared to $74 million in the prior year quarter.

Economic investment expenditures in the first quarter of 2025 were primarily related to:

•

The Upgrader 1 coke drum replacement project, and the purchase of haul trucks equipped with autonomous haul systems at Oil Sands Base.

•

Ongoing design and construction of well pads to develop additional reserves that are intended to maintain existing production levels at In Situ.

•

Progressing the second opening at the North Pit mine at Fort Hills.

•

Progressing the Midred Lake West Extension mining project at Syncrude.

•

Progressing the West White Rose Project at E&P.

•

Enhancing the company’s R&M sales and marketing business.

Asset sustainment and maintenance expenditures in the first quarter of 2025 were primarily related to:

•

Preparation for planned turnarounds, mine tailings, mine equipment and other maintenance projects within the Oil Sands segment.

•

Planned turnaround activity in the current quarter, preparation for upcoming planned turnaround activity and sustainment of refinery, retail and logistics assets within the R&M segment.

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First Quarter Discussion

FINANCIAL CONDITION AND LIQUIDITY

Indicators

	Twelve months ended<br> <br><br> March 31
	2025		2024
Return on capital employed (ROCE)(1)(2)(3) (%)		12.8		15.7
Net debt to adjusted funds from operations(1)(4) (times)		0.6		0.7
Total debt to total debt plus shareholders’ equity(1)(4) (%)		18.7		21.3
Net debt to net debt plus shareholders’ equity(1)(4) (%)		14.4		17.7

(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)

For the twelve months ended March 31, 2025, and the twelve months ended March 31, 2024, there were no impairments or impairment reversals. As a result, ROCE excluding impairments was equal to ROCE.

(3)

Beginning in the second quarter of 2024, the company revised the definition of ROCE to exclude lease liabilities from the calculation of average capital employed and interest on lease liabilities from net interest expense to better align with how management and industry monitor capital structure. Prior period comparatives have been restated to reflect this change.

(4)

Beginning in the second quarter of 2024, the company revised the definition of net debt and total debt to exclude lease liabilities to better align with how management and industry monitor capital structure. Prior period comparatives have been restated to reflect this change.

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 2025 capital spending program of $6.1 billion to $6.3 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, 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 March 31, 2025, cash and cash equivalents decreased to $2.773 billion from $3.484 billion as at December 31, 2024. The use of cash in the first quarter of 2025 was due to the company’s shareholder returns, including the repurchase of Suncor’s common shares under its normal course issuer bid (NCIB) and the payment of dividends, and the company’s capital and exploration expenditures exceeding the company’s cash flow provided by operating activities.

As at March 31, 2025, the weighted average days to maturity of the company’s short-term investment portfolio was approximately 32 days.

As at March 31, 2025, available credit facilities for liquidity purposes were $5.470 billion, compared to $5.475 billion as at December 31, 2024.

Financing Activities

Management of debt levels and liquidity continues to be a priority for Suncor given the company’s long-term plans and the expected future volatility in the business environment. Suncor believes a phased and flexible approach to existing and future projects will help the company maintain its ability to manage project costs and debt levels.

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 and lease liabilities to not exceed 65% of its total debt and lease liabilities plus shareholders’ equity. As at March 31, 2025, total debt and lease liabilities to total debt and lease liabilities plus shareholders’ equity was 24.8% (December 31, 2024 – 24.8%). The company also continues to be in compliance with all operating covenants under its debt agreements.

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Change in Debt

	Three months ended
($ millions)	March 31, 2025
Total debt(1)(2) – beginning of period		10 345
Foreign exchange on debt, and other		(13)
Total debt(1)(2) – March 31, 2025		10 332
Less: Cash and cash equivalents – March 31, 2025		2 773
Net debt(1)(2) – March 31, 2025		7 559

(1)

Non-GAAP financial measures. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A.

(2)

The company’s total debt decreased slightly in the first quarter of 2025, due to favourable foreign exchange rates on U.S. dollar denominated debt compared to December 31, 2024.

As at March 31, 2025, Suncor’s net debt was $7.559 billion, compared to $6.861 billion as at December 31, 2024. The increase in net debt was primarily due to a decrease in cash and cash equivalents and the factors discussed above.

Common Shares

	March 31,
(thousands)	2025
Common shares		1 232 579
Common share options – exercisable		5 048
Common share options – non-exercisable		2 401

As at May 1, 2025, the total number of common shares outstanding was 1,227,580,565 and the total number of exercisable and non-exercisable common share options outstanding was 7,392,351. Once vested, each outstanding common share option is exercisable for one common share.

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First Quarter Discussion

Share Repurchases

	Commencement		Maximum<br> <br><br> Shares for		Maximum<br> <br><br> Shares for		Number of<br> <br><br> Shares
(thousands of common shares)	Date	Expiry	Repurchase		Repurchase (%)		Repurchased
2023 NCIB	February 17, 2023	February 16, 2024		132 900		10		47 107
2024 NCIB	February 26, 2024	February 25, 2025		128 700		10		61 066
2025 NCIB	March 3, 2025	March 2, 2026		123 800		10		10 039

Between March 3, 2025, and May 1, 2025, pursuant to Suncor’s NCIB, Suncor repurchased 10,039,441 common shares on the open market, representing the equivalent of 0.8% of its common shares as at February 18, 2025, for $511 million, at a weighted average price of $50.91 per share.

The actual number of common shares that may be repurchased under the NCIB and the timing of any such repurchases will be determined by Suncor. The company believes that, depending on the trading price of its common shares and other relevant factors, repurchasing 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<br> <br><br> March 31
($ millions, except as noted)	2025		2024
Share repurchase activities (thousands of common shares)		13 600		6 438
Weighted average repurchase price per share (dollars per share)		55.15		45.53
Share repurchase cost(1)		750		293

(1)

The three months ended March 31, 2025, excludes $48 million of taxes paid on 2024 share repurchase costs.

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 2024 annual MD&A, with no material updates to note during the three months ended March 31, 2025. 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.

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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.

Financial Summary

Three months ended<br> <br><br> ($ millions, unless otherwise noted)
Total production (mbbls/d)
Oil Sands	790.9	817.5	776.0	716.0	785.0	757.4	646.1	679.1
Exploration and Production	62.3	57.5	52.6	54.6	50.3	50.7	44.4	62.8
Total upstream production	853.2	875.0	828.6	770.6	835.3	808.1	690.5	741.9
Refinery crude oil processed (mbbls/d)	482.7	486.2	487.6	430.5	455.3	455.9	463.2	394.4
Revenues and other income
Gross revenues	13 330	13 657	13 905	14 014	13 305	13 589	13 911	12 434
Royalties	(1 007)	(1 126)	(1 017)	(1 125)	(924)	(779)	(1 262)	(715)
Operating revenues, net of royalties	12 323	12 531	12 888	12 889	12 381	12 810	12 649	11 719
Other income (loss)	130	(28)	174	151	148	1 328	(13)	(3)
	12 453	12 503	13 062	13 040	12 529	14 138	12 636	11 716
Net earnings	1 689	818	2 020	1 568	1 610	2 820	1 544	1 879
Per common share – basic (dollars)	1.36	0.65	1.59	1.22	1.25	2.18	1.19	1.44
Adjusted operating earnings(1)	1 629	1 566	1 875	1 626	1 817	1 635	1 980	1 253
Per common share(1)(2) (dollars)	1.31	1.25	1.48	1.27	1.41	1.26	1.52	0.96
Adjusted funds from operations(1)	3 045	3 493	3 787	3 397	3 169	4 034	3 634	2 655
Per common share(1)(2) (dollars)	2.46	2.78	2.98	2.65	2.46	3.12	2.80	2.03
Cash flow provided by operating activities	2 156	5 083	4 261	3 829	2 787	4 318	4 184	2 803
Per common share(2) (dollars)	1.74	4.05	3.36	2.98	2.16	3.34	3.22	2.14
Free funds flow(1)	1 900	1 923	2 232	1 350	1 858	2 482	2 057	1 042
Per common share(1)(2) (dollars)	1.53	1.53	1.76	1.05	1.44	1.92	1.58	0.80
ROCE(1)(3) (%) for the twelve months ended	12.8	13.0	15.6	15.6	15.7	16.3	16.5	13.2
ROCE excluding impairments and impairment reversals(1)(3) (%) for the twelve months ended	12.8	13.0	15.6	15.6	15.7	16.3	16.5	16.7
Net debt(1)(4)	7 559	6 861	7 968	9 054	9 552	9 852	9 837	11 170
Common share information (dollars)
Dividend per common share(2)	0.57	0.57	0.55	0.55	0.55	0.55	0.52	0.52
Share price at the end of trading
Toronto Stock Exchange (Cdn$)	55.72	51.31	49.92	52.15	49.99	42.45	46.71	38.86
New York Stock Exchange (US$)	38.72	35.68	36.92	38.10	36.91	32.04	34.38	29.32

(1)

Such financial measure is a non-GAAP financial measure or contains a non-GAAP financial measure. See the Non-GAAP and Other Financial Measures Advisory section of this MD&A. Adjusted operating earnings, adjusted funds from operations, net debt, free funds flow, ROCE and ROCE excluding impairments are defined in the Non-GAAP and Other Financial Measures Advisory section and reconciled to GAAP measures in the Consolidated Financial Information and the Segment Results and Analysis section in the respective Quarterly Report to Shareholders (Quarterly Report) issued by Suncor in respect of the relevant quarter, which information is incorporated by reference herein and is available on SEDAR+ at www.sedarplus.ca.

(2)

Presented on a basic per share basis.

(3)

(4)

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First Quarter Discussion

Business Environment

(average for the three months ended)
WTI crude oil at Cushing	US$/bbl	71.40	70.30	75.15	80.55	76.95	78.35	82.20	73.75
Dated Brent crude	US$/bbl	75.70	74.70	80.25	84.90	83.25	84.05	86.70	78.35
Dated Brent/Maya FOB price differential	US$/bbl	11.10	11.85	13.90	12.05	14.10	12.55	11.15	14.75
MSW at Edmonton	Cdn$/bbl	95.30	94.95	98.00	105.25	92.20	99.70	107.80	95.10
WCS at Hardisty	US$/bbl	58.75	57.75	61.65	67.00	57.60	56.45	69.30	58.70
WCS-WTI heavy/light differential	US$/bbl	(12.65)	(12.55)	(13.50)	(13.55)	(19.35)	(21.90)	(12.90)	(15.05)
SYN-WTI (differential) premium	US$/bbl	(2.35)	0.85	1.30	2.80	(7.40)	0.30	2.80	2.90
Condensate at Edmonton	US$/bbl	69.90	70.65	71.30	77.15	72.80	76.25	77.90	72.35
Natural gas (Alberta spot) at AECO	Cdn$/GJ	2.05	1.45	0.65	1.10	2.20	2.15	2.50	2.35
Alberta Power Pool Price	Cdn$/MWh	39.80	51.50	55.35	45.15	99.30	81.60	151.60	159.80
New York Harbor 2-1-1 crack(1)	US$/bbl	21.05	18.80	21.05	24.75	27.05	28.60	39.95	32.30
Chicago 2-1-1 crack(1)	US$/bbl	14.65	13.85	19.35	18.85	19.80	17.10	27.45	28.60
Portland 2-1-1 crack(1)	US$/bbl	22.30	20.95	20.35	29.30	26.85	29.35	55.90	37.30
Gulf Coast 2-1-1 crack(1)	US$/bbl	20.85	17.00	18.90	22.10	27.95	23.00	39.10	29.15
U.S. Renewable Volume Obligation	US$/bbl	4.75	4.05	3.90	3.40	3.70	4.75	7.45	7.70
Suncor custom 5-2-2-1 index(2)	US$/bbl	26.80	24.25	26.05	26.70	35.95	33.45	36.00	34.20
Exchange rate (average)	US$/Cdn$	0.70	0.71	0.73	0.73	0.74	0.73	0.75	0.74
Exchange rate (end of period)	US$/Cdn$	0.69	0.69	0.74	0.73	0.74	0.76	0.74	0.76

(1)

(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 2024 annual MD&A.

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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 2024 annual MD&A and in notes 3 and 5 of Suncor’s audited Consolidated Financial Statements for the year ended December 31, 2024.

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, 2024, and in the Accounting Policies and Critical Accounting Estimates section of Suncor’s 2024 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. 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, 2024, note 9 to the unaudited interim Consolidated Financial Statements for the three months ended March 31, 2025, and the Financial Condition and Liquidity section of the 2024 annual MD&A.

Control Environment

Based on their evaluation as at March 31, 2025, 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 addition, as at March 31, 2025, there were no 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 March 31, 2025, 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 as deemed necessary from time to time.

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.

Tariffs

In March 2025, the government of the United States of America announced tariffs on certain goods and products. Several countries (including Canada) responded with an escalation in tariffs and/or retaliatory tariffs. This has resulted in economic uncertainty in the global markets, disruption of supply chains, international competitiveness and fluctuations in commodity pricing. The company is closely monitoring these developments and will continue to assess the impacts of such tariffs and measures as the situation develops.

Corporate Guidance

There have been no changes to Suncor’s previously announced 2025 corporate guidance ranges (which were originally disclosed via press release on December 12, 2024), a copy of which is also available on www.sedarplus.ca.

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First Quarter Discussion

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 and Operating 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 analysis in 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, except for the company’s Libya operations, 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 the company’s Libya operations, 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.

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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 March 31
($ millions, except as noted)		2025		2024
Adjustments to net earnings
Net earnings			6 095		7 853
Add after-tax amounts for:
Unrealized foreign exchange loss on U.S. dollar denominated debt			393		27
Net interest expense			267		377
Adjusted net earnings(1)	A		6 755		8 257
Capital employed – beginning of twelve-month period
Net debt(2)(4)			9 552		12 439
Shareholders’ equity			44 308		39 949
			53 860		52 388
Capital employed – end of twelve-month period
Net debt(2)(4)			7 559		9 552
Shareholders’ equity			44 834		44 308
			52 393		53 860
Average capital employed	B		52 690		52 643
ROCE (%)(3)(5)	A/B		12.8		15.7

(1)

Total before-tax impact of adjustments is $799 million for the twelve months ended March 31, 2025, and $529 million for the twelve months ended March 31, 2024.

(2)

Net debt is a non-GAAP financial measure.

(3)

For the twelve months ended March 31, 2025, and the twelve months ended March 31, 2024, there were no impairments or impairment reversals. As a result, ROCE excluding impairments was equal to ROCE.

(4)

(5)

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First Quarter Discussion

Adjusted Funds From (Used In) Operations

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 March 31	Oil Sands				Exploration and<br> <br><br> Production				Refining and<br> <br><br> Marketing				Corporate and<br> <br><br> Eliminations				Income<br> <br><br> Taxes				Total
($ millions)	2025		2024		2025		2024		2025		2024		2025		2024		2025		2024		2025		2024
Earnings (loss) before income taxes		1 675		1 371		158		274		672		1 114		(215)		(539)		—		—		2 290		2 220
Adjustments for:
Depreciation, depletion, amortization and impairment		1 199		1 185		171		170		257		244		36		29		—		—		1 663		1 628
Accretion		124		126		16		16		3		3		—		—		—		—		143		145
Unrealized foreign exchange (gain) loss <br> <br><br> on U.S. dollar denominated debt		—		—		—		—		—		—		(14)		220		—		—		(14)		220
Change in fair value of financial instruments and trading inventory		(68)		2		(6)		3		17		25		—		—		—		—		(57)		30
Gain on disposal of assets		—		—		—		—		—		—		—		(3)				—		—		(3)
Share-based compensation		(86)		(171)		(6)		3		(40)		(78)		(171)		(128)		—		—		(303)		(374)
Settlement of decommissioning and restoration liabilities		(79)		(112)		(3)		(2)		(12)		(9)		—		—		—		—		(94)		(123)
Other		45		42		—		3		5		7		15		23		—		—		65		75
Current income tax expense		—		—		—		—		—		—		—		—		(648)		(649)		(648)		(649)
Adjusted funds from (used in) operations		2 810		2 443		330		467		902		1 306		(349)		(398)		(648)		(649)		3 045		3 169
Change in non-cash working capital																						(889)		(382)
Cash flow provided by operating<br> <br><br> activities																						2 156		2 787

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Free Funds Flow

Three months ended March 31	Oil Sands				Exploration and<br> <br><br> Production				Refining and<br> <br><br> Marketing				Corporate and<br> <br><br> Eliminations				Income<br> <br><br> Taxes				Total
($ millions)	2025		2024		2025		2024		2025		2024		2025		2024		2025		2024		2025		2024
Adjusted funds from (used in)<br> <br><br> operations		2 810		2 443		330		467		902		1 306		(349)		(398)		(648)		(649)		3 045		3 169
Capital expenditures including capitalized interest		(749)		(995)		(209)		(142)		(180)		(168)		(7)		(6)		—		—		(1 145)		(1 311)
Free funds flow (deficit)		2 061		1 448		121		325		722		1 138		(356)		(404)		(648)		(649)		1 900		1 858

Oil Sands Operations, Fort Hills and Syncrude Cash Operating Costs

Cash operating costs are calculated by adjusting Oil Sands segment OS&G expenses 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 – Cash Operating Costs section of this MD&A. Management uses cash operating costs to measure operating performance.

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First Quarter Discussion

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 expenses 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<br> <br><br> March 31
($ millions, except as noted)	2025		2024
Refining and marketing gross margin reconciliation
Operating revenues		7 628		7 613
Purchases of crude oil and products		(5 922)		(5 588)
		1 706		2 025
Other (loss) income		(12)		74
Non-refining and marketing margin		(13)		(42)
Refining and marketing gross margin – FIFO		1 681		2 057
Refinery production(1) (mbbls)		45 798		44 074
Refining and marketing gross margin – FIFO ($/bbl)		36.70		46.65
FIFO and risk management activities adjustment		60		(40)
Refining and marketing gross margin – LIFO		1 741		2 017
Refining and marketing gross margin – LIFO ($/bbl)		38.00		45.75
Refining operating expense reconciliation
Operating, selling and general expense		609		618
Non-refining costs		(301)		(303)
Refining operating expense		308		315
Refinery production(1) (mbbls)		45 798		44 074
Refining operating expense ($/bbl)		6.75		7.15

(1)

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Impact of 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, 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

	March 31		December 31
($ millions, except as noted)	2025		2024
Short-term debt		—		—
Current portion of long-term debt		997		997
Long-term debt		9 335		9 348
Total debt(1)		10 332		10 345
Less: Cash and cash equivalents		2 773		3 484
Net debt(1)		7 559		6 861
Shareholders’ equity		44 834		44 514
Total debt plus shareholders’ equity		55 166		54 859
Total debt to total debt plus shareholders’ equity(1) (%)		18.7		18.9
Net debt to net debt plus shareholders’ equity(1) (%)		14.4		13.4

(1)

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First Quarter Discussion

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

Three months ended	March 31, 2025								March 31, 2024
($ millions, except as noted)	Non-<br> <br><br> Upgraded<br> <br><br> Bitumen		Upgraded – <br> <br><br> Net<br> <br><br> SCO and<br> <br><br> Diesel		Average<br> <br><br> Crude		Oil<br> <br><br> Sands<br> <br><br> Segment		Non-<br> <br><br> Upgraded<br> <br><br> Bitumen		Upgraded – <br> <br><br> Net<br> <br><br> SCO and<br> <br><br> Diesel		Average<br> <br><br> Crude		Oil<br> <br><br> Sands<br> <br><br> Segment
Operating revenues		2 285		4 856		7 141		7 141		2 062		4 860		6 922		6 922
Other income (loss)		41		57		98		98		59		(4)		55		55
Purchases of crude oil and products		(572)		(37)		(609)		(609)		(557)		(72)		(629)		(629)
Gross realization adjustment(1)		(35)		(154)		(189)				(22)		(94)		(116)
Gross realization		1 719		4 722		6 441				1 542		4 690		6 232
Transportation and distribution		(151)		(145)		(296)		(296)		(158)		(134)		(292)		(292)
Price realization		1 568		4 577		6 145				1 384		4 556		5 940
Sales volumes (mbbls)		22 041		47 567		69 608				21 280		50 077		71 357
Price realization per barrel		71.13		96.24		88.28				65.11		90.97		83.24

(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.

E&P Price Realizations

Three months ended	March 31, 2025						March 31, 2024
($ millions, except as noted)	E&P<br> <br><br> Canada		Other(1)(2)		E&P<br> <br><br> Segment		E&P<br> <br><br> Canada		Other(1)(2)		E&P<br> <br><br> Segment
Operating revenues		470		259		729		609		156		765
Transportation and distribution		(19)		(3)		(22)		(23)		(2)		(25)
Price realization		451		256				586		154
Sales volumes (mbbls)		4 344						5 432
Price realization per barrel		103.82						107.52

(1)

Reflects other E&P assets, such as Libya, for which price realizations are not provided.

(2)

Production from the company’s Libya operations is presented on an economic basis. Revenue and royalties from the company’s Libya operations are presented on a working-interest basis, which is required for presentation purposes in the company’s Consolidated Financial Statements. In the first quarter of 2025, revenue included a gross-up amount of $196 million (2024 – $119 million), with an offsetting amount of $106 million (2024 – $62 million) in royalties in the E&P segment and $90 million (2024 – $57 million) in income tax expense recorded at the consolidated level.

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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
GJ	Gigajoule	US$	United States dollars

MW	megawatts
MWh	megawatts per hour	Financial and Business Environment
		Q1	Three months ended March 31
		DD&A	Depreciation, depletion and amortization
		WTI	West Texas Intermediate
		WCS	Western Canadian Select
		SCO	Synthetic crude oil
		SYN	Synthetic crude oil benchmark
		MSW	Mixed Sweet Blend

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First Quarter Discussion

ADVISORIES

Forward-Looking Statements

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;

•

expectations regarding planned maintenance events, including the timing and completion of turnarounds at the Sarnia and Edmonton refineries and at Firebag, and maintenance events at Oil Sands Upgrader 1 and Fort Hills.

•

Suncor’s expectation that production at White Rose will return to normal levels in the second quarter;

•

Suncor’s expectation that In Situ design and construction of new well pads will maintain existing production levels;

•

statements regarding Suncor’s planned 2025 capital spending program of $6.1 billion to $6.3 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;

•

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;

•

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, and Suncor’s belief that a phased and flexible approach to existing and future projects will help the company manage project costs and debt levels; and

•

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.

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,

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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 the 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 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, currency exchange rates and potential trade tariffs (including as a result of demand and supply effects resulting from the actions of OPEC+ and/or the impact of armed conflicts in the Middle East, the impact of the Russian invasion of Ukraine and/or the impact of changes to the U.S. government economic policy); 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; the ability to maintain 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 relating to increased activism and public opposition to fossil fuels and oil sands; 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 2024 annual MD&A, the 2024 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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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(unaudited)

	Three months ended <br> <br><br> March 31
($ millions)	2025		2024
Revenues and Other Income
Gross revenues (note 3)		13 330		13 305
Less: royalties		(1 007)		(924)
Other income (note 4)		130		148
		12 453		12 529
Expenses
Purchases of crude oil and products		4 300		4 358
Operating, selling and general		3 297		3 440
Transportation and distribution		448		410
Depreciation, depletion, amortization and impairment		1 663		1 628
Exploration		122		59
Gain on disposal of assets		—		(3)
Financing expenses (note 6)		333		417
		10 163		10 309
Earnings before Income Taxes		2 290		2 220
Income Tax Expense (Recovery)
Current		648		649
Deferred		(47)		(39)
		601		610
Net Earnings		1 689		1 610
Other Comprehensive Income
Items That May be Subsequently Reclassified to Earnings:
Foreign currency translation adjustment		(21)		(16)
Items That Will Not be Reclassified to Earnings:
Actuarial gain on employee retirement benefit plans, net of income taxes		35		399
Other Comprehensive Income		14		383
Total Comprehensive Income		1 703		1 993
Per Common Share (dollars) (note 7)
Net earnings – basic and diluted		1.36		1.25
Cash dividends		0.57		0.55

See accompanying notes to the condensed interim consolidated financial statements.

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CONSOLIDATED BALANCE SHEETS

(unaudited)

($ millions)
Assets
Current assets
Cash and cash equivalents	2 773	3 484
Accounts receivable	5 379	5 245
Inventories	5 679	5 041
Income taxes receivable	522	518
Total current assets	14 353	14 288
Property, plant and equipment, net	68 280	68 512
Exploration and evaluation	1 742	1 742
Other assets	1 626	1 559
Goodwill and other intangible assets	3 489	3 503
Deferred income taxes	208	180
Total assets	89 698	89 784
Liabilities and Shareholders’ Equity
Current liabilities
Current portion of long-term debt	997	997
Current portion of long-term lease liabilities	617	599
Accounts payable and accrued liabilities	7 779	8 161
Current portion of provisions	935	958
Income taxes payable	33	32
Total current liabilities	10 361	10 747
Long-term debt	9 335	9 348
Long-term lease liabilities	3 841	3 745
Other long-term liabilities	1 290	1 502
Provisions	12 049	11 931
Deferred income taxes	7 988	7 997
Equity	44 834	44 514
Total liabilities and shareholders’ equity	89 698	89 784

See accompanying notes to the condensed interim consolidated financial statements.

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CONSOLIDATED STATEMENTS OF CASH FLOWS

(unaudited)

	Three months ended <br> <br><br> March 31
($ millions)	2025		2024
Operating Activities
Net Earnings		1 689		1 610
Adjustments for:
Depreciation, depletion, amortization and impairment		1 663		1 628
Deferred income tax recovery		(47)		(39)
Accretion (note 6)		143		145
Unrealized foreign exchange (gain) loss on U.S. dollar denominated debt (note 6)		(14)		220
Change in fair value of financial instruments and trading inventory		(57)		30
Gain on disposal of assets		—		(3)
Share-based compensation		(303)		(374)
Settlement of decommissioning and restoration liabilities		(94)		(123)
Other		65		75
Increase in non-cash working capital		(889)		(382)
Cash flow provided by operating activities		2 156		2 787
Investing Activities
Capital and exploration expenditures		(1 145)		(1 311)
Proceeds from disposal of assets		—		8
Other investments		(6)		(1)
Increase in non-cash working capital		(104)		(31)
Cash flow used in investing activities		(1 255)		(1 335)
Financing Activities
Net increase in short-term debt		—		221
Lease liability payments		(180)		(98)
Issuance of common shares under share option plans		75		130
Repurchase of common shares(1) (note 8)		(798)		(293)
Distributions relating to non-controlling interest		(4)		(4)
Dividends paid on common shares		(705)		(702)
Cash flow used in financing activities		(1 612)		(746)
(Decrease) Increase in Cash and Cash Equivalents		(711)		706
Effect of foreign exchange on cash and cash equivalents		—		29
Cash and cash equivalents at beginning of period		3 484		1 729
Cash and Cash Equivalents at End of Period		2 773		2 464
Supplementary Cash Flow Information
Interest paid		148		136
Income taxes paid		604		25

(1)

Includes $48 million of taxes paid on 2024 share repurchases for the three months ended March 31, 2025.

See accompanying notes to the condensed interim consolidated financial statements.

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CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY

(unaudited)

($ millions)
At December 31, 2023	21 661	569	1 048	20 001	43 279	1 290 100
Net earnings	—	—	—	1 610	1 610	—
Foreign currency translation adjustment	—	—	(16)	—	(16)	—
Actuarial gain on employee retirement benefit plans, <br> <br><br> net of income taxes of $126	—	—	—	399	399	—
Total comprehensive income	—	—	(16)	2 009	1 993	—
Issued under share option plans	151	(21)	—	—	130	3 352
Repurchase of common shares for cancellation (note 8)	(108)	—	—	(185)	(293)	(6 438)
Change in liability for share repurchase commitment	(25)	—	—	(77)	(102)	—
Share-based compensation	—	3	—	—	3	—
Dividends paid on common shares	—	—	—	(702)	(702)	—
At March 31, 2024	21 679	551	1 032	21 046	44 308	1 287 014
At December 31, 2024	21 121	520	1 201	21 672	44 514	1 244 332
Net earnings	—	—	—	1 689	1 689	—
Foreign currency translation adjustment	—	—	(21)	—	(21)	—
Actuarial gain on employee retirement benefit plans, <br> <br><br> net of income taxes of $11	—	—	—	35	35	—
Total comprehensive income	—	—	(21)	1 724	1 703	—
Issued under share option plans	88	(13)	—	—	75	1 847
Repurchase of common shares for cancellation(1) (note 8)	(232)	—	—	(531)	(763)	(13 600)
Change in liability for share repurchase commitment <br> <br><br> (note 8)	10	—	—	(4)	6	—
Share-based compensation (note 5)	—	4	—	—	4	—
Dividends paid on common shares	—	—	—	(705)	(705)	—
At March 31, 2025	20 987	511	1 180	22 156	44 834	1 232 579

(1)

Includes $13 million of taxes on share repurchases for the three months ended March 31, 2025 (March 31, 2024 – nil).

See accompanying notes to the condensed interim consolidated financial statements.

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NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

REPORTING ENTITY AND DESCRIPTION OF THE BUSINESS

The address of the company’s registered office is 150 – 6th Avenue S.W., Calgary, Alberta, Canada, T2P 3E3.

BASIS OF PREPARATION

(a) Statement of Compliance

These condensed interim consolidated financial statements are based on International Financial Reporting Standards as issued by the International Accounting Standards Board, and have been prepared in accordance with International Accounting Standard 34 Interim Financial Reporting. They are condensed as they do not include all of the information required for full annual financial statements, and

they should be read in conjunction with the audited consolidated financial statements of the company for the year ended December 31, 2024.

(b) Basis of Measurement

The consolidated financial statements are prepared on a historical cost basis except as detailed in the accounting policies disclosed in the company’s audited consolidated financial statements for the year ended December 31, 2024.

These consolidated financial statements are presented in Canadian dollars, which is the company’s functional currency.

(d) Use of Estimates, Assumptions and Judgments

The timely preparation of financial statements requires that management make estimates and assumptions and use judgment. Accordingly, actual results may differ from estimated amounts as future confirming events occur. Significant estimates and judgment used in the preparation of the financial statements are described in the company’s audited consolidated financial statements for the year ended December 31, 2024.

(e) Income Taxes

The company recognizes the impacts of income tax rate changes in earnings in the period that the applicable rate change is enacted or substantively enacted.

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SEGMENTED INFORMATION

The company’s operating segments are reported based on the nature of their products and services and management responsibility.

Intersegment sales of crude oil are accounted for at market values and are included, for segmented reporting, in revenues of the segment making the transfer and expenses of the segment receiving the transfer. Intersegment amounts are eliminated on consolidation.

Three months ended March 31	Oil Sands				Exploration and<br> <br><br> Production				Refining and<br> <br><br> Marketing				Corporate and<br> <br><br> Eliminations				Total
($ millions)	2025		2024		2025		2024		2025		2024		2025		2024		2025		2024
Revenues and Other Income
Gross revenues		4 990		4 938		729		765		7 611		7 603		—		(1)		13 330		13 305
Intersegment revenues		2 151		1 984		—		—		17		10		(2 168)		(1 994)		—		—
Less: Royalties		(815)		(782)		(192)		(142)		—		—		—		—		(1 007)		(924)
Operating revenues, net of royalties		6 326		6 140		537		623		7 628		7 613		(2 168)		(1 995)		12 323		12 381
Other income (loss)		98		55		5		6		(12)		74		39		13		130		148
		6 424		6 195		542		629		7 616		7 687		(2 129)		(1 982)		12 453		12 529
Expenses
Purchases of crude oil and products		609		629		—		—		5 922		5 588		(2 231)		(1 859)		4 300		4 358
Operating, selling and general		2 392		2 482		120		141		609		618		176		199		3 297		3 440
Transportation and distribution		296		292		22		25		139		103		(9)		(10)		448		410
Depreciation, depletion, amortization and impairment		1 199		1 185		171		170		257		244		36		29		1 663		1 628
Exploration		68		57		54		2		—		—		—		—		122		59
Gain on disposal of assets		—		—		—		—		—		—		—		(3)		—		(3)
Financing expenses		185		179		17		17		17		20		114		201		333		417
		4 749		4 824		384		355		6 944		6 573		(1 914)		(1 443)		10 163		10 309
Earnings (Loss) before<br> <br><br> Income Taxes		1 675		1 371		158		274		672		1 114		(215)		(539)		2 290		2 220
Income Tax Expense (Recovery)
Current		—		—		—		—		—		—		—		—		648		649
Deferred		—		—		—		—		—		—		—		—		(47)		(39)
		—		—		—		—		—		—		—		—		601		610
Net Earnings		—		—		—		—		—		—		—		—		1 689		1 610
Capital and Exploration Expenditures		749		995		209		142		180		168		7		6		1 145		1 311

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NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

Disaggregation of Revenue from Contracts with Customers and Intersegment Revenue

The company’s revenues are from the following major commodities:

Three months ended March 31	2025						2024
($ millions)	North America		International		Total		North America		International		Total
Oil Sands
Synthetic crude oil and diesel		4 856		—		4 856		4 860		—		4 860
Bitumen		2 285		—		2 285		2 062		—		2 062
		7 141		—		7 141		6 922		—		6 922
Exploration and Production
Crude oil and natural gas liquids		470		259		729		609		156		765
		470		259		729		609		156		765
Refining and Marketing
Gasoline		3 248		—		3 248		2 990		—		2 990
Distillate		3 747		—		3 747		3 961		—		3 961
Other		633		—		633		662		—		662
		7 628		—		7 628		7 613		—		7 613
Corporate and Eliminations
		(2 168)		—		(2 168)		(1 995)		—		(1 995)
Total Revenue from Contracts with Customers		13 071		259		13 330		13 149		156		13 305

OTHER INCOME

Other income consists of the following:

	Three months ended <br> <br><br> March 31
($ millions)	2025		2024
Energy trading and risk management		69		56
Investment and interest income		56		39
Insurance proceeds and other		5		53
		130		148

SHARE-BASED COMPENSATION

The following table summarizes the share-based compensation expense for all plans recorded within operating, selling and general expense:

	Three months ended <br> <br><br> March 31
($ millions)	2025		2024
Equity-settled plans		4		3
Cash-settled plans		141		156
		145		159

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FINANCING EXPENSES

	Three months ended <br> <br><br> March 31
($ millions)	2025		2024
Interest on debt		148		181
Interest on lease liabilities		73		56
Capitalized interest		(58)		(74)
Interest expense		163		163
Interest on partnership liability		12		12
Interest on pension and other post-retirement benefits		(1)		6
Accretion		143		145
Foreign exchange (gain) loss on U.S. dollar denominated debt and leases		(14)		220
Operational foreign exchange and other		30		(129)
		333		417

EARNINGS PER COMMON SHARE

	Three months ended <br> <br><br> March 31
($ millions)	2025		2024
Net earnings		1 689		1 610
(millions of common shares)
Weighted average number of common shares		1 239		1 288
Dilutive securities:
Effect of share options		1		2
Weighted average number of diluted common shares		1 240		1 290
(dollars per common share)
Basic and diluted earnings per share		1.36		1.25

NORMAL COURSE ISSUER BID

Share Repurchase Programs

(thousands of common shares)	Commencement<br> <br><br> Date	Expiry
2023 Normal Course Issuer Bid	February 17, 2023	February 16, 2024	132 900	10	47 107
2024 Normal Course Issuer Bid	February 26, 2024	February 25, 2025	128 700	10	61 066
2025 Normal Course Issuer Bid	March 3, 2025	March 2, 2026	123 800	10	4 650

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NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

The following table summarizes the share repurchase activities during the period: mmarizes the share repurchase activities during the period:

	Three months ended <br> <br><br> March 31
($ millions, except as noted)	2025		2024
Share repurchase activities (thousands of common shares)
Shares repurchased		13 600		6 438
Amounts charged to:
Share capital		232		108
Retained earnings		518		185
Share repurchase cost before tax		750		293
Retained earnings – share buyback tax payable		13		—
Share repurchase cost		763		293

Under an automatic repurchase plan agreement with an independent broker, the company has recorded the following liability for share repurchases that may take place during its internal blackout periods:

($ millions)
Amounts charged to:
Share capital	94	104
Retained earnings	213	209
Liability for share purchase commitment	307	313

FINANCIAL INSTRUMENTS

Derivative Financial Instruments

(a) Non-Designated Derivative Financial Instruments

The company uses derivative financial instruments, such as physical and financial contracts, to manage certain exposures to fluctuations in interest rates, commodity prices and foreign currency exchange rates, as part of its overall risk management program, as well as for trading purposes.

The changes in the fair value of non-designated derivatives are as follows:

	($ millions)			Total
	Fair value outstanding at December 31, 2024					82
	Changes in fair value recognized in earnings during the period					37
	Cash settlements – (received) paid during the period					(20)
	Fair value outstanding at March 31, 2025					99

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(b) Fair Value Hierarchy

To estimate the fair value of derivatives, the company uses quoted market prices when available, or third-party models and valuation methodologies that utilize observable market data. In addition to market information, the company incorporates transaction-specific details that market participants would utilize in a fair value measurement, including the impact of non-performance risk. However, these fair value estimates may not necessarily be indicative of the amounts that could be realized or settled in a current market transaction. The company characterizes inputs used in determining fair value using a hierarchy that prioritizes inputs depending on the degree to which they are observable. The three levels of the fair value hierarchy are as follows:

•

Level 1 consists of instruments with a fair value determined by an unadjusted quoted price in an active market for identical assets or liabilities. An active market is characterized by readily and regularly available quoted prices where the prices are representative of actual and regularly occurring market transactions to assure liquidity.

•

Level 2 consists of instruments with a fair value that is determined by quoted prices in an inactive market, prices with observable inputs or prices with insignificant non-observable inputs. The fair value of these positions is determined using observable inputs from exchanges, pricing services, third-party independent broker quotes and published transportation tolls. The observable inputs may be adjusted using certain methods, which include extrapolation over the quoted price term and quotes for comparable assets and liabilities.

•

Level 3 consists of instruments with a fair value that is determined by prices with significant unobservable inputs. As at March 31, 2025, the company does not have any derivative instruments measured at fair value Level 3.

In forming estimates, the company utilizes the most observable inputs available for valuation purposes. If a fair value measurement reflects inputs of different levels within the hierarchy, the measurement is categorized based upon the lowest level of input that is significant to the fair value measurement.

The following table presents the company’s derivative financial instruments measured at fair value for each hierarchy level as at March 31, 2025:

($ millions)
Accounts receivable	73	124	—	197
Accounts payable	(72)	(26)	—	(98)
	1	98	—	99

During the first quarter of 2025, there were no transfers between Level 1 and Level 2 fair value measurements.

Non-Derivative Financial Instruments

At March 31, 2025, the carrying value of fixed-term debt accounted for under amortized cost was $10.3 billion (December 31, 2024 – $10.3 billion) and the fair value was $10.2 billion (December 31, 2024 – $10.1 billion). The estimated fair value of long-term debt is based on pricing sourced from market data.

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Supplemental Financial and Operating Information

      Quarterly Financial Summary

(unaudited)

	Quarter Ended										Year Ended
($ millions, except per share amounts)	Mar 31<br> <br><br> 2025		Dec 31<br> <br><br> 2024		Sep 30<br> <br><br> 2024		Jun 30<br> <br><br> 2024		Mar 31<br> <br><br> 2024		Dec 31<br> <br><br> 2024
Gross revenues		13 330		13 657		13 905		14 014		13 305		54 881
Less: Royalties		(1 007)		(1 126)		(1 017)		(1 125)		(924)		(4 192)
Operating revenues, net of royalties		12 323		12 531		12 888		12 889		12 381		50 689
Earnings (loss) before income taxes
Oil Sands		1 675		1 625		1 819		1 792		1 371		6 607
Exploration and Production		158		125		272		196		274		867
Refining and Marketing		672		410		479		593		1 114		2 596
Corporate and Eliminations		(215)		(1 070)		124		(398)		(539)		(1 883)
Income tax expense		(601)		(272)		(674)		(615)		(610)		(2 171)
Net earnings		1 689		818		2 020		1 568		1 610		6 016
Adjusted operating earnings (loss)(A)
Oil Sands		1 620		1 609		1 786		1 745		1 365		6 505
Exploration and Production		158		125		272		196		274		867
Refining and Marketing		667		410		484		588		1 118		2 600
Corporate and Eliminations		(229)		(200)		1		(295)		(319)		(813)
Income tax expense included in adjusted operating earnings		(587)		(378)		(668)		(608)		(621)		(2 275)
Total		1 629		1 566		1 875		1 626		1 817		6 884
Adjusted funds from (used in) operations(A)
Oil Sands		2 810		3 126		3 165		3 108		2 443		11 842
Exploration and Production		330		274		471		398		467		1 610
Refining and Marketing		902		638		701		893		1 306		3 538
Corporate and Eliminations		(349)		(131)		71		(221)		(398)		(679)
Current income tax expense		(648)		(414)		(621)		(781)		(649)		(2 465)
Total		3 045		3 493		3 787		3 397		3 169		13 846
Change in non-cash working capital		(889)		1 590		474		432		(382)		2 114
Cash flow provided by operating activities		2 156		5 083		4 261		3 829		2 787		15 960
Free funds flow (deficit)(A)(B)
Oil Sands		2 061		2 185		2 198		1 671		1 448		7 502
Exploration and Production		121		19		190		169		325		703
Refining and Marketing		722		286		406		518		1 138		2 348
Corporate and Eliminations		(356)		(153)		59		(227)		(404)		(725)
Current income tax expense		(648)		(414)		(621)		(781)		(649)		(2 465)
Total		1 900		1 923		2 232		1 350		1 858		7 363
Per common share
Net earnings – basic		1.36		0.65		1.59		1.22		1.25		4.72
Net earnings – diluted		1.36		0.65		1.59		1.22		1.25		4.72
Adjusted operating earnings(A)(C)		1.31		1.25		1.48		1.27		1.41		5.40
Cash dividends(C)		0.57		0.57		0.55		0.55		0.55		2.22
Adjusted funds from operations(A)(C)		2.46		2.78		2.98		2.65		2.46		10.87
Cash flow provided by operating activities(C)		1.74		4.05		3.36		2.98		2.16		12.53
Free funds flow(A)(B)(C)		1.53		1.53		1.76		1.05		1.44		5.78
Returns to shareholders
Dividends paid on common shares		705		713		690		698		702		2 803
Repurchase of common shares		750		1 000		790		825		293		2 908
Total returns to shareholders		1 455		1 713		1 480		1 523		995		5 711
Capital and exploration expenditures (including capitalized interest)
Oil Sands		749		941		967		1 437		995		4 340
Exploration and Production		209		255		281		229		142		907
Refining and Marketing		180		352		295		375		168		1 190
Corporate and Eliminations		7		22		12		6		6		46
Total capital and exploration expenditures		1 145		1 570		1 555		2 047		1 311		6 483

(A)

Non-GAAP financial measures or contains non-GAAP financial measures. See the Operating Summary Information – Non-GAAP and Other Financial Measures section of this Quarterly Report.

(B)

Beginning in the second quarter of 2024, the company included the presentation of free funds flow by segment and on a basic per share basis.

(C)

Presented on a basic per share basis.

See accompanying footnotes and definitions to the quarterly operating summaries.

46 2025 First Quarter Suncor Energy Inc.

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Supplemental Financial and Operating Information (continued)

      Quarterly Financial Summary

(unaudited)

	For the twelve months ended
	Mar 31<br> <br><br> 2025		Dec 31<br> <br><br> 2024		Sep 30<br> <br><br> 2024		Jun 30<br> <br><br> 2024		Mar 31<br> <br><br> 2024
Return on capital employed (ROCE)(A)(D) (%)		12.8		13.0		15.6		15.6		15.7
ROCE excluding impairments and impairment reversals(A)(D) (%)		12.8		13.0		15.6		15.6		15.7

(A)

Non-GAAP financial measures or contains non-GAAP financial measures. See the Operating Summary Information – Non-GAAP and Other Financial Measures section of this Quarterly Report.

(D)

See accompanying footnotes and definitions to the quarterly operating summaries.

2025 First Quarter Suncor Energy Inc. 47

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Quarterly Operating Summary

(unaudited)

	Quarter Ended										Year <br> <br><br> Ended
Oil Sands	Mar 31<br> <br><br> 2025		Dec 31<br> <br><br> 2024		Sep 30<br> <br><br> 2024		Jun 30<br> <br><br> 2024		Mar 31<br> <br><br> 2024		Dec 31<br> <br><br> 2024
Production volumes (mbbls/d)
Total Oil Sands bitumen production		937.3		951.5		909.6		834.4		932.1		907.0
Oil Sands production volumes(A)
Oil Sands operations – SCO, diesel and other products		361.3		357.6		329.5		321.6		374.6		345.8
Oil Sands operations – Bitumen		165.3		180.9		128.5		136.9		120.3		141.8
Syncrude – SCO, diesel and bitumen		206.0		214.9		213.8		171.1		197.9		199.5
Fort Hills – Bitumen		176.4		161.7		166.0		166.9		177.6		168.0
Inter-asset transfers and consumption		(118.1)		(97.6)		(61.8)		(80.5)		(85.4)		(81.3)
Total Oil Sands production volumes		790.9		817.5		776.0		716.0		785.0		773.8
Oil Sands – upgraded – net SCO and diesel
Oil Sands operations		361.3		357.6		329.5		321.6		374.6		345.8
Syncrude		206.0		214.9		213.7		166.7		197.9		198.4
Inter-asset transfers and consumption		(30.7)		(28.9)		(29.4)		(26.6)		(27.5)		(28.1)
Total Oil Sands – upgraded – net SCO and diesel production		536.6		543.6		513.8		461.7		545.0		516.1
Oil Sands – non-upgraded bitumen
Oil Sands operations		165.3		180.9		128.5		136.9		120.3		141.8
Fort Hills		176.4		161.7		166.0		166.9		177.6		168.0
Syncrude		—		—		0.1		4.4		—		1.1
Inter-asset transfers		(87.4)		(68.7)		(32.4)		(53.9)		(57.9)		(53.2)
Total Oil Sands – non-upgraded bitumen production		254.3		273.9		262.2		254.3		240.0		257.7
Oil Sands production volumes to market
Upgraded – net SCO and diesel		536.6		543.6		513.8		461.7		545.0		516.1
Non-upgraded bitumen		254.3		273.9		262.2		254.3		240.0		257.7
Total Oil Sands production volumes		790.9		817.5		776.0		716.0		785.0		773.8
Oil Sands sales volumes (mbbls/d)
Upgraded – net SCO and diesel		528.5		538.3		510.3		453.8		550.3		513.2
Non-upgraded bitumen		244.9		282.3		254.2		272.6		233.8		260.8
Total Oil Sands sales volumes		773.4		820.6		764.5		726.4		784.1		774.0
Oil Sands operations cash operating costs(1)(B) ($ millions)
Cash costs		1 194		1 235		1 045		1 123		1 107		4 510
Natural gas		123		80		40		65		103		288
		1 317		1 315		1 085		1 188		1 210		4 798
Oil Sands operations cash operating costs(1)(B) ($/bbl)*
Cash costs		25.20		24.95		24.80		26.90		24.55		25.30
Natural gas		2.60		1.60		0.95		1.55		2.30		1.60
		27.80		26.55		25.75		28.45		26.85		26.90
Fort Hills cash operating costs(1)(B) ($ millions)
Cash costs		514		493		501		453		505		1 952
Natural gas		24		17		9		12		26		64
		538		510		510		465		531		2 016
Fort Hills cash operating costs(1)(B) ($/bbl)*
Cash costs		32.35		33.15		32.80		29.80		31.20		31.75
Natural gas		1.50		1.10		0.60		0.80		1.65		1.05
		33.85		34.25		33.40		30.60		32.85		32.80
Syncrude cash operating costs(1)(B) ($ millions)
Cash costs		654		637		643		615		620		2 515
Natural gas		16		12		6		10		22		50
		670		649		649		625		642		2 565
Syncrude cash operating costs(1)(B) ($/bbl)*
Cash costs		35.25		32.20		32.70		39.50		34.45		34.45
Natural gas		0.85		0.60		0.30		0.65		1.25		0.70
		36.10		32.80		33.00		40.15		35.70		35.15

(A)

Beginning in the first quarter of 2024, to better reflect the company’s individual asset performance, the company revised the presentation of its production volumes to include a gross production view for individual assets.

(B)

Non-GAAP financial measures or contains non-GAAP financial measures. See the Quarterly Operating Metrics Reconciliation and the Operating Summary Information – Non-GAAP and Other Financial Measures sections of this Quarterly Report.

See accompanying footnotes and definitions to the quarterly operating summaries.

48 2025 First Quarter Suncor Energy Inc.

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Quarterly Operating Summary (continued)

(unaudited)

	Quarter Ended										Year Ended
Oil Sands Segment Operating Netbacks(A)(B)	Mar 31<br> <br><br> 2025		Dec 31<br> <br><br> 2024		Sep 30<br> <br><br> 2024		Jun 30<br> <br><br> 2024		Mar 31<br> <br><br> 2024		Dec 31<br> <br><br> 2024
Non-upgraded bitumen ($/bbl)
Average price realized		78.00		76.43		79.37		88.08		72.52		79.31
Royalties		(10.20)		(12.13)		(10.77)		(13.29)		(10.41)		(11.71)
Transportation and distribution costs		(6.87)		(7.19)		(6.49)		(5.62)		(7.41)		(6.66)
Net operating expenses		(19.05)		(19.65)		(22.93)		(19.94)		(22.74)		(21.22)
Operating netback		41.88		37.46		39.18		49.23		31.96		39.72
Upgraded – net SCO and diesel ($/bbl)
Average price realized		99.27		98.58		103.52		110.20		93.64		101.05
Royalties		(12.41)		(12.58)		(14.32)		(16.25)		(11.19)		(13.45)
Transportation and distribution costs		(3.03)		(3.30)		(2.95)		(3.71)		(2.67)		(3.14)
Net operating expenses		(36.83)		(35.31)		(33.39)		(39.28)		(34.49)		(35.48)
Operating netback		47.00		47.39		52.86		50.96		45.29		48.98
Average Oil Sands segment ($/bbl)
Average price realized		92.54		90.96		95.49		101.90		87.34		93.73
Royalties		(11.71)		(12.43)		(13.14)		(15.14)		(10.96)		(12.87)
Transportation and distribution costs		(4.26)		(4.64)		(4.13)		(4.42)		(4.10)		(4.32)
Net operating expenses		(31.20)		(29.92)		(29.91)		(32.02)		(30.98)		(30.68)
Operating netback		45.37		43.97		48.31		50.32		41.30		45.86

(A)

Contains non-GAAP financial measures. See the Quarterly Operating Metrics Reconciliation and the Operating Summary Information – Non-GAAP and Other Financial Measures sections of this Quarterly Report.

(B)

Netbacks are based on sales volumes. Impact of inventory writedown is excluded until product is sold.

See accompanying footnotes and definitions to the quarterly operating summaries.

2025 First Quarter Suncor Energy Inc. 49

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Quarterly Operating Summary (continued)

(unaudited)

	Quarter Ended										Year Ended
Exploration and Production	Mar 31<br> <br><br> 2025		Dec 31<br> <br><br> 2024		Sep 30<br> <br><br> 2024		Jun 30<br> <br><br> 2024		Mar 31<br> <br><br> 2024		Dec 31<br> <br><br> 2024
Production volumes
E&P Canada (mbbls/d)		55.6		50.3		52.6		49.0		46.7		49.7
E&P International (mbbls/d)		6.7		7.2		—		5.6		3.6		4.1
Total production volumes (mbbls/d)		62.3		57.5		52.6		54.6		50.3		53.8

Total sales volumes (mbbls/d)		55.0		44.8		70.1		46.8		63.3		56.2
Operating netbacks(A)(B)
E&P Canada ($/bbl)
Average price realized		108.18		104.85		111.40		117.08		111.73		111.61
Royalties		(19.85)		(19.45)		(14.63)		(9.43)		(14.68)		(14.50)
Transportation and distribution costs		(4.36)		(6.59)		(2.16)		(5.69)		(4.21)		(4.23)
Operating costs		(20.24)		(25.29)		(17.90)		(27.23)		(21.46)		(22.06)
Operating netback		63.73		53.52		76.71		74.73		71.38		70.82

(A)

(B)

Netbacks are based on sales volumes.

See accompanying footnotes and definitions to the quarterly operating summaries.

50 2025 First Quarter Suncor Energy Inc.

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Quarterly Operating Summary (continued)

(unaudited)

	Quarter Ended										Year Ended
Refining and Marketing	Mar 31<br> <br><br> 2025		Dec 31<br> <br><br> 2024		Sep 30<br> <br><br> 2024		Jun 30<br> <br><br> 2024		Mar 31<br> <br><br> 2024		Dec 31<br> <br><br> 2024
Refined product sales (mbbls/d)		604.9		613.3		612.3		594.7		581.0		600.4
Crude oil processed (mbbls/d)		482.7		486.2		487.6		430.5		455.3		465.0
Rack forward sales volume (ML)		5 419		5 609		5 955		5 592		5 108		22 264
Utilization of refining capacity (%)		104		104		105		92		98		100
Refining and marketing gross margin – first-in, <br> <br><br> first-out (FIFO) ($/bbl)(A)		36.70		30.00		32.25		37.65		46.65		36.40
Refining and marketing gross margin – last-in, <br> <br><br> first-out (LIFO) ($/bbl)(A)		38.00		30.60		35.85		36.35		45.75		37.00
Rack forward gross margin (cpl)(A)		6.45		7.35		7.30		6.25		5.00		6.50
Refining operating expense ($/bbl)(A)		6.75		6.55		5.80		6.95		7.15		6.60
Rack forward operating expense (cpl)(A)		3.15		3.45		3.10		3.10		3.20		3.25
Eastern North America
Refined product sales (mbbls/d)
Transportation fuels
Gasoline		130.4		127.2		121.6		112.9		112.6		118.6
Distillate		121.4		121.3		120.4		105.0		118.4		116.3
Total transportation fuel sales		251.8		248.5		242.0		217.9		231.0		234.9
Petrochemicals		7.3		9.5		6.3		10.3		13.7		10.0
Asphalt		18.7		20.8		24.2		15.3		15.8		19.1
Other		18.9		27.0		19.6		23.4		24.6		23.6
Total refined product sales		296.7		305.8		292.1		266.9		285.1		287.6
Crude oil supply and refining
Processed at refineries (mbbls/d)		236.9		232.4		235.4		169.8		216.5		213.6
Utilization of refining capacity (%)		107		105		106		76		98		96
Western North America
Refined product sales (mbbls/d)
Transportation fuels
Gasoline		132.4		133.1		135.0		140.0		130.9		134.7
Distillate		141.2		142.2		146.3		152.0		141.7		145.6
Total transportation fuel sales		273.6		275.3		281.3		292.0		272.6		280.3
Asphalt		6.6		11.7		16.6		13.4		5.4		11.8
Other		28.0		20.5		22.3		22.4		17.9		20.7
Total refined product sales		308.2		307.5		320.2		327.8		295.9		312.8
Crude oil supply and refining
Processed at refineries (mbbls/d)		245.8		253.8		252.2		260.7		238.8		251.4
Utilization of refining capacity (%)		101		104		103		107		98		103

(A)

See accompanying footnotes and definitions to the quarterly operating summaries.

2025 First Quarter Suncor Energy Inc. 51

TABLE OF CONTENTS

Quarterly Operating Metrics Reconciliation

(unaudited)

Oil Sands Operating Netbacks(A)(B)

($ millions, except per barrel amounts)

				March 31, 2025																		December 31, 2024
	Quarter ended			Non-<br> <br><br> Upgraded <br> <br><br> Bitumen						Upgraded – <br> <br><br> Net SCO and <br> <br><br> Diesel						Oil Sands <br> <br><br> Segment						Non-<br> <br><br> Upgraded <br> <br><br> Bitumen						Upgraded – <br> <br><br> Net SCO and <br> <br><br> Diesel						Oil Sands <br> <br><br> Segment
	Operating revenues					2 285						4 856						7 141						2 682						4 979						7 661
	Other income					41						57						98						30						4						34
	Purchases of crude oil and products					(572)						(37)						(609)						(695)						(53)						(748)
	Gross realization adjustment(2)					(35)						(154)												(32)						(48)
	Gross realizations					1 719						4 722												1 985						4 882
	Royalties					(225)						(590)						(815)						(315)						(624)						(939)
	Transportation and distribution					(151)						(145)						(296)						(187)						(163)						(350)
	Operating, selling and general (OS&G)					(451)						(1 941)						(2 392)						(551)						(1 894)						(2 445)
	OS&G adjustment(3)					31						189												41						144
	Net operating expenses					(420)						(1 752)												(510)						(1 750)
	Operating netback					923						2 235												973						2 345
	Sales volumes (mbbls)					22 041						47 567												25 973						49 519
	Operating netback per barrel					41.88						47.00												37.46						47.39
				September 30, 2024																		June 30, 2024
---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---
	Quarter ended			Non-<br> <br><br> Upgraded <br> <br><br> Bitumen						Upgraded – <br> <br><br> Net SCO and <br> <br><br> Diesel						Oil Sands <br> <br><br> Segment						Non-<br> <br><br> Upgraded <br> <br><br> Bitumen						Upgraded – <br> <br><br> Net SCO and <br> <br><br> Diesel						Oil Sands <br> <br><br> Segment
	Operating revenues					2 362						4 883						7 245						2 818						4 614						7 432
	Other (loss) income					(7)						22						15						60						12						72
	Purchases of crude oil and products					(468)						(18)						(486)						(651)						(45)						(696)
	Gross realization adjustment(2)					(33)						(27)												(43)						(30)
	Gross realizations					1 854						4 860												2 184						4 551
	Royalties					(251)						(672)						(923)						(330)						(671)						(1 001)
	Transportation and distribution					(152)						(139)						(291)						(139)						(153)						(292)
	OS&G					(615)						(1 608)						(2 223)						(572)						(1 706)						(2 278)
	OS&G adjustment(3)					79						42												77						81
	Net operating expenses					(536)						(1 566)												(495)						(1 625)
	Operating netback					915						2 483												1 220						2 102
	Sales volumes (mbbls)					23 383						46 952												24 811						41 296
	Operating netback per barrel					39.18						52.86												49.23						50.96

(A)

Non-GAAP financial measures. See the Operating Summary Information – Non-GAAP and Other Financial Measures section of this Quarterly Report.

(B)

Impact of inventory writedown is excluded until product is sold.

See accompanying footnotes and definitions to the quarterly operating summaries.

52 2025 First Quarter Suncor Energy Inc.

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Quarterly Operating Metrics Reconciliation(continued)

(unaudited)

Oil Sands Operating Netbacks(A)(B)

($ millions, except per barrel amounts)

				March 31, 2024
	Quarter ended			Non-<br> <br><br> Upgraded<br> <br><br> Bitumen						Upgraded – <br> <br><br> Net SCO and<br> <br><br> Diesel						Oil Sands<br> <br><br> Segment
	Operating revenues					2 062						4 860						6 922
	Other income (loss)					59						(4)						55
	Purchases of crude oil and products					(557)						(72)						(629)
	Gross realization adjustment(2)					(22)						(94)
	Gross realizations					1 542						4 690
	Royalties					(222)						(560)						(782)
	Transportation and distribution					(158)						(134)						(292)
	OS&G					(582)						(1 900)						(2 482)
	OS&G adjustment(3)					98						174
	Net operating expenses					(484)						(1 726)
	Operating netback					678						2 270
	Sales volumes (mbbls)					21 280						50 077
	Operating netback per barrel					31.96						45.29
				December 31, 2024
---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---
	Year ended			Non-<br> <br><br> Upgraded<br> <br><br> Bitumen						Upgraded – <br> <br><br> Net SCO and<br> <br><br> Diesel						Oil Sands<br> <br><br> Segment
	Operating revenues					9 924						19 336						29 260
	Other income					142						34						176
	Purchases of crude oil and products					(2 371)						(188)						(2 559)
	Gross realization adjustment(2)					(130)						(199)
	Gross realizations					7 565						18 983
	Royalties					(1 118)						(2 527)						(3 645)
	Transportation and distribution					(636)						(589)						(1 225)
	OS&G					(2 320)						(7 108)						(9 428)
	OS&G adjustment(3)					295						441
	Net operating expenses					(2 025)						(6 667)
	Operating netback					3 786						9 200
	Sales volumes (mbbls)					95 447						187 844
	Operating netback per barrel					39.72						48.98

(A)

Non-GAAP financial measures. See the Operating Summary Information – Non-GAAP and Other Financial Measures section of this Quarterly Report.

(B)

Impact of inventory writedown is excluded until product is sold.

See accompanying footnotes and definitions to the quarterly operating summaries.

2025 First Quarter Suncor Energy Inc. 53

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Quarterly Operating Metrics Reconciliation (continued)

(unaudited)

Exploration and Production Operating Netbacks(A)(B)

($ millions, except per barrel amounts)

				March 31, 2025																		December 31, 2024
	Quarter ended			E&P<br> <br><br> Canada						Other(4)(5)						E&P<br> <br><br> Segment						E&P<br> <br><br> Canada						Other(4)(5)						E&P<br> <br><br> Segment
	Operating revenues					470						259						729						363						279						642
	Royalties					(86)						(106)						(192)						(67)						(120)						(187)
	Transportation and distribution					(19)						(3)						(22)						(23)						(3)						(26)
	OS&G					(95)						(25)						(120)						(96)						(28)						(124)
	Non-production costs(6)					7																		9
	Operating netback					277																		186
	Sales volumes (mbbls)					4 344																		3 464
	Operating netback per barrel					63.73																		53.52
				September 30, 2024																		June 30, 2024
---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---
	Quarter ended			E&P<br> <br><br> Canada						Other(4)(5)						E&P<br> <br><br> Segment						E&P<br> <br><br> Canada						Other(4)(5)						E&P<br> <br><br> Segment
	Operating revenues					718						—						718						437						236						673
	Royalties					(94)						—						(94)						(35)						(89)						(124)
	Transportation and distribution					(14)						—						(14)						(21)						(3)						(24)
	OS&G					(121)						(18)						(139)						(109)						(11)						(120)
	Non-production costs(6)					6																		7
	Operating netback					495																		279
	Sales volumes (mbbls)					6 451																		3 748
	Operating netback per barrel					76.71																		74.73
				March 31, 2024
---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---
	Quarter ended			E&P<br> <br><br> Canada						Other(4)(5)						E&P<br> <br><br> Segment
	Operating revenues					609						156						765
	Royalties					(80)						(62)						(142)
	Transportation and distribution					(23)						(2)						(25)
	OS&G					(128)						(13)						(141)
	Non-production costs(6)					11
	Operating netback					389
	Sales volumes (mbbls)					5 432
	Operating netback per barrel					71.38

(A)

Non-GAAP financial measures. See the Operating Summary Information – Non-GAAP and Other Financial Measures section of this Quarterly Report.

(B)

Netbacks are based on sales volumes.

See accompanying footnotes and definitions to the quarterly operating summaries.

54 2025 First Quarter Suncor Energy Inc.

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Quarterly Operating Metrics Reconciliation (continued)

(unaudited)

Exploration and Production Operating Netbacks(A)(B)

($ millions, except per barrel amounts)

	December 31, 2024
Year ended	E&P<br> <br><br> Canada		Other(4)(5)		E&P<br> <br><br> Segment
Operating revenues		2 127		671		2 798
Royalties		(276)		(271)		(547)
Transportation and distribution		(81)		(8)		(89)
OS&G		(454)		(70)		(524)
Non-production costs(6)		33
Operating netback		1 349
Sales volumes (mbbls)		19 095
Operating netback per barrel		70.82

(A)

Non-GAAP financial measures. See the Operating Summary Information – Non-GAAP and Other Financial Measures section of this Quarterly Report.

(B)

Netbacks are based on sales volumes.

See accompanying footnotes and definitions to the quarterly operating summaries.

2025 First Quarter Suncor Energy Inc. 55

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Quarterly Operating Metrics Reconciliation (continued)

(unaudited)

Refining and Marketing

($ millions, except as noted)

	Quarter Ended										Year Ended
Refining and marketing gross margin reconciliation	Mar 31<br> <br><br> 2025		Dec 31<br> <br><br> 2024		Sep 30<br> <br><br> 2024		Jun 30<br> <br><br> 2024		Mar 31<br> <br><br> 2024		Dec 31<br> <br><br> 2024
Operating revenues		7 628		7 547		8 124		8 057		7 613		31 341
Purchases of crude oil and products		(5 922)		(6 123)		(6 685)		(6 519)		(5 588)		(24 915)
		1 706		1 424		1 439		1 538		2 025		6 426
Other (loss) income		(12)		58		80		43		74		255
Non-refining and marketing margin(7)		(13)		(56)		(1)		(13)		(42)		(112)
Refining and marketing gross margin – FIFO(A)		1 681		1 426		1 518		1 568		2 057		6 569
Refinery production (mbbls)(8)		45 798		47 519		47 094		41 669		44 074		180 356
Refining and marketing gross margin – FIFO ($/bbl)(A)		36.70		30.00		32.25		37.65		46.65		36.40
FIFO loss (gain) and risk management activities adjustment(B)		60		29		171		(53)		(40)		107
Refining and marketing gross margin – LIFO(A)(B)		1 741		1 455		1 689		1 515		2 017		6 676
Refining and marketing gross margin – LIFO ($/bbl)(A)(B)(C)		38.00		30.60		35.85		36.35		45.75		37.00
Rack forward gross margin
Refining and marketing gross margin – FIFO(A)		1 681		1 426		1 518		1 568		2 057		6 569
Refining and supply gross margin		(1 331)		(1 014)		(1 085)		(1 218)		(1 802)		(5 119)
Rack forward gross margin(A)(9)		350		412		433		350		255		1 450
Sales volume (ML)		5 419		5 609		5 955		5 592		5 108		22 264
Rack forward gross margin (cpl)(A)		6.45		7.35		7.30		6.25		5.00		6.50
Refining and rack forward operating expense reconciliation
Operating, selling and general		609		653		592		603		618		2 466
Less: Rack forward operating expense(A)(10)		171		195		186		174		165		720
Less: Other operating expenses(11)		130		147		133		139		138		557
Refining operating expense(A)		308		311		273		290		315		1 189
Refinery production (mbbls)(8)		45 798		47 519		47 094		41 669		44 074		180 356
Refining operating expense ($/bbl)(A)		6.75		6.55		5.80		6.95		7.15		6.60
Sales volume (ML)		5 419		5 609		5 955		5 592		5 108		22 264
Rack forward operating expense (cpl)(A)		3.15		3.45		3.10		3.10		3.20		3.25

(A)

Non-GAAP financial measures or contains non-GAAP financial measures. See the Operating Summary Information – Non-GAAP and Other Financial Measures section of this Quarterly Report.

(B)

Refining and marketing gross margin – LIFO excludes the impact of risk management activities.

(C)

The Suncor 5-2-2-1 index is most comparable to the company’s realized refining and marketing margin presented on a LIFO basis.

See accompanying footnotes and definitions to the quarterly operating summaries.

56 2025 First Quarter Suncor Energy Inc.

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Quarterly Operating Metrics Reconciliation (continued)

(unaudited)

Refining and Marketing
Suncor custom 5-2-2-1 index(A)(12)

(US$/bbl, except as noted)		Quarter Ended										Year Ended
(average for the three months and twelve months ended)		Mar 31<br> <br><br> 2025		Dec 31<br> <br><br> 2024		Sep 30<br> <br><br> 2024		Jun 30<br> <br><br> 2024		Mar 31<br> <br><br> 2024		Dec 31<br> <br><br> 2024
WTI crude oil at Cushing			71.40		70.30		75.15		80.55		76.95		75.70
SYN crude oil at Edmonton			69.05		71.15		76.45		83.35		69.55		75.10
WCS at Hardisty			58.75		57.75		61.65		67.00		57.60		61.00
New York Harbor 2-1-1 crack(B)			21.05		18.80		21.05		24.75		27.05		22.90
Chicago 2-1-1 crack(B)			14.65		13.85		19.35		18.85		19.80		17.95
Product value
New York Harbor 2-1-1 crack(C)	40%		37.00		35.65		38.50		42.10		41.60		39.45
Chicago 2-1-1 crack(D)	40%		34.40		33.65		37.80		39.75		38.70		37.45
WTI	20%		14.30		14.05		15.05		16.10		15.40		15.15
Seasonality factor			6.50		6.50		5.00		5.00		6.50		5.75
			92.20		89.85		96.35		102.95		102.20		97.80
Crude value
SYN	40%		27.60		28.45		30.60		33.35		27.80		30.05
WCS	40%		23.50		23.10		24.65		26.80		23.05		24.40
WTI	20%		14.30		14.05		15.05		16.10		15.40		15.15
			65.40		65.60		70.30		76.25		66.25		69.60
Suncor custom 5-2-2-1 index			26.80		24.25		26.05		26.70		35.95		28.20
Suncor custom 5-2-2-1 index (Cdn$/bbl)(A)			38.45		33.95		35.50		36.55		48.50		38.65

(A)

The Suncor 5-2-2-1 index is most comparable to the company’s realized refining and marketing margin presented on a LIFO basis.

(B)

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.

(C)

Product value of the New York Harbor 2-1-1 crack is calculated by adding the values of the New York Harbor 2-1-1 crack and WTI, multiplying it by 40% and rounding to the nearest nickel.

(D)

Product value of the Chicago 2-1-1 crack is calculated by adding the values of the Chicago 2-1-1 crack and WTI, multiplying it by 40% and rounding to the nearest nickel.

See accompanying footnotes and definitions to the quarterly operating summaries.

2025 First Quarter Suncor Energy Inc. 57

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Operating Summary Information

Non-GAAP and Other Financial Measures

Certain financial measures in this Supplemental Financial and Operating Information – namely adjusted operating earnings (loss), adjusted funds from (used in) operations, free funds flow, measures contained in return on capital employed (ROCE) and ROCE excluding impairments and impairment reversals, Oil Sands operations cash operating costs, Fort Hills cash operating costs, Syncrude cash operating costs, refining and marketing gross margin, rack forward gross margin, refining operating expense, rack forward operating expense and operating netbacks – are not prescribed by generally accepted accounting principles (GAAP). Suncor uses this information to analyze business performance, leverage and liquidity and includes these financial measures because investors may find such measures useful 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. The additional information should not be considered in isolation or as a substitute for measures of performance prepared in accordance with GAAP.

Adjusted operating earnings (loss), Oil Sands operations cash operating costs, Fort Hills cash operating costs and Syncrude cash operating costs 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 respective Quarterly Report to Shareholders in respect of the relevant quarter (Quarterly Report). Adjusted funds from (used in) operations, free funds flow and measures contained 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 respective Quarterly Report. Refining and marketing gross margin, rack forward gross margin, refining operating expense and rack forward operating expense are defined in the Non-GAAP and Other Financial Measures Advisory section and reconciled to GAAP measures in the Quarterly Operating Metrics Reconciliation section of each respective Quarterly Report. Operating netbacks are defined below and are reconciled to GAAP measures in the Quarterly Operating Metrics Reconciliation section of each respective Quarterly Report. The remainder of the non-GAAP financial measures not otherwise mentioned in this paragraph are defined and reconciled in this Quarterly Report.

Oil Sands Operating Netbacks

Oil Sands operating netbacks are a non-GAAP measure, presented on a crude product and sales barrel basis, and are derived from the Oil Sands segmented statement of net earnings (loss), after adjusting for items not directly attributable to the revenues and costs associated with production and delivery. Management uses Oil Sands operating netbacks to measure crude product profitability on a sales barrel basis.

Exploration and Production (E&P) Operating Netbacks

E&P operating netbacks are a non-GAAP measure, presented on an asset location and sales barrel basis, and are derived from the E&P segmented statement of net earnings (loss), after adjusting for items not directly attributable to the revenues and costs associated with production and delivery. Management uses E&P operating netbacks to measure asset profitability by location on a sales barrel basis.

Definitions

(1)

Cash operating costs are calculated by adjusting Oil Sands segment operating, selling and general 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.

(2)

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.

(3)

Reflects adjustments for general and administrative costs not directly attributed to the production of each crude product type, as well as the revenues associated with excess power generated from cogeneration units and sold that is recorded in operating revenue.

(4)

Reflects other E&P assets, such as Libya, for which netbacks are not provided.

(5)

Production from the company’s Libya operations has been presented in this document 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. Under the working-interest basis, revenue includes a gross-up amount with offsetting amounts presented in royalties in the E&P segment and income tax expense reported at the total consolidated level.

(6)

Reflects adjustments for general and administrative costs not directly attributed to production.

(7)

Reflects adjustments for intersegment marketing fees.

(8)

Refining production is the output of the refining process and differs from crude oil processed as a result of volumetric adjustment for non-crude feedstock, volumetric gain associated with the refining process and changes in unfinished product inventories.

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(9)

Rack forward operating revenues, other income less purchases of crude oil and products.

(10)

Rack forward operating expense reflects operating, selling and general expenses associated with retail and wholesale operations.

(11)

Reflects operating, selling and general expenses associated with the company’s ethanol businesses and certain general and administrative costs not directly attributable to refinery production.

(12)

The custom 5-2-2-1 index is designed to represent Suncor’s Refining and Marketing business based on publicly available pricing data and approximates the gross margin on five barrels of crude oil of varying grades that is refined to produce two barrels of both gasoline and distillate and one barrel of secondary product. The index is a single value that is calculated by taking the product value of refined products less the crude value of refinery feedstock incorporating the company’s refining, product supply and rack forward businesses, but excluding the impact of first-in, first-out accounting. The product value is influenced by New York Harbor 2-1-1 crack, Chicago 2-1-1 crack, WTI benchmarks and seasonal factors. The seasonal factor is an estimate and reflects the location, quality and grade differentials for refined products sold in the company’s core markets during the winter and summer months. The crude value is influenced by SYN, WCS and WTI benchmarks.

Explanatory Notes

Users are cautioned that the Oil Sands operations, Fort Hills and Syncrude cash operating costs per barrel measures may not be fully comparable to one another or to similar information calculated by other entities due to the differing operations of each entity as well as other entities’ respective accounting policy choices.

Abbreviations

	bbl			– barrel
	bbls/d			– barrels per day
	mbbls			– thousands of barrels
	mbbls/d			– thousands of barrels per day
	cpl			– cents per litre
	ML			– million litres
	WTI			– West Texas Intermediate
	SYN			– Synthetic crude oil benchmark
	WCS			– Western Canadian Select

Metric Conversion

1 m3 (cubic metre) = approximately 6.29 barrels

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