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EXHIBIT 99.1
Suncor Energy Inc. 2018 Annual Report to Shareholders for the period ended
December 31, 2018

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ANNUAL REPORT 2018 Suncor Energy Inc. |  |
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2018 HIGHLIGHTS

This Annual Report contains forward-looking statements based on Suncor's current expectations, estimates, projections and assumptions, as well as certain financial measures, namely operating earnings (loss), funds from operations, return on capital employed (ROCE), Oil Sands operations cash operating costs, Fort Hills cash operating costs, Syncrude cash operating costs, free funds flow and discretionary free funds flow, that are not prescribed by generally accepted accounting principles (GAAP). Refer to the Advisories sections of this Annual Report and Suncor's Management's Discussion and Analysis dated February 28, 2019 (MD&A).

2018 ANNUAL REPORT Suncor Energy Inc. 1

THE SUNCOR ADVANTAGE

A PROVEN INTEGRATED MODEL

From the ground to the gas station, we optimize profits through each link in the value chain. Our flexible model allows us to capture the shift in value between operating segments during periods of market volatility and limits Suncor's exposure to crude differentials, with a significant portion of bitumen production being upgraded to higher priced light oil and refined products. The company's midstream assets and pipeline commitments, strategically acquired with the future in mind, provide operational flexibility through secured market access, including to the U.S. Gulf Coast and other international markets.

RESERVES BASE

Our focus on operational excellence allows us to unlock the full value of our resources. For more information on our reserves base, refer to our Annual Information Form dated February 28, 2019. |  |

2 2018 ANNUAL REPORT Suncor Energy Inc.

FINANCIAL STRENGTH

We aim to deliver competitive, sustainable and increasing returns to our shareholders, by focusing on capital discipline, operational excellence, and long-term profitable growth. We have returned value to shareholders through consistent dividend growth, with 2018 marking the sixteenth consecutive year we increased our annual dividend, while also significantly increasing our share repurchase program. This demonstrates confidence in our ability to generate cash flow across a wide range of business environments and commitment to returning it to shareholders. |  |

SUSTAINABILITY, TECHNOLOGY AND INNOVATION

Sustainability is about seeing the big picture and working together to enhance social and economic benefits while minimizing the environmental impacts of resource development. We believe technology and innovative thinking are critical to ensuring our resilience in a lower carbon future.

ENVIRONMENT We're advancing reclamation with our new tailings treatment process, Permanent Aquatic Storage Structure (PASS). In 2018, PASS doubled our tailings treatment to 165% of total tailings produced that year, ultimately drawing down our inventory. SOCIAL We sought early and ongoing engagement with Indigenous stakeholders to help shape our Demonstration Pit Lake (DPL) pilot. We continue to collaborate with local communities on research, implementation and monitoring. GOVERNANCE Suncor's climate-related disclosures are well-aligned with the Task Force on Climate-Related Disclosure (TCFD) recommendations, and we look forward to working with the task force to evolve climate risk disclosure so it meets the needs of both companies and investors. |  | TECHNOLOGY In 2018, we increased deployment of Autonomous Haul Systems (AHS), advanced a number of greenhouse gas reduction pilots at our in situ sites, and jointly moved forward on the Water Technology Development Centre (WTDC), expected to be operational in the second quarter of 2019. For more information on our sustainable development, refer to the 2018 Report on Sustainability.

2018 ANNUAL REPORT Suncor Energy Inc. 3

MESSAGE TO SHAREHOLDERS

This past September, Suncor celebrated the official grand opening of Fort Hills, a development that exemplifies "the new face of the oil sands."

Fort Hills will use new technologies such as autonomous haul systems and paraffinic froth treatment, resulting in lower operating costs and a greenhouse gas emissions intensity which is on par with the average refined barrel in North America — a significant step forward for our industry. Fort Hills also reflects Suncor's evolving relationship with Indigenous Peoples through the equity partnership we formed with the Fort McKay and Mikisew Cree First Nations on the East Tank Farm Development – a landmark for First Nation investment in Canada.

Poised to deliver energy the world needs and be a key supplier for the next 50 years, Fort Hills is one of many reasons Suncor shareholders and other stakeholders can look forward with confidence and optimism.

Our integrated business model also continued to deliver significant results in 2018 – minimizing Suncor's exposure to heavy and light crude differentials that dramatically widened over the course of the year.

With the completion of Fort Hills and Hebron, a focus on operational excellence and the ongoing deployment of new technology to improve our operations, we are positioned to deliver reliable cash flow growth for years.

Integral to our success, and our aspirations, is Suncor's long-standing commitment to being a leader in sustainability. By continuing to invest in technology and innovation, Suncor is positioned to be a progressive, cost-efficient and carbon competitive energy provider of choice for decades.

4 2018 ANNUAL REPORT Suncor Energy Inc.

2018: INTEGRATION PROVES INVALUABLE DURING VOLATILE YEAR

We continued to live through interesting times in 2018, a year when Suncor's strategy and business model demonstrated value once again.

The integration of our upstream oil sands operations, downstream refining and marketing assets, as well as midstream logistics, allowed us to remain flexible, resilient and profitable even as western Canadian oil differentials widened dramatically through most of 2018.

Among the reasons we successfully mitigated the impact of volatile differentials are the fact we:

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  process a majority of our produced bitumen in our upgraders where it is converted to synthetic crude oil;
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  run some of the bitumen and synthetic oil through our refineries, where it is converted into transportation fuels;
•
  capture value through our flexible midstream and retail operations;
•
  and continue to maximize the profit of offshore barrels as well as volumes transported to the Gulf of Mexico markets where we achieve higher global-based pricing.

Another key reason for our resilience: Suncor has secured adequate market access for all of our current production, including our net Fort Hills barrels.

These built-in advantages – distinct and unique – didn't occur by chance. We made strategic decisions years ago to invest in value-added upgrading and refining capacity in Alberta. We also invested in obtaining committed pipeline capacity for our major growth projects.

Over the years Suncor has invested significant capital to increase the flexibility of our Edmonton refinery, expand our upgrading capacity and develop Fort Hills, which produces partially upgraded bitumen. Today, fully 75% of what we produce in Alberta is upgraded or refined locally.

I believe the strategy we've implemented demonstrates economic, environmental and social leadership. Our value-added investments created job opportunities for tens of thousands of employees and contractors and generated significant economic benefit for all Albertans and Canadians.

These strategic decisions also lead to positive results for our shareholders. In addition to unprecedented oil differentials, 2018 was a year when Suncor underwent the largest maintenance turnaround program in our history, including significant planned refinery and upgrader maintenance. Despite these challenges, we continued to:

Underpinning these results is Suncor's unwavering focus on capital discipline, cost management, operational excellence and sustainability.

With Fort Hills, we oversaw one of the most visible examples of operational excellence and successful project execution. Fort Hills exceeded our expectations on many metrics, including speed of ramp up and reliability, as well as hitting targeted per barrel cash operating costs. I want to thank the dedicated team that safely executed this project's careful planning, construction, handover, commissioning and start-up. In my view, their efforts were world-class.

We also continued a disciplined program of cost reductions even as we grew production. This is not a one-time event. We believe we've created sustainable reductions to the company's cost structure.

Going forward, we will continue our unrelenting focus on the many aspects of our business that we can control. However, we must also be prepared to deal with the unexpected.

In response to widening oil differentials, in December 2018, the Government of Alberta announced a mandatory production curtailment program, effectively imposing production caps for 2019. Suncor continues to work with the Government of Alberta and the Alberta Energy Regulator to manage and mitigate the unintended consequences of the curtailment orders.

Suncor's production guidance for 2019 assumes the full amount of mandatory production curtailments will be in place for three months before easing to 29% for the remainder of the year. We see this government action as a short-term response. The longer-term solution to differentials and industry competitiveness is clear – improved tidewater access for Canadian resources.

2018 ANNUAL REPORT Suncor Energy Inc. 5

MARKET ACCESS GOING FORWARD

While Suncor has adequate pipeline capacity for our current production, we firmly believe expanded market access is in the national interest. We further believe a new pipeline to tidewater is the best and safest option for expanding access.

This issue is vital not just to our industry, but for all Canadians. In a resource-based economy like ours, we need to ensure we are getting full value for our production.

Improved market access ensures we can help meet growing global energy needs by bringing responsibly developed Canadian crude oil to market. It strengthens our economy through jobs, royalties and taxes. It supports our quality of life by helping to fund critical social programs like health care and education. It provides Indigenous communities with increased opportunities to directly participate in resource development. And it gives us the means to continue investing in innovation and technology to improve our environmental performance and lower our carbon footprint.

SYNCRUDE SETBACKS AND PATH TO IMPROVEMENTS

I'm proud of Suncor's multi-year journey on operational reliability and the successes we've had along the way. That said, I've also been very candid in expressing my frustration over the need to improve Syncrude's operational performance. The good news is that, together with our Syncrude partners, we are now on a clear path toward improved reliability and lower cash costs – which is starting to pay off. In the fourth quarter of 2018, Syncrude achieved a new quarterly production record of 355,000 bbls/d (101% utilization).

The fact is operational excellence is never a straight line. We are taking lessons learned from our journey at Base Plant, where reliability and costs significantly improved between 2011 and 2016.

A critical part of our success at Base Plant was the construction of an interconnecting pipeline from our Firebag in situ operation to the upgrader, providing greater feedstock flexibility. We expect a similar step change in performance as we implement the memorandum of understanding signed by the Syncrude partners in the fourth quarter of 2018, which commits us to building essential pipeline links between Syncrude and our Base Plant.

Along with other collective measures now underway, I'm confident we can achieve our average utilization rates of 90% and Syncrude cash operating costs of $30 per barrel by the end of 2020.

6 2018 ANNUAL REPORT Suncor Energy Inc.

CONTINUITY THROUGH CHANGE

It has been my honour and privilege to serve as part of the Suncor team through both challenging and exciting times.

Suncor's previous CEO, the late Rick George, brought me to Suncor in 2002 and I quickly came to share his passion for the oil sands. A decade later, when Rick retired, I greatly appreciated the confidence and support both he and Suncor's Board of Directors placed in my leadership.

I've worked closely with Mark for a number of years and I've always been impressed by his business acumen, passion and energy, as well as his personal commitment to engagement with Indigenous communities. I'm confident in Mark's ability to lead Suncor toward an even brighter future.

This leadership transition marks another chapter in Suncor's strong succession planning – a key part of our business strategy. Though faces may change around the leadership table, our shared commitment to safety, reliability, operational excellence and capital discipline, carry forward.

As I reflect back over the past seven years, I'm very proud of the progress the team has made on improving our safety results, our reliability and cost structure, improving value for shareholders by making acquisitions during the cycle at opportune times, and by advocating that our industry must be part of solving complex challenges facing all of us, including taking a leadership position on sustainability.

Shortly after I took on the role of Suncor's chief executive officer in 2012, our leadership team agreed to focus on a strategy of continuous improvement in every aspect of our business. We also agreed we would not seek growth solely for the sake of growth. Rather, we'd seek profitable growth through a relentless focus on capital discipline and operational excellence, while delivering increased returns to our shareholders.

We've stayed true to that strategy through both high- and low-price environments, and I believe it's given us a strong competitive advantage – as a company uniquely positioned to deliver value, and grow in a disciplined manner, for decades to come.

Suncor has shown leadership in understanding and advocating for the essential connection between the social, economic and environmental aspects of resource development. It's why we focus so much effort on ensuring that the communities we engage with – including Indigenous communities – benefit from our shared energy future. And it's why we are driven to continuously improve our environmental performance.

As an energy leader, and a father, I've been particularly outspoken on the need to seek collaborative solutions to a defining challenge of our time – climate change. Science and facts matter, and we all have a responsibility to work together on the transition to a low-carbon economy.

More than anything, my time at Suncor has convinced me that collaboration is at the heart of all meaningful progress. I've been part of so many positive collaborations that it seems unfair to cite just a few. But it's been a particular honour to be a member of the National Roundtable on Energy and the Environment, a founding member of the Advisory Board of the Ecofiscal Commission, which focuses on the intersection of the economy and the environment, Canada's Oil Sands Innovation Alliance (COSIA), which is advancing industry-wide technology and innovation to improve environmental performance. I've also been honoured to support Indspire, an Indigenous-led charity that invests in the education of Indigenous people, and Canada's Olympic movement.

Throughout my years at Suncor, I've benefited immensely from the knowledge and counsel of our Board of Directors. I also want to thank all of Suncor's employees who, day-in and day-out, reflect our dedication and commitment to shareholders and the communities where we work.

I'm certain Suncor's brightest and most exciting days are ahead. I look forward to seeing the next chapter of this great company's history.

Steve Williams
Chief Executive Officer

2018 ANNUAL REPORT Suncor Energy Inc. 7

MESSAGE TO SHAREHOLDERS

8 2018 ANNUAL REPORT Suncor Energy Inc.

STRATEGIES FOR REALIZING THE SUNCOR ADVANTAGE

Suncor's integrated business model and disciplined execution of strategy have served us well through a range of market conditions. Despite a challenging oil price environment, we consistently outperformed our peer group. While many competitors retreated or withdrew, we grew production, reduced costs and increased returns to shareholders through dividends and share buybacks. We also executed counter-cyclical acquisitions (including obtaining a majority interest in Syncrude) and maintained a strong balance sheet.

We were similarly undeterred in 2018 as our industry faced the headwinds of widening differentials and Suncor underwent the largest maintenance turnaround program in its history. Despite this, Suncor continued to grow production by 7% and generated a record $10.2 billion funds from operations.

With two major capital spending projects behind us, and a strong balance sheet we see as a strategic asset, we can now lay out a plan for low-cost, reliable and profitable growth that stretches well into the 2030s.

In the immediate term, with Fort Hills fully on stream, Hebron ramping up, and continued improved reliability from Syncrude, our 2019 guidance includes a production increase, of approximately 10%, from 730,000 barrels of oil equivalent per day (boe/d) in 2018. This projection takes into account the industry-wide mandated production curtailments introduced by the Government of Alberta.

Suncor's 2019 capital spend range of $4.9 billion to $5.6 billion provides the flexibility to respond to volatile market conditions. The majority of the 2019 capital program (63%) is allocated to planned sustaining and maintenance activities to ensure continued safe, reliable and efficient operations. The remainder of the capital program is focused on low capital intensity, value-creating projects, including continued deployment of autonomous haul trucks, development of the Syncrude bi-directional pipeline and additional investment in midstream logistics infrastructure.

In the medium term (2020 to 2023), our focus is on generating "free funds flow" growth, with lower capital intensity projects that generate high-return margin improvements and cost savings while still incrementally increasing production through debottlenecks. Based on the current commodity price levels, we expect the cumulative impact of these projects and the existing asset base to increase our annual free funds flow by approximately $2 billion by 2023.

Longer term (2024 and beyond), we have the potential for funds flow growth as a result of significant production growth through the sanctioning and development of more than 350,000 barrels per day of in situ projects. But clearly, we will need to have much greater certainty on pipeline access to markets before we would proceed.

In summary, we have a long-term plan to deliver predictable, profitable growth through variable market conditions. Throughout this period, we will remain true to our strategy. We will continue to focus on operational excellence, exercising strong capital discipline, maintaining a strong balance sheet and increasing returns to our shareholders.

SUSTAINABILITY: BUILDING RESILIENCE FOR THE LONG TERM

A key part of our investor proposition is our commitment to sustainability. The economic, environmental and social dimensions of energy development are deeply integrated. We will continue to improve our performance in all of these dimensions.

Our vision for sustainability is guided by working with diverse stakeholders. We are shaped and changed by these conversations. They help make us a more sustainable and resilient energy company.

CLIMATE CHANGE

Climate change is one of the most pressing challenges of our times and demands shared solutions. Suncor believes we have an important role to play in a lower carbon world.

To remain an energy provider of choice over the long term, we must be globally competitive on both costs and carbon. I'm encouraged by the progress we're making in these areas and other dimensions of sustainability.

We continue to pursue an ambitious goal of reducing the greenhouse gas (GHG) emissions intensity of our oil and petroleum production by 30% by 2030. Technology and innovation are pointing to a realistic path for reaching that goal and a low-carbon future, which we believe will also move us towards ultimately bending the curve on our absolute GHG emissions.

We plan to remain resilient and thrive in tomorrow's low-carbon economy, and our annual Climate Risk and Resilience Report sets out why we believe we can be resilient over the long term. This year, we took another step forward on climate risk transparency by supporting the desire for consistency and transparency embodied in the Task Force on Climate-Related Disclosure, an international initiative of the Financial Stability Board.

2018 ANNUAL REPORT Suncor Energy Inc. 9

TECHNOLOGY

Innovation and technology are critical to achieving our climate change strategies as well as our other economic, social and environmental goals. That's why, last year alone, Suncor invested $400 million in the development and deployment of new technology. In some cases, we lead the development and deployment of new technologies on our own. In most cases, we work with consortiums like Canada's Oil Sands Innovation Alliance (COSIA) or third parties. In addition, we work closely with organizations like Evok Innovations, Clean Resource Innovation Network (CRIN) and Energy Futures Lab on clean technology solutions to advance the transition to a lower carbon economy and improve our overall performance. Collaboration is a key enabler to accelerating the development and deployment of technology.

Fort Hills is a good example of the kind of progress that's possible. The facility employs new paraffinic froth treatment technology resulting in a GHG emissions intensity on par with the average refined barrel in North America. Fort Hills will also use autonomous haul trucks, which result in safer and more productive mining operations, with improved fuel efficiency and lower emissions.

For future growth, we can and will get beyond today's technologies. That includes next-generation in situ technologies that could lower costs as well as dramatically reduce GHG emissions from operations – in some cases, potentially by 50% to 70%. We're in the process of advancing some of these technologies at commercial scale.

We already extensively use information technology across our business, investing $235 million in digital technologies in 2018, and the increasingly digital world brings new and exciting opportunities. As part of our approach to innovation, we are harnessing digital technology in areas such as improved data, analytics, artificial intelligence technology and automation to help improve the safety, productivity, reliability and environmental performance of our operations. Digital solutions promise to significantly change how we do business – in a very positive way – and is a key focus area as we move forward.

INDIGENOUS PARTNERSHIPS

Fort Hills also represented a historic step forward in strengthening our relationship with Canada's Indigenous Peoples. By acquiring a 49% equity position in the East Tank Farm Development, at a value of $500 million, the Fort McKay and Mikisew Cree First Nations engaged in the largest First Nations business investment to date in Canada.

The East Tank Farm provides a hub for receiving, storing, cooling, blending and shipping bitumen to market – it's a lifeline between Fort Hills and our customers. The investment will provide a steady stream of income every year to the First Nations for at least 25 years, revenues that will help support education, health care, elder care, infrastructure and more. We are excited that we'll be joint venture partners with these two First Nations for decades.

In previous roles with Suncor, I was closely involved in talks with the First Nations Chiefs that led to this landmark equity agreement. When we began discussions five years ago, they were just that – wide-ranging conversations about our respective aspirations based on listening, learning from each other and building a sense of mutual respect and trust.

Those conversations profoundly changed my outlook. I used to think engaging Indigenous business was about supporting them. What I learned is that Indigenous businesses are incredibly strong and dynamic and can compete. Working with Indigenous businesses can be a "win-win" proposition – a point I've been stressing in my role as co-chair of the Canadian Council for Aboriginal Business' (CCABs') Aboriginal Procurement Champions Initiative.

Suncor's social sustainability goal is also about changing the way we think and act so we can work collaboratively with Indigenous Peoples to create opportunities for economic and social reconciliation.

10 2018 ANNUAL REPORT Suncor Energy Inc.

We already have a number of strong relationships. There are now 30 Petro-Canada stations across the country owned by First Nations. Suncor is a joint venture partner in an Ontario wind farm with the Aamjiwnaang First Nation. We also hold an equity interest in PetroNor, a Quebec-based fuel distribution company owned and operated by the James Bay Cree.

Suncor spent $703 million in goods and services with Indigenous businesses in 2018 bringing the total spend to approximately $5 billion since 1999, when we first started tracking this. Over 30% of the increased spend came from new suppliers and our Downstream business where we doubled our spend.

But our social goal is about much more than business. Going forward, we will continue to support Indigenous youth, increase the participation of Indigenous Peoples in our workforce and improve Suncor employees' awareness of the history and experience of Indigenous Peoples.

Most of all, we will continue to listen and learn.

THE SUNCOR TEAM

By continuing to capture value – and at the same time launch a 50-year project like Fort Hills – Suncor again demonstrated we have the combination of people, assets and strategies to succeed for the long run.

Our ability to successfully navigate a wide range of market cycles is rooted in the talent, hard work and ingenuity of our employees. We are also indebted to our Board of Directors, whose guidance keeps us strategically focused on long-term objectives.

As we move forward, one value continues to stand above the rest – safety. Suncor is committed to eliminating all workplace injuries and providing a safe workplace for all of our people. As part of that commitment, we implemented random drug testing for employees in safety-sensitive positions in the Regional Municipality of Wood Buffalo. For Suncor, this is all about ensuring our people go home to their loved ones safely at the end of their shifts.

Whatever challenges come along, we will maintain an unwavering focus on the strengths that got us here, including capital discipline, operational excellence and sustainability.

We know investors have many choices, both within the energy sector and across the investment landscape. That's why we believe it's important to gain your confidence – not only through words, but through performance and actions.

By fully exercising the Suncor Advantage, we will continue to provide the energy the world needs while generating the increased value that you, our shareholders, have come to expect from us.

Mark Little
President and Chief Operating Officer

2018 ANNUAL REPORT Suncor Energy Inc. 11

2019 CORPORATE GUIDANCE

The following table highlights forecasts from Suncor's 2019 Full Year Outlook and actual results for the year ended December 31, 2018. For further details regarding Suncor's 2019 Full Year Outlook including certain assumptions, see www.suncor.com/guidance. See also the Advisories section of this Annual Report.

| 2018 Full Year Outlook October 31, 2018 |  | Actual Year Ended December 31, 2018 |  | 2019 Full Year Outlook December 15, 2018
Oil Sands operations (bbls/d) | 415 000 – 430 000 |  | 418 300 |  | 410 000 – 440 000
Fort Hills (bbls/d) | 60 000 – 70 000 |  | 66 100 |  | 85 000 – 95 000
Syncrude (bbls/d) | 140 000 – 145 000 |  | 144 200 |  | 160 000 – 180 000
Exploration and Production (boe/d)(1) | 105 000 – 115 000 |  | 103 400 |  | 105 000 – 115 000
Oil Sands operations cash operating costs ($/bbl) | 23.00 – 26.00 |  | 25.25 |  | 24.00 – 26.50
Fort Hills cash operating costs ($/bbl) | 28.50 – 32.50 |  | 31.20 |  | 23.00 – 26.00
Syncrude cash operating costs ($/bbl) | 44.50 – 47.50 |  | 47.25 |  | 33.50 – 36.50
Refinery utilization(2) | 90% – 94% |  | 93% |  | 93% – 97%

(1)
  At the time of publication, production in Libya continues to be affected by political unrest and, therefore, no forward-looking production for Libya is factored into the Exploration and Production guidance.
(2)
  Refinery utilization is based on the following crude processing capacities: Montreal – 137,000 bbls/d; Sarnia – 85,000 bbls/d; Edmonton – 142,000 bbls/d; and Commerce City – 98,000 bbls/d.

Capital Expenditures(1)

($ millions) |  | 2019 Full Year Outlook December 14, 2018 |  | % Economic Investment
| Upstream Oil Sands |  | 3 050 – 3 400 |  | 17%
| Upstream E&P |  | 1 000 – 1 200 |  | 97%
Total Upstream |  | 4 050 – 4 600 |  | 38%
Downstream (including Ethanol) |  | 700 – 775 |  | 23%
Corporate |  | 150 – 225 |  | 53%
Total |  | 4 900 – 5 600 |  | 37%

(1)
  Capital expenditures exclude capitalized interest of approximately $150 million.
(2)
  Economic Investment capital expenditures include capital investments that result in an increase in value through adding reserves, improving processing capacity, utilization, cost or margin, including associated infrastructure. Balance of capital expenditures represents Asset Sustainment and Maintenance capital expenditures which include capital investments that deliver on existing value by: ensuring compliance or maintaining relations with regulators and other stakeholders, maintaining current processing capacity, and delivering existing developed reserves.

12 2018 ANNUAL REPORT Suncor Energy Inc.

ADVISORIES

All financial information in the preceding sections of this Annual Report is reported in Canadian dollars, unless otherwise noted. Production volumes are presented on a working-interest basis, before royalties, unless otherwise noted, except for 2016 to 2018 production from Libya, which is on an entitlement basis. References to "we", "our", "Suncor", or "the company" mean Suncor Energy Inc., and the company's subsidiaries and interests in associates and jointly controlled entities, unless the context requires otherwise.

FORWARD-LOOKING INFORMATION

The preceding sections of this Annual Report contain certain forward-looking information and forward-looking statements (collectively referred to herein as "forward-looking statements") within the meaning of applicable Canadian and U.S. securities laws. Forward-looking statements are 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 and resources 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 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 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", "promise", "forecast", "potential", "opportunity", "would" and similar expressions. Forward-looking statements in the preceding sections of this Annual Report include references to:

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  Suncor's strategies, including focusing on capital discipline, operational excellence, maintaining a strong balance sheet, cost management, sustainability, reliability, long-term profitable growth and delivering increasing, competitive and sustainable returns to shareholders, improving performance in the economic, environmental and social dimensions of energy development, and the company's commitment to unlocking the full value of its resources and generating cash flow;
•
  The belief that reductions to the company's cost structure are sustainable and that Suncor is positioned to deliver reliable cash flow growth for years;
•
  Suncor's potential growth opportunities and its plan for low-cost, reliable and profitable growth that stretches well into the 2030s, including the focus from 2020 to 2023 on generating free funds flow growth and the expectation of increasing annual free funds flow by approximately $2 billion by 2023, and the potential for funds flow growth from 2024 and beyond through the sanctioning and development of more than 350,000 barrels per day of in situ projects, subject to greater certainty on pipeline access to markets;
•
  Suncor's social goal and GHG emissions intensity reduction goal, expectations around GHG emissions and emissions intensity, plans for and potential benefits of new technologies and digital solutions, and Suncor's plan to remain resilient and thrive in tomorrow's low-carbon economy;
•
  The belief that Fort Hills will be a key supplier of energy for the next 50 years, and that Fort Hills and Hebron are poised to provide reliable, low-cost, high-return production for many years to come;
•
  Suncor's reserves and reserves life estimates;
•
  Expectations around improving reliability and lowering cash costs at Syncrude and achieving average utilization rates at Syncrude of 90% and Syncrude cash operating costs of $30 per barrel by the end of 2020;
•
  The belief that Suncor is positioned to be a progressive, cost-efficient and carbon competitive energy provider of choice for decades;

2018 ANNUAL REPORT Suncor Energy Inc. 13

•
  The belief that improved tidewater access for Canadian resources will be the longer-term solution to differentials and industry competitiveness;
•
  Suncor's commitment to eliminating all workplace injuries and providing a safe workplace; and
•
  Suncor's outlook for 2019 and beyond, Suncor's 2019 Corporate Guidance, and projects to which Suncor's 2019 capital expenditures are anticipated to be directed.

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, Exploration and Production, and Refining and Marketing, may be affected by a number of factors.

Factors that affect our 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 our proprietary production will be closed, experience equipment failure or other accidents; our ability to operate our 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; our dependence on pipeline capacity and other logistical constraints, which may affect our ability to distribute our products to market and which may cause the company to delay or cancel planned growth projects in the event of insufficient takeaway capacity; our 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 our 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 our Exploration and Production segment include, but are not limited to, volatility in crude oil and natural gas prices; operational risks and uncertainties associated with oil and gas activities, including unexpected formations or pressures, premature declines of reservoirs, fires, blow-outs, equipment failures and other accidents, uncontrollable flows of crude oil, natural gas or well fluids, and pollution and other environmental risks; adverse weather conditions, which could disrupt output from producing assets or impact drilling programs, resulting in increased costs and/or delays in bringing on new production; political, economic and socio-economic risks associated with Suncor's foreign operations, including the unpredictability of operating in Libya due to ongoing political unrest; and market demand for mineral rights and producing properties, potentially leading to losses on disposition or increased property acquisition costs.

Factors that affect our Refining and Marketing 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; our ability to reliably operate refining and marketing facilities in order to meet production or sales targets; and risks and uncertainties affecting construction or planned maintenance schedules, including the availability of labour and other impacts of competing projects drawing on the same resources during the same time period.

Additional risks, uncertainties and other factors that could influence the financial and operating performance of all of Suncor's operating segments and activities include, but are not limited to, changes in general economic, market and business conditions, such as commodity prices, interest rates and currency exchange rates; 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 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

14 2018 ANNUAL REPORT Suncor Energy Inc.

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, tariffs, quotas and other government-imposed compliance costs, and mandatory production curtailment orders and changes thereto; 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 we have material relationships to perform their obligations to us; 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; our ability to find new oil and gas reserves that can be developed economically; the accuracy of Suncor's reserves, resources and future production estimates; market instability affecting Suncor's ability to borrow in the capital debt markets at acceptable rates or to issue other securities at acceptable prices; maintaining an optimal debt to cash flow ratio; the success of the company's risk management 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; risks and uncertainties associated with closing a transaction for the purchase or sale of a business, asset or oil and gas property, including estimates of the final consideration to be paid or received; the ability and willingness 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 Aboriginal 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 list of important factors is not exhaustive.

Many of these risk factors and other assumptions related to Suncor's forward-looking statements are discussed in further detail throughout the MD&A, including under the heading Risk Factors, and the company's most recent Annual Information Form/Form 40-F dated February 28, 2019 available at www.sedar.com and www.sec.gov, which risk factors are incorporated by reference herein. Readers are also referred to the risk factors and assumptions described in other documents that Suncor files from time to time with securities regulatory authorities. Copies of these documents are available without charge from the company.

The forward-looking statements contained in this Annual Report are made as of the date of this Annual Report. 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.

Suncor's corporate guidance is based on the following assumptions around oil prices: WTI, Cushing of US$58.00/bbl; Brent, Sullom Voe of US$66.00/bbl; and WCS, Hardisty of US$33.00/bbl. In addition, the guidance is based on the assumption of a natural gas price (AECO-C Spot) of Cdn$1.70 per gigajoule, US$/Cdn$ exchange rate of $0.76 and synthetic crude oil sales from Oil Sands operations of 315,000 to 335,000 bbls/d. Assumptions for the Oil Sands operations, Syncrude and Fort Hills 2019 production outlook include those relating to reliability and operational efficiency initiatives that the company expects will minimize unplanned maintenance in 2019. Assumptions for the Exploration and Production 2019 production outlook include those relating to reservoir performance, drilling results and facility reliability. Factors that could potentially impact Suncor's 2019 corporate guidance include, but are not limited to: Bitumen supply – Bitumen supply may be dependent on unplanned maintenance of mine equipment and extraction plants,

2018 ANNUAL REPORT Suncor Energy Inc. 15

bitumen ore grade quality, tailings storage and in situ reservoir performance; Third-party infrastructure – Production estimates could be negatively impacted by issues with third-party infrastructure, including pipeline or power disruptions, that may result in the apportionment of capacity, pipeline or third-party facility shutdowns, which would affect the company's ability to produce or market its crude oil; Performance of recently commissioned facilities or well pads – Production rates while new equipment is being brought into service are difficult to predict and can be impacted by unplanned maintenance; Unplanned maintenance – Production estimates could be negatively impacted if unplanned work is required at any of our mining, extraction, upgrading, in situ processing, refining, natural gas processing, pipeline, or offshore assets; Planned maintenance events – Production estimates, including production mix, could be negatively impacted if planned maintenance events are affected by unexpected events or are not executed effectively. The successful execution of maintenance and start-up of operations for offshore assets, in particular, may be impacted by harsh weather conditions, particularly in the winter season; Commodity prices – Declines in commodity prices may alter our production outlook and/or reduce our capital expenditure plans; Foreign operations – Suncor's foreign operations and related assets are subject to a number of political, economic and socio-economic risks; Government Action – Suncor's guidance reflects Suncor's expectations and assumptions regarding the production curtailments imposed by the Government of Alberta. Further action by the Government of Alberta regarding production curtailment may impact Suncor's Corporate Guidance and such impact may be material.

NON-GAAP FINANCIAL MEASURES

Certain financial measures used in the preceding sections of this Annual Report, namely operating earnings (loss), funds from operations, ROCE, Oil Sands operations cash operating costs, Fort Hills cash operating costs, Syncrude cash operating costs, free funds flow and discretionary free funds flow, are not prescribed by GAAP. Operating earnings (loss) is defined in the Advisories – Non-GAAP Financial Measures section of the MD&A and is reconciled to GAAP measures in the Financial Information section of Suncor's annual management's discussion and analysis for each respective year. Oil Sands operations cash operating costs, Fort Hills cash operating costs and Syncrude cash operating costs are defined in the Advisories – Non-GAAP Financial Measures section of the MD&A and reconciled to GAAP measures in the Segment Results and Analysis section of the MD&A. Funds from operations (previously referred to as cash flow from operations) and ROCE are defined and reconciled to GAAP measures in the Advisories – Non-GAAP Financial Measures section of Suncor's annual management's discussion and analysis for each respective year. Free funds flow is calculated by taking funds from operations and subtracting capital expenditures, including capitalized interest. Discretionary free funds flow (previously referred to as discretionary free cash flow) is defined in the MD&A, for the years 2014 to 2016 and is reconciled to GAAP measures in the Advisories – Non-GAAP Financial Measures section of Suncor's management's discussion and analysis for the year ended December 31, 2016 and for 2017 and 2018 is reconciled in the Advisories – Non-GAAP Financial Measures section of the MD&A. These non-GAAP financial measures are included because management uses this information to analyze business performance, leverage and liquidity and it may be useful to investors on the same basis. These non-GAAP measures do not have any standardized meaning and therefore are unlikely to be 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.

RESERVES

Reserves information presented herein is presented as Suncor's working interests (operating and non-operating) before deduction of royalties, and without including any royalty interests of Suncor, and is at December 31, 2018. For more information on Suncor's reserves, including definitions of proved and probable reserves, Suncor's interest, the location of the reserves and the product types reasonably expected, please see Suncor's most recent Annual Information Form dated February 28, 2019 available at www.sedar.com and www.sec.gov. Reserves data is based upon evaluations conducted by independent qualified reserves evaluators.

MEASUREMENT CONVERSIONS

Certain crude oil and natural gas liquids volumes have been converted to mcfe on the basis of one bbl to six mcf. Also, certain natural gas volumes have been converted to boe or mboe on the same basis. Refer to the Advisories – Measurement Conversions section of the MD&A.

RECLAMATION

Land is considered permanently reclaimed when landform construction and contouring, clean material placement (as required), reclamation material placement and revegetation has taken place. Land cannot be listed under permanent reclamation until revegetation has occurred which is reflective of the approved Reclamation and Revegetation Plans.

16 2018 ANNUAL REPORT Suncor Energy Inc.

MANAGEMENT'S DISCUSSION AND ANALYSIS February 28, 2019 |

This Management's Discussion and Analysis (this MD&A) should be read in conjunction with Suncor's December 31, 2018 audited Consolidated Financial Statements and the accompanying notes. 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 28, 2019 (the 2018 AIF), which is also filed with the SEC under cover of Form 40-F, is available online at www.sedar.com, www.sec.gov and our website www.suncor.com. Information on or connected to our website, even if referred to in this MD&A, does not constitute part of this MD&A.

References to "we", "our", "Suncor", or "the company" mean Suncor Energy Inc. and the company's subsidiaries and interests in associates and jointly controlled entities, unless the context requires otherwise. For a list of abbreviations that may be used in this MD&A, refer to the Advisories – Common Abbreviations section of this MD&A.

2018 ANNUAL REPORT Suncor Energy Inc. 17

MD&A – Table of Contents
19 |  | Financial and Operating Summary
21 |  | Suncor Overview
23 |  | Financial Information
27 |  | Segment Results and Analysis
40 |  | Fourth Quarter 2018 Analysis
42 |  | Quarterly Financial Data
45 |  | Capital Investment Update
47 |  | Financial Condition and Liquidity
52 |  | Accounting Policies and Critical Accounting Estimates
56 |  | Risk Factors
67 |  | Other Items
68 |  | Advisories

Basis of Presentation

Unless otherwise noted, all financial information has been prepared in accordance with International Financial Reporting Standards (IFRS) as issued by the International Accounting Standards Board (IASB) and Canadian generally accepted accounting principles (GAAP) as contained within Part 1 of the Canadian Institute of Chartered Professional Accountants Handbook.

All financial information is reported in Canadian dollars, unless otherwise noted. Production volumes, apart from Libya, are presented on a working-interest basis, before royalties, unless otherwise noted. Libyan volumes are presented on an entitlement basis.

Non-GAAP Financial Measures

Certain financial measures in this MD&A – namely operating earnings (loss), funds from (used in) operations, return on capital employed (ROCE), Oil Sands operations cash operating costs, In Situ cash operating costs, Fort Hills cash operating costs, Syncrude cash operating costs, refining margin, refining operating expense, discretionary free funds flow, and last-in, first-out (LIFO) inventory valuation methodology – are not prescribed by GAAP. Operating earnings (loss), Oil Sands operations cash operating costs, Fort Hills cash operating costs, Syncrude cash operating costs and LIFO inventory valuation methodology are defined in the Advisories – Non-GAAP Financial Measures section of this MD&A and reconciled to the most directly comparable GAAP measures in the Financial Information and Segment Results and Analysis sections of this MD&A. ROCE, Funds from (used in) operations, discretionary free funds flow, refining margin, refining operating expense and In Situ cash operating costs are defined and reconciled to the most directly comparable GAAP measures in the Advisories – Non-GAAP Financial Measures section of this MD&A.

Measurement Conversions

Crude oil and natural gas liquids volumes have been converted to mcfe on the basis of one bbl to six mcf in this MD&A. Also, certain natural gas volumes have been converted to boe or mboe on the same basis. Refer to the Advisories – Measurement Conversions section of this MD&A.

Common Abbreviations

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

Risks and Forward-Looking Information

The company's business, reserves, financial condition and results of operations may be affected by a number of factors, including, but not limited to, the factors described in the Risk Factors section of this MD&A.

This MD&A contains forward-looking information based on Suncor's current expectations, estimates, projections and assumptions. This information is subject to a number of risks and uncertainties, including those discussed in this MD&A and Suncor's other disclosure documents filed with Canadian securities regulatory authorities and the SEC, many of which are beyond the company's control. Users of this information are cautioned that actual results may differ materially. Refer to the Advisories – Forward-Looking Information section of this MD&A for information on the material risk factors and assumptions underlying our forward-looking information.

18 2018 ANNUAL REPORT Suncor Energy Inc.

1. FINANCIAL AND OPERATING SUMMARY

Year ended December 31 ($ millions, except per share amounts) |  | 2018 |  | 2017 |  | 2016 |  |
Gross revenues |  | 39 592 |  | 32 885 |  | 26 863 |  |
| Royalties |  | (1 050 | ) | (931 | ) | (265 | ) |
Operating revenues, net of royalties |  | 38 542 |  | 31 954 |  | 26 598 |  |
Net earnings (loss) |  | 3 293 |  | 4 458 |  | 445 |  |
| per common share – basic |  | 2.03 |  | 2.68 |  | 0.28 |  |
| per common share – diluted |  | 2.02 |  | 2.68 |  | 0.28 |  |
Operating earnings (loss)(1) |  | 4 312 |  | 3 188 |  | (83 | ) |
| per common share – basic |  | 2.65 |  | 1.92 |  | (0.05 | ) |
Funds from operations(1) |  | 10 172 |  | 9 139 |  | 5 988 |  |
| per common share – basic |  | 6.27 |  | 5.50 |  | 3.72 |  |
Cash flow provided by operating activities |  | 10 580 |  | 8 966 |  | 5 680 |  |
| per common share – basic |  | 6.54 |  | 5.40 |  | 3.53 |  |
Dividends paid on common shares |  | 2 333 |  | 2 124 |  | 1 877 |  |
| per common share – basic |  | 1.44 |  | 1.28 |  | 1.16 |  |
Weighted average number of common shares in millions – basic |  | 1 623 |  | 1 661 |  | 1 610 |  |
Weighted average number of common shares in millions – diluted |  | 1 629 |  | 1 665 |  | 1 612 |  |
ROCE(1) (%) |  | 8.0 |  | 6.7 |  | 0.4 |  |
ROCE(1)(2) (%), excluding major projects in progress |  | 8.2 |  | 8.6 |  | 0.5 |  |
Capital Expenditures(3) |  | 5 250 |  | 5 822 |  | 5 986 |  |
| Sustaining |  | 3 926 |  | 2 916 |  | 2 275 |  |
| Growth |  | 1 324 |  | 2 906 |  | 3 711 |  |
Discretionary free funds flow(1) |  | 3 862 |  | 4 056 |  | 1 797 |  |
Balance Sheet (at December 31) |  |  |  |  |  |  |  |
| Total assets |  | 89 579 |  | 89 494 |  | 88 702 |  |
| Total debt(4) |  | 17 350 |  | 15 579 |  | 17 430 |  |
| Net debt(5) |  | 15 129 |  | 12 907 |  | 14 414 |  |
| Total liabilities |  | 45 574 |  | 44 111 |  | 44 072 |  |

(1)
  Non-GAAP financial measures. See the Advisories – Non-GAAP Financial Measures section of this MD&A.
(2)
  Excludes capitalized costs related to major projects in progress.
(3)
  Excludes capitalized interest.
(4)
  Includes short-term debt, current portion of long-term debt and long-term debt.
(5)
  Net debt is equal to total debt less cash and cash equivalents.

2018 ANNUAL REPORT Suncor Energy Inc. 19

Operating Summary

Year ended December 31 |  | 2018 |  | 2017 |  | 2016 |
Production Volumes (mboe/d) |  |  |  |  |  |  |
| Oil Sands |  | 628.6 |  | 563.7 |  | 504.9 |
| Exploration and Production |  | 103.4 |  | 121.6 |  | 117.9 |
Total |  | 732.0 |  | 685.3 |  | 622.8 |
Production Mix |  |  |  |  |  |  |
| Crude oil and liquids / natural gas (%) |  | 100/0 |  | 100/0 |  | 99/1 |
Average Price Realizations(1) ($/boe) |  |  |  |  |  |  |
| Oil Sands operations |  | 54.91 |  | 54.24 |  | 39.97 |
| Syncrude |  | 70.19 |  | 66.05 |  | 56.38 |
| Fort Hills |  | 38.46 |  | — |  | — |
| Exploration and Production |  | 86.96 |  | 66.20 |  | 53.34 |
Refinery crude oil processed (mbbls/d) |  | 430.8 |  | 441.2 |  | 428.6 |
Refinery Utilization(2) (%) |  |  |  |  |  |  |
| Eastern North America |  | 94 |  | 93 |  | 92 |
| Western North America |  | 93 |  | 98 |  | 94 |
|  | 93 |  | 96 |  | 93 |

(1)
  Net of transportation costs, but before royalties. Price realizations in 2017 and 2016 have been restated due to the impact of IFRS 15 adoption on January 1, 2018 and to remove the impact of risk management activities.
(2)
  Refinery utilization is the amount of crude oil run through crude distillation units, expressed as a percentage of the nameplate capacity of these units.

Segment Summary

Year ended December 31 ($ millions) |  | 2018 |  | 2017 |  | 2016 |  |
Net earnings (loss) |  |  |  |  |  |  |  |
| Oil Sands |  | 853 |  | 1 009 |  | (1 149 | ) |
| Exploration and Production |  | 808 |  | 732 |  | 190 |  |
| Refining and Marketing |  | 3 153 |  | 2 658 |  | 1 890 |  |
| Corporate, Energy Trading and Eliminations |  | (1 521 | ) | 59 |  | (486 | ) |
Total |  | 3 293 |  | 4 458 |  | 445 |  |
Operating earnings (loss)(1) |  |  |  |  |  |  |  |
| Oil Sands |  | 793 |  | 954 |  | (1 109 | ) |
| Exploration and Production |  | 898 |  | 746 |  | 10 |  |
| Refining and Marketing |  | 3 153 |  | 2 164 |  | 1 890 |  |
| Corporate, Energy Trading and Eliminations |  | (532 | ) | (676 | ) | (874 | ) |
Total |  | 4 312 |  | 3 188 |  | (83 | ) |
Funds from (used in) operations(1) |  |  |  |  |  |  |  |
| Oil Sands |  | 4 870 |  | 4 738 |  | 2 669 |  |
| Exploration and Production |  | 1 869 |  | 1 725 |  | 1 313 |  |
| Refining and Marketing |  | 3 794 |  | 2 841 |  | 2 606 |  |
| Corporate, Energy Trading and Eliminations |  | (361 | ) | (165 | ) | (600 | ) |
Total Funds from operations |  | 10 172 |  | 9 139 |  | 5 988 |  |
Change in non-cash working capital |  | 408 |  | (173 | ) | (308 | ) |
Cash flow provided by operating activities |  | 10 580 |  | 8 966 |  | 5 680 |  |

(1)
  Non-GAAP financial measures. See the Advisories – Non-GAAP Financial Measures section of this MD&A.

20 2018 ANNUAL REPORT Suncor Energy Inc.

2. SUNCOR OVERVIEW

Suncor is an integrated energy company headquartered in Calgary, Alberta, Canada. We are strategically focused on developing one of the world's largest petroleum resource basins – Canada's Athabasca oil sands. In addition, we explore for, acquire, develop, produce and market crude oil and natural gas in Canada and internationally; we transport and refine crude oil, and we market petroleum and petrochemical products primarily in Canada. We also conduct energy trading activities focused principally on the marketing and trading of crude oil, natural gas and byproducts. We also operate a renewable energy business as part of our overall portfolio of assets.

For a description of Suncor's business segments, refer to the Segment Results and Analysis section of this MD&A.

Suncor's Strategy

Delivering competitive and sustainable returns to shareholders is a top priority of the company and we aim to consistently grow these returns by focusing on our operational excellence initiatives; capital discipline with asset reliability and optimization; long-term profitable growth, and our commitment to environmental stewardship and sustainability. In an industry that has experienced volatility in recent years, Suncor is well positioned to succeed due to its competitive advantages: an industry-leading long-life, low-decline oil sands reserves base, a highly efficient, tightly integrated downstream business, an offshore business that provides geographically diversified cash flow, financial strength and industry expertise.

Key components of Suncor's strategy are to:

•
  Profitably operate and develop our reserves – Suncor's growth and development plan is focused on projects and initiatives that are expected to create long-term value for the company through structural cash flow growth, such as optimizing production rates at Fort Hills following the successful ramp up in 2018, Syncrude asset optimization, development of regional operating synergies, and value developments and asset extensions within our offshore business. The company's significant long-life, low-decline reserves base combined with our industry expertise allows the company to execute improvement strategies at existing assets, such as debottlenecks and the deployment of autonomous haul trucks, that are expected to generate additional value for years to come. In addition, the company's regional oil sands advantage provides the company with the economies of scale required to further develop our in situ resources in a low-cost manner under the company's replication strategy.
•
  Optimize value through integration and secured market access – From the ground to the gas station, Suncor optimizes profit along each step of the value chain through integration of the company's oil sands assets with our midstream and refining assets. This integration helps to significantly shield Suncor from the effects of western Canadian crude price differentials, and our midstream assets provide the logistical flexibility to move production to a wide range of markets. Production from our Exploration and Production (E&P) assets also provides Suncor with exposure to global Brent crude-based oil prices.
•
  Achieve industry-leading unit costs in each business segment – Suncor aims to get the most out of our assets through a focus on operational excellence, which means operating in a way that is safe, reliable, cost-efficient and environmentally responsible. Driving down costs and a continued focus on improved productivity and reliability will help us achieve maximum value from our operations.
•
  Be an industry leader in sustainable development – Suncor is focused on triple bottom line sustainability, which means leadership and industry collaboration in environmental performance, social responsibility and creating a strong economy.

2018 Highlights

Financial results summary

•
  In 2018, Suncor achieved record funds from operations(1) of $10.172 billion, compared to $9.139 billion in 2017.
•
  Cash flow provided by operating activities, which includes changes in non-cash working capital, was $10.580 billion in 2018, compared to $8.966 billion in 2017.
•
  Operating earnings(1) in 2018 were $4.312 billion, compared to $3.188 billion in 2017.
•
  Net earnings for 2018 were $3.293 billion, compared to $4.458 billion in 2017.
•
  ROCE(1) improved to 8.0% in 2018, compared to 6.7% in 2017.

(1)
  Non-GAAP financial measures. See the Advisories – Non-GAAP Financial Measures section of this MD&A.

2018 ANNUAL REPORT Suncor Energy Inc. 21

Successful ramp up of operations at both Fort Hills and Hebron.

•
  Following the commissioning of the secondary extraction assets early in 2018, Fort Hills produced an average of 66,100 bbls/d, net to Suncor, for the year and successfully ramped up to full operating rates by the fourth quarter of 2018, with 94% average plant utilization in the fourth quarter.
•
  Production at Hebron averaged 13,000 bbls/d in 2018, net to Suncor, with four production wells online by the end of the year. Hebron is expected to deliver 31,600 bbls/d, net to Suncor, when fully ramped up.

Oil Sands production increased to 628,600 bbls/d in 2018, compared to 563,700 bbls/d in 2017.

•
  Record production was achieved at both Firebag and MacKay River in 2018, with the company's In Situ assets achieving 99% utilization for the year. Total In Situ production was 240,000 bbls/d compared to nameplate capacity of 241,000 bbls/d.
•
  With production being impacted by an increase in major planned maintenance in 2018, Oil Sands operations produced 418,300 bbls/d in 2018, compared to 429,400 bbls/d in the prior year.
•
  Early in 2018, Suncor acquired an additional 5% working interest in Syncrude from Mocal Energy Limited (Mocal), adding approximately 17,500 bbls/d of SCO capacity.

Refining and Marketing (R&M) attained several new records in 2018 and achieved 93% average refinery utilization, despite the completion of the most intensive planned maintenance program in the company's history.

•
  Record annual financial results in R&M were achieved in 2018, with net and operating earnings of $3.153 billion and funds from operations of $3.794 billion. Record results were driven by a favourable business environment, including wider crude oil differentials, and strong refinery utilization in 2018.
•
  Continued strong product demand helped R&M establish a new sales volumes record through its wholesale channels in Canada.
•
  Crude throughput of 430,800 bbls/d was achieved in 2018, despite the completion of planned turnarounds at all of the company's refineries, including the entire Edmonton refinery undergoing the first total plant turnaround in its history. Strong throughput was maintained due to a strategic accumulation of inventory leading up to the spring turnarounds.

Exploration and Production (E&P) delivered diversified Brent crude-based cash flow in 2018 and continued to pursue development opportunities.

•
  E&P funds from operations increased to $1.869 billion from $1.725 billion in 2017, and operating earnings were $898 million, compared to $746 million in the prior year, as a result of increased benchmark crude prices.
•
  Several strategic investments were completed throughout the year, including the acquisition of an additional 10% working interest in the Rosebank future development project in the U.K. North Sea, and the acquisition of a 17.5% working interest in the Fenja project offshore Norway.
•
  During 2018, the company and its partners sanctioned the Buzzard Phase 2 project, with first oil expected in early 2021.
•
  The company continued to advance development work at the Oda project in Norway, with first oil expected in the second quarter of 2019.
•
  Development drilling continued to progress at existing East Coast assets throughout the year.

Suncor continued to return value to shareholders in 2018 through increased dividends and additional share repurchases.

•
  A total of $2.333 billion in dividends were paid in 2018, an increase of 12.5% per share over the prior year, making 2018 the 16th consecutive year of annual dividend increases for Suncor.
•
  The company repurchased $3.053 billion of its own shares for cancellation during 2018, compared to $1.413 billion in 2017.
•
  Subsequent to the end of the year, Suncor's Board of Directors approved a quarterly dividend of $0.42 per share to be paid in the first quarter of 2019, an increase of 17%, and also approved a further share repurchase program of up to $2.0 billion.

22 2018 ANNUAL REPORT Suncor Energy Inc.

3. FINANCIAL INFORMATION

Net Earnings

Suncor's net earnings in 2018 were $3.293 billion, compared to $4.458 billion in 2017. Net earnings were impacted by the same factors that influenced operating earnings, which are described below. Other items affecting net earnings in 2018 and 2017 included:

•
  The after-tax unrealized foreign exchange loss on the revaluation of U.S. dollar denominated debt was $989 million in 2018, compared to an after-tax gain of $702 million in 2017.
•
  In 2018, the company recorded a net non-cash loss of $90 million, after-tax, in the E&P segment related to an asset exchange with Canbriam Energy Inc. (Canbriam), a private natural gas company, as a result of the decline in benchmark natural gas prices in B.C.
•
  In 2018, the company recorded an after-tax gain of $60 million in the Oil Sands segment on the sale of the company's interest in the Joslyn Oil Sands mining project. 2017 net earnings included a $354 million after-tax gain in the R&M segment related to the sale of the company's lubricants business, and an after-tax gain of $83 million in the Corporate segment related to the sale of the company's interest in the Cedar Point wind facility.
•
  In 2017, the company recorded an adjustment to its deferred income taxes of $124 million related to tax reform legislation in the U.S., with the most significant impact resulting from a decrease in the corporate income tax rate from 35% to 21%. In 2016, the U.K. government enacted a decrease in the supplementary charge on oil and gas profits in the North Sea that reduced the statutory tax rate on Suncor's earnings in the U.K. from 50% to 40%, resulting in an adjustment to the company's deferred income taxes of $180 million.
•
  The company received after-tax property damage insurance proceeds of $55 million during 2017 related to a facility incident at Syncrude that occurred earlier that year, in the Oil Sands segment.
•
  During 2017, the company redeemed US$1.250 billion, US$600 million and $700 million of higher interest long-term debt that was originally due in 2018, reducing future financing charges for a net economic benefit. As a result of the early redemption, the company incurred an after-tax charge of $28 million, net of associated realized foreign currency hedges, in the Corporate segment.
•
  In 2017, the company recognized an after-tax loss on forward interest rate swaps of $20 million in the Corporate segment due to changes in long-term interest rates.

Operating Earnings

Consolidated Operating Earnings (Loss) Reconciliation(1)

Year ended December 31 ($ millions) |  | 2018 |  | 2017 |  | 2016 |  |
Net earnings as reported |  | 3 293 |  | 4 458 |  | 445 |  |
Unrealized foreign exchange loss (gain) on U.S. dollar denominated debt |  | 989 |  | (702 | ) | (524 | ) |
(Gain) on significant disposals and loss on equity investment |  | 30 |  | (437 | ) | — |  |
Loss (gain) on interest rate swaps(2) |  | — |  | 20 |  | (6 | ) |
Impact of income tax adjustments on deferred income taxes(3) |  | — |  | (124 | ) | (180 | ) |
Non-cash loss on early payment of long-term debt(4) |  | — |  | 28 |  | 73 |  |
Recognition of property damage insurance proceeds |  | — |  | (55 | ) | — |  |
Derecognition and impairments(5) |  | — |  | — |  | 71 |  |
Canadian Oil Sands Limited (COS) acquisition and integration costs(6) |  | — |  | — |  | 38 |  |
Operating earnings (loss)(1) |  | 4 312 |  | 3 188 |  | (83 | ) |

(1)
  Non-GAAP financial measure. See the Advisories – Non-GAAP Financial Measures section of this MD&A.
(2)
  Loss (gain) on forward interest rate swaps associated with issued debt, due to changes in long-term interest rates, in the Corporate segment.
(3)
  The year ended December 31, 2016 was impacted by an adjustment to the company's deferred income taxes resulting from a decrease from 50% to 40% in the United Kingdom tax rate on oil and gas profits from the North Sea.
(4)
  Charges associated with the early repayment of debt, net of associated realized foreign currency hedges, in the Corporate segment.
(5)
  In 2016, the company recorded after-tax derecognition charges of $40 million on certain upgrading and logistics assets in the Oil Sands segment as a result of the uncertainty of future benefits from the assets, as well as a $31 million charge in the Corporate segment relating to an initial investment in an undeveloped pipeline and on certain renewable energy development assets as a result of the uncertainty of future benefits from these assets.
(6)
  Transaction and related charges associated with the acquisition of COS in the Corporate segment.

2018 ANNUAL REPORT Suncor Energy Inc. 23

Bridge Analysis of Consolidated Operating Earnings ($ millions)(1)

(1)
  For an explanation of the construction of this bridge analysis, see the Advisories – Non-GAAP Financial Measures section of this MD&A.

Suncor's consolidated operating earnings in 2018 were $4.312 billion, compared to $3.188 billion in the prior year. The increase was primarily due to improved overall benchmark crude pricing, increased refining margins, higher overall upstream production, primarily attributed to the ramp up of Fort Hills and Hebron and the increased working interest in Syncrude acquired in early 2018, as well as improved energy trading earnings. These factors were partially offset by an increase in expenses associated with the expansion of the company's production in 2018, an increase in maintenance expenditures at Syncrude and Oil Sands operations resulting from an increase in planned and unplanned maintenance, a decrease in the capitalization of borrowing costs with the commissioning of the company's major growth projects, as well as a net unfavourable inventory valuation change on declining crude feedstock costs at the end of 2018.

Cash Flow Provided by Operating Activities and Funds from Operations

Consolidated funds from operations for 2018 were $10.172 billion, compared to $9.139 billion in 2017, and were impacted by the same factors as operating earnings described above.

Cash flow provided by operating activities, which includes changes in non-cash working capital, was $10.580 billion in 2018, compared to $8.966 billion in 2017, and reflected a source of cash from the company's working capital balances in 2018, compared to a use of cash in 2017, as a result of lower year end benchmark prices.

Results for 2017 Compared with 2016

Net earnings in 2017 were $4.458 million, compared to $445 million in 2016. The increase in net earnings was mainly due to the same factors impacting operating earnings described below, as well as the net earnings adjustments impacting 2017 and 2016, which are described in detail above.

Operating earnings were $3.188 billion in 2017, compared to an operating loss of $83 million in 2016. The increase was primarily due to improved benchmark crude pricing, favourable crack spreads, higher upstream production, lower DD&A, a decrease in exploration expense and higher sales volumes at R&M. These factors were partially offset by the impact of a stronger Canadian dollar, an increase in operating expenses, which was primarily due to the acquisition of additional working interests in Syncrude in 2016, increased maintenance costs at Syncrude, an increase in royalties associated with higher production and the impact of the sale of the lubricants business. Operating earnings in 2016 were significantly impacted by the shut in of production associated with the forest fires in the Fort McMurray area in the second quarter of that year.

Consolidated funds from operations for 2017 were $9.139 billion, compared to $5.988 billion in 2016. Funds from operations were impacted by the same factors as operating earnings, after removing the impact of non-cash expenses primarily related to DD&A.

Cash flow provided by operating activities, which includes changes in non-cash working capital, was $8.966 billion in 2017, compared to $5.680 billion in 2016.

24 2018 ANNUAL REPORT Suncor Energy Inc.

Business Environment

Commodity prices, refining crack spreads and foreign exchange rates are important factors that affect the results of Suncor's operations.

Average for the year ended December 31 |  | 2018 |  | 2017 |  | 2016 |
WTI crude oil at Cushing (US$/bbl) |  | 64.80 |  | 50.95 |  | 43.35 |
Dated Brent Crude (US$/bbl) |  | 71.05 |  | 54.25 |  | 43.75 |
Dated Brent/Maya FOB price differential (US$/bbl) |  | 9.10 |  | 7.70 |  | 7.50 |
MSW at Edmonton (Cdn$/bbl) |  | 69.30 |  | 63.20 |  | 51.90 |
WCS at Hardisty (US$/bbl) |  | 38.50 |  | 38.95 |  | 29.55 |
Light/heavy differential for WTI at Cushing less WCS at Hardisty (US$/bbl) |  | 26.30 |  | 11.95 |  | 13.85 |
Condensate at Edmonton (US$/bbl) |  | 61.05 |  | 51.55 |  | 42.50 |
Natural gas (Alberta spot) at AECO (Cdn$/mcf) |  | 1.50 |  | 2.15 |  | 2.15 |
Alberta Power Pool Price (Cdn$/MWh) |  | 50.20 |  | 22.15 |  | 18.20 |
New York Harbor 3-2-1 crack(1) (US$/bbl) |  | 18.00 |  | 17.70 |  | 14.05 |
Chicago 3-2-1 crack(1) (US$/bbl) |  | 15.90 |  | 16.30 |  | 12.60 |
Portland 3-2-1 crack(1) (US$/bbl) |  | 22.80 |  | 22.15 |  | 16.50 |
Gulf Coast 3-2-1 crack(1) (US$/bbl) |  | 17.45 |  | 17.65 |  | 13.40 |
Exchange rate (US$/Cdn$) |  | 0.77 |  | 0.77 |  | 0.75 |
Exchange rate (end of period) (US$/Cdn$) |  | 0.73 |  | 0.80 |  | 0.74 |

(1)
  3-2-1 crack spreads are indicators of the refining margin generated by converting three barrels of WTI into two barrels 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.

Suncor's sweet SCO price realizations are influenced primarily by the price of WTI at Cushing and by the supply and demand of sweet SCO from Western Canada, which influences SCO differentials. Price realizations for sweet SCO were favourably impacted by the improvement in the WTI crude benchmark, which increased to US$64.80/bbl in 2018, from US$50.95/bbl in 2017, partially offset by wider SCO differentials impacting the latter portion of the year resulting from oversupply and takeaway constraints impacting the Alberta crude market.

Suncor also produces a specific grade of sour SCO, the price realizations for which are influenced by various crude benchmarks including, but not limited to, MSW at Edmonton and WCS at Hardisty, and which can also be affected by prices negotiated for spot sales. Prices for MSW at Edmonton increased in 2018 compared to 2017, to $69.30/bbl from $63.20/bbl, while WCS at Hardisty decreased slightly to US$38.50 in 2018 compared to US$38.95 in 2017, reflecting the impact of wider western Canadian heavy crude differentials.

Bitumen production that Suncor does not upgrade is blended with diluent to facilitate delivery on pipeline systems. Net bitumen price realizations are therefore influenced by both prices for Canadian heavy crude oil (WCS at Hardisty is a common reference) and prices for diluent (Condensate at Edmonton and SCO), and pipeline tolls. Bitumen price realizations can also be affected by bitumen quality and spot sales and, in the second half of 2018, were also impacted by a substantial widening of heavy crude differentials.

Subsequent to the end of the year, crude differentials for SCO and heavy crude improved from the significant discounts experienced in the fourth quarter of 2018, primarily as a result of the Alberta government's mandatory production curtailments.

Suncor's price realizations for production from East Coast Canada and E&P International assets are influenced primarily by the price for Brent crude, which averaged US$71.05/bbl in 2018, compared to US$54.25/bbl in 2017. Due to the nature of cargo shipments at the company's offshore assets, the timing associated with bulk cargo sales can result in price realizations that deviate from the average benchmark price over the period.

Natural gas used in Suncor's Oil Sands and Refining operations is primarily referenced to Alberta spot prices at AECO. The average AECO benchmark decreased to $1.50/mcf in 2018, from $2.15/mcf in the prior year.

Suncor's refining margins are primarily influenced by 3-2-1 benchmark crack spreads, which are industry indicators approximating the gross margin on a barrel of crude oil that is refined to produce gasoline and distillates, and crude differentials. More complex refineries can earn greater

2018 ANNUAL REPORT Suncor Energy Inc. 25

refining margins by processing less expensive, heavier crudes, or lighter crudes discounted relative to the WTI benchmark. Crude differentials in Alberta widened considerably during the second half of 2018, resulting in lower refinery feedstock costs for the majority of the company's refineries and improved refining margins. Crack spreads do not necessarily reflect the margins of a specific refinery. Crack spreads quoted in the market are based on current crude feedstock prices whereas actual earnings are based on first-in, first-out (FIFO) inventory accounting, where a delay exists between the time that feedstock is purchased and when it is processed and sold to a third party. A FIFO loss normally reflects a declining price environment for crude oil and finished products, whereas FIFO gains reflect an increasing price environment for crude oil and finished products. Specific refinery margins are further impacted by actual crude purchase costs, refinery configuration, production mix and realized prices for refined products sales in markets unique to each refinery.

Excess electricity produced in Suncor's Oil Sands operations business is sold to the Alberta Electric System Operator, with the proceeds netted against the Oil Sands operations cash operating costs per barrel metric. The Alberta power pool price increased to an average of $50.20/MWh in 2018 from $22.15/MWh in the prior year.

The majority of Suncor's revenues from the sale of oil and natural gas commodities are based on prices that are determined by or referenced to U.S. dollar benchmark prices. The majority of Suncor's expenditures are realized in Canadian dollars. A decrease in the value of the Canadian dollar relative to the U.S. dollar will increase the revenues received from the sale of commodities. An increase in the value of the Canadian dollar relative to the U.S. dollar will decrease revenue received from the sale of commodities. In both 2018 and 2017, the average exchange rate was US$0.77 per one Canadian dollar.

Conversely, some of Suncor's assets and liabilities, notably 75% of the company's debt, are denominated in U.S. dollars and translated to Suncor's reporting currency (Canadian dollars) at each balance sheet date. A decrease in the value of the Canadian dollar relative to the U.S. dollar from the previous balance sheet date increases the amount of Canadian dollars required to settle U.S. dollar denominated obligations.

Economic Sensitivities(1)(2)

The following table illustrates the estimated effects that changes in certain factors would have had on 2018 net earnings and funds from operations(3) if the listed changes had occurred.

(Estimated change, in $ millions) |  | Net Earnings |  | Funds From Operations(3) |  |
Crude oil +US$1.00/bbl |  | 220 |  | 220 |  |
Natural gas +Cdn$0.10/mcf |  | (24 | ) | (24 | ) |
WTI – narrowing light/heavy differential +US$1.00/bbl |  | 31 |  | 31 |  |
3-2-1 crack spreads +US$1.00/bbl |  | 144 |  | 144 |  |
Foreign exchange +$0.01 US$/Cdn$ related to operating activities(4) |  | (193 | ) | (193 | ) |
Foreign exchange on U.S. dollar denominated debt +$0.01 US$/Cdn$ |  | 167 |  | — |  |

(1)
  Each line item in this table shows the effects of a change in that variable only, with other variables being held consistent.
(2)
  Changes for a variable imply that all such similar variables are impacted, such that Suncor's average price realizations increase uniformly. For instance, "Crude oil +US$1.00/bbl" implies that price realizations influenced by WTI, Brent, SCO, WCS, par crude at Edmonton and condensate all increase by US$1.00/bbl.
(3)
  Non-GAAP financial measure. See the Advisories – Non-GAAP Financial Measures section of this MD&A.
(4)
  Excludes the foreign exchange impact on U.S. dollar denominated debt.

26 2018 ANNUAL REPORT Suncor Energy Inc.

4. SEGMENT RESULTS AND ANALYSIS

Suncor has classified its operations into the following segments:

OIL SANDS

Suncor's Oil Sands segment, with assets located in the Athabasca oil sands of northeast Alberta, recovers bitumen from mining and in situ operations and either upgrades this production into SCO for refinery feedstock and diesel fuel, or blends the bitumen with diluent for direct sale to market. The Oil Sands segment includes:

•
  Oil Sands operations refer to Suncor's owned and operated mining, extraction, upgrading, in situ and related logistics and storage assets in the Athabasca oil sands region. Oil Sands operations consist of:
  •
    Oil Sands Base operations include the Millennium and North Steepbank mining and extraction operations, integrated upgrading facilities known as Upgrader 1 and Upgrader 2, and the associated infrastructure for these assets – including utilities, energy, reclamation and storage facilities.
  •
    In Situ operations include oil sands bitumen production from Firebag and MacKay River and supporting infrastructure, including central processing facilities, cogeneration units, product transportation infrastructure, diluent import capabilities, storage assets, and a cooling and blending facility. In Situ also includes development opportunities which may support future in situ production, including Meadow Creek (75%), Lewis (100%), OSLO (77.78%), various interests in Chard (25% to 50%), and a non-operated interest in Kirby (10%). In Situ production is either upgraded by Oil Sands Base, or blended with diluent and marketed directly to customers.
•
  Fort Hills includes Suncor's 54.11% interest in the Fort Hills mining project, which the company operates, and the East Tank Farm Development (ETFD) in which Suncor holds a 51% interest.
•
  Syncrude refers to Suncor's 58.74% interest in the Syncrude oil sands mining and upgrading joint arrangement.

EXPLORATION AND PRODUCTION

Suncor's E&P segment consists of offshore operations off the east coast of Canada and in the North Sea, and onshore assets in Libya and Syria.

•
  E&P Canada operations include Suncor's 37.675% working interest in Terra Nova, which Suncor operates. Suncor also holds non-operated interests in Hibernia (20% in the base project and 19.190% in the Hibernia Southern Extension Unit), White Rose (27.5% in the base project and 26.125% in the extensions), and the Hebron project (21.034%). In addition, the company holds interests in several exploration licences offshore Newfoundland and Labrador. Previously, E&P Canada also included Suncor's working interest in natural gas leases in northeast B.C., which were exchanged for a 37% equity interest in Canbriam during the first quarter of 2018.
•
  E&P International operations include Suncor's non-operated interests in Buzzard (29.89%), the Golden Eagle Area Development (26.69%), the Rosebank future development project (40%), the Oda project (30%) and the Fenja project (17.5%). The first three projects are located in the U.K. sector of the North Sea, while the Oda and Fenja projects are located in the Norwegian North Sea and the Norwegian Sea, respectively. In addition, Suncor owns, pursuant to Exploration and Production Sharing Agreements (EPSAs), working interests in the exploration and development of oilfields in the Sirte Basin in Libya, although production in Libya remained partially shut in throughout 2018 due to continued political unrest. The timing of a return to normal operations in Libya remains uncertain. Suncor also owns, pursuant to a Production Sharing Contract (PSC), an interest in the Ebla gas development in Syria, which has been suspended, indefinitely, since 2011 due to political unrest in the country.

REFINING AND MARKETING

Suncor's R&M segment consists of two primary operations:

•
  Refining and Supply operations refine crude oil and intermediate feedstock into a wide range of petroleum and petrochemical products. Refining and Supply consists of:
  •
    Eastern North America operations include a 137,000 bbls/d refinery located in Montreal, Quebec and an 85,000 bbls/d refinery located in Sarnia, Ontario.
  •
    Western North America operations include a 142,000 bbls/d refinery located in Edmonton, Alberta and a 98,000 bbls/d refinery in Commerce City, Colorado.
  •
    Other Refining and Supply assets include interests in a petrochemical plant and a sulphur recovery facility in Montreal, Quebec, product pipelines and terminals throughout Canada and the U.S., and the St. Clair ethanol plant in Ontario.
•
  Marketing operations sell refined petroleum products to retail, commercial and industrial customers through a

2018 ANNUAL REPORT Suncor Energy Inc. 27

combination of company-owned, Petro-Canada® and Sunoco® branded-dealers in Canada and other non-branded retail stations in the U.S., a nationwide commercial road transportation network in Canada, and a bulk sales channel in Canada.

CORPORATE, ENERGY TRADING AND ELIMINATIONS

The grouping Corporate, Energy Trading and Eliminations includes the company's investments in renewable energy projects, results related to energy marketing, supply and trading activities, and other activities not directly attributable to any other operating segment.

•
  Renewable Energy includes interests in four wind farm operations in Ontario and Western Canada, being Adelaide, Chin Chute, Magrath and Sunbridge.
•
  Energy Trading activities primarily involve the marketing, supply and trading of crude oil, natural gas, power and byproducts, and the use of midstream infrastructure and financial derivatives to optimize related trading strategies.
•
  Corporate activities include stewardship of Suncor's debt and borrowing costs, expenses not allocated to the company's businesses, and the company's captive insurance activities that self-insure a portion of the company's asset base.
•
  Intersegment revenues and expenses are removed from consolidated results in Eliminations. Intersegment activity includes the sale of product between the company's segments and insurance for a portion of the company's operations by the Corporate captive insurance entity. The sale of product between the company's segments is primarily related to crude refining feedstock sold from Oil Sands to R&M.

OIL SANDS

2018 Highlights

•
  Production at Fort Hills began in the first quarter of 2018 and the project successfully ramped up to 94% of nameplate capacity ahead of schedule in the fourth quarter of 2018. Average production in the year was 66,100 bbls/d, net to Suncor.
•
  Record production achieved at both Firebag and MacKay River, with the company's In Situ assets achieving 99% utilization for the year, and average annual In Situ cash operating costs per barrel(1) were below $10 for the first time.
•
  Suncor completed the acquisition of an additional 5% working interest in Syncrude from Mocal, adding approximately 17,500 bbls/d of sweet SCO capacity and bringing the company's working interest up to 58.74%.

Strategy and Investment Update

Oil Sands has developed a significant asset base within the Athabasca oil sands and has established a regional advantage given the close proximity of the company's assets to one another. This collection of high-quality assets, combined with long-life, low-decline reserves and industry-leading expertise, provides the opportunity to create structural cash flow growth improvements through asset optimization initiatives, such as debottlenecks and further integration with Syncrude to improve operational flexibility.

Reliability at Firebag and MacKay River improved in 2018, with both facilities setting new annual production records of 204,000 bbls/d and 36,000 bbls/d, respectively. Oil Sands upgrading reliability was 80% for the year, and reflected the impact of an increase in major planned maintenance with the successful completion of the first turnaround at Upgrader 1 since moving to a five year cycle.

Oil Sands remains focused on safe, reliable and sustainable operations. The company's operational excellence initiatives are aimed at improving facility utilization and workforce productivity, and are expected to achieve steady production growth while reducing operating costs. In 2018, Suncor completed the implementation of Autonomous Haulage Systems (AHS) at our North Steepbank Extension Mine. The program is expected to include the deployment of more than 150 autonomous haul trucks across our business over approximately six years.

Following the commissioning of the Fort Hills project in 2018 and the successful ramp up to 94% of nameplate capacity in the fourth quarter of 2018, Suncor will now focus on asset optimization, including AHS and low cost debottleneck opportunities, and continue its execution of safe and reliable operations in 2019.

Suncor remains committed to profitable growth, as was demonstrated by the company's acquisition of an additional 5% working interest in Syncrude in the first quarter of 2018. In an effort to improve reliability at Syncrude, Suncor and its joint venture partners reached an agreement in 2018 to build bi-directional interconnecting pipelines, which will connect Syncrude's Mildred Lake site with Suncor's Oil Sands Base plant. The lines will provide increased operational flexibility through the ability to transfer bitumen and gas oils between the two plants, enabling higher reliability and utilization and profit optimization. The pipelines are expected to be operational by the end of 2020, subject to finalized commercial terms and regulatory approval.

(1)
  Non-GAAP financial measure. See the Advisories – Non-GAAP Financial Measures section of this MD&A.

28 2018 ANNUAL REPORT Suncor Energy Inc.

Cost management and capital discipline at Oil Sands will continue to be top priorities in 2019 as the company expects to sustainably reduce controllable operating costs through initiatives that include coordinated maintenance strategies, equipment standardization, adoption of digital technologies and inventory management improvements. Capital discipline continues to focus on managing investment opportunities, including asset synergies and sustainability priorities, such as the replacement of the coke-fired boilers at Oil Sands operations with lower carbon-intensive natural gas and accelerating tailings remediation, through a robust asset development process focused on value creation.

Financial Highlights

Year ended December 31 ($ millions) |  | 2018 |  | 2017 |  | 2016 |  |
Gross revenues |  | 15 743 |  | 13 274 |  | 9 538 |  |
Less: Royalties |  | (398 | ) | (355 | ) | (52 | ) |
Operating revenues, net of royalties |  | 15 345 |  | 12 919 |  | 9 486 |  |
Net earnings (loss) |  | 853 |  | 1 009 |  | (1 149 | ) |
Adjusted for: |  |  |  |  |  |  |  |
| Gain on significant disposal |  | (60 | ) | — |  | — |  |
| Insurance proceeds |  | — |  | (55 | ) | — |  |
| Derecognition and impairments |  | — |  | — |  | 40 |  |
Operating earnings (loss)(1) |  | 793 |  | 954 |  | (1 109 | ) |
Funds from operations(1) |  | 4 870 |  | 4 738 |  | 2 669 |  |

(1)
  Non-GAAP financial measures. See the Advisories – Non-GAAP Financial Measures section of this MD&A.

Bridge Analysis of Operating Earnings ($ millions)(1)

(1)
  For an explanation of the construction of this bridge analysis, see the Advisories – Non-GAAP Financial Measures section of this MD&A.

Operating earnings in Oil Sands operations were $793 million in 2018, compared to $954 million in 2017. The ramp up of Fort Hills in early 2018 increased both the company's sales volumes as well as operating and transportation expenses. The decrease in operating earnings was due to an unfavourable sales mix associated with a decrease in SCO production as a result of significant planned upgrader maintenance, lower bitumen price realizations and higher maintenance costs related to turnarounds, partially offset by the acquisition of an additional 5% working interest in Syncrude and record production at In Situ, combined with an increase in SCO price realizations.

Net earnings for Oil Sands were $853 million in 2018, compared to $1.009 billion in 2017 and were impacted by the same factors as operating earnings described above. In addition, 2018 net earnings included a $60 million gain on the sale of the company's interest in the Joslyn oil sands mining project. 2017 net earnings included $55 million of

2018 ANNUAL REPORT Suncor Energy Inc. 29

property damage insurance proceeds related to a facility incident that occurred at Syncrude earlier that year.

Funds from operations for the Oil Sands segment were $4.870 billion in 2018, compared to $4.738 billion in 2017. The increase was primarily due to the acquisition of an additional 5% working interest in Syncrude, and was also impacted by the same factors that impacted operating earnings, adjusted for the impact of non-cash DD&A.

Production Volumes(1)

Year ended December 31 (mbbls/d) |  | 2018 |  | 2017 |  | 2016 |
Upgraded product (SCO and diesel) |  | 280.3 |  | 317.7 |  | 258.9 |
In Situ non-upgraded bitumen |  | 138.0 |  | 111.7 |  | 115.9 |
Total Oil Sands operations production |  | 418.3 |  | 429.4 |  | 374.8 |
Fort Hills bitumen |  | 66.1 |  | — |  | — |
Syncrude (sweet SCO and diesel) |  | 144.2 |  | 134.3 |  | 130.1 |
Total |  | 628.6 |  | 563.7 |  | 504.9 |

(1)
  Bitumen from Oil Sands Base operations is upgraded, while bitumen from In Situ operations is upgraded or sold directly to customers. Yields of SCO from Suncor's upgrading processes are approximately 79% of bitumen feedstock input. Yields of SCO from Syncrude's upgrading processes are approximately 85% of bitumen feedstock input.

Oil Sands operations production decreased to 418,300 bbls/d in 2018 from 429,400 bbls/d in 2017, due to an increase in planned and unplanned upgrader maintenance in 2018, offset by an increase in non-upgraded bitumen production, with record volumes achieved at the company's In Situ facilities. Upgrader utilization was 80% in 2018, compared to 91% in 2017.

Fort Hills bitumen production averaged 66,100 bbls/d in 2018 and reflects the ramp up of operations to 94% plant utilization for the fourth quarter of 2018.

Sales Volumes and Mix

Year ended December 31 (mbbls/d) |  | 2018 |  | 2017 |  | 2016 |
Oil Sands operations sales volumes |  |  |
| Sweet SCO |  | 96.1 |  | 107.9 |  | 87.3 |
| Diesel |  | 28.8 |  | 27.5 |  | 21.2 |
| Sour SCO |  | 162.6 |  | 183.6 |  | 153.4 |
Upgraded product (SCO) |  | 287.5 |  | 319.0 |  | 261.9 |
Non-upgraded bitumen |  | 134.0 |  | 110.6 |  | 117.4 |
Oil Sands operations |  | 421.5 |  | 429.6 |  | 379.3 |
Fort Hills bitumen |  | 57.3 |  | — |  | — |
Syncrude sweet SCO |  | 144.2 |  | 134.3 |  | 130.1 |
Total |  | 623.0 |  | 563.9 |  | 509.4 |

Sales volumes for Oil Sands operations decreased to 421,500 bbls/d in 2018, compared to 429,600 bbls/d in 2017, reflecting the same factors impacting production volumes.

Fort Hills bitumen sales averaged 57,300 bbls/d in 2018 and reflect a build of inventory due to an increase in production volumes at the end of the year and the associated transit time to market.

Suncor's share of Syncrude production and sales volumes averaged 144,200 bbls/d in 2018, compared to 134,300 bbls/d in 2017. The increase is due to the additional 5% working interest in Syncrude acquired in 2018, combined with strong reliability during the fourth quarter of 2018, partially offset by the decrease in production associated with a power outage that occurred in the second quarter of 2018. Syncrude production in 2017 was also negatively impacted by a facility event.

30 2018 ANNUAL REPORT Suncor Energy Inc.

Bitumen Production from Operations

Year ended December 31 |  | 2018 |  | 2017 |  | 2016 |
Oil Sands Base |  |  |  |  |  |  |
| Bitumen production (mbbls/d) |  | 258.8 |  | 305.4 |  | 238.0 |
| Bitumen ore mined (thousands of tonnes/day) |  | 378.0 |  | 464.4 |  | 351.1 |
| Bitumen ore grade quality (bbls/tonne) |  | 0.68 |  | 0.66 |  | 0.68 |
In Situ |  |  |  |  |  |  |
| Bitumen production – Firebag (mbbls/d) |  | 204.0 |  | 181.5 |  | 180.8 |
| Steam-to-oil ratio – Firebag |  | 2.7 |  | 2.7 |  | 2.6 |
| Bitumen production – MacKay River (mbbls/d) |  | 36.0 |  | 31.1 |  | 27.6 |
| Steam-to-oil ratio – MacKay River |  | 2.9 |  | 3.1 |  | 3.2 |
| Total In Situ bitumen production (mbbls/d) |  | 240.0 |  | 212.6 |  | 208.4 |
| Total Oil Sands operations bitumen production (mbbls/d) |  | 498.8 |  | 518.0 |  | 446.4 |
Fort Hills |  |  |  |  |  |  |
| Bitumen production (mbbls/d) |  | 66.1 |  | — |  | — |
| Bitumen from froth |  | 1.3 |  | — |  | — |
| Bitumen ore mined (thousands of tonnes/day) |  | 106.2 |  | — |  | — |
| Bitumen ore grade quality (bbls/tonne) |  | 0.63 |  | — |  | — |
Syncrude |  |  |  |  |  |  |
| Bitumen production (mbbls/d) |  | 172.0 |  | 163.6 |  | 151.1 |
| Bitumen ore mined (thousands of tonnes/day) |  | 277.5 |  | 252.7 |  | 245.8 |
| Bitumen ore grade quality (bbls/tonne) |  | 0.62 |  | 0.63 |  | 0.61 |
| Total Oil Sands bitumen production |  | 738.2 |  | 681.6 |  | 597.5 |

Oil Sands operations bitumen production decreased to 498,800 bbls/d in 2018, compared to 518,000 bbls/d in 2017. The decrease was primarily attributed to lower Oil Sands Base mined bitumen production due to lower upgrader availability associated with both planned and unplanned maintenance activities in 2018, partially offset by record production volumes from Firebag and MacKay River as a result of improved reliability.

Syncrude bitumen production increased to 172,000 bbls/d in 2018 from 163,600 bbls/d in 2017, and was impacted by the same factors as production and sales described above.

Price Realizations(1)

Year ended December 31 Net of transportation costs, but before royalties ($/bbl) |  | 2018 |  | 2017 |  | 2016 |  |
Oil Sands operations |  |  |  |  |  |  |  |
| SCO and diesel |  | 68.97 |  | 61.47 |  | 49.75 |  |
| Bitumen |  | 24.70 |  | 33.47 |  | 18.48 |  |
| Crude sales basket (all products) |  | 54.91 |  | 54.26 |  | 40.07 |  |
| Crude sales basket, relative to WTI |  | (29.24 | ) | (11.91 | ) | (17.73 | ) |
Fort Hills bitumen |  | 38.46 |  | — |  | — |  |
Syncrude – sweet SCO |  | 70.19 |  | 66.05 |  | 56.38 |  |
Syncrude, relative to WTI |  | (13.97 | ) | (0.12 | ) | (1.42 | ) |

(1)
  Price realizations for 2017 and 2016 have been restated in accordance with the new IFRS 15 revenue requirements, with no impact to net earnings or operating earnings, as well as the removal of the impact of risk management activities. For further information on the restatements associated with IFRS 15, refer to Note 5 in Suncor's audited Consolidated Financial Statements for the year ended December 31, 2018.

Price realizations for SCO and diesel were positively impacted by the increase in WTI benchmark prices, partially offset by unfavourable SCO and heavy crude differentials in the latter half of 2018 as a result of takeaway constraints in the Alberta market. Average price realizations for Oil Sands operations were $54.91/bbl in 2018, compared to $54.26/bbl in 2017.

Average price realizations for Fort Hills bitumen were $38.46/bbl in 2018 and were higher than In Situ bitumen realizations due to a higher proportion of sales being made in the U.S. mid-continent and the U.S. Gulf Coast, where Suncor is able to utilize its logistics network to access favourable pricing in the U.S. market, combined with the improved quality associated with paraffinic froth-treated bitumen produced at Fort Hills.

Suncor's average price realization for Syncrude sales increased in 2018 to $70.19/bbl, compared to $66.05/bbl in 2017, due to improved WTI benchmark pricing, partially offset by wider SCO differentials, as mentioned above.

Royalties

Royalties were higher in 2018 relative to 2017, primarily due to higher production volumes, partially offset by lower bitumen pricing.

2018 ANNUAL REPORT Suncor Energy Inc. 31

Expenses and Other Factors

Operating expenses for 2018 were higher relative to 2017, primarily due to increased operating and maintenance costs from the addition of Fort Hills, the company's increased working interest in Syncrude acquired early in 2018, and higher planned and unplanned maintenance expenses at Syncrude and Oil Sands operations. See the Cash Operating Costs section below for further details.

Transportation expense was higher in 2018, when compared to 2017, primarily due to the increased sales volumes associated with Fort Hills and the acquisition of the additional ownership interest in Syncrude in 2018.

DD&A expense for 2018 increased when compared to 2017 due to the addition of DD&A at Fort Hills and an increased share of Syncrude DD&A as a result of the additional working interest acquired in 2018.

Cash Operating Costs

Year ended December 31 |  | 2018 |  | 2017 |  | 2016 |  |
Oil Sands operating, selling and general expense (OS&G) |  | 7 570 |  | 6 257 |  | 5 777 |  |
Oil Sands operations cash operating costs(1) reconciliation |  |  |  |  |  |  |  |
| Oil Sands operations OS&G |  | 4 214 |  | 4 062 |  | 4 028 |  |
| Non-production costs(2) |  | (93 | ) | (102 | ) | (136 | ) |
| Excess power capacity and other(3) |  | (237 | ) | (232 | ) | (197 | ) |
| Inventory changes |  | (14 | ) | 1 |  | (63 | ) |
Oil Sands operations cash operating costs(1) ($ millions) |  | 3 870 |  | 3 729 |  | 3 632 |  |
Oil Sands operations cash operating costs(1) ($/bbl) |  | 25.25 |  | 23.80 |  | 26.50 |  |
Fort Hills cash operating costs(1) reconciliation |  |  |  |  |  |  |  |
| Fort Hills OS&G |  | 832 |  | — |  | — |  |
| Non-production costs(2) |  | (120 | ) | — |  | — |  |
| Inventory changes |  | 55 |  | — |  | — |  |
Fort Hills cash operating costs(1) ($ millions) |  | 767 |  | — |  | — |  |
Fort Hills cash operating costs(1) ($/bbl) |  | 31.20 |  | — |  | — |  |
Syncrude cash operating costs(1) reconciliation |  |  |  |  |  |  |  |
| Syncrude OS&G |  | 2 523 |  | 2 195 |  | 1 749 |  |
| Non-production costs(2) |  | (33 | ) | (37 | ) | (31 | ) |
Syncrude cash operating costs(1) ($ millions) |  | 2 490 |  | 2 158 |  | 1 718 |  |
Syncrude cash operating costs(1) ($/bbl) |  | 47.25 |  | 44.05 |  | 35.95 |  |

(1)
  Non-GAAP financial measures. See the Advisories – Non-GAAP Financial Measures section of this MD&A.
(2)
  Significant non-production costs include, but are not limited to, share-based compensation expense and research expenses. Non-production costs at Fort Hills also include, but are not limited to, project start-up costs, excess power revenue from cogeneration units and an adjustment to reflect internally produced diesel from Oil Sands operations at the cost of production.
(3)
  Excess power capacity and other includes, but is not limited to, the operational revenue impacts of excess power from cogeneration units and 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) averaged $25.25 in 2018, compared to $23.80 in 2017. The increase was due to higher maintenance costs associated with a planned Upgrader 1 turnaround in the spring and major maintenance at Upgrader 2 in the fall, as well as

(1)
  Non-GAAP financial measures. See the Advisories – Non-GAAP Financial Measures section of this MD&A.

32 2018 ANNUAL REPORT Suncor Energy Inc.

unplanned upgrader maintenance, partially offset by lower natural gas prices. Total Oil Sands operations cash operating costs increased to $3.870 billion from $3.729 billion in the prior year as a result of the factors described above, as well as the operating costs associated with a draw of inventory in 2018, compared to a build of inventory in the prior year.

In 2018, non-production costs, which are excluded from Oil Sands operations cash operating costs, were lower than the prior year, primarily due to a decrease in share-based compensation expense attributed to a decrease in the company's share price in the current year, as opposed to a share price increase in 2017.

Fort Hills cash operating costs per barrel(1) averaged $31.20 in 2018, reflecting the impact of the production ramp up throughout the year. Non-production costs at Fort Hills were $120 million and included commissioning and start-up costs, in addition to excess power capacity.

Syncrude cash operating costs per barrel(1) increased to $47.25 in 2018, compared to $44.05 in the previous year, primarily as a result of the increase in operating costs associated with planned and unplanned maintenance. Suncor's share of total Syncrude cash operating costs increased to $2.490 billion from $2.158 billion in 2017, with the increase primarily attributed to the increased working interest in the project acquired early in 2018, in addition to higher maintenance costs.

Planned Maintenance

Planned Upgrader 1 maintenance at Oil Sands Base and turnaround events at Firebag and Fort Hills are scheduled for the second quarter of 2019. Coker maintenance at Syncrude and maintenance events at Upgrader 2 are scheduled for the third quarter of 2019, extending into the fourth quarter of 2019, and Fort Hills expects to complete planned maintenance in the fourth quarter of 2019. The anticipated impact of these maintenance events has been reflected in the company's 2019 guidance.

EXPLORATION AND PRODUCTION

2018 Highlights

•
  After achieving first oil ahead of schedule in the fourth quarter of 2017, the Hebron project continued to ramp up throughout 2018 and delivered average production of 13,000 bbls/d, net to Suncor.
•
  Several strategic investments were completed throughout the year, including the acquisition of an additional 10% working interest in the Rosebank future development project, bringing the company's participating interest in the project to 40%, and the acquisition of a 17.5% working interest in the Fenja project offshore Norway.
•
  During 2018, the company and its partners sanctioned the Buzzard Phase 2 project, with first oil expected in early 2021.
•
  The company continued to advance development work at the Oda project offshore Norway, with first oil expected in the second quarter of 2019.

Strategy and Investment Update

The Exploration and Production segment delivers geographically diversified cash flows and focuses primarily on low-cost projects that deliver significant returns, cash flow and long-term value.

The company has ongoing development activities offshore the east coast of Canada and in the U.K. North Sea, intended to leverage existing facilities and infrastructure to provide incremental production and extend the productive life of existing fields. These activities are planned to continue in 2019, along with development drilling at Hebron as part of the continued ramp up phase, in addition to development work on the West White Rose Project, Buzzard Phase 2, the Oda project and the Fenja project. First oil from the Oda project is expected in the second quarter of 2019.

Subsequent to the end of 2018, the company received $300 million in risk mitigation proceeds for its Libyan assets (approximately $260 million after-tax). The proceeds may be subject to a provisional repayment which is dependent on the future performance and cash flows from Suncor's Libyan assets.

(1)
  Non-GAAP financial measures. See the Advisories – Non-GAAP Financial Measures section of this MD&A.

2018 ANNUAL REPORT Suncor Energy Inc. 33

Financial Highlights

Year ended December 31 ($ millions) |  | 2018 |  | 2017 |  | 2016 |  |
Gross revenues(1) |  | 3 474 |  | 3 177 |  | 2 432 |  |
Less: Royalties |  | (257 | ) | (266 | ) | (201 | ) |
Operating revenues, net of royalties |  | 3 217 |  | 2 911 |  | 2 231 |  |
Net earnings |  | 808 |  | 732 |  | 190 |  |
Adjusted for: |  |  |  |  |  |  |  |
| Non-cash loss on equity investment(2) |  | 90 |  | — |  | — |  |
| Impact of income tax rate adjustments on deferred income taxes |  | — |  | 14 |  | (180 | ) |
Operating earnings(3) |  | 898 |  | 746 |  | 10 |  |
Funds from operations(3) |  | 1 869 |  | 1 725 |  | 1 313 |  |

(1)
  Production, revenues and royalties from the company's Libya operations have been presented in the E&P section of this document on an entitlement basis and exclude an equal and offsetting gross up of revenues and royalties, which is required for presentation purposes in the company's financial statements under the working-interest basis.
(2)
  In 2018, the company recorded a net non-cash loss of $90 million, after-tax, in the E&P segment related to an asset exchange with Canbriam.
(3)
  Non-GAAP financial measures. See the Advisories – Non-GAAP Financial Measures section of this MD&A.

Bridge Analysis of Operating Earnings ($ millions)(1)

(1)
  For an explanation of the construction of this bridge analysis, see the Advisories – Non-GAAP Financial Measures section of this MD&A.

Operating earnings were $898 million for E&P in 2018, compared to $746 million in the prior year. The improvement is primarily due to increased price realizations, consistent with higher Brent crude benchmarks, lower DD&A and exploration charges, partially offset by a decrease in sales volumes and increased operating expenses.

Net earnings were $808 million for E&P in 2018, compared to $732 million in 2017, and were impacted by the same factors as operating earnings described above. In addition, 2018 net earnings included a $90 million non-cash loss on an asset exchange with Canbriam, while 2017 net earnings were impacted by a $14 million charge associated with a change in the U.S. corporate tax rate.

Funds from operations were $1.869 billion in 2018, compared to $1.725 billion in 2017. The increase was largely due to the same factors that impacted operating earnings above, adjusted for the impact of non-cash DD&A.

34 2018 ANNUAL REPORT Suncor Energy Inc.

Production Volumes

Year ended December 31 |  | 2018 |  | 2017 |  | 2016 |
E&P Canada |  |  |  |  |  |  |
| Terra Nova (mbbls/d) |  | 11.7 |  | 11.5 |  | 12.4 |
| Hibernia (mbbls/d) |  | 22.1 |  | 28.5 |  | 26.8 |
| White Rose (mbbls/d) |  | 6.6 |  | 11.4 |  | 10.9 |
| Hebron (mbbls/d) |  | 13.0 |  | 0.4 |  | — |
| North America Onshore (mboe/d) |  | 0.5 |  | 1.9 |  | 2.8 |
|  | 53.9 |  | 53.7 |  | 52.9 |
E&P International |  |  |  |  |  |  |
| Buzzard (mboe/d) |  | 34.2 |  | 43.8 |  | 46.0 |
| Golden Eagle (mboe/d) |  | 12.4 |  | 19.6 |  | 18.6 |
| United Kingdom (mboe/d) |  | 46.6 |  | 63.4 |  | 64.6 |
| Libya (mbbls/d)(1) |  | 2.9 |  | 4.5 |  | 0.4 |
|  | 49.5 |  | 67.9 |  | 65.0 |
| Total Production (mboe/d) |  | 103.4 |  | 121.6 |  | 117.9 |
| Production Mix (liquids/gas) (%) |  | 99/1 |  | 97/3 |  | 96/4 |
| Total Sales Volumes (mboe/d) |  | 102.8 |  | 120.8 |  | 119.3 |

(1)
  Effective in 2016, production volumes for Libya are presented on an entitlement basis.

E&P Canada production volumes averaged 53,900 boe/d in 2018, compared to 53,700 boe/d in 2017, with production from Hebron and development drilling at existing facilities offsetting the impact of a major storm system at the end of 2018, natural declines, and planned and unplanned maintenance events throughout 2018. Production at the White Rose field was shut in from mid-November to late January 2019 due to unplanned maintenance. The return to normal production rates is expected to occur in a phased approach.

Production volumes in the U.K. decreased to 46,600 boe/d from 63,400 boe/d as a result of natural declines at both Golden Eagle and Buzzard, in addition to an increase in planned and unplanned maintenance at Buzzard in 2018.

Price Realizations

Year ended December 31 Net of transportation costs, but before royalties |  | 2018 |  | 2017 |  | 2016 |
Exploration and Production |  |  |  |  |  |  |
| E&P Canada – Crude oil and natural gas liquids ($/bbl) |  | 87.82 |  | 69.14 |  | 57.37 |
| E&P Canada – Natural gas ($/mcf) |  | 1.94 |  | 1.77 |  | 1.71 |
| E&P International ($/boe) |  | 86.77 |  | 65.46 |  | 52.07 |
E&P average price ($/boe) |  | 86.96 |  | 66.20 |  | 53.34 |

Average price realizations from E&P Canada and E&P International in 2018 were higher than 2017, consistent with the increase in benchmark prices for Brent crude in 2018.

Expenses and Other Factors

Operating expenses were higher in 2018, compared to 2017, primarily due to the addition of Hebron operating costs and an increase in maintenance expense.

DD&A and exploration expenses decreased in 2018, compared to the prior year, with decreased production in the U.K., White Rose and Hibernia more than offsetting additional DD&A from Hebron.

Planned Maintenance of Operated Assets

A planned two-week maintenance event at Terra Nova is scheduled to commence in the second quarter of 2019. The anticipated impact of this maintenance has been reflected in the company's 2019 guidance.

2018 ANNUAL REPORT Suncor Energy Inc. 35

REFINING AND MARKETING

2018 Highlights

•
  The Refining and Marketing segment achieved record financial results in 2018, with $3.153 billion in net and operating earnings and $3.794 billion of funds from operations, despite completing the most significant maintenance program in the company's history.
•
  R&M continues to be a key component of the company's integrated business model, allowing Suncor to significantly offset the impact of wider crude differentials in the Oil Sands segment in 2018 through increased refining margins by processing a crude slate comprising approximately 52% of SCO and diluted bitumen.
•
  Refined products sales were 527,400 bbls/d, with record Canadian wholesale sales achieved in 2018, reflecting continued strong product demand.

Strategy and Investment Update

The Refining and Marketing network serves to maximize Suncor's integrated returns by extending the value chain from oil sands production to the end customer and is a key component of the integrated business model. The company aims to operate its refineries at optimal levels of utilization to provide reliable offtake and secure pricing for a portion of the production from the Oil Sands segment.

Suncor continued to grow retail market share in Canada through its Petro-Canada® branded-network. In 2018, Suncor leveraged its strong Petro-Canada® brand through a nationwide campaign to increase sales volumes and non-petroleum revenues through the company's network of convenience stores and car washes, and will continue these efforts in 2019.

Financial Highlights

Year ended December 31 ($ millions) |  | 2018 |  | 2017 |  | 2016 |
Operating revenues |  | 23 724 |  | 19 704 |  | 17 260 |
Net earnings |  | 3 153 |  | 2 658 |  | 1 890 |
Adjusted for: |  |  |  |  |  |  |
| Impact of income tax rate adjustments on deferred taxes |  | — |  | (140 | ) | — |
| Gain on significant disposal |  | — |  | (354 | ) | — |
Operating earnings(1) |  | 3 153 |  | 2 164 |  | 1 890 |
Funds from operations(1) |  | 3 794 |  | 2 841 |  | 2 606 |

(1)
  Non-GAAP financial measures. See the Advisories – Non-GAAP Financial Measures section of this MD&A.

Bridge Analysis of Operating Earnings ($ millions)(1)

(1)
  For an explanation of the construction of this bridge analysis, see the Advisories – Non-GAAP Financial Measures section of this MD&A.

36 2018 ANNUAL REPORT Suncor Energy Inc.

R&M contributed record annual operating earnings of $3.153 billion in 2018, compared with $2.164 billion in 2017. The increase was due to improved refining margins resulting from wider crude differentials, favourable product location differentials, and improved benchmark crack spreads, partially offset by a FIFO loss and lower crude throughput due to an increase in planned maintenance.

Net earnings in 2018 were $3.153 billion, compared to net earnings of $2.658 billion in 2017, and were impacted by the same factors as operating earnings described above. 2017 net earnings also included a $354 million gain related to the sale of the company's lubricants business, and a $140 million deferred tax recovery related to changes in the U.S. corporate tax rate from 35% to 21%.

The FIFO loss was a result of the significant decline in crude oil and refined product benchmarks near the end of 2018 and was partially offset by a realization of intersegment profit associated with the consumption of internal crude feedstock from the company's Oil Sands assets, for a net inventory valuation loss of $216 million in the year. In addition, the favourable impact of wider crude differentials on refining margins partially offset the decrease in Oil Sands bitumen price realizations.

Funds from operations were also an annual record of $3.794 billion in 2018, compared to $2.841 billion in 2017, due primarily to the same factors that impacted operating earnings described above.

Volumes

Year ended December 31 |  | 2018 |  | 2017 |  | 2016 |
Crude oil processed (mbbls/d) |  |  |  |  |  |  |
| Eastern North America |  | 208.1 |  | 206.4 |  | 203.1 |
| Western North America |  | 222.7 |  | 234.8 |  | 225.5 |
Total |  | 430.8 |  | 441.2 |  | 428.6 |
Refinery utilization(1) (%) |  |  |  |  |  |  |
| Eastern North America |  | 94 |  | 93 |  | 92 |
| Western North America |  | 93 |  | 98 |  | 94 |
Total |  | 93 |  | 96 |  | 93 |
Refined Product Sales (mbbls/d) |  |  |  |  |  |  |
| Gasoline |  | 245.6 |  | 242.9 |  | 244.3 |
| Distillate |  | 203.4 |  | 199.3 |  | 186.1 |
| Other |  | 78.4 |  | 88.3 |  | 91.0 |
Total |  | 527.4 |  | 530.5 |  | 521.4 |
| Refining margin(2) ($/bbl) |  | 34.50 |  | 24.20 |  | 20.45 |
| Refining operating expense(2) ($/bbl) |  | 5.35 |  | 5.05 |  | 5.10 |

(1)
  Refinery utilization is the amount of crude oil and natural gas plant liquids run through crude distillation units, expressed as a percentage of the capacity of these units.
(2)
  Non-GAAP financial measures. See the Advisories – Non-GAAP Financial Measures section of this MD&A.

Refinery utilization averaged 93% in 2018, compared with 96% in 2017. The decrease in utilization was primarily due to an increase in planned maintenance in 2018 compared to 2017, with the Edmonton refinery undergoing its first full plant turnaround in its history, in addition to planned maintenance events at Montreal, Sarnia and Commerce City. The company was able to partially mitigate the impact of the planned maintenance that occurred during the second quarter of 2018 with the sale of inventory that had been strategically built up earlier in the year.

Total refined products sales in 2018 were comparable to 2017, reflecting continued strong product demand and record wholesale volumes in Canada.

Prices and Margins

Refining and Product Supply prices and margins were higher in 2018 compared to 2017, and were impacted primarily by the following factors:

•
  An overall favourable business environment, driven by wider crude differentials, improved product location differentials and higher benchmark distillate crack spreads, partially offset by lower gasoline crack spreads.
•
  In 2018, the impact of FIFO inventory accounting, as used by the company, relative to an estimated LIFO(1) basis of accounting, had a negative impact on refining margins and net income of approximately $468 million after-tax, compared to a positive impact of $157 million after-tax in 2017, for an unfavourable year-over-year impact of $625 million.

Marketing gross margins in 2018 were higher than in the prior year, primarily due to an increase in wholesale sales as well as stronger wholesale unit margins.

Expenses and Other Factors

Operating and transportation expenses were higher in 2018 compared to 2017, primarily due to an increase in refinery maintenance costs, partially offset by lower natural gas input prices.

Planned Maintenance

A less intensive maintenance program is planned in 2019 following the completion of significant turnaround events in 2018. Planned maintenance events in 2019 are focused only on certain units within each of the refineries and include a two-week turnaround at the Commerce City refinery scheduled in the first quarter, an eight-week turnaround at the Sarnia refinery and a six-week turnaround at the Montreal refinery, both scheduled to begin in the second quarter of 2019. The Edmonton refinery has a planned six-week turnaround scheduled to begin in the third quarter and extend into the fourth quarter of 2019. The estimated impact of these maintenance events has been reflected in the company's 2019 guidance.

(1)
  The LIFO inventory valuation methodology is a non-GAAP financial measure. See the Advisories – Non GAAP Financial Measures section of this MD&A.

2018 ANNUAL REPORT Suncor Energy Inc. 37

CORPORATE, ENERGY TRADING AND ELIMINATIONS

2018 Highlights

•
  The company returned $2.333 billion to shareholders through dividends in 2018, a 12.5% increase in the dividend per share over the prior year. 2018 was the 16th consecutive year of annual dividend increases for the company.
•
  The company repurchased $3.053 billion of its own shares for cancellation during 2018, compared to $1.413 billion in 2017.
•
  The company completed an early retirement of US$83 million in long-term debt originally due in 2019.
•
  Subsequent to the end of the year, Suncor's Board of Directors approved a quarterly dividend of $0.42 per share to be paid in the first quarter of 2019, an increase of 17%, and also approved a further share repurchase program of up to $2.0 billion.

Strategy and Investment Update

The Energy Trading business supports the company by securing market access, optimizing price realizations, managing inventory levels and limiting the impacts of external market factors, such as pipeline disruptions, lack of egress or outages at refining customers, while generating trading earnings through established strategies. The Energy Trading business continues to evaluate additional transportation and storage agreements to maximize crude price realizations and is developing an asset backed trading program to realize incremental value from market dislocations and arbitrage opportunities impacting Suncor's producing assets.

Returning value to shareholders continues to be a top priority for Suncor, as demonstrated by the company's history of dividend increases and commitment to its share repurchase program. Since reinstating the share repurchase program in 2017, the company has completed $4.818 billion in share repurchases as of February 25, 2019 and the Board of Directors has approved up to a further $2.0 billion in share repurchases, reinforcing the company's belief in its ongoing ability to generate cash flow and its commitment to return cash to shareholders.

Financial Highlights

Year ended December 31 ($ millions) |  | 2018 |  | 2017 |  | 2016 |  |
Net (loss) earnings |  | (1 521 | ) | 59 |  | (486 | ) |
Adjusted for: |  |  |  |  |  |  |  |
Unrealized foreign exchange loss (gain) on U.S. dollar denominated debt |  | 989 |  | (702 | ) | (524 | ) |
Loss (gain) on interest rate swaps |  | — |  | 20 |  | (6 | ) |
Non-cash loss on early payment of long-term debt |  | — |  | 28 |  | 73 |  |
Gain on significant disposal |  | — |  | (83 | ) | — |  |
Impact of income tax rate adjustments on deferred income taxes |  | — |  | 2 |  | — |  |
Derecognition and impairments |  | — |  | — |  | 31 |  |
COS acquisition and related costs |  | — |  | — |  | 38 |  |
Operating (loss) earnings(1) |  | (532 | ) | (676 | ) | (874 | ) |
| Renewable Energy |  | — |  | (4 | ) | 38 |  |
| Energy Trading |  | 92 |  | (62 | ) | 4 |  |
| Corporate |  | (876 | ) | (528 | ) | (864 | ) |
| Eliminations – Intersegment profit realized (eliminated) |  | 252 |  | (82 | ) | (52 | ) |
Funds used in operations(1) |  | (361 | ) | (165 | ) | (600 | ) |

(1)
  Non-GAAP financial measures. See the Advisories – Non-GAAP Financial Measures section of this MD&A.

38 2018 ANNUAL REPORT Suncor Energy Inc.

Renewable Energy

Year ended December 31 |  | 2018 |  | 2017 |  | 2016 |
Power generation marketed (gigawatt hours)(1) |  | 183 |  | 255 |  | 478 |

(1)
  Power generated includes curtailed production for which the company was compensated.

Suncor's Renewable Energy assets realized nil operating earnings during the year, compared to an operating loss of $4 million in 2017. The improvement was primarily due to higher power prices.

Energy Trading

Energy Trading activities reported operating earnings of $92 million in 2018, compared to an operating loss of $62 million in 2017. The increase was primarily due to improved crude location spreads in the current year.

Corporate

Corporate incurred an operating loss of $876 million in 2018, compared with an operating loss of $528 million in 2017. The increased loss was primarily due to a decrease in the amount of capitalized interest, partially offset by a decrease in share-based compensation expense, a larger operational foreign exchange gain compared to 2017 and lower interest expense as a result of a lower amount of outstanding debt. Suncor capitalized $156 million of its borrowing costs in 2018 as part of the cost of major development assets and construction projects in progress, compared to $729 million in the prior year. The decrease was driven by the commissioning of Fort Hills in early 2018 and the completion of the Hebron project in late 2017.

Eliminations – Intersegment profit realized (eliminated)

Eliminations reflect the deferral or realization of profit on crude oil sales from Oil Sands and East Coast Canada to Refining and Marketing. Consolidated profits are only realized when the company sells the products produced from intersegment purchases of crude feedstock to third parties. In 2018, the company realized $252 million of after-tax intersegment profit, compared to an elimination of profit of $82 million in the prior year. This combined with the FIFO loss in the R&M segment resulted in a net $216 million after-tax inventory valuation loss in 2018. The change year-over-year was primarily due to the decrease in Oil Sands crude margins towards the end of 2018, as higher margin crude feedstock inventory sourced internally from Oil Sands was sold and replaced by lower margin crude feedstock inventory, resulting in a net release of profit at the enterprise level.

2018 ANNUAL REPORT Suncor Energy Inc. 39

5. FOURTH QUARTER 2018 ANALYSIS

Financial and Operational Highlights

Year ended December 31 ($ millions, except as noted) |  | 2018 |  | 2017 |  |
Net (loss) earnings |  |  |  |  |  |
| Oil Sands |  | (393 | ) | 670 |  |
| Exploration and Production |  | (115 | ) | 217 |  |
| Refining and Marketing |  | 723 |  | 886 |  |
| Corporate, Energy Trading and Eliminations |  | (495 | ) | (391 | ) |
Total |  | (280 | ) | 1 382 |  |
Operating earnings (loss)(1) |  |  |  |  |  |
| Oil Sands |  | (393 | ) | 615 |  |
| Exploration and Production |  | 108 |  | 231 |  |
| Refining and Marketing |  | 723 |  | 746 |  |
| Corporate, Energy Trading and Eliminations |  | 142 |  | (282 | ) |
Total |  | 580 |  | 1 310 |  |
Funds from (used in) operations(1) |  |  |  |  |  |
| Oil Sands |  | 601 |  | 1 780 |  |
| Exploration and Production |  | 367 |  | 431 |  |
| Refining and Marketing |  | 826 |  | 935 |  |
| Corporate, Energy Trading and Eliminations |  | 213 |  | (130 | ) |
Total funds from operations |  | 2 007 |  | 3 016 |  |
| Changes in non-cash working capital |  | 1 033 |  | (261 | ) |
Cash flow provided by operating activities |  | 3 040 |  | 2 755 |  |
Production volumes (mboe/d) |  |  |  |  |  |
| Oil Sands |  | 740.8 |  | 621.2 |  |
| Exploration and Production |  | 90.2 |  | 115.2 |  |
Total |  | 831.0 |  | 736.4 |  |

(1)
  Non-GAAP financial measures. See the Advisories – Non-GAAP Financial Measures section of this MD&A.

Net Earnings (Loss)

Suncor had a consolidated net loss for the fourth quarter of 2018 of $280 million, compared to net earnings of $1.382 billion for the prior year quarter. Net earnings were primarily affected by the same factors that influenced operating earnings described subsequently in this section of this document. Other items affecting net earnings (loss) over these periods included:

•
  The after-tax unrealized foreign exchange impact on the revaluation of U.S. dollar denominated debt was a loss of $637 million for the fourth quarter of 2018, compared to a loss of $91 million for the fourth quarter of 2017.
•
  The fourth quarter of 2018 included a $223 million after-tax impairment charge in the E&P segment associated with the company's equity investment in Canbriam.
•
  In the fourth quarter of 2017, Suncor recognized a net $124 million deferred income tax recovery related to a decrease in the U.S. corporate tax rate from 35% to 21%, including a $140 million recovery in the R&M segment, offset by a $14 million expense in the E&P segment and a $2 million expense in the Corporate segment.
•
  In the fourth quarter of 2017, the company received after-tax proceeds of $55 million for property damage insurance related to the facility incident at Syncrude that occurred in the first quarter of 2017, in the Oil Sands segment.
•
  In the fourth quarter of 2017, the company recorded an after-tax loss of $18 million for early payment of debt, in the Corporate segment.
•
  In the fourth quarter of 2017, the company recognized an after-tax gain on forward interest rate swaps associated with issued debt of $2 million in the Corporate segment due to changes in long-term interest rates.

Cash Flow provided by Operating Activities and Funds from Operations

Funds from operations were $2.007 billion in the fourth quarter of 2018, compared to $3.016 billion in the fourth quarter of 2017, and were influenced by the same factors impacting operating earnings described in the Segmented Analysis below, excluding the recovery of non-cash share-based compensation, as well as unrealized gains on crude optimization activities.

Cash flow provided by operating activities, which includes changes in non-cash working capital, was $3.040 billion in the fourth quarter of 2018, compared to $2.755 billion in the fourth quarter of 2017, and was influenced by the same factors impacting operating earnings noted below, excluding the recovery of non-cash share-based compensation, as well as unrealized gains on crude optimization activities.

Segmented Analysis

Oil Sands

The Oil Sands segment had an operating loss of $393 million in the fourth quarter of 2018, compared to operating earnings of $615 million in the prior year quarter. The decrease was due to lower crude price realizations across all product lines, higher operating costs with the addition of Fort Hills production, as well as lower sales of SCO from Oil Sands operations due to planned and unplanned

40 2018 ANNUAL REPORT Suncor Energy Inc.

maintenance at Upgrader 2. These factors were partially offset by an increase in overall sales volumes.

Oil Sands operations production was 432,700 bbls/d in the fourth quarter of 2018, compared to 446,800 bbls/d in the prior year quarter. The decrease was primarily due to the completion of planned maintenance at Upgrader 2 early in the fourth quarter of 2018 and unplanned maintenance at Upgrader 2, which occurred late in the fourth quarter of 2018 and was resolved prior to the end of the quarter, partially offset by an associated increase in non-upgraded bitumen production. Upgrader utilization was 79% in the fourth quarter of 2018, compared to 93% in the prior year period.

Fort Hills exceeded target production rates with a utilization rate of 94% for the fourth quarter of 2018 and production of 98,500 bbls/d of bitumen net to Suncor.

Sales volumes for Oil Sands operations were 460,500 bbls/d in the fourth quarter of 2018, compared to 461,700 bbls/d in the prior year quarter, with an inventory draw in both non-upgraded bitumen and SCO offsetting the decline in overall production.

Bitumen sales at Fort Hills averaged 94,600 bbls/d, net to Suncor, in the fourth quarter of 2018, reflecting a small build of inventory as increased sales were transported to customers extending to the U.S. Gulf Coast.

Suncor's share of Syncrude production and sales was 209,600 bbls/d in the fourth quarter of 2018, compared to 174,400 bbls/d in the prior year quarter. The increase was primarily due to stronger reliability at Syncrude, with 101% utilization achieved in the period, in addition to the acquisition of an additional 5% working interest in Syncrude in the first quarter of 2018.

Exploration and Production

Operating earnings for the E&P segment in the fourth quarter of 2018 decreased to $108 million, from $231 million in the prior year quarter, as a result of lower overall production and an increase in operating expenses, primarily associated with the ramp up of Hebron, partially offset by lower royalties.

Production volumes for E&P Canada were 47,900 boe/d in the fourth quarter of 2018, compared to 55,500 boe/d in the prior year quarter. The decrease in production was due to a temporary production interruption at the company's East Coast Canada assets as a result of a major storm system during the quarter, in addition to natural declines, partially offset by the addition of production from Hebron, which averaged 15,700 bbls/d, net to the company. Production at the White Rose field was shut in from mid-November 2018 to late January 2019 due to operational complications, with partial production restarting at the end of January 2019.

E&P International production decreased to 42,300 boe/d in the fourth quarter of 2018, from 59,700 boe/d in the prior year quarter, primarily due to natural declines in the U.K. and an unplanned outage at Buzzard, which was resolved by the end of the fourth quarter.

E&P sales volumes decreased to 83,100 boe/d in the fourth quarter of 2018, compared to 104,800 boe/d in the prior year quarter, due to the decrease in production, as well as a larger inventory build at East Coast Canada associated with the timing of cargo sales.

Refining and Marketing

R&M operating earnings in the fourth quarter of 2018 were $723 million, compared to $746 million in the prior year quarter. The decrease was due to a FIFO loss associated with the significant decline in crude and refined product benchmarks during the quarter, partially offset by improved refining margins, primarily attributed to wider crude differentials, as well as record crude throughput.

At the company level, the FIFO loss was partially offset by a realization of intersegment profit associated with the consumption of internal crude feedstock from the company's Oil Sands assets. The favourable impact of wider crude differentials partially offset the decrease in Oil Sands price realizations.

Refinery crude throughput of 467,900 bbls/d in the fourth quarter of 2018 represents a new quarterly record, compared to 432,400 bbls/d in the prior year quarter, in which the Montreal refinery was impacted by a third-party power outage. Reliability at all of the company's refineries was strong in the fourth quarter of 2018, resulting in a utilization rate of 101%, compared to 94% in the prior year quarter.

Total refined products sales of 530,600 bbls/d in the fourth quarter of 2018 were comparable to 526,800 bbls/d in the prior year quarter, reflecting higher refinery crude throughput and strong product demand.

Corporate, Energy Trading and Eliminations

Corporate, Energy Trading and Eliminations had operating earnings of $142 million in the fourth quarter of 2018, compared to an operating loss of $282 million in the fourth quarter of 2017. The increase was due primarily to higher intersegment profit realizations, lower share-based compensation expense for the quarter, favourable trading results in the Energy Trading business, due to stronger crude location spreads, interest savings as a result of early debt repayment and higher Renewable Energy earnings as a result of higher power prices, partially offset by a significant decrease in capitalized interest during the quarter. Suncor capitalized $28 million of its borrowing costs in the fourth quarter of 2018 as part of the cost of major development assets and construction projects in progress, compared to $177 million in the prior year quarter, mainly as a result of the commissioning of the Fort Hills project early in 2018.

2018 ANNUAL REPORT Suncor Energy Inc. 41

6. QUARTERLY FINANCIAL DATA

Financial Summary

Three months ended ($ millions, unless otherwise noted) |  | Dec 31 2018 |  | Sept 30 2018 |  | June 30 2018 |  | Mar 31 2018 |  | Dec 31 2017 |  | Sept 30 2017 |  | June 30 2017 |  | Mar 31 2017 |
Total production (mboe/d) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
| Oil Sands |  | 740.8 |  | 651.7 |  | 547.6 |  | 571.7 |  | 621.2 |  | 628.4 |  | 413.6 |  | 590.6 |
| Exploration and Production |  | 90.2 |  | 92.1 |  | 114.1 |  | 117.7 |  | 115.2 |  | 111.5 |  | 125.5 |  | 134.5 |
|  | 831.0 |  | 743.8 |  | 661.7 |  | 689.4 |  | 736.4 |  | 739.9 |  | 539.1 |  | 725.1 |
Revenues and other income |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
| Operating revenues, net of royalties |  | 8 561 |  | 10 847 |  | 10 327 |  | 8 807 |  | 8 973 |  | 7 963 |  | 7 231 |  | 7 787 |
| Other income |  | 384 |  | 16 |  | 101 |  | (57 | ) | 41 |  | 43 |  | 16 |  | 25 |
|  | 8 945 |  | 10 863 |  | 10 428 |  | 8 750 |  | 9 014 |  | 8 006 |  | 7 247 |  | 7 812 |
Net (loss) earnings |  | (280 | ) | 1 812 |  | 972 |  | 789 |  | 1 382 |  | 1 289 |  | 435 |  | 1 352 |
| per common share – basic (dollars) |  | (0.18 | ) | 1.12 |  | 0.60 |  | 0.48 |  | 0.84 |  | 0.78 |  | 0.26 |  | 0.81 |
| per common share – diluted (dollars) |  | (0.18 | ) | 1.11 |  | 0.59 |  | 0.48 |  | 0.84 |  | 0.78 |  | 0.26 |  | 0.81 |
Operating earnings(1) |  | 580 |  | 1 557 |  | 1 190 |  | 985 |  | 1 310 |  | 867 |  | 199 |  | 812 |
| per common share – basic(1) (dollars) |  | 0.36 |  | 0.96 |  | 0.73 |  | 0.60 |  | 0.79 |  | 0.52 |  | 0.12 |  | 0.49 |
Funds from operations(1) |  | 2 007 |  | 3 139 |  | 2 862 |  | 2 164 |  | 3 016 |  | 2 472 |  | 1 627 |  | 2 024 |
| per common share – basic(1) (dollars) |  | 1.26 |  | 1.94 |  | 1.75 |  | 1.32 |  | 1.83 |  | 1.49 |  | 0.98 |  | 1.21 |
Cash flow provided by operating activities |  | 3 040 |  | 4 370 |  | 2 446 |  | 724 |  | 2 755 |  | 2 912 |  | 1 671 |  | 1 628 |
| per common share – basic (dollars) |  | 1.90 |  | 2.70 |  | 1.50 |  | 0.44 |  | 1.67 |  | 1.75 |  | 1.00 |  | 0.98 |
ROCE(1) (%) for the twelve months ended |  | 8.0 |  | 9.7 |  | 8.3 |  | 6.5 |  | 6.7 |  | 5.5 |  | 4.9 |  | 3.5 |
ROCE(1) (%) excluding major projects in progress for the twelve months ended |  | 8.2 |  | 10.4 |  | 9.5 |  | 7.8 |  | 8.6 |  | 7.0 |  | 6.2 |  | 4.4 |
After-tax unrealized foreign exchange (loss) gain on U.S. dollar denominated debt |  | (637 | ) | 195 |  | (218 | ) | (329 | ) | (91 | ) | 412 |  | 278 |  | 103 |
Common share information (dollars) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
| Dividend per common share |  | 0.36 |  | 0.36 |  | 0.36 |  | 0.36 |  | 0.32 |  | 0.32 |  | 0.32 |  | 0.32 |
| Share price at the end of trading |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
|  | Toronto Stock Exchange (Cdn$) |  | 38.13 |  | 49.98 |  | 53.50 |  | 44.49 |  | 46.15 |  | 43.73 |  | 37.89 |  | 40.83 |
|  | New York Stock Exchange (US$) |  | 27.97 |  | 38.69 |  | 40.68 |  | 34.54 |  | 36.72 |  | 35.05 |  | 29.20 |  | 30.75 |

(1)
  Non-GAAP financial measures. See the Advisories – Non-GAAP Financial Measures section of this MD&A. ROCE excludes capitalized costs related to major projects in progress. Operating earnings (loss) for each quarter are defined in the Non-GAAP Financial Measures Advisory section and reconciled to GAAP measures in the Consolidated Financial Information and Segment Results and Analysis sections of each quarterly Report to Shareholders issued by Suncor (Quarterly Reports) in respect of the relevant quarter. Funds from operations and ROCE for each quarter are defined and reconciled to GAAP measures in the Non-GAAP Financial Measures Advisory section of each Quarterly Report issued by Suncor in respect of the relevant quarter.

42 2018 ANNUAL REPORT Suncor Energy Inc.

Business Environment

Three months ended (average for the period ended, except as noted) |  | Dec 31 2018 |  | Sept 30 2018 |  | June 30 2018 |  | Mar 31 2018 |  | Dec 31 2017 |  | Sept 30 2017 |  | June 30 2017 |  | Mar 31 2017 |
WTI crude oil at Cushing |  | US$/bbl |  | 58.85 |  | 69.50 |  | 67.90 |  | 62.90 |  | 55.40 |  | 48.20 |  | 48.30 |  | 51.85 |
Dated Brent crude |  | US$/bbl |  | 67.80 |  | 75.25 |  | 74.40 |  | 66.80 |  | 61.40 |  | 52.50 |  | 49.85 |  | 53.75 |
Dated Brent/Maya FOB price differential |  | US$/bbl |  | 4.35 |  | 10.20 |  | 12.40 |  | 7.70 |  | 9.60 |  | 6.30 |  | 5.80 |  | 9.05 |
MSW at Edmonton |  | Cdn$/bbl |  | 42.70 |  | 82.10 |  | 80.95 |  | 72.45 |  | 69.30 |  | 57.05 |  | 62.30 |  | 64.25 |
WCS at Hardisty |  | US$/bbl |  | 19.50 |  | 47.35 |  | 48.65 |  | 38.60 |  | 43.10 |  | 38.25 |  | 37.20 |  | 37.30 |
Light/heavy crude oil differential for WTI at Cushing less WCS at Hardisty |  | US$/bbl |  | 39.35 |  | 22.15 |  | 19.25 |  | 24.30 |  | 12.30 |  | 9.95 |  | 11.10 |  | 14.55 |
Condensate at Edmonton |  | US$/bbl |  | 45.30 |  | 66.82 |  | 68.50 |  | 63.15 |  | 57.95 |  | 47.60 |  | 48.45 |  | 52.20 |
Natural gas (Alberta spot) at AECO |  | Cdn$/mcf |  | 1.60 |  | 1.19 |  | 1.20 |  | 1.77 |  | 1.70 |  | 1.45 |  | 2.80 |  | 2.70 |
Alberta Power Pool Price |  | Cdn$/MWh |  | 55.55 |  | 54.45 |  | 56.00 |  | 34.95 |  | 22.35 |  | 24.55 |  | 19.30 |  | 22.40 |
New York Harbor 3-2-1 crack(1) |  | US$/bbl |  | 16.20 |  | 19.65 |  | 20.65 |  | 15.50 |  | 19.40 |  | 22.35 |  | 16.35 |  | 12.55 |
Chicago 3-2-1 crack(1) |  | US$/bbl |  | 13.35 |  | 19.05 |  | 18.30 |  | 12.85 |  | 20.20 |  | 19.25 |  | 14.40 |  | 11.15 |
Portland 3-2-1 crack(1) |  | US$/bbl |  | 21.60 |  | 21.40 |  | 27.90 |  | 20.35 |  | 22.10 |  | 26.80 |  | 21.25 |  | 18.45 |
Gulf Coast 3-2-1 crack(1) |  | US$/bbl |  | 15.10 |  | 18.85 |  | 20.25 |  | 15.55 |  | 18.25 |  | 21.45 |  | 16.80 |  | 14.00 |
Exchange rate |  | US$/Cdn$ |  | 0.76 |  | 0.77 |  | 0.77 |  | 0.79 |  | 0.79 |  | 0.80 |  | 0.74 |  | 0.76 |
Exchange rate (end of period) |  | US$/Cdn$ |  | 0.73 |  | 0.77 |  | 0.76 |  | 0.78 |  | 0.80 |  | 0.80 |  | 0.77 |  | 0.75 |

(1)
  3-2-1 crack spreads are indicators of the refining margin generated by converting three barrels of WTI into two barrels 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.

2018 ANNUAL REPORT Suncor Energy Inc. 43

Significant or Unusual Items Impacting Net Earnings

Trends in Suncor's quarterly net earnings and cash flow provided by operating activities are driven primarily by production volumes, which can be significantly impacted by major maintenance events, such as the planned upgrader maintenance and the turnaround at the Edmonton refinery that occurred in the second quarter of 2018, and unplanned outages such as the major storm system on the east coast of Canada in the fourth quarter of 2018.

Trends in Suncor's quarterly net earnings and cash flow provided by operating activities are also affected by changes in commodity prices, price differentials, refining crack spreads and foreign exchange rates, as described in the Financial Information section of this MD&A. In addition to the impacts of changes in production volumes and business environment, net earnings over the last eight quarters were affected by the following events or significant adjustments:

•
  The fourth quarter of 2018 included a $223 million after-tax impairment charge in the E&P segment associated with the company's equity investment in Canbriam. This included the reversal of a $133 million after-tax gain recorded in the first quarter of 2018, when the equity investment was acquired through an asset exchange, for a net after-tax impairment of $90 million in 2018.
•
  The third quarter of 2018 included an after-tax gain of $60 million in the Oil Sands segment relating to the sale of the company's interest in the Joslyn oil sands mining project.
•
  The fourth quarter of 2017 included a net deferred tax recovery of $124 million related to a decrease in the U.S. corporate tax rate from 35% to 21%, after-tax proceeds of $55 million ($76 million before tax) for property damage insurance related to the facility incident at Syncrude that occurred in the first quarter of 2017, an after-tax loss of $18 million for early payment of debt, and an after-tax gain on forward interest rate swaps of $2 million associated with issued debt.
•
  The third quarter of 2017 included a non-cash after-tax gain of $10 million on forward interest rate swaps.
•
  The second quarter of 2017 included an after-tax charge of $10 million for early payment of debt, net of associated realized foreign currency hedge gains, and a non-cash after-tax loss of $32 million on forward interest rate swaps and foreign currency derivatives.
•
  The first quarter of 2017 included $437 million of after-tax gains on the sale of the company's lubricants business and its interest in the Cedar Point wind facility.

44 2018 ANNUAL REPORT Suncor Energy Inc.

7. CAPITAL INVESTMENT UPDATE

Capital and Exploration Expenditures by Segment

Year ended December 31 ($ millions) |  | 2018 |  | 2017 |  | 2016 |  |
Oil Sands |  | 3 546 |  | 5 059 |  | 4 724 |  |
Exploration and Production |  | 946 |  | 824 |  | 1 139 |  |
Refining and Marketing |  | 856 |  | 634 |  | 685 |  |
Corporate, Energy Trading and Eliminations |  | 58 |  | 34 |  | 34 |  |
Total |  | 5 406 |  | 6 551 |  | 6 582 |  |
Less: capitalized interest on debt |  | (156 | ) | (729 | ) | (596 | ) |
|  | 5 250 |  | 5 822 |  | 5 986 |  |

Capital and Exploration Expenditures by Type(1)(2)(3)

Year ended December 31, 2018 ($ millions) |  | Sustaining |  | Growth |  | Total |
Oil Sands |  |  |  |  |  |  |
| Oil Sands Base |  | 1 820 |  | 32 |  | 1 852 |
| In Situ |  | 351 |  | 26 |  | 377 |
| Fort Hills |  | 250 |  | 365 |  | 615 |
| Syncrude |  | 583 |  | 3 |  | 586 |
Exploration and Production |  | 11 |  | 898 |  | 909 |
Refining and Marketing |  | 853 |  | — |  | 853 |
Corporate, Energy Trading and Eliminations |  | 58 |  | — |  | 58 |
|  | 3 926 |  | 1 324 |  | 5 250 |

(1)
  Capital expenditures in this table exclude capitalized interest on debt.
(2)
  Growth capital expenditures include capital investments that result in i) an increase in production levels at existing Oil Sands and R&M operations; ii) new facilities or operations that increase overall production; iii) new infrastructure and logistics that are required to support higher production levels; iv) new reserves or a positive change in the company's reserves profile in Exploration and Production operations; or v) margin improvement, by increasing revenues or reducing costs.
(3)
  Sustaining capital expenditures include capital investments that i) ensure compliance with regulations; ii) improve efficiency and reliability of operations or maintain productive capacity; iii) deliver existing proved developed reserves for Exploration and Production operations; or iv) maintain current production capacities at existing Oil Sands and R&M operations.

In 2018, Suncor's capital expenditures on property, plant and equipment and exploration activities totalled $5.250 billion, excluding capitalized borrowing costs of $156 million. Activity in 2018 included the following:

Oil Sands Base

Oil Sands Base sustaining capital expenditures were $1.820 billion in 2018 and were primarily focused on ensuring continued safe, reliable and efficient operations, as well as environmental compliance such as the continued development of tailings infrastructure. The company's planned maintenance program in 2018 included a planned turnaround at Upgrader 1 in the spring and major maintenance at Upgrader 2 in the fall, in addition to other maintenance initiatives.

Oil Sands Base growth capital of $32 million in 2018 was focused on projects expected to improve productive capacity, including development of the coke-fired boiler replacement project.

In Situ

In Situ capital expenditures were $377 million, of which $351 million was directed towards sustaining capital expenditures, which focused on the ongoing design and construction of well pads that are expected to maintain existing production levels at Firebag and MacKay River in future years as production from existing well pads declines.

Growth capital of $26 million in 2018 was related to development of emerging properties and new technologies.

Fort Hills

Fort Hills capital expenditures were $615 million in 2018, with $365 million directed toward growth spending and completion of the project within the year.

Sustaining capital of $250 million in 2018 included activities supporting the execution of the mine and tailings plan following the achievement of first oil.

2018 ANNUAL REPORT Suncor Energy Inc. 45

Syncrude

Syncrude capital and exploration expenditures were $586 million in 2018, the majority of which was for sustaining capital expenditures focused on maintaining assets, including capital related to turnarounds and maintenance.

Exploration and Production

Exploration and Production capital and exploration expenditures were $909 million in 2018, which was primarily directed to development drilling at all offshore assets, as well as development work on the West White Rose Project, the Norwegian Oda and Fenja projects, and pre-sanction design work on the Rosebank project in the U.K.

Refining and Marketing

Refining and Marketing capital expenditures were $853 million in 2018, all of which was directed to sustaining activities focused on planned maintenance events at the company's refineries, enhancements to retail operations and technology upgrades. In 2018, the company undertook the most significant maintenance program in its history, performing a full plant shutdown of the Edmonton refinery for the first time.

Capital Projects Update

Suncor anticipates 2019 capital expenditures to be directed to the following projects and initiatives:

Oil Sands Operations

For 2019, plans for sustaining capital will primarily be focused on tailings management, planned maintenance, which includes major maintenance on coker drums, and the naphtha and gasoil hydrotreaters. Other investments to maintain production capacity at existing facilities include continued development of new well pads at In Situ to offset natural production declines, development of an autonomous haul truck program to further improve the efficiency of mining operations and replacement of the coke-fired boilers at Oil Sands Base.

Fort Hills

Sustaining capital expenditures in 2019 for Fort Hills will be focused on tailings management and projects to preserve production capacity and maintain reliability, including mining equipment.

Syncrude

Sustaining capital expenditures in 2019 for Syncrude are expected to focus on reliability programs, planned maintenance and maintaining production capacity.

Exploration and Production

Capital expenditures in 2019 for E&P will be focused on future growth projects, including the West White Rose Project off the east coast of Canada. The West White Rose Project was sanctioned in the second quarter of 2017. Suncor is a non-operating partner with a blended working interest of approximately 26% and the company's share of peak oil is expected to be 20,000 bbls/d. The operator originally estimated first oil would be achieved in 2022; however, due to a recent delay in the tow-out schedule, achieving this first-oil date is uncertain. An update from the project operator is expected in the first half of 2019.

Additional growth capital in 2019 will include development drilling at Hibernia, White Rose, Terra Nova and Buzzard, development of the Buzzard Phase 2 project, which was sanctioned in 2018, and the Norwegian Oda and Fenja projects, as well as pre-sanction design work on the Rosebank future development project.

Refining and Marketing

The company expects that sustaining capital will focus on planned maintenance events, technological investments and routine asset replacement.

46 2018 ANNUAL REPORT Suncor Energy Inc.

8. FINANCIAL CONDITION AND LIQUIDITY

Liquidity and Capital Resources

At December 31 ($ millions, except as noted) |  | 2018 |  | 2017 |  | 2016 |  |
Net cash from (used in) |  |  |  |  |  |  |  |
| Operating activities |  | 10 580 |  | 8 966 |  | 5 680 |  |
| Investing activities |  | (6 697 | ) | (5 019 | ) | (7 507 | ) |
| Financing activities |  | (4 426 | ) | (4 223 | ) | 869 |  |
| Foreign exchange gain (on cash and cash equivalents) |  | 92 |  | (68 | ) | (75 | ) |
(Decrease) increase in cash and cash equivalents |  | (451 | ) | (344 | ) | (1 033 | ) |
Cash and cash equivalents, end of year |  | 2 221 |  | 2 672 |  | 3 016 |  |
Return on Capital Employed (%)(1) |  |  |  |  |  |  |  |
| Excluding major projects in progress |  | 8.2 |  | 8.6 |  | 0.5 |  |
| Including major projects in progress |  | 8.0 |  | 6.7 |  | 0.4 |  |
Net debt to funds from operations(1) (times) |  | 1.5 |  | 1.4 |  | 2.4 |  |
Interest coverage on long-term debt (times) |  |  |  |  |  |  |  |
| Earnings basis(2) |  | 6.4 |  | 6.5 |  | 0.5 |  |
| Funds from operations basis(1)(3) |  | 14.1 |  | 11.2 |  | 6.5 |  |

(1)
  Non-GAAP financial measures. See the Advisories – Non-GAAP Financial Measures section of this MD&A.
(2)
  Net earnings plus income taxes and interest expense, divided by the sum of interest expense and capitalized interest on debt.
(3)
  Funds from operations plus current income taxes and interest expense, divided by the sum of interest expense and capitalized interest on debt.

Cash Flow provided by Operating Activities

Cash flow provided by operating activities was $10.580 billion in 2018 compared to $8.966 billion in 2017. The increase was primarily due to improved overall benchmark crude pricing, increased refining margins and higher overall upstream production, primarily attributed to the ramp up of Fort Hills and Hebron and the increased working interest in Syncrude. These factors were partially offset by an increase in expenses associated with the expansion of the company's production in 2018, an increase in maintenance expenditures at Syncrude and Oil Sands operations, and a decrease in the capitalization of borrowing costs.

Cash Flow used in Investment Activities

Cash flow used in investing activities was $6.697 billion in 2018 compared to $5.019 billion in 2017. The increase was primarily due to the purchase of an additional 5% interest in the Syncrude project and a decrease in proceeds from disposals, with the previous year including the sale of the company's lubricants business and its interest in two wind facilities, partially offset by a decrease in capital and exploration expenditures following the completion of the company's major growth projects in 2018.

Cash Flow used in Financing Activities

Cash flow used in financing activities was $4.426 billion in 2018, compared to $4.223 billion in 2017. The increase was primarily due to an increase in the purchase of the company's own shares under its normal course issuer bid (NCIB), an increase in dividends paid and a smaller increase in short-term debt. In addition, 2017 included a significant net reduction of long-term debt, partially offset by proceeds relating to the sale of a 49% interest in the ETFD, which was treated as a financing activity due to the existence of non-discretionary distributions within the arrangement.

Management of debt levels continues to be a priority for Suncor given the company's long-term growth plans and future expected volatility in the pricing environment. Suncor believes a phased and flexible approach to existing and future growth projects should assist the company in maintaining its ability to manage project costs and debt levels.

Capital Resources

Suncor's capital resources consist primarily of cash flow provided by operating activities, cash and cash equivalents and available credit facilities, including commercial paper. Suncor's management believes the company will have the capital resources to fund its planned 2019 capital spending program of $4.9 to $5.6 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 accessing capital markets. The company's cash flow provided by operating activities depends on a number of factors, including commodity prices, production and sales volumes, refining and marketing

2018 ANNUAL REPORT Suncor Energy Inc. 47

margins, operating expenses, taxes, royalties and foreign exchange rates.

The company has invested excess 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 will be with counterparties with investment grade debt ratings.

Available Sources of Liquidity

Cash and Cash Equivalents

Included in cash and cash equivalents of $2.221 billion at December 31, 2018 are short-term investments with weighted average terms to maturity of approximately 14 days. In 2018, the company earned approximately $32 million of interest income on this portfolio.

Financing Activities

Suncor's interest on debt (before capitalized interest) in 2018 was $897 million, a decrease from $945 million in 2017, due to the net reduction in long-term debt that occurred over the course of 2017, including the exchange of higher interest rate debt for debt issued at a lower interest rate, partially offset by an increase in short-term debt in 2018 combined with higher short-term interest rates and the unfavourable impact of the weaker Canadian dollar on U.S. dollar denominated debt.

Available lines of credit at December 31, 2018 decreased to $3.608 billion, compared to $4.489 billion at December 31, 2017, due to an increase in short-term indebtedness.

A summary of total and unutilized credit facilities at December 31, 2018 is as follows:

($ millions) |  | 2018 |  |
Fully revolving and expires in 2022 |  | 4 000 |  |
Fully revolving and expires in 2021 |  | 2 729 |  |
Fully revolving and expires within the next two years |  | 1 537 |  |
Can be terminated at any time at the option of the lenders |  | 132 |  |
Total credit facilities |  | 8 398 |  |
Credit facilities supporting outstanding commercial paper |  | (3 231 | ) |
Credit facilities supporting standby letters of credit |  | (1 269 | ) |
Total unutilized credit facilities(1) |  | 3 898 |  |

(1)
  Available credit facilities for general purposes were $3.608 billion at December 31, 2018 (December 31, 2017 – $4.489 billion).

Total Debt to Total Debt Plus Shareholders' Equity

Suncor is subject to financial and operating covenants related to its bank debt and public market debt. Failure to meet the terms of one or more of these covenants may constitute an Event of Default as defined in the respective debt agreements, potentially resulting in accelerated repayment of one or more of the debt obligations. The company is in compliance with its financial covenant that requires total debt to not exceed 65% of its total debt plus shareholders' equity. At December 31, 2018, total debt to total debt plus shareholders' equity was 28.3% (December 31, 2017 – 25.6%). The company is currently in compliance with all operating covenants as at December 31, 2018.

At December 31 ($ millions, except as noted) |  | 2018 |  | 2017 |
| Short-term debt |  | 3 231 |  | 2 136 |
| Current portion of long-term debt |  | 229 |  | 71 |
| Long-term debt |  | 13 890 |  | 13 372 |
Total debt |  | 17 350 |  | 15 579 |
| Less: Cash and cash equivalents |  | 2 221 |  | 2 672 |
Net debt |  | 15 129 |  | 12 907 |
Shareholders' equity |  | 44 005 |  | 45 383 |
Total debt plus shareholders' equity |  | 61 355 |  | 60 962 |
Total debt to total debt plus shareholders' equity (%) |  | 28.3 |  | 25.6 |

48 2018 ANNUAL REPORT Suncor Energy Inc.

Change in Net Debt

($ millions) |  |  |  |
Total debt – December 31, 2017 |  | 15 579 |  |
Decrease in long-term debt |  | (186 | ) |
Increase in short-term debt |  | 866 |  |
Foreign exchange on debt, and other |  | 1 091 |  |
Total Debt – December 31, 2018 |  | 17 350 |  |
Less: Cash and cash equivalents – December 31, 2018 |  | 2 221 |  |
Net Debt – December 31, 2018 |  | 15 129 |  |

At December 31, 2018, Suncor's net debt was $15.129 billion, compared to $12.907 billion at December 31, 2017. During 2018, total debt increased by $1.771 billion, primarily due to unrealized foreign exchange losses on U.S. dollar denominated debt and an increase in short-term indebtedness due to acquisitions, partially offset by a decrease in long-term debt.

For the year ended December 31, 2018, the company's net debt to funds from operations measure was 1.5 times, which is lower than management's maximum target of less than 3.0 times.

Credit Ratings

The company's credit ratings impact its cost of funds and liquidity. In particular, the company's ability to access unsecured funding markets and to engage in certain activities on a cost-effective basis is primarily dependent upon maintaining a strong credit rating. A lowering of the company's credit rating may also have potentially adverse consequences for the company's funding capacity or access to the capital markets, may affect the company's ability, and the cost, to enter into normal course derivative or hedging transactions, and may require the company to post additional collateral under certain contracts.

As at February 28, 2019, the company's long-term senior debt ratings are:

Long-Term Senior Debt |  | Rating |  | Long-Term Outlook |
Standard & Poor's |  | A- |  | Stable |
Dominion Bond Rating Service |  | A (low | ) | Stable |
Moody's Investors Service |  | Baa1 |  | Stable |

The company's commercial paper ratings are:

Commercial Paper | Cdn Program Rating |  | U.S. Program Rating |
Standard & Poor's | A-1 (low | ) | A-2 |
Dominion Bond Rating Service | R-1 (low | ) | Not rated |
Moody's Investors Service | Not rated |  | P2 |

Refer to the Description of Capital Structure – Credit Ratings section of Suncor's 2018 AIF for a description of credit ratings listed above.

Common Shares

Outstanding Shares

December 31, 2018 (thousands) |  |  |
Common shares |  | 1 584 484 |
Common share options – non-exercisable |  | 15 374 |
Common share options – exercisable |  | 13 561 |

As at February 25, 2019, the total number of common shares outstanding was 1,577,725,157 and the total number of exercisable and non-exercisable common share options outstanding was 35,618,386. Once exercisable, each outstanding common share option may be exercised for one common share.

Share Repurchases

In May 2018, Suncor renewed its NCIB to continue to repurchase its common shares through the facilities of the Toronto Stock Exchange (TSX), New York Stock Exchange and/or alternative trading platforms between May 4, 2018 and May 3, 2019. In November 2018, following the approval by the Board of Directors to increase the company's share repurchase program to $3.0 billion, the Toronto Stock Exchange TSX accepted a notice filed by Suncor of its intention to amend its NCIB effective as of November 19, 2018. The notice provided that Suncor may increase the maximum number of common shares that may be purchased for cancellation between May 4, 2018 and May 3, 2019 from 52,285,330 common shares, or approximately 3% of Suncor's issued and outstanding common shares as at April 30, 2018, to 81,695,830 common shares, or approximately 5% of Suncor's issued and outstanding common shares as at April 30, 2018. Suncor security holders may obtain a copy of the notice, without charge, by contacting the company.

Since commencing its share buyback program in 2011, Suncor has purchased 262,664,000 common shares as of February 25, 2018 for a total return to shareholders of 10.2 billion under this program, with close to half of these share repurchases occurring in the last 2 years. Subsequent to the end of the year, Suncor's Board of Directors approved a further share repurchase program of up to $2.0 billion.

2018 ANNUAL REPORT Suncor Energy Inc. 49

At December 31 ($ millions, except as noted) |  | 2018 |  | 2017 |  | 2016 |  | 2015 |
Share repurchase activities (thousands of common shares) |  |  |  |  |  |  |  |  |
| Shares repurchased |  | 64 426 |  | 33 153 |  | — |  | 1 230 |
Share repurchase cost ($ millions) |  | 3 053 |  | 1 413 |  | — |  | 43 |
Weighted average repurchase price per share (dollars per share) |  | 47.38 |  | 42.61 |  | — |  | 34.93 |

Contractual Obligations, Commitments, Guarantees, and Off-Balance Sheet Arrangements

In addition to the enforceable and legally binding obligations in the table below, Suncor has other obligations for goods and services that were entered into in the normal course of business, which may terminate on short notice, including commitments for the purchase of commodities for which an active, highly liquid market exists, and which are expected to be re-sold shortly after purchase.

The company 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 condition or financial performance, including liquidity and capital resources.

In the normal course of business, the company is obligated to make future payments, including contractual obligations and non-cancellable commitments.

|  | Payment due by period |
($ millions) |  | 2019 |  | 2020 |  | 2021 |  | 2022 |  | 2023 |  | 2024 and beyond |  | Total |
Fixed and revolving term debt(1) |  | 4 161 |  | 733 |  | 2 172 |  | 883 |  | 632 |  | 18 648 |  | 27 229 |
Finance lease obligations |  | 37 |  | 39 |  | 42 |  | 46 |  | 53 |  | 1 043 |  | 1 260 |
Decommissioning and restoration costs(2) |  | 542 |  | 462 |  | 413 |  | 348 |  | 211 |  | 11 074 |  | 13 050 |
Operating lease agreements, pipeline capacity and energy services commitments(3) |  | 1 896 |  | 1 671 |  | 1 632 |  | 1 575 |  | 1 492 |  | 14 771 |  | 23 037 |
Exploration work commitments |  | 33 |  | — |  | 44 |  | — |  | — |  | 490 |  | 567 |
Other long-term obligations(4) |  | 2 |  | 21 |  | 21 |  | 21 |  | 21 |  | — |  | 86 |
Total |  | 6 671 |  | 2 926 |  | 4 324 |  | 2 873 |  | 2 409 |  | 46 026 |  | 65 229 |

(1)
  Includes debt that is redeemable at Suncor's option and interest payments on fixed-term debt.
(2)
  Represents the undiscounted amount of decommissioning and restoration costs.
(3)
  Operating lease payments, apart from short-term leases, will be captured in the IFRS 16 transition adjustment effective January 1, 2019. Please refer to note 5 to Suncor's 2018 audited Consolidated Financial Statements for further details.
(4)
  Includes the Libya ESPA signature bonus and merger consent. See the Other Long-Term Liabilities note to the 2018 audited Consolidated Financial Statements.

Transactions with Related Parties

The company enters into transactions with related parties in the normal course of business. These transactions primarily include sales to associated entities in the company's Refining and Marketing segment and service provisions to Fort Hills. For more information on these transactions and for a summary of Compensation of Key Management Personnel, refer to note 29 to the 2018 audited Consolidated Financial Statements.

Financial Instruments

Suncor periodically enters into derivative contracts for risk management purposes. The derivative contracts hedge risks related to purchases and sales of commodities, to manage exposure to interest rates and to hedge risks specific to individual transactions, such as currency risk associated with repayment of U.S. dollar denominated debt. For the year ended December 31, 2018, the pre-tax earnings impact of risk management activities was $126 million (2017 – pre-tax loss of $19 million).

The company's Energy Trading business uses crude oil, natural gas, refined products futures contracts and other derivative financial instruments to optimize related trading and risk management strategies. For the year ended December 31, 2018, the pre-tax earnings impact for Energy Trading activities was $129 million (2017 – pre-tax loss of $37 million).

Gains or losses related to derivatives are recorded as Other Income in the Consolidated Statements of Comprehensive Income.

50 2018 ANNUAL REPORT Suncor Energy Inc.

($ millions) |  | Energy Trading |  | Risk Management |  | Total |  |
Fair value of contracts outstanding – December 31, 2016 |  | (36 | ) | (18 | ) | (54 | ) |
Cash settlements – (received) paid during the year |  | (12 | ) | 17 |  | 5 |  |
Unrealized losses recognized in earnings during the year |  | (37 | ) | (19 | ) | (56 | ) |
Fair value outstanding – December 31, 2017 |  | (85 | ) | (20 | ) | (105 | ) |
Cash settlements – (received) during the year |  | (43 | ) | (47 | ) | (90 | ) |
Unrealized gains recognized in earnings during the year |  | 129 |  | 126 |  | 255 |  |
Fair value outstanding – December 31, 2018 |  | 1 |  | 59 |  | 60 |  |

The fair value of derivative financial instruments is recorded on the Consolidated Balance Sheets.

Fair value of derivative contracts at December 31 ($ millions) |  | 2018 |  | 2017 |  |
Accounts receivable |  | 215 |  | 74 |  |
Accounts payable |  | (155 | ) | (179 | ) |
|  | 60 |  | (105 | ) |

Risks Associated with Derivative Financial Instruments

Suncor may be exposed to certain losses in the event that counterparties to derivative financial instruments are unable to fulfil their obligations under these contracts. The company minimizes this risk by entering into agreements with investment grade counterparties. Risk is also minimized through regular management review of the potential exposure to and credit ratings of such counterparties. Suncor's exposure is limited to those counterparties holding derivative contracts with net positive fair values at a reporting date.

Suncor's risk management activities are subject to periodic reviews by management to determine appropriate hedging requirements based on the company's tolerance for exposure to market volatility, as well as the need for stable cash flow to finance future growth. Energy Trading activities are governed by a separate risk management group that reviews and monitors practices and policies and provides independent verification and valuation of these activities.

For further details on our derivative financial instruments, including assumptions made in the calculation of fair value, a sensitivity analysis of the effect of changes in commodity prices on our derivative financial instruments, and additional discussion of exposure to risks and mitigation activities, see the Financial Instruments and Risk Management note in the company's 2018 audited Consolidated Financial Statements.

2018 ANNUAL REPORT Suncor Energy Inc. 51

9. ACCOUNTING POLICIES AND CRITICAL ACCOUNTING ESTIMATES

Suncor's significant accounting policies are described in note 3 to the audited Consolidated Financial Statements for the year ended December 31, 2018.

(a) Recently Implemented Accounting Pronouncements

Impact of the application of IFRS 9

Effective January 1, 2018, the company adopted IFRS 9 Financial Instruments (IFRS 9) which replaces the multiple classification and measurement models for financial assets under IAS 39 Financial Instruments (IAS 39) with a new model that has two measurement categories: amortized cost and fair value, either through profit/loss (FVTPL) or through other comprehensive income. This determination is made at initial recognition. For financial liabilities, the new standard retains most of the IAS 39 requirements; however, the main change arises in cases where the company chooses to designate a financial liability as FVTPL. In these situations, the portion of the fair value change related to the company's own credit risk is recognized in other comprehensive income rather than net earnings. As a result of adopting IFRS 9, the company's financial assets classified as loans and receivables at December 31, 2017 have been reclassified to financial assets at amortized cost; however, there is no impact to the measurement of these financial assets. There were no changes to the classifications of the company's financial liabilities. The classification and measurement guidance was adopted retrospectively in accordance with the transitional provisions of IFRS 9.

The company also adopted the new hedge accounting guidance in IFRS 9. The new hedge accounting guidance replaces strict quantitative tests of effectiveness with less restrictive assessments of how well the hedging instrument accomplishes the company's risk management objectives for financial and non-financial risk exposures. IFRS 9 also allows the company to hedge risk components of non-financial items which meet certain measurability or identifiable characteristics. The company did not apply hedge accounting to any of its derivative instruments during 2018.

After adoption of IFRS 9, the company's accounting policies are substantially the same as at December 31, 2017 and there were no impacts to the company's financial statements, except for the change in financial asset categories as discussed above.

Impact of the application of IFRS 15

On January 1, 2018, the company adopted IFRS 15 Revenue from Contracts with Customers (IFRS 15) using the retrospective method, which sets out guidelines for the recognition of revenue.

IFRS 15 replaces IAS 18 Revenue and presents a new single model for recognition of revenue from contracts with customers. The model features a contract-based five-step analysis of transactions to determine the nature of an entity's obligation to perform and whether, how much, and when revenue is recognized.

Under IFRS 15, the revenue from the sale of commodities and other operating revenue the company earns represent contractual arrangements with customers. The company recognizes revenue when title of the product is transferred to the buyer and collection is reasonably assured in accordance with specified contract terms. All operating revenue is generally earned at a point in time and is based on the consideration that the company expects to receive for the transfer of the goods to the customers.

The company has reviewed its sources of revenue and major contracts with customers using the guidance found in IFRS 15 and determined there are no material changes to the timing and measurement of the company's revenue in the reporting period, as compared to the provisions of the previous standard. In accordance with the new standard, the company assessed its principal versus agent requirements and the impact was a decrease in revenue, with a corresponding decrease to Operating, Selling and General expense and Transportation expense, resulting in no impact on the company's consolidated net earnings.

Adjustments to Consolidated Statements of Comprehensive Income

($ millions, decrease) |  | For the twelve months ended December 31, 2017 IFRS 15 |  |
Revenues and Other Income |  |  |  |
| Operating revenues, net of royalties |  | (97 | ) |
Expenses |  |  |  |
| Operating, selling and general |  | (57 | ) |
| Transportation |  | (40 | ) |
Net Earnings |  | — |  |
Total Comprehensive Income |  | — |  |

(b) Recently Announced Accounting Pronouncements

The standards, amendments and interpretations that are issued, but not yet effective up to the date of authorization of the company's audited Consolidated Financial Statements, and that may have an impact on the disclosures and financial position of the company, are disclosed below. The company intends to adopt these standards, amendments and interpretations when they become effective.

Leases

In January 2016, the IASB issued IFRS 16 Leases (IFRS 16) which replaces the existing leasing standard IAS 17 Leases

52 2018 ANNUAL REPORT Suncor Energy Inc.

(IAS 17) and requires the recognition of leases on the balance sheet, with optional exemptions for short-term leases where the term is twelve months or less and for leases of low-value items. IFRS 16 effectively removes the classification of leases as either finance or operating leases and treats all leases as finance leases for lessees. The accounting treatment for lessors remains essentially unchanged, with the requirement to classify leases as either finance or operating.

The company will adopt the standard on the effective date of January 1, 2019 and has selected the modified retrospective transition approach. The company has also elected to apply the optional exemptions for short-term leases. IFRS 16 will have an impact on the following components of the audited Consolidated Financial Statements of the company. The company has completed the implementation of an information technology solution, including uploading of data for identified leases into its leasing system. All contracts have been reviewed, new business processes are developed and internal controls have been implemented.

Consolidated Balance Sheets: IFRS 16 requires the recognition of lease liabilities and right-of-use (ROU) assets for all leases except for the optional exemptions for low-value assets and short-term leases. The company will recognize the lease liability at the present value of the remaining lease payments discounted using the company's incremental borrowing rate upon adoption of the new standard. Upon transition, the company will measure the ROU assets equal to the lease liability, adjusted by the amount of any prepaid payments or onerous contracts recognized in the December 31, 2018 audited Consolidated Financial Statements.

The company will recognize additional ROU assets and lease liabilities of $1.8 billion, subject to finalization of reviews, as of January 1, 2019.

Consolidated Statements of Comprehensive Income: Adoption of IFRS 16 will result in an increase to DD&A expense due to the recognition of ROU assets, an increase to Financing expense from the unwinding of the discounted value of the lease liabilities and a decrease to Operating, Selling and General expense, Purchases of Crude Oil and Products and Transportation expense. Based on the company's leases at January 1, 2019, this standard will not have a material impact on consolidated net earnings.

Consolidated Statements of Cash Flows: Due to the change in presentation of former operating lease expenses, Cash flow provided by operating activities will increase due to the decrease in Operating, Selling and General expense, Purchases of Crude Oil and Products and Transportation expense, partially offset by increased Financing expense, which represents an operating activity for the company. Cash flow from financing activities will decrease due to the addition of principal payments for former operating leases. The overall impact to cash flow for the company will be unchanged.

Uncertainty over Income Tax Treatments

In June 2017, the IASB issued IFRIC 23 Uncertainty over Income Tax Treatments. The interpretation clarifies the accounting for current and deferred tax liabilities and assets in circumstances in which there is uncertainty over income tax treatments. The interpretation requires an entity to consider whether it is probable that a taxation authority will accept an uncertain tax treatment. If the entity considers it to be not probable that a taxation authority will accept an uncertain tax provision, the interpretation requires the entity to use the most likely amount or the expected value. The amendments are to be applied retrospectively and are effective for annual periods beginning on or after January 1, 2019, with earlier application permitted. The adoption of this amendment will not have any impact on the company's audited Consolidated Financial Statements.

Significant Accounting Estimates and Judgments

The preparation of financial statements in accordance with IFRS requires management to make estimates and judgments that affect reported assets, liabilities, revenues, expenses, gains, losses, and disclosures of contingencies. These estimates and judgments are subject to change based on experience and new information. The financial statement areas that require significant estimates and judgments are as follows:

Oil and Gas Reserves

Measurements of depletion, depreciation, impairment and decommissioning and restoration obligations are determined in part based on the company's estimate of oil and gas reserves. The estimation of reserves is an inherently complex process and involves the exercise of professional judgment. All reserves have been evaluated at December 31, 2018 by independent qualified reserves evaluators. Oil and gas reserves estimates are based on a range of geological, technical and economic factors, including projected future rates of production, projected future commodity prices, engineering data, and the timing and amount of future expenditures, all of which are subject to uncertainty. Estimates reflect market and regulatory conditions existing at December 31, 2018, which could differ significantly from other points in time throughout the year, or future periods. Changes in market and regulatory conditions and assumptions can materially impact the estimation of net reserves.

Oil and Gas Activities

The company is required to apply judgment when designating the nature of oil and gas activities as exploration, evaluation, development or production, and

2018 ANNUAL REPORT Suncor Energy Inc. 53

when determining whether the costs of these activities shall be expensed or capitalized.

Exploration and Evaluation Costs

Certain exploration and evaluation costs are initially capitalized with the intent to establish commercially viable reserves. The company is required to make judgments about future events and circumstances and applies estimates to assess the economic viability of extracting the underlying resources. The costs are subject to technical, commercial and management review to confirm the continued intent to develop the project. Level of drilling success or changes to project economics, resource quantities, expected production techniques, production costs and required capital expenditures are important judgments when making this determination. Management uses judgment to determine when these costs are reclassified to Property, Plant and Equipment based on several factors including the existence of reserves, appropriate approvals from regulatory bodies and the company's internal project approval process.

Determination of Cash Generating Units (CGUs)

A CGU is the lowest grouping of integrated assets that generate identifiable cash inflows that are largely independent of the cash inflows of other assets or groups of assets. The allocation of assets into CGUs requires significant judgment and interpretations with respect to the integration between assets, the existence of active markets, similar exposure to market risks, shared infrastructure, and the way in which management monitors the operations.

Asset Impairment and Reversals

Management applies judgment in assessing the existence of impairment and impairment reversal indicators based on various internal and external factors.

The recoverable amount of CGUs and individual assets is determined based on the higher of fair value less costs of disposal or value-in-use calculations. The key estimates the company applies in determining the recoverable amount normally include estimated future commodity prices, expected production volumes, future operating and development costs, discount rates, tax rates, and refining margins. In determining the recoverable amount, management may also be required to make judgments regarding the likelihood of occurrence of a future event. Changes to these estimates and judgments will affect the recoverable amounts of CGUs and individual assets and may then require a material adjustment to their related carrying value.

Decommissioning and Restoration Costs

The company recognizes liabilities for the future decommissioning and restoration of Exploration and Evaluation assets and Property, Plant and Equipment based on estimated future decommissioning and restoration costs. Management applies judgment in assessing the existence and extent as well as the expected method of reclamation of the company's decommissioning and restoration obligations at the end of each reporting period. Management also uses judgment to determine whether the nature of the activities performed is related to decommissioning and restoration activities or normal operating activities.

Actual costs are uncertain and estimates may vary as a result of changes to relevant laws and regulations related to the use of certain technologies, the emergence of new technology, operating experience, prices and closure plans. The estimated timing of future decommissioning and restoration may change due to certain factors, including reserves life. Changes to estimates related to future expected costs, discount rates, inflation assumptions, and timing may have a material impact on the amounts presented.

Employee Future Benefits

The company provides benefits to employees, including pensions and other post-retirement benefits. The cost of defined benefit pension plans and other post-retirement benefits received by employees is estimated based on actuarial valuation methods that require professional judgment. Estimates typically used in determining these amounts include, as applicable, rates of employee turnover, future claim costs, discount rates, future salary and benefit levels, the return on plan assets, mortality rates and future medical costs. Changes to these estimates may have a material impact on the amounts presented.

Other Provisions

The determination of other provisions, including, but not limited to, provisions for royalty disputes, onerous contracts, litigation and constructive obligations, is a complex process that involves judgments about the outcomes of future events, the interpretation of laws and regulations, and estimates on the timing and amount of expected future cash flows and discount rates.

Income Taxes

Management evaluates tax positions, annually or when circumstances require, which involves judgment and could be subject to differing interpretations of applicable tax legislation. The company recognizes a tax provision when a payment to tax authorities is considered probable. However, the results of audits and reassessments and changes in the interpretations of standards may result in changes to those positions and, potentially, a material increase or decrease in the company's assets, liabilities and net earnings.

Deferred Income Taxes

Deferred tax assets are recognized when it is considered probable that deductible temporary differences will be recovered in the foreseeable future. To the extent that future taxable income and the application of existing tax laws in each jurisdiction differ significantly from the

54 2018 ANNUAL REPORT Suncor Energy Inc.

company's estimate, the ability of the company to realize the deferred tax assets could be impacted.

Deferred tax liabilities are recognized when there are taxable temporary differences that will reverse and result in a future outflow of funds to a taxation authority. The company records a provision for the amount that is expected to be settled, which requires judgment as to the ultimate outcome. Deferred tax liabilities could be impacted by changes in the company's judgment of the likelihood of a future outflow and estimates of the expected settlement amount, timing of reversals, and the tax laws in the jurisdictions in which the company operates.

Fair Value of Financial Instruments

The fair value of a financial instrument is determined, whenever possible, based on observable market data. If not available, the company uses third-party models and valuation methodologies that utilize observable market data that includes forward commodity prices, foreign exchange rates and interest rates to estimate the fair value of financial instruments, including derivatives. 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.

Functional Currency

The designation of the functional currency of the company and each of its subsidiaries is a management judgment based on the composition of revenue and costs in the locations in which it operates.

Fair Value of Share-Based Compensation

The fair values of equity-settled and cash-settled share-based payment awards are estimated using the Black-Scholes options pricing model. These estimates depend on certain assumptions, including share price, volatility, risk-free interest rate, the term of the awards, the forfeiture rate and the annual dividend yield, which, by their nature, are subject to measurement uncertainty.

2018 ANNUAL REPORT Suncor Energy Inc. 55

10. RISK FACTORS

Suncor is committed to a proactive program of enterprise risk management intended to enable decision-making through consistent identification and assessment of risks inherent to its assets, activities and operations. Some of these risks are common to operations in the oil and gas industry as a whole, while some are unique to Suncor. The realization of any of the following risks could have a material adverse effect on Suncor's business, financial condition, reserves or results of operations.

Volatility of Commodity Prices

Suncor's financial performance is closely linked to prices for crude oil in the company's upstream business and prices for refined petroleum products in the company's downstream business and, to a lesser extent, to natural gas prices in the company's upstream business where natural gas is both an input and output of production processes. The prices for all of these commodities can be influenced by global and regional supply and demand factors, which are factors that are beyond the company's control and can result in a high degree of price volatility.

Crude oil prices are also affected by, among other things, global economic health and global economic growth (particularly in emerging markets), market access constraints, regional and international supply and demand imbalances, political developments and government action (including the mandatory production curtailments recently imposed by the Government of Alberta), decisions by the Organization of Petroleum Exporting Countries (OPEC) to not impose quotas on its members, compliance or non-compliance with quotas agreed upon by OPEC members and other countries, and weather. These factors impact the various types of crude oil and refined products differently and can impact differentials between light and heavy grades of crude oil (including blended bitumen), and between conventional oil and SCO.

Refined petroleum product prices and refining margins are also affected by, among other things, crude oil prices, the availability of crude oil and other feedstock, levels of refined product inventories, regional refinery availability, market access, marketplace competitiveness, and other local market factors. Natural gas prices in North America are affected by, among other things, supply and demand, and by prices for alternative energy sources. Decreases in product margins or increases in natural gas prices could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

In addition, oil and natural gas producers in North America, and particularly in Canada, may receive discounted prices for their production relative to certain international prices, due in part to constraints on the ability to transport and sell such products to international markets. A failure to resolve such constraints may result in continued discounted or reduced commodity prices realized by oil and natural gas producers such as Suncor. Suncor's production from Oil Sands includes significant quantities of bitumen and SCO that may trade at a discount to light and medium crude oil. Bitumen and SCO are typically more expensive to produce and process. In addition, the market prices for these products may differ from the established market indices for light and medium grades of crude oil. As a result, the price received for bitumen and SCO may differ from the benchmark they are priced against. Future quality differentials are uncertain and unfavourable differentials could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

In the fourth quarter of 2018, there was insufficient market access capacity to remove production from the Western Canada Sedimentary Basin causing the differential between WTI and WCS to widen significantly. The situation triggered a response from the Government of Alberta in the form of a mandatory production curtailment, which commenced in early 2019. Such circumstances may result in worsening and/or prolonged price volatility and/or further negative impacts on market dynamics that cannot currently be fully anticipated. Wide differentials, such as those experienced in the fourth quarter of 2018 or a prolonged period of low and/or volatile commodity prices, particularly for crude oil, could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations, and may also lead to the impairment of assets, or to the cancellation or deferral of Suncor's growth projects.

Market Access

Suncor's production of bitumen is expected to grow. The markets for bitumen blends or heavy crude oil are more limited than those for light crude oil, making them more susceptible to supply and demand changes and imbalances (whether as a result of the availability, proximity, and capacity of pipeline facilities, railcars, or otherwise). Heavy crude oil generally receives lower market prices than light crude, due principally to the lower quality and value of the refined product yield and the higher cost to transport the more viscous product on pipelines, and this price differential can be amplified due to supply and demand imbalances.

Market access for Suncor's oil sands production may be constrained by insufficient pipeline takeaway capacity, including the lack of new pipelines due to an inability to secure required approvals and negative public perception. There is a risk that constrained market access for oil sands production, growing inland production and refinery outages could create widening differentials that could impact the profitability of product sales. Market access for refined products may also be constrained by insufficient takeaway capacity, which could create a supply/demand imbalance. The occurrence of any of the foregoing could have a material

56 2018 ANNUAL REPORT Suncor Energy Inc.

adverse effect on the company's business, financial condition, reserves and results of operations.

Major Operational Incidents (Safety, Environmental and Reliability)

Each of Suncor's primary operating businesses – Oil Sands, E&P, and Refining and Marketing – requires significant levels of investment in the design, operation and maintenance and decommissioning of facilities, and carries the additional economic risk associated with operating reliably or enduring a protracted operational outage. The breadth and level of integration of Suncor's operations adds complexity.

The company's businesses also carry the risks associated with environmental and safety performance, which is closely scrutinized by governments, the public and the media, and could result in a suspension of or inability to obtain regulatory approvals and permits, or, in the case of a major environmental or safety incident, delays in resuming normal operations, fines, civil suits or criminal charges against the company.

In general, Suncor's operations are subject to operational hazards and risks such as, among others, fires (including forest fires), explosions, blow-outs, power outages, severe winter climate conditions, prolonged periods of extreme cold or extreme heat, flooding, droughts and other extreme weather conditions, railcar incidents or derailments, the migration of harmful substances such as oil spills, gaseous leaks or a release of tailings into water systems, pollution and other environmental risks, and accidents, any of which can interrupt operations or cause personal injury or death, or damage to property, equipment, the environment, and information technology systems and related data and control systems.

The reliable operation of production and processing facilities at planned levels and Suncor's ability to produce higher value products can also be impacted by, among other things, failure to follow the company's policies, standards and operating procedures or operate within established operating parameters, equipment failure through inadequate maintenance, unanticipated erosion or corrosion of facilities, manufacturing and engineering flaws, and labour shortage or interruption. The company is also subject to operational risks such as sabotage, terrorism, trespass, theft and malicious software, network or cyber attacks.

In addition to the foregoing factors that affect Suncor's business generally, each business unit is susceptible to additional risks due to the nature of its business, including, among others, the following:

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  Suncor's Oil Sands business is susceptible to loss of production, slowdowns, shutdowns or restrictions on its ability to produce higher value products, due to the failure of any one or more interdependent component systems, and other risks inherent to oil sands operations;
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  For Suncor's E&P businesses, there are risks and uncertainties associated with drilling for oil and natural gas, the operation and development of such properties and wells (including encountering unexpected formations, pressures, or the presence of hydrogen sulphide), premature declines of reservoirs, sour gas releases, uncontrollable flows of crude oil, natural gas or well fluids and other accidents;
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  E&P offshore operations occur in areas subject to hurricanes and other extreme weather conditions, such as winter storms, pack ice, icebergs and fog. The occurrence of any of these events could result in production shut-ins, the suspension of drilling operations, damage to or destruction of the equipment involved and injury or death of rig personnel. Harsh weather conditions, particularly in the winter season, may also impact the successful execution of maintenance and start-up of operations. Suncor's offshore operations could be indirectly affected by catastrophic events occurring at other third-party offshore operations, which could give rise to liability, damage to the company's equipment, harm to individuals, force a shutdown of facilities or operations, or result in a shortage of appropriate equipment or specialists required to perform planned operations; and
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  Suncor's Refining and Marketing operations are subject to all of the risks normally inherent in the operation of refineries, terminals, pipelines and other distribution facilities and service stations, including, among others, loss of production, slowdowns or shutdowns due to equipment failures, unavailability of feedstock, price and quality of feedstock or other incidents.

Although the company maintains a risk management program, which includes an insurance component, such insurance may not provide comprehensive coverage in all circumstances, nor are all such risks insurable. The company self-insures some risks, and the company's insurance coverage does not cover all the costs arising out of the allocation of liabilities and risk of loss arising from Suncor operations.

The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

Government/Regulatory and Policy Effectiveness

Suncor's businesses operate under federal, provincial, territorial, state and municipal laws in numerous countries. The company is also subject to regulation and intervention by governments in oil and gas industry matters, such as, among others, land tenure, royalties, taxes (including income taxes), government fees, production rates (including restrictions on production), environmental protection, wildlife, fish, safety performance, the reduction of greenhouse gas (GHG) and other emissions, the export of crude oil, natural gas and other products, interactions with

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foreign governments, the awarding or acquisition of exploration and production rights, oil sands leases or other interests, the imposition of specific drilling obligations, control over the development, reclamation and abandonment of fields and mine sites, mine financial security requirements, approval of logistics infrastructure, and, possibly, expropriation or cancellation of contract rights. As part of ongoing operations, the company is also required to comply with a large number of Environment, Health and Safety (EH&S) regulations under a variety of Canadian, U.S., U.K., Norwegian and other foreign, federal, provincial, territorial, state and municipal laws and regulations. Failure to comply with applicable laws and regulations may result in, among other things, the imposition of fines and penalties, production constraints, a compulsory shutdown of facilities or suspension of operations, reputational damage, delays, increased costs, denial of operating and growth permit applications, censure, liability for cleanup costs and damages, and the loss of important licences and permits.

Before proceeding with most major projects, including significant changes to existing operations, Suncor must obtain various federal, provincial, territorial, state and municipal permits and regulatory approvals, and must also obtain licences to operate certain assets. These processes can involve, among other things, Aboriginal and stakeholder consultation, environmental impact assessments and public hearings, government intervention and may be subject to conditions, including security deposit obligations and other commitments. Suncor's businesses can also be indirectly impacted by a third party's inability to obtain regulatory approval for a shared infrastructure project or a third-party infrastructure project on which a portion of Suncor's business depends. Compliance can also be affected by the loss of skilled staff, inadequate internal processes and compliance auditing.

Failure to obtain, comply with, satisfy the conditions of or maintain regulatory permits, licences and approvals, or failure to obtain them on a timely basis or on satisfactory terms, could result in delays, abandonment or restructuring of projects and increased costs, all of which could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

Changes in government policy, regulation or other laws, or the interpretation thereof, or opposition to Suncor's projects or third-party pipeline and infrastructure projects that delays or prevents necessary permits or regulatory approvals, or which makes current operations or growth projects less profitable or uneconomic could materially impact Suncor's operations, existing and planned projects, financial condition, reserves and results of operations. Obtaining necessary approvals or permits has become more difficult due to increased public opposition and consultation, including Aboriginal consultation requirements as well as increased political involvement. The federal government also issued Bill C-69, An Act to enact the Impact Assessment Act and the Canadian Energy Regulator Act, to amend the Navigation Protection Act and to make consequential amendments to other Acts (Bill C-69) in February 2018. If enacted, it will impact the manner in which large energy projects are approved. The result of these developments could also lead to significant delays and additional compliance costs and staffing and resource levels, and also increase exposure to other risks to Suncor's business, including environmental or safety non-compliance, permit approvals and project development and execution, all of which could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

Suncor is subject to the mandatory production curtailments imposed by the Government of Alberta that commenced in early 2019. The duration, extent and consequences of the curtailments to Suncor's business are not fully known; however, prolonged production curtailment or changes to the curtailment levels could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

Competition

The global petroleum industry is highly competitive in many aspects, including the exploration for and the development of new sources of supply, the acquisition of crude oil and natural gas interests, and the refining, distribution and marketing of refined petroleum products. Suncor competes in virtually every aspect of its business with other energy companies. The petroleum industry also competes with other industries in supplying energy, fuel and related products to consumers. The increasing volatility of the political and social landscape at provincial, federal, territorial, state, municipal and international levels adds complexity.

For Suncor's Oil Sands business, a number of other companies have entered, or may enter, the oil sands business and begin producing bitumen and SCO, or expand their existing operations. It is difficult to assess the number, level of production and ultimate timing of all potential new projects or when existing production levels may increase. During recent years, a global focus on the oil sands through increasing industry consolidation that has created competitors with financial capacity has significantly increased the supply of bitumen, SCO and heavy crude oil in the marketplace. Although current commodity pricing and increased regulatory requirements have slowed certain larger projects in the short term, the impact of this level of activity on regional infrastructure, including pipelines, has placed stress on the availability and cost of all resources required to build and run new and existing oil sands operations.

For Suncor's Refining and Marketing business, management expects that fluctuations in demand for refined products, margin volatility and overall marketplace competitiveness

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will continue. In addition, to the extent that the company's downstream business unit participates in new product markets, it could be exposed to margin risk and volatility from either cost and/or selling price fluctuations.

There is a risk that increased competition could cause costs to increase, put further strain on existing infrastructure and cause margins for refined and unrefined products to be volatile, and impact demand for Suncor's products, which could have a material adverse effect on Suncor's business, financial condition and results of operations.

Carbon Risk

Public support for climate change action and receptivity to alternative/renewable energy technologies has grown in recent years. Governments in Canada and around the world have responded to these shifting societal attitudes by adopting ambitious emissions reduction targets and supporting legislation, including measures relating to carbon pricing, clean energy and fuel standards, and alternative energy incentives and mandates. There has also been increased activism and public opposition to fossil fuels, and oil sands in particular.

Existing and future laws and regulations may impose significant liabilities on a failure to comply with their requirements. Concerns over climate change, fossil fuel extraction, GHG emissions, and water and land-use practices could lead governments to enact additional or more stringent laws and regulations applicable to Suncor and other companies in the energy industry in general, and in the oil sands industry in particular.

Changes to environmental regulations, including regulation relating to climate change, could impact the demand for, formulation or quality of the company's products, or could require increased capital expenditures, operating expenses, abandonment and reclamation obligations and distribution costs, which may not be recoverable in the marketplace and which may result in current operations or growth projects becoming less profitable or uneconomic. In addition, such regulatory changes could necessitate that Suncor develop new technologies. Such technology development could require a significant investment of capital and resources, and any delay in or failure to identify and develop such technologies could prevent Suncor from obtaining regulatory approvals for projects or being able to successfully compete with other companies. Increasing environmental regulation in the jurisdictions in which Suncor operates may also make it difficult for Suncor to compete with companies operating in other jurisdictions with fewer or less costly regulations. In addition, legislation or policies that limit the purchase of production from the oil sands may be adopted in domestic and/or foreign jurisdictions, which, in turn, may limit the world market for Suncor's upstream production and reduce the prices the company receives for its products, and could result in delayed development, stranded assets or the company being unable to further develop its resources. The complexity and breadth of changes in environmental regulation make it extremely difficult to predict the potential impact to Suncor.

Suncor continues to monitor the international and domestic efforts to address climate change. While it currently appears that GHG regulations and targets will continue to become more stringent, and while Suncor continues its efforts to reduce the intensity of its GHG emissions, the absolute GHG emissions of the company are expected to rise as it pursues a growth strategy. Increases in GHG emissions may impact the profitability of the company's projects, as Suncor will be subject to incremental levies and taxes. There is also a risk that Suncor could face litigation initiated by third parties relating to climate change, including litigation pertaining to GHG emissions, the production, sale, or promotion of fossil fuels and petroleum products, and/or disclosure. For example, the Board of County Commissioners of Boulder County, the Board of County Commissioners of San Miguel County and the City of Boulder, all of Colorado, have brought an action against Suncor and certain of its subsidiaries seeking, among other things, compensation for impacts they allege with respect to climate change. In addition, the mechanics of implementation and enforcement of the Oil Sands Emissions Limit Act (OSELA) are currently under review and it is not yet possible to predict the impact on Suncor. However, such impact could be material.

These developments and future developments could adversely impact the demand for Suncor's products, the ability of Suncor to maintain and grow its production and reserves, and Suncor's reputation, and could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

Environmental Compliance

Water and Tailings Management

There are risks associated with Suncor's water and tailings management plans. Each mine is required under the Alberta Energy Regulator's Directive 085 – Fluid Tailings Management for Oil Sands Mining Projects to update its mine fluid tailings management plans. If those plans are not approved in the timelines anticipated or at all, or if any conditions to the approval for the plans are not satisfied, the operators' ability to implement additional fluid tailings treatment facilities could be adversely impacted, which could result in reductions in production and lower volumes of treated tailings. If the mine exceeds certain compliance levels specified in the Tailings Management Framework (TMF), the applicable company could be subject to enforcement actions, including being required to curtail production, and financial consequences, including being subject to a compliance levy or being required to post additional security under the Mine Financial Security Program. The full impact of the TMF, including the financial consequences of exceeding

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compliance levels, is not yet fully known, as certain associated policies and regulations are still under development. Such policies and regulations could also restrict the technologies that the company may employ for tailings management, which could adversely impact the company's business plans. There could also be risks if the company's tailings management operations fail to operate as anticipated. The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

In addition, an integrated water management approach to support operations and successful reclamation and closure requires the release of water to the environment. An Alberta water return policy is currently being developed by the government using a multi-stakeholder approach and the federal government has started working to develop an oil sands effluent regulation. The timing and content of these policies and regulations is not yet known; however, the absence of effective government policies and regulations in this area could impact the success and timing of closure and reclamation plans, which could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

Alberta's Land-Use Framework (LARP)

The implementation of, and compliance with, the terms of the Lower Athabasca Regional Plan (LARP) may adversely impact Suncor's current properties and projects in northern Alberta due to, among other things, environmental limits and thresholds. The impact of the LARP on Suncor's operations may be outside of the control of the company, as Suncor's operations could be impacted as a result of restrictions imposed due to the cumulative impact of development by the other operators in the area and not solely in relation to Suncor's direct impact. The uncertainty of changes in Suncor's future development and existing operations required as a result of the LARP could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

Alberta Environment and Parks (AEP) Water Licences

Suncor currently relies on water obtained under licences from AEP to provide domestic and utility water for the company's Oil Sands business. Water licences, like all regulatory approvals, contain conditions to be met in order to maintain compliance with the licence. There can be no assurance that the licences to withdraw water will not be rescinded or that additional conditions will not be added. It is also possible that regional water management approaches may require water sharing agreements between stakeholders. In addition, the expansion of the company's projects may rely on securing licences for additional water withdrawal, and there can be no assurance that these licences will be granted in a timely manner or that they will be granted on terms favourable to Suncor. There is also a risk that future laws or changes to existing laws or regulations relating to water access could cause capital expenditures and operating expenses relating to water licence compliance to increase. The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

Species at Risk Act

Woodland caribou have been identified as "threatened" under the Species at Risk Act (Canada). In response to the Government of Canada's Recovery Strategy for Woodland Caribou, provincial caribou range plans are being developed. Suncor has existing, planned and potential future projects within caribou ranges in Alberta. The development and implementation of range plans in these areas may have an impact on the pace and amount of development in these areas and could potentially increase costs for restoration or offsetting requirements, which could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

Air Quality Management

A number of Canadian federal and provincial air quality regulations and frameworks are currently being developed, changed and/or implemented, which could have an impact on the company's existing and planned projects by requiring the company to invest additional capital or incur additional operating and compliance expenses, including, among other things, potentially requiring the company to retrofit equipment to meet new requirements and increase monitoring and mitigation plans. The full impact of these regulations and frameworks is not yet known; however, they could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

Alberta Wetland Policy

Pursuant to the Alberta Wetland Policy, development in wetland areas may be obligated to avoid wetlands or mitigate the development's effects on wetlands. Although the full impact of the policy on Suncor is not yet fully known, certain of Suncor's operations and growth projects will be affected by aspects of the policy where avoidance is not possible and wetland reclamation or replacement may be required, which could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

Information Security

The efficient operation of Suncor's business is dependent on computer hardware, software and networked systems, including the systems of cloud providers and third parties with which Suncor conducts business. In the ordinary course of Suncor's business, Suncor collects and stores sensitive data, including intellectual property, proprietary business information and personal information of the company's

60 2018 ANNUAL REPORT Suncor Energy Inc.

employees and retail customers. Suncor's operations are also dependent upon a large and complex information framework. Suncor relies on industry accepted security measures, controls and technology to protect Suncor's information systems and securely maintain confidential and proprietary information stored on the company's information systems, and has adopted a continuous process to identify, assess and manage threats to the company's information systems. Suncor's information security risk oversight is conducted by the Audit Committee of the Board of Directors. However, the measures, controls and technology on which the company relies may not be adequate due to the increasing volume, sophistication and rapidly evolving nature of cyber threats. Suncor's information technology and infrastructure, including process control systems, may be vulnerable to attacks by malicious persons or entities motivated by, among others, geopolitical, financial or activist reasons, or breached due to employee error, malfeasance or other disruptions, including natural disasters and acts of war. Any such attack or breach could compromise Suncor's networks, and the information Suncor stores could be accessed, publicly disclosed, lost, stolen or compromised. Any such attack, breach, access, disclosure or loss of information could result in legal claims or proceedings, liability under laws that protect the privacy of personal information, regulatory penalties, disruptions to Suncor's operations, decreased performance and production, increased costs, and damage to Suncor's reputation, physical harm to people or the environment or other negative consequences to Suncor or third parties, which could have a material adverse effect on Suncor's business, financial condition and results of operations. Although the company maintains a risk management program, which includes an insurance component that may provide coverage for the operational impacts from an attack to, or breach of, Suncor's information technology and infrastructure, including process control systems, the company does not maintain stand-alone cyber insurance. Furthermore, not all cyber risks are insurable. As a result, Suncor's existing insurance may not provide adequate coverage for losses stemming from a cyber attack to, or breach of, its information technology and infrastructure.

Security and Terrorist Threats

Security threats and terrorist or activist activities may impact Suncor's personnel, which could result in injury, death, extortion, hostage situations and/or kidnapping, including unlawful confinement. A security threat, terrorist attack or activist incident targeted at a facility or office owned or operated by Suncor could result in the interruption or cessation of key elements of Suncor's operations. Outcomes of such incidents could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

Project Development and Execution

There are certain risks associated with the development and execution of Suncor's major projects and the commissioning and integration of new facilities within its existing asset base.

Project development and execution risk consists of four related primary risks:

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  Development – a failure to select the right projects and identify effective scope and solution;
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  Engineering – a failure in the specification, design or technology selection;
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  Construction – a failure to build the project in the approved time, in accordance with design, and at the agreed cost; and
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  Commissioning and start-up – a failure of the facility to meet agreed performance targets, including operating costs, efficiency, yield and maintenance costs.

Project development and execution can also be impacted by, among other things:

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  The effect of changing government regulation and public expectations in relation to the impact of oil sands development on the environment which could significantly impact the company's ability to obtain the necessary environmental and other regulatory approvals;
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  The impact of general economic, business and market conditions and the company's ability to finance growth, including major growth projects in progress, if commodity prices were to decline and stay at low levels for an extended period;
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  The complexity and diversity of Suncor's portfolio;
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  Failure to comply with Suncor's Asset Development and Execution Model;
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  The accuracy of project cost and schedule estimates, as actual costs and schedules for major projects can vary from estimates, and these differences can be material;
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  The availability and cost of materials, equipment, qualified personnel, and logistics infrastructure, maintaining adequate quality management and risks associated with logistics and offshore fabrication, including that the cost of materials and equipment fabricated offshore may be impacted by tariffs, duties and quotas;
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  The inability or unwillingness of third party vendors, contractors or service providers to provide materials, equipment, personnel and services of necessary quality in the timelines anticipated and at the agreed upon cost;
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  The complexities and uncertainties associated with identification, development and integration of new technologies into the company's existing and new assets;

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•
  Complexities and risks associated with constructing projects within operating environments and confined construction areas;
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  The commissioning and integration of new facilities within the company's existing asset base could cause delays in achieving guidance, targets and objectives;
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  Risks relating to restarting projects placed in safe mode, including increased capital costs; and
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  The impact of weather conditions.

The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

Technology Risk

There are risks associated with growth and other capital projects that rely largely or partly on new technologies and the incorporation of such technologies into new or existing operations, including that the results of the application of new technologies may differ from simulated, test or pilot environments; or that third party intellectual property protections may impede the development and implementation of new technology. The success of projects incorporating new technologies cannot be assured. Advantages accrue to companies that can develop and adopt emerging technologies in advance of competitors. The inability to develop, implement and monitor new technologies may impact the company's ability to develop its new or existing operations in a profitable manner or comply with regulatory requirements, which could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

Cumulative Impact and Pace of Change

In order to achieve Suncor's business objectives, the company must operate efficiently, reliably and safely, and, at the same time, deliver growth and sustaining projects safely, on budget and on schedule. The ability to achieve these two sets of objectives is critically important for Suncor to deliver value to shareholders and stakeholders. These ambitious business objectives compete for resources, and may negatively impact the company should there be inadequate consideration of the cumulative impacts of prior and parallel initiatives on people, processes and systems. There is also a risk that these objectives may exceed Suncor's capacity to adopt and implement change. The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

Joint Arrangement Risk

Suncor has entered into joint arrangements and other contractual arrangements with third parties, including arrangements where other entities operate assets in which Suncor has ownership or other interests. These joint arrangements include, among others, those with respect to Syncrude, Fort Hills, In Situ assets, and operations in Suncor's E&P Canada and E&P International businesses. The success and timing of activities relating to assets and projects operated by others, or developed jointly with others, depend upon a number of factors that are outside of Suncor's control, including, among others, the timing and amount of capital expenditures, the timing and amount of operational and maintenance expenditures, the operator's expertise, financial resources and risk management practices, the approval of other participants, and the selection of technology.

These co-owners may have objectives and interests that do not coincide with and may conflict with Suncor's interests. Major capital decisions affecting joint arrangements may require agreement among the co-owners, while certain operational decisions may be made solely at the discretion of the operator of the applicable assets. While joint venture counterparties may generally seek consensus with respect to major decisions concerning the direction and operation of the assets and the development of projects, no assurance can be provided that the future demands or expectations of the parties relating to such assets and projects will be met satisfactorily or in a timely manner. Failure to satisfactorily meet demands or expectations by all of the parties may affect the company's participation in the operation of such assets or in the development of such projects, the company's ability to obtain or maintain necessary licences or approvals, or the timing for undertaking various activities. In addition, disputes may arise pertaining to the timing, funding and/or capital commitments with respect to projects that are being jointly developed, which could materially adversely affect the development of such projects and Suncor's business and operations.

The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

Financial Risks

Energy Trading and Risk Management Activities and the Exposure to Counterparties

The nature of Suncor's energy trading and risk management activities, which may make use of derivative financial instruments to manage its exposure to commodity price and other market risks, creates exposure to financial risks, which include, but are not limited to, the following:

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  Unfavourable movements in commodity prices, interest rates or foreign exchange could result in a financial or opportunity loss to the company;
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  A lack of counterparties, due to market conditions or other circumstances, could leave the company unable to liquidate or offset a position, or unable to do so at or near the previous market price;

62 2018 ANNUAL REPORT Suncor Energy Inc.

•
  The company may not receive funds or instruments from counterparties at the expected time or at all;
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  The counterparty could fail to perform an obligation owed to Suncor;
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  Loss as a result of human error or deficiency in the company's systems or controls; and
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  Loss as a result of contracts being unenforceable or transactions being inadequately documented.

The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition and results of operations.

Exchange Rate Fluctuations

The company's 2018 audited Consolidated Financial Statements are presented in Canadian dollars. The majority of Suncor's revenues from the sale of oil, natural gas and petroleum products are based on prices that are determined by, or referenced to, U.S. dollar benchmark prices, while the majority of Suncor's expenditures are realized in Canadian dollars. The company also owes a portion of its debt in U.S. dollars. Suncor's financial results, therefore, can be affected significantly by the exchange rates between the Canadian dollar and the U.S. dollar. The company also undertakes operations administered through international subsidiaries, and therefore, to a lesser extent, Suncor's results can be affected by the exchange rates between the Canadian dollar and the euro, the British pound and the Norwegian krone. These exchange rates may vary substantially and may give rise to favourable or unfavourable foreign currency exposure. A decrease in the value of the Canadian dollar relative to the U.S. dollar will increase the revenues received from the sale of commodities. An increase in the value of the Canadian dollar relative to the U.S. dollar will decrease revenue received from the sale of commodities. A decrease in the value of the Canadian dollar relative to the U.S. dollar from the previous balance sheet date increases the amount of Canadian dollars required to settle U.S. dollar denominated obligations. As at December 31, 2018, the Canadian dollar weakened in relation to the U.S. dollar to $0.73 from $0.80 at the start of 2018. Exchange rate fluctuations could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

Interest Rate Risk

The company is exposed to fluctuations in short-term Canadian and U.S. interest rates as Suncor maintains a portion of its debt capacity in revolving and floating rate credit facilities and commercial paper, and invests surplus cash in short-term debt instruments and money market instruments. Suncor is also exposed to interest rate risk when debt instruments are maturing and require refinancing, or when new debt capital needs to be raised. The company is also exposed to changes in interest rates on derivative instruments used to manage the debt portfolio, including hedges of prospective new debt issuances. Unfavourable changes in interest rates could have a material adverse effect on Suncor's business, financial condition and results of operations.

Issuance of Debt and Debt Covenants

Suncor expects that future capital expenditures will be financed out of cash and cash equivalents balances, cash flow provided by operating activities, available committed credit facilities, issuing commercial paper and accessing capital markets. This ability is dependent on, among other factors, commodity prices, the overall state of the capital markets, and financial institutions and investor appetite for investments in the energy industry generally, and the company's securities in particular. To the extent that external sources of capital become limited or unavailable or available on unfavourable terms, the ability to make capital investments and maintain existing properties may be constrained.

If the company finances capital expenditures in whole or in part with debt, that may increase its debt levels above industry standards for oil and gas companies of similar size. Depending on future development and growth plans, additional debt financing may be required that may not be available or, if available, may not be available on favourable terms, including higher interest rates and fees. Neither the articles of Suncor (the Articles) nor its by-laws limit the amount of indebtedness that may be incurred; however, Suncor is subject to covenants in its existing credit facilities and seeks to avoid an unfavourable cost of debt. The level of the company's indebtedness, from time to time, could impair its ability to obtain additional financing on a timely basis to take advantage of business opportunities that may arise and could negatively affect its credit ratings.

Suncor is required to comply with financial and operating covenants under existing credit facilities and debt securities. Covenants are reviewed based on actual and forecast results and the company has the ability to make changes to its development plans, capital structure and/or dividend policy to comply with covenants under the credit facilities. If Suncor does not comply with the covenants under its credit facilities and debt securities, there is a risk that repayment could be accelerated and/or the company's access to capital could be restricted or only be available on unfavourable terms.

Rating agencies regularly evaluate the company, including its subsidiaries. Their ratings of Suncor's long-term and short-term debt are based on a number of factors, including the company's financial strength, as well as factors not entirely within its control, including conditions affecting the oil and gas industry generally, and the wider state of the economy. Credit ratings may be important to customers or counterparties when Suncor competes in certain markets and when it seeks to engage in certain transactions, including

2018 ANNUAL REPORT Suncor Energy Inc. 63

transactions involving over-the-counter derivatives. There is a risk that one or more of Suncor's credit ratings could be downgraded, which could potentially limit its access to private and public credit markets and increase the company's cost of borrowing.

The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

Royalties and Taxes

Suncor is subject to royalties and taxes imposed by governments in numerous jurisdictions.

Royalties can be impacted by changes in crude oil and natural gas pricing, production volumes, and capital and operating costs, by changes to existing legislation or PSCs, and by results of regulatory audits of prior year filings and other such events. The final determination of these events may have a material impact on the company's royalties expense.

An increase in Suncor's royalties expense, income taxes, property taxes, carbon taxes, levies, tariffs, duties, quotas, border taxes, and other taxes and government-imposed compliance costs, could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

Dividends and Share Repurchases

Suncor's payment of future dividends on its common shares and future share repurchases by Suncor of its common shares will be dependent on, among other things, legislative and stock exchange requirements, the company's financial condition, results of operations, cash flow, the need for funds to finance ongoing operations and growth projects, debt covenants and other business considerations as the company's Board of Directors considers relevant. There can be no assurance that Suncor will continue to pay dividends or repurchase shares in the future.

E&P Reserves Replacement

Suncor's future offshore production, and therefore its cash flows and results of operations from E&P, are highly dependent upon success in exploiting its current reserves base and acquiring or discovering additional reserves. Without additions to its E&P reserves through exploration, acquisition or development activities, Suncor's production from its offshore assets will decline over time as reserves are depleted. The business of exploring for, developing or acquiring reserves is capital intensive. To the extent Suncor's cash flow is insufficient to fund capital expenditures and external sources of capital become limited or unavailable, Suncor's ability to make the necessary capital investments to maintain and expand its reserves will be impaired. In addition, Suncor may be unable to develop or acquire additional reserves to replace its crude oil and natural gas production at acceptable costs.

Uncertainties Affecting Reserves Estimates

There are numerous uncertainties inherent in estimating quantities of reserves, including many factors beyond the company's control. Suncor's actual production, revenues, royalties, taxes, and development and operating expenditures with respect to the company's reserves will vary from its estimates, and such variances could be material. Refer to the Statement of Reserves Data and Other Oil and Gas Information – Significant Risk Factors and Uncertainties Affecting Reserves in the 2018 AIF.

Third-Party Service Providers

Suncor's businesses are reliant on the operational integrity of a large number of third-party service providers, including input and output commodity transport (pipelines, rail, trucking, marine) and utilities associated with various Suncor and jointly owned facilities, including electricity. A disruption in service or limited availability by one of these third parties can also have a dramatic impact on Suncor's operations and growth plans. Pipeline constraints that affect takeaway capacity or supply of inputs, such as hydrogen and power for example, could impact the company's ability to produce at capacity levels. Disruptions in pipeline service could adversely affect commodity prices, Suncor's price realizations, refining operations and sales volumes, or limit the company's ability to produce and deliver production. These interruptions may be caused by the inability of the pipeline to operate or by the oversupply of feedstock into the system that exceeds pipeline capacity. Short-term operational constraints on pipeline systems arising from pipeline interruption and/or increased supply of crude oil have occurred in the past and could occur in the future. There is a risk that third-party outages could impact Suncor's production or price realizations, which could have a material adverse effect on Suncor's business, financial condition and results of operations.

Foreign Operations

The company has operations in a number of countries with different political, economic and social systems. As a result, the company's operations and related assets are subject to a number of risks and other uncertainties arising from foreign government sovereignty over the company's international operations, which may include, among other things:

•
  Currency restrictions and restrictions on repatriation of funds;
•
  Loss of revenue, property and equipment as a result of expropriation, nationalization, war, insurrection and geopolitical and other political risks;
•
  Increases in taxes and government royalties;
•
  Compliance with existing and emerging anti-corruption laws, including the Foreign Corrupt Practices Act (United States), the Corruption of Foreign Public Officials Act (Canada) and the United Kingdom Bribery Act;

64 2018 ANNUAL REPORT Suncor Energy Inc.

•
  Renegotiation of contracts with government entities and quasi-government agencies;
•
  Changes in laws and policies governing operations of foreign-based companies; and
•
  Economic and legal sanctions (such as restrictions against countries experiencing political violence, or countries that other governments may deem to sponsor terrorism).

If a dispute arises in the company's foreign operations, the company may be subject to the exclusive jurisdiction of foreign courts or may not be able to subject foreign persons to the jurisdiction of a court in Canada or the U.S. In addition, as a result of activities in these areas and a continuing evolution of an international framework for corporate responsibility and accountability for international crimes, there is a risk the company could also be exposed to potential claims for alleged breaches of international or local law.

The impact that future potential terrorist attacks, regional hostilities or political violence, such as that experienced in Libya and Syria, may have on the oil and gas industry, and on our operations in particular, is not known at this time. This uncertainty may affect operations in unpredictable ways, including disruptions of fuel supplies and markets, particularly crude oil, and the possibility that infrastructure facilities, including pipelines, production facilities, processing plants and refineries, could be direct targets of, or collateral damage of, an act of terror, political violence or war. Suncor may be required to incur significant costs in the future to safeguard our assets against terrorist activities or to remediate potential damage to our facilities. There can be no assurance that Suncor will be successful in protecting itself against these risks and the related safety and financial consequences.

Despite Suncor's training and policies around bribery and other forms of corruption, there is a risk that Suncor, or some of its employees or contractors, could be charged with bribery or corruption. Any of these violations could result in onerous penalties. Even allegations of such behaviour could impair Suncor's ability to work with governments or non-government organizations and could result in the formal exclusion of Suncor from a country or area, sanctions, fines, project cancellations or delays, the inability to raise or borrow capital, reputational impacts and increased investor concern.

The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.

Skills, Resource Shortage and Reliance on Key Personnel

The successful operation of Suncor's businesses and the company's ability to expand operations will depend upon the availability of, and competition for, skilled labour and materials supply. There is a risk that the company may have difficulty sourcing the required labour for current and future operations. The risk could manifest itself primarily through an inability to recruit new staff without a dilution of talent, to train, develop and retain high-quality and experienced staff without unacceptably high attrition, and to satisfy an employee's work/life balance and desire for competitive compensation. The labour market in Alberta has been historically tight, and, while the current economic situation has partially moderated this effect, it remains a risk to be managed. The increasing age of the company's existing workforce adds further pressure. The availability of competent and skilled contractors for current and future operations is also a risk depending on market conditions. Materials may also be in short supply due to smaller labour forces in many manufacturing operations. Suncor's ability to operate safely and effectively and complete all projects on time and on budget has the potential to be significantly impacted by these risks and this impact could be material.

The company's success also depends in large measure on certain key personnel. The loss of the services of such key personnel could have a material adverse effect on the company. The contributions of the existing management team to the immediate and near-term operations of the company are likely to continue to be of central importance for the foreseeable future.

Labour Relations

Hourly employees at Suncor's Oil Sands operations facilities (excluding MacKay River), all of the company's refineries, and the majority of the company's terminal and distribution operations are represented by labour unions or employee associations. Approximately 32% of the company's employees were covered by collective agreements at the end of 2018. Negotiations for new collective agreements are in progress for 12 facilities across the company. Any work interruptions involving the company's employees (including as a result of a strike or lockout), contract trades utilized in the company's projects or operations, or any jointly owned facilities operated by another entity present a significant risk to the company and could have a material adverse effect on Suncor's business, financial condition and results of operations.

Land Claims and Aboriginal Consultation

Aboriginal Peoples have claimed Aboriginal title and rights to portions of Western Canada. In addition, Aboriginal Peoples have filed claims against industry participants relating in part to land claims, which may affect the company's business.

The requirement to consult with Aboriginal Peoples in respect of oil and gas projects and related infrastructure has also increased in recent years. In addition, the Canadian federal government and the provincial government in Alberta have made a commitment to renew their relationships with the Aboriginal Peoples of Canada. The

2018 ANNUAL REPORT Suncor Energy Inc. 65

federal government has stated it now fully supports the United Nations Declaration on the Rights of Indigenous Peoples (the Declaration) without qualification and that Canada intends "nothing less than to adopt and implement the Declaration in accordance with the Canadian Constitution". Recently, the federal government announced its support of a private member's bill, Bill C-262, An Act to ensure that the laws of Canada are in harmony with the United Nations Declaration on the Rights of Indigenous Peoples, promoting the full adoption of the Declaration into Canadian law. It is anticipated that the Bill will be passed by the Senate and become law in the second quarter of 2019. The Alberta government is also currently exploring how best to implement the principles and objectives of the Declaration in a way that is consistent with the Constitution and Alberta law. At this time, it is unclear how the Declaration will be adopted into Canadian law and the impact of the Declaration on the Crown's duty to consult with Aboriginal Peoples.

Suncor is unable to assess the effect, if any, that any such land claims, consultation requirements with Aboriginal Peoples or adoption of the Declaration into Canadian law may have on Suncor's business; however, the impact may be material.

Litigation Risk

There is a risk that Suncor or entities in which it has an interest may be subject to litigation, and claims under such litigation may be material. Various types of claims may be raised in these proceedings, including, but not limited to, environmental damage, climate change and the impacts thereof, breach of contract, product liability, antitrust, bribery and other forms of corruption, tax, patent infringement, disclosure, employment matters and in relation to an attack, breach or unauthorized access to Suncor's information technology and infrastructure. Litigation is subject to uncertainty and it is possible that there could be material adverse developments in pending or future cases. Unfavourable outcomes or settlements of litigation could encourage the commencement of additional litigation. Suncor may also be subject to adverse publicity and reputational impacts associated with such matters, regardless of whether Suncor is ultimately found liable. There is a risk that the outcome of such litigation may be materially adverse to the company and/or the company may be required to incur significant expenses or devote significant resources in defence against such litigation, the success of which cannot be guaranteed.

Trade Risk Relating to CUSMA

If the Canada-United States-Mexico Agreement (CUSMA) is ratified, Canada will no longer be subject to the proportionality provisions in the North American Free Trade Agreement's (NAFTA) energy chapter. Ratification should thus permit the expansion of oil and gas exports beyond the U.S., and a change to the oil and gas rules of origin, which will allow Canadian exporters to more easily qualify for duty-free treatment for shipments to the U.S. Canada must, however, notify the U.S. of its intention to enter into free trade talks with any "non-market economies" under CUSMA, which may include China or any other importers of Canadian oil and gas exports. Although CUSMA has been signed, legislators from each of the three countries have yet to ratify CUSMA according to their own legislative processes before it goes into effect and replaces NAFTA. The outcome of the ratification process in each of these countries is not complete and is therefore uncertain. If CUSMA is not ratified and adopted by all three countries, this may alter the terms of trade for energy resources in a manner adverse to the company. This could have a material adverse effect on the sale and transportation of Suncor's products within North America, which could have a significant negative impact on Suncor's business, financial condition and results from operations.

Control Environment

Based on their inherent limitations, disclosure controls and procedures and internal controls 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. Failure to adequately prevent, detect and correct misstatements could have a material adverse effect on Suncor's business, financial condition and results of operations.

66 2018 ANNUAL REPORT Suncor Energy Inc.

11. OTHER ITEMS

Control Environment

Based on their evaluation as of December 31, 2018, 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 of December 31, 2018, 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 year ended December 31, 2018 that have materially affected, or are reasonably likely to materially affect, the company's internal control over financial reporting. Management will continue to periodically evaluate the company's disclosure controls and procedures and internal control over financial reporting and will make any modifications from time to time as deemed necessary.

The effectiveness of our internal control over financial reporting as at December 31, 2018 was audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm, as stated in their report, which is included in our audited Consolidated Financial Statements for the year ended December 31, 2018.

Based on their inherent limitations, disclosure controls and procedures and internal control over financial reporting may not prevent or detect misstatements, and even those controls determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.

Corporate Guidance

There have been no changes to the corporate guidance ranges previously issued on December 14, 2018. For further details and advisories regarding Suncor's 2019 corporate guidance, see www.suncor.com/guidance.

2018 ANNUAL REPORT Suncor Energy Inc. 67

12. ADVISORIES

Non-GAAP Financial Measures

Certain financial measures in this MD&A – namely operating earnings (loss), ROCE, funds from (used in) operations, discretionary free funds flow, Oil Sands operations cash operating costs, In Situ cash operating costs, Fort Hills cash operating costs, Syncrude cash operating costs, refining margin, refining operating expense and LIFO inventory valuation methodology – are not prescribed by GAAP. These non-GAAP financial measures are included because management uses the information to analyze business performance, leverage and liquidity, 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 measures are calculated and disclosed on a consistent basis from period to period. Specific adjusting items may only be relevant in certain periods.

(a) Operating Earnings (Loss)

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 operating earnings (loss) to evaluate operating performance, because management believes it provides better comparability between periods. For the years ended December 31, 2018, December 31, 2017 and December 31, 2016, consolidated operating earnings (loss) are reconciled to net earnings (loss) in the Financial Information section of this MD&A and operating earnings (loss) for each segment are reconciled to net earnings (loss) in the Segment Results and Analysis section of the MD&A. Operating earnings (loss) for the three months ended December 31, 2018 and December 31, 2017 are reconciled to net earnings (loss) below.

(b) Bridge Analyses of Operating Earnings

Throughout this MD&A, the company presents charts that illustrate the change in operating earnings from the comparative period through key variance factors. These factors are analyzed in the Operating Earnings narratives following the bridge analyses in that particular section of the MD&A. These bridge analyses are presented because management uses this presentation to analyze performance.

•
  The factor for Sales Volumes and Mix is calculated based on sales volumes and mix for the Oil Sands and Exploration and Production segments and throughput volumes and mix for the Refining and Marketing segment.
•
  The factor for Price, Margin and Other Revenue includes upstream price realizations before royalties, with the exception of Libya, which is net of royalties. Also included are refining and marketing margins, other operating revenues, 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 inventory valuation includes the after-tax impact of the FIFO method of inventory valuation in the company's 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, as both represent inventory valuation adjustments.
•
  The factor for Royalties excludes the impact of Libya, as royalties in Libya are taken into account in Price, Margin and Other Revenue as described above.
•
  The factor for Operating and Transportation Expense includes project start-up costs, operating, selling and general expense, and transportation expense.
•
  The factor for Financing Expense and Other Income includes financing expenses, other income, operational foreign exchange gains and losses, changes in gains and losses on disposal of assets that are not operating earnings adjustments, changes in statutory income tax rates, other income tax adjustments and the net impact of the sale of the lubricants business in the first quarter of 2017.

(c) Return on Capital Employed (ROCE)

ROCE is a non-GAAP financial measure that management uses to analyze operating performance and the efficiency of Suncor's capital allocation process. 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.

68 2018 ANNUAL REPORT Suncor Energy Inc.

The company presents two ROCE calculations – one including and one excluding the impacts on capital employed of major projects in progress. Major projects in progress includes accumulated capital expenditures and capitalized interest for significant projects still under construction or in the process of being commissioned, and acquired assets that are still being evaluated. Management uses ROCE excluding the impacts of major projects in progress on capital employed to assess performance of operating assets.

Year ended December 31 ($ millions, except as noted) |  |  |  | 2018 |  | 2017 |  | 2016 |  |
Adjustments to net earnings |  |  |  |  |  |  |  |  |  |
| Net earnings attributed to common shareholders |  |  |  | 3 293 |  | 4 458 |  | 434 |  |
| Add after-tax amounts for: |  |  |  |  |  |  |  |  |  |
|  | Unrealized foreign exchange loss (gain) on U.S. dollar denominated debt |  |  |  | 989 |  | (702 | ) | (524 | ) |
|  | Net interest expense |  |  |  | 541 |  | 158 |  | 304 |  |
|  | A |  | 4 823 |  | 3 914 |  | 214 |  |
Capital employed – beginning of twelve-month period |  |  |  |  |  |  |  |
| Net debt |  |  |  | 12 907 |  | 14 414 |  | 11 254 |  |
| Shareholders' equity |  |  |  | 45 383 |  | 44 630 |  | 39 039 |  |
|  |  |  | 58 290 |  | 59 044 |  | 50 293 |  |
Capital employed – end of twelve-month period |  |  |  |  |  |  |  |
| Net debt |  |  |  | 15 129 |  | 12 907 |  | 14 414 |  |
| Shareholders' equity |  |  |  | 44 005 |  | 45 383 |  | 44 630 |  |
|  |  |  | 59 134 |  | 58 290 |  | 59 044 |  |
Average capital employed |  | B |  | 60 347 |  | 58 667 |  | 57 999 |  |
ROCE – including major projects in progress (%) |  | A/B |  | 8.0 |  | 6.7 |  | 0.4 |  |
Average capitalized costs related to major projects in progress |  | C |  | 1 412 |  | 12 901 |  | 10 147 |  |
ROCE – excluding major projects in progress (%) |  | A/(B-C) |  | 8.2 |  | 8.6 |  | 0.5 |  |

2018 ANNUAL REPORT Suncor Energy Inc. 69

(d) Funds from (used in) Operations and Discretionary Free Funds Flow

Funds from (used in) operations is a non-GAAP financial measure that adjusts a GAAP measure – cash flow provided by (used in) 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 include, among other factors, the timing of offshore feedstock purchases and payments for fuel and income taxes, and the timing of cash flows related to accounts receivable and accounts payable, which management believes reduces comparability between periods.

|  | Oil Sands |  | Exploration and Production |  | Refining and Marketing |  |
Year ended December 31 ($ millions) |  | 2018 |  | 2017 |  | 2016 |  | 2018 |  | 2017 |  | 2016 |  | 2018 |  | 2017 |  | 2016 |  |
Net (loss) earnings |  | 853 |  | 1 009 |  | (1 149 | ) | 808 |  | 732 |  | 190 |  | 3 153 |  | 2 658 |  | 1 890 |  |
Adjustments for: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
| Depreciation, depletion, amortization and impairment |  | 4 024 |  | 3 782 |  | 3 864 |  | 967 |  | 1 028 |  | 1 381 |  | 683 |  | 685 |  | 702 |  |
| Deferred income taxes |  | 351 |  | 170 |  | (78 | ) | (112 | ) | (113 | ) | (506 | ) | 39 |  | (138 | ) | 12 |  |
| Accretion |  | 209 |  | 195 |  | 208 |  | 48 |  | 45 |  | 53 |  | 7 |  | 7 |  | 7 |  |
| Unrealized foreign exchange (gain) loss on U.S. dollar denominated debt |  | — |  | — |  | — |  | — |  | — |  | — |  | — |  | — |  | — |  |
| Change in fair value of financial instruments and trading inventory |  | (61 | ) | 2 |  | 19 |  | — |  | — |  | — |  | (20 | ) | 9 |  | 27 |  |
| Loss on debt extinguishment |  | — |  | — |  | — |  | — |  | — |  | — |  | — |  | — |  | — |  |
| (Gain) loss on disposal of assets |  | (108 | ) | (50 | ) | (33 | ) | 91 |  | — |  | — |  | (7 | ) | (354 | ) | (35 | ) |
| Share-based compensation |  | (28 | ) | (3 | ) | 41 |  | (5 | ) | 6 |  | 12 |  | (19 | ) | 4 |  | 21 |  |
| Exploration expenses |  | — |  | — |  | — |  | 11 |  | 41 |  | 204 |  | — |  | — |  | — |  |
| Settlement of decommissioning and restoration liabilities |  | (428 | ) | (305 | ) | (248 | ) | (23 | ) | (31 | ) | (1 | ) | (17 | ) | (17 | ) | (20 | ) |
| Other |  | 58 |  | (62 | ) | 45 |  | 84 |  | 17 |  | (20 | ) | (25 | ) | (13 | ) | 2 |  |
Funds from (used in) operations |  | 4 870 |  | 4 738 |  | 2 669 |  | 1 869 |  | 1 725 |  | 1 313 |  | 3 794 |  | 2 841 |  | 2 606 |  |
(Increase) decrease in non-cash working capital |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Cash flow provided by operating activities |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |

70 2018 ANNUAL REPORT Suncor Energy Inc.

|  | Corporate, Energy Trading and Eliminations |  | Total |  |
Year ended December 31 ($ millions) |  | 2018 |  | 2017 |  | 2016 |  | 2018 |  | 2017 |  | 2016 |  |
Net (loss) earnings |  | (1 521 | ) | 59 |  | (486 | ) | 3 293 |  | 4 458 |  | 445 |  |
Adjustments for: |  |  |  |  |  |  |  |  |  |  |  |  |  |
| Depreciation, depletion, amortization and impairment |  | 64 |  | 106 |  | 170 |  | 5 738 |  | 5 601 |  | 6 117 |  |
| Deferred income taxes |  | 162 |  | 330 |  | 60 |  | 440 |  | 249 |  | (512 | ) |
| Accretion of liabilities |  | 2 |  | — |  | 1 |  | 266 |  | 247 |  | 269 |  |
| Unrealized foreign exchange (gain) loss on U.S. dollar denominated debt |  | 1 090 |  | (771 | ) | (458 | ) | 1 090 |  | (771 | ) | (458 | ) |
| Change in fair value of financial instruments and trading inventory |  | (98 | ) | 117 |  | (53 | ) | (179 | ) | 128 |  | (7 | ) |
| Loss on debt extinguishment |  | 3 |  | 51 |  | 99 |  | 3 |  | 51 |  | 99 |  |
| Gain on disposal of assets |  | — |  | (70 | ) | — |  | (24 | ) | (474 | ) | (68 | ) |
| Share-based compensation |  | (65 | ) | 24 |  | 68 |  | (117 | ) | 31 |  | 142 |  |
| Exploration expenses |  | — |  | — |  | — |  | 11 |  | 41 |  | 204 |  |
| Settlement of decommissioning and restoration liabilities |  | (1 | ) | — |  | — |  | (469 | ) | (353 | ) | (269 | ) |
| Other |  | 3 |  | (11 | ) | (1 | ) | 120 |  | (69 | ) | 26 |  |
Funds (used in) from operations |  | (361 | ) | (165 | ) | (600 | ) | 10 172 |  | 9 139 |  | 5 988 |  |
(Increase) decrease in non-cash working capital |  |  |  |  |  |  |  | 408 |  | (173 | ) | (308 | ) |
Cash flow provided by operating activities |  |  |  |  |  |  |  | 10 580 |  | 8 966 |  | 5 680 |  |

Discretionary free funds flow is a non-GAAP financial measure that is calculated by taking funds from operations and subtracting sustaining capital, inclusive of associated capitalized interest, and dividends. Discretionary free funds flow reflects cash available for increasing distributions to shareholders and to fund growth investments. Management uses discretionary free funds flow to measure the capacity of the company to increase returns to shareholders and grow the business. The following is a reconciliation of discretionary free funds flow for Suncor's last three years of operations.

($ millions) |  | 2018 |  | 2017 |  | 2016 |  |
Funds from operations |  | 10 172 |  | 9 139 |  | 5 988 |  |
Sustaining capital and dividends |  | (6 310 | ) | (5 083 | ) | (4 191 | ) |
Discretionary free funds flow |  | 3 862 |  | 4 056 |  | 1 797 |  |

(e) Oil Sands Operations, In Situ, Fort Hills and Syncrude Cash Operating Costs

Oil Sands operations, In Situ, Fort Hills and Syncrude cash operating costs are non-GAAP financial measures. Oil Sands operations cash operating costs are calculated by adjusting Oil Sands segment OS&G expense (a GAAP measure based on sales volumes) for i) costs pertaining to Fort Hills and Syncrude operations; ii) non production costs that management believes do not relate to the production performance of Oil Sands operations, including, but not limited to, share-based compensation adjustments, research and the expense recorded as part of a non-monetary arrangement involving a third party processor; iii) revenues associated with excess capacity, including excess power generated and sold that is recorded in operating revenue; iv) project start-up costs; and v) the impacts of changes in inventory levels, such that the company is able to present cost information based on production volumes. To determine In Situ cash operating costs, Oil Sands operations cash operating costs are further adjusted to remove costs pertaining to Oil Sands operations mining and upgrading. Syncrude and Fort Hills cash operating costs are calculated by adjusting Syncrude OS&G expense and Fort Hills OS&G expense, respectively, for non-production costs that management believes do not relate to the production performance of Syncrude operations or Fort Hills operations, respectively, including, but not limited to, share-based compensation, research and project start-up costs, if applicable. Oil Sands operations, Fort Hills and Syncrude cash operating costs are reconciled in the Segment Results and Analysis – Oil Sands section of this document. Management uses cash operating costs to measure operating performance. Oil Sands operations cash operating costs in 2018 were $3.870 billion and included $740 million related to In Situ production for In Situ cash operating costs per barrel of $8.45, based on total In Situ production of 240,000 bbls/d.

2018 ANNUAL REPORT Suncor Energy Inc. 71

(f) Refining Margin and Refining Operating Expense

Refining margin and refining operating expense are non-GAAP financial measures. Refining margin is calculated by adjusting R&M segment operating revenues, other income and purchases of crude oil and products (GAAP measures) for non-refining margin pertaining to the company's supply, marketing and ethanol businesses, and the company's former lubricants business, which was disposed of in early 2017. Refinery operating expense is calculated by adjusting R&M segment OS&G for i) non-refining costs pertaining to the company's supply, marketing and ethanol businesses and the company's former lubricants business; 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 margin and refining operating expense to measure operating performance on a production barrel basis.

Year ended December 31 ($ millions, except as noted) |  | 2018 |  | 2017 |  | 2016 |  |
Refining margin reconciliation |  |  |  |  |  |  |  |
| Gross margin, operating revenues less purchases of crude oil and products(1) |  | 7 068 |  | 5 692 |  | 5 506 |  |
| Other income |  | 21 |  | 73 |  | 16 |  |
| Non-refining margin |  | (1 250 | ) | (1 546 | ) | (2 074 | ) |
| Refining margin |  | 5 839 |  | 4 219 |  | 3 448 |  |
| Refinery production(2) (mbbls) |  | 169 138 |  | 174 461 |  | 168 798 |  |
| Refining margin ($/bbl) |  | 34.50 |  | 24.20 |  | 20.45 |  |
Refining operating expense reconciliation |  |  |  |  |  |  |  |
| Operating, selling and general expense(1) |  | 1 979 |  | 1 950 |  | 2 147 |  |
| Non-refining costs |  | (1 078 | ) | (1 068 | ) | (1 287 | ) |
| Refining operating expense |  | 901 |  | 882 |  | 860 |  |
| Refinery production(2) |  | 169 138 |  | 174 461 |  | 168 798 |  |
| Refining operating expense ($/bbl) |  | 5.35 |  | 5.05 |  | 5.10 |  |

(1)
  2017 and 2016 have been restated due to IFRS 15 adoption and for the removal of risk management activities.
(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.

(g) Impact of First-in, First-out Inventory Valuation on Refining and Marketing Net Earnings

GAAP requires the use of a FIFO valuation methodology. For Suncor, this results in a lag between the sales prices for refined products, which reflects current market conditions, and the amount recorded as the cost of sale for the related refinery feedstock, which reflects market conditions at the time when the feedstock was purchased.

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 United States GAAP (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.

72 2018 ANNUAL REPORT Suncor Energy Inc.

(h) Operating Earnings Reconciliations – Fourth Quarter 2018 and 2017

Three months ended December 31 |  | Oil Sands |  | Exploration and Production |  | Refining and Marketing |  | Corporate, Energy Trading and Eliminations |  | Total |  |
($ millions) |  | 2018 |  | 2017 |  | 2018 |  | 2017 |  | 2018 |  | 2017 |  | 2018 |  | 2017 |  | 2018 |  | 2017 |  |
Net earnings (loss) as reported |  | (393 | ) | 670 |  | (115 | ) | 217 |  | 723 |  | 886 |  | (495 | ) | (391 | ) | (280 | ) | 1 382 |  |
Unrealized foreign exchange loss on U.S. dollar denominated debt |  | — |  | — |  | — |  | — |  | — |  | — |  | 637 |  | 91 |  | 637 |  | 91 |  |
Non-cash loss on equity investment |  | — |  | — |  | 223 |  | — |  | — |  | — |  | — |  | — |  | 223 |  | — |  |
Impact of income tax rate adjustment on deferred taxes |  | — |  | — |  | — |  | 14 |  | — |  | (140 | ) | — |  | 2 |  | — |  | (124 | ) |
Insurance Proceeds |  | — |  | (55 | ) | — |  | — |  | — |  | — |  | — |  | — |  | — |  | (55 | ) |
Loss on early repayment of long term debt |  | — |  | — |  | — |  | — |  | — |  | — |  | — |  | 18 |  | — |  | 18 |  |
Non-cash mark to market gain on interest rate swaps |  | — |  | — |  | — |  | — |  | — |  | — |  | — |  | (2 | ) | — |  | (2 | ) |
Operating earnings (loss) |  | (393 | ) | 615 |  | 108 |  | 231 |  | 723 |  | 746 |  | 142 |  | (282 | ) | 580 |  | 1 310 |  |

(i) Funds from Operations Reconciliations – Fourth Quarter 2018 and 2017

Three months ended December 31 |  | Oil Sands |  | Exploration and Production |  | Refining and Marketing |  | Corporate, Energy Trading and Eliminations |  | Total |  |
($ millions) |  | 2018 |  | 2017 |  | 2018 |  | 2017 |  | 2018 |  | 2017 |  | 2018 |  | 2017 |  | 2018 |  | 2017 |  |
Net earnings (loss) |  | (393 | ) | 670 |  | (115 | ) | 217 |  | 723 |  | 886 |  | (495 | ) | (391 | ) | (280 | ) | 1 382 |  |
Adjustments for: |  | — |  |  |  | — |  |  |  | — |  |  |  | — |  |  |  |  |  |  |  |
| Depreciation, depletion, amortization and impairment |  | 1 019 |  | 1 055 |  | 199 |  | 219 |  | 184 |  | 196 |  | 17 |  | 18 |  | 1 419 |  | 1 488 |  |
| Deferred income taxes |  | 89 |  | 181 |  | 3 |  | 5 |  | (51 | ) | (161 | ) | 119 |  | 78 |  | 160 |  | 103 |  |
| Accretion of liabilities |  | 53 |  | 49 |  | 12 |  | 12 |  | 2 |  | 2 |  | — |  | — |  | 67 |  | 63 |  |
| Unrealized foreign exchange loss on U.S. dollar denominated debt |  | — |  | — |  | — |  | — |  | — |  | — |  | 688 |  | 74 |  | 688 |  | 74 |  |
| Change in fair value of financial instruments and trading inventory |  | (74 | ) | 2 |  | — |  | — |  | (15 | ) | 9 |  | (59 | ) | 5 |  | (148 | ) | 16 |  |
| Gain on disposal of assets |  | (1 | ) | (46 | ) | 253 |  | — |  | (2 | ) | (2 | ) | — |  | — |  | 250 |  | (48 | ) |
| Loss on debt extinguishment |  | — |  | — |  | — |  | — |  | — |  | — |  | 3 |  | 26 |  | 3 |  | 26 |  |
| Share-based compensation |  | (22 | ) | 34 |  | (3 | ) | 4 |  | (10 | ) | 17 |  | (53 | ) | 61 |  | (88 | ) | 116 |  |
| Exploration expenses |  | — |  | — |  | 11 |  | — |  | — |  | — |  | — |  | — |  | 11 |  | — |  |
| Settlement of decommissioning and restoration liabilities |  | (91 | ) | (76 | ) | (8 | ) | (15 | ) | (5 | ) | (7 | ) | — |  | — |  | (104 | ) | (98 | ) |
| Other |  | 21 |  | (89 | ) | 15 |  | (11 | ) | — |  | (5 | ) | (7 | ) | (1 | ) | 29 |  | (106 | ) |
Funds from (used in) operations |  | 601 |  | 1 780 |  | 367 |  | 431 |  | 826 |  | 935 |  | 213 |  | (130 | ) | 2 007 |  | 3 016 |  |
Increase (decrease) in non-cash working capital |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | 1 033 |  | (261 | ) |
Cash flow provided by (used in) operating activities |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | 3 040 |  | 2 755 |  |

2018 ANNUAL REPORT Suncor Energy Inc. 73

Measurement Conversions

Certain crude oil and natural gas liquids volumes have been converted to mcfe or mmcfe on the basis of one bbl to six mcf. Also, certain natural gas volumes have been converted to boe or mboe on the same basis. Any figure presented in mcfe, mmcfe, boe or mboe may be misleading, particularly if used in isolation. A conversion ratio of one bbl of crude oil or natural gas liquids to six mcf of natural gas is based on an energy equivalency conversion method primarily applicable at the burner tip and does not necessarily represent value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, conversion on a 6:1 basis may be misleading as an indication of value.

Common Abbreviations

The following is a list of abbreviations that may be used in this MD&A:

Measurement
bbl |  | barrel
bbls/d |  | barrels per day
mbbls/d |  | thousands of barrels per day
boe |  | barrels of oil equivalent
boe/d |  | barrels of oil equivalent per day
mboe |  | thousands of barrels of oil equivalent
mboe/d |  | thousands of barrels of oil equivalent per day
mcf |  | thousands of cubic feet of natural gas
mcfe |  | thousands of cubic feet of natural gas equivalent
mmcf |  | millions of cubic feet of natural gas
mmcf/d |  | millions of cubic feet of natural gas per day
mmcfe |  | millions of cubic feet of natural gas equivalent
mmcfe/d |  | millions of cubic feet of natural gas equivalent per day
m3 |  | cubic metres
MW |  | Megawatts
MWh |  | Megawatt hour
Places and Currencies
U.S. |  | United States
U.K. |  | United Kingdom
B.C. |  | British Columbia
$ or Cdn$ |  | Canadian dollars
US$ |  | United States dollars
£ |  | Pounds sterling
€ |  | Euros
Financial and Business Environment
DD&A |  | Depreciation, depletion and amortization
WTI |  | West Texas Intermediate
WCS |  | Western Canadian Select
SCO |  | Synthetic crude oil
MSW |  | Mixed Sweet Blend
NYMEX |  | New York Mercantile Exchange

Forward-Looking Information

This MD&A contains certain forward-looking statements and forward-looking information (collectively, forward-looking statements) within the meaning of applicable Canadian and U.S. securities laws 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 and resources 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 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 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", "potential", "future", "opportunity", "would", "priority", "strategy", "aim" and similar expressions.

Forward-looking statements in this MD&A include references to:

Suncor's strategy, business plans and expectations about projects, the performance of assets, production volumes and capital expenditures, including:

•
  Suncor's strategies and priorities, including delivering competitive and sustainable returns to shareholders and aiming to consistently grow these returns by focusing on operational excellence initiatives, including capital discipline with asset reliability and optimization, long-term profitable growth and the company's commitment to environmental stewardship and sustainability, and the key components of its strategy, including profitably operating and developing the

74 2018 ANNUAL REPORT Suncor Energy Inc.

company's reserves, optimizing value through integration and secured market access, achieving industry-leading unit costs in each business segment, and being an industry leader in sustainable development;

•
  Suncor's belief that it is well positioned to succeed due to its competitive advantages of an industry-leading long-life, low-decline oil sands reserves base, a highly efficient, tightly integrated downstream business, an offshore business that provides geographically diversified cash flow, financial strength, and industry expertise;
•
  The expectation that long-term value will be created for the company through structural cash flow growth as a result of projects and initiatives such as optimizing production rates at Fort Hills following the successful ramp up in 2018, Syncrude asset optimization, development of regional operating synergies and value developments and asset extensions within the company's offshore business, improvement strategies at existing assets, such as debottlenecks and the deployment of autonomous haul trucks, and the company's regional oil sands advantage; including the expectation that it will provide the company with the economies of scale required to further develop its in situ resources in a low cost manner under the company's replication strategy;
•
  The company's belief that driving down costs and a continued focus on improved productivity and reliability will help achieve maximum value from the company's operations;
•
  Expectations about Hebron, including that it is expected to deliver 31,600 bbls/d, net to Suncor, when fully ramped up;
•
  Expectations about the Buzzard Phase 2 project, including that first oil from the project is expected in early 2021;
•
  Expectations about the Oda project, including that first oil from the project is expected in the second quarter of 2019;
•
  The belief that Suncor's midstream assets provide the logistical flexibility to move production to a wide range of markets;
•
  The opportunity to create structural cash flow growth improvements in Oil Sands through asset optimization initiatives like debottlenecks and further integration with Syncrude;
•
  Expectations for the Oil Sands segment, including the focus on safe, reliable and sustainable operations, the aim of the company's operational excellence initiatives to improve facility utilization and workforce productivity and the expectation that these initiatives will achieve steady production growth while reducing operating costs, the expectation that more than 150 autonomous haul trucks will be deployed across the company's business over approximately six years, the focus in 2019 on asset optimization and execution of safe and reliable operations at Fort Hills, Suncor's commitment to profitable growth, expectations for the interconnecting pipelines between Syncrude's Mildred Lake site and Suncor's Oil Sands Base plant, including that the lines will provide increased operational flexibility through the ability to transfer bitumen and gas oils between the two plants, enabling higher reliability and utilization and profit optimization and that they will be operational by the end of 2020, subject to finalized commercial terms and regulatory approval, and priorities around cost management and capital discipline at Oil Sands in 2019, including the expectation that the company will sustainably reduce controllable operating costs, and focus on managing investment opportunities through a robust asset development process which is focused on value creation;
•
  Expectations for the E&P segment, including the segment's focus on low-cost projects that deliver significant returns, cash flow and long-term value, and development activities offshore the east coast of Canada and in the U.K. North Sea intended to leverage existing facilities and infrastructure to provide incremental production and extend the productive life of existing fields which are planned to continue in 2019, along with development drilling at Hebron as part of the continued ramp-up phase and development work on the West White Rose Project, Buzzard Phase 2, Oda project and Fenja project;
•
  The expectation that the return to normal operations at the White Rose field will occur in a phased approach;
•
  The company's aim to operate its refineries at optimal levels of utilization to provide reliable offtake and secure pricing for a portion of the production from the Oil Sands segment, and Suncor's plan to continue to leverage the Petro-Canada® brand to increase sales volumes and non-petroleum revenues through the company's network of convenience stores and car washes;
•
  Additional transportation and storage agreements being evaluated and the asset backed trading program being developed;
•
  Expectations about the West White Rose Project, including the operator's original estimate that first oil would be achieved in 2022, the expectation of an update from the project operator in the first half of 2019, and that the company's share of peak oil production is expected to be 20,000 bbls/d;
•
  Plans for the projects and initiatives to which capital expenditures are anticipated to be directed in 2019 at Oil Sands operations, Syncrude, Fort Hills, E&P and R&M,

2018 ANNUAL REPORT Suncor Energy Inc. 75

and the expected impact of those projects and initiatives; and

•
  The expectation that well pads being designed and constructed will maintain existing production levels at Firebag and MacKay River in future years as production from existing well pads declines.

The expected timing, duration and impact of planned maintenance events, including:

•
  Planned Upgrader 1 maintenance at Oil Sands Base and turnaround events at Firebag and Fort Hills in the second quarter of 2019, Syncrude coker maintenance and maintenance events at Upgrader 2 in the third and fourth quarters of 2019, and planned maintenance expected to be completed at Fort Hills in the fourth quarter of 2019;
•
  The planned two-week maintenance event at Terra Nova scheduled to commence in the second quarter of 2019; and
•
  That a less intensive maintenance program is planned in 2019 for R&M following the completion of significant turnaround events in 2018 that will only focus on certain units within each of the refineries, including the planned two-week turnaround at the Commerce City refinery in the first quarter of 2019, the eight-week turnaround at the Sarnia refinery and the six-week turnaround at the Montreal refinery scheduled to begin in the second quarter of 2019 and the planned six-week turnaround at the Edmonton refinery scheduled to begin in the third quarter and extend into the fourth quarter of 2019.

Also:

•
  Economic sensitivities;
•
  The company's priority regarding returning value to shareholders, statements about the company's share repurchase program, and the company's belief in its ongoing ability to generate cash flow and its commitment to return cash to shareholders;
•
  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 condition or financial performance, including liquidity and capital resources;
•
  Suncor's planned 2019 capital spending program of $4.9 to $5.6 billion and the belief that the company will have the capital resources to fund its planned 2019 capital spending program 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 accessing capital markets;
•
  The objectives of the company's short-term investment portfolio and the expectation that the maximum weighted average term to maturity of the company's short-term investment portfolio will not exceed six months, and all investments will be with counterparties with investment grade debt ratings;
•
  Management of debt levels continuing to be a priority for Suncor given the company's long-term growth plans and future expected volatility in the commodity pricing environment, and Suncor's belief that a phased and flexible approach to existing and future growth projects should assist Suncor in maintaining its ability to manage project costs and debt levels;
•
  Management's maximum target for the company's net debt to funds from operations of less than 3.0 times; and
•
  Expectations with respect to changes to law and government policy.

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

76 2018 ANNUAL REPORT Suncor Energy Inc.

(including other oil sands projects) for goods and services and demands on infrastructure in Alberta's Wood Buffalo region and the surrounding area (including housing, roads and schools).

Factors that affect Suncor's E&P segment include, but are not limited to, volatility in crude oil and natural gas prices; operational risks and uncertainties associated with oil and gas activities, including unexpected formations or pressures, premature declines of reservoirs, fires, blow outs, equipment failures and other accidents, uncontrollable flows of crude oil, natural gas or well fluids, and pollution and other environmental risks; adverse weather conditions, which could disrupt output from producing assets or impact drilling programs, resulting in increased costs and/or delays in bringing on new production; political, economic and socio-economic 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 Suncor's R&M segment include, but are not limited to, fluctuations in demand and supply for refined products that impact the company's margins; market competition, including potential new market entrants; the company's ability to reliably operate refining and marketing facilities in order to meet production or sales targets; and risks and uncertainties affecting construction or planned maintenance schedules, including the availability of labour and other impacts of competing projects drawing on the same resources during the same time period.

Additional risks, uncertainties and other factors that could influence the financial and operating performance of all of Suncor's operating segments and activities include, but are not limited to, changes in general economic, market and business conditions, such as commodity prices, interest rates and currency exchange rates; 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 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, tariffs, quotas and other government-imposed compliance costs, and mandatory production curtailment orders and changes thereto; changes to laws and government policies that could impact the company's business, including environmental (including climate change), royalty and tax laws and policies; the ability and willingness of parties with whom Suncor has material relationships to perform their obligations to the company; the unavailability of, or outages to third-party infrastructure that could cause disruptions to production or prevent the company from being able to transport its products; the occurrence of a protracted operational outage, a major safety or environmental incident, or unexpected events such as fires (including forest fires), equipment failures and other similar events affecting Suncor or other parties whose operations or assets directly or indirectly affect Suncor; the potential for security breaches of Suncor's information technology and infrastructure by malicious persons or entities, and the unavailability or failure of such systems to perform as anticipated as a result of such breaches; security threats and terrorist or activist activities; the risk that competing business objectives may exceed Suncor's capacity to adopt and implement change; risks and uncertainties associated with obtaining regulatory, third-party and stakeholder approvals outside of Suncor's control for the company's operations, projects, initiatives, and exploration and development activities and the satisfaction of any conditions to approvals; the potential for disruptions to operations and construction projects as a result of Suncor's relationships with labour unions that represent employees at the company's facilities; the company's ability to find new oil and gas reserves that can be developed economically; the accuracy of Suncor's reserves, resources and future production estimates; market instability affecting Suncor's ability to borrow in the capital debt markets at acceptable rates or to issue other securities at acceptable prices; maintaining an optimal debt to cash flow ratio; the success of the company's risk management 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; risks and uncertainties associated with closing a transaction for the purchase or sale of a business, asset or oil and gas property, including estimates of the final consideration to be paid or received; the ability of counterparties to comply with their obligations in a timely manner; risks associated with joint arrangements in which the company has an interest; risks associated with land claims and Aboriginal 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.

2018 ANNUAL REPORT Suncor Energy Inc. 77

Many of these risk factors and other assumptions related to Suncor's forward-looking statements are discussed in further detail throughout this MD&A, including under the heading Risk Factors, and the company's 2018 AIF and Form 40-F on file with Canadian securities commissions at www.sedar.com 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 documents that Suncor files from time to time with securities regulatory authorities. Copies of these documents 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.

78 2018 ANNUAL REPORT Suncor Energy Inc.

MANAGEMENT'S STATEMENT
OF RESPONSIBILITY FOR FINANCIAL REPORTING

The management of Suncor Energy Inc. is responsible for the presentation and preparation of the accompanying consolidated financial statements of Suncor Energy Inc. and all related financial information contained in the Annual Report, including Management's Discussion and Analysis.

The consolidated financial statements have been prepared in accordance with Canadian generally accepted accounting principles applicable to publicly accountable enterprises, which is within the framework of International Financial Reporting Standards as issued by the International Accounting Standards Board incorporated into the Canadian Institute of Chartered Professional Accountants Handbook Part 1. They include certain amounts that are based on estimates and judgments.

In management's opinion, the consolidated financial statements have been properly prepared within reasonable limits of materiality and within the framework of the significant accounting policies adopted by management. If alternate accounting methods exist, management has chosen those policies it deems the most appropriate in the circumstances. In discharging its responsibilities for the integrity and reliability of the financial statements, management maintains and relies upon a system of internal controls designed to ensure that transactions are properly authorized and recorded, assets are safeguarded against unauthorized use or disposition and liabilities are recognized. These controls include quality standards in hiring and training of employees, formalized policies and procedures, a corporate code of conduct and associated compliance program designed to establish and monitor conflicts of interest, the integrity of accounting records and financial information, among others, and employee and management accountability for performance within appropriate and well-defined areas of responsibility.

The system of internal controls is further supported by the professional staff of an internal audit function who conduct periodic audits of the company's financial reporting.

The Audit Committee of the Board of Directors, currently composed of four independent directors, reviews the effectiveness of the company's financial reporting systems, management information systems, internal control systems and internal auditors. It recommends to the Board of Directors the external auditor to be appointed by the shareholders at each annual meeting and reviews the independence and effectiveness of their work. In addition, it reviews with management and the external auditor any significant financial reporting issues, the presentation and impact of significant risks and uncertainties, and key estimates and judgments of management that may be material for financial reporting purposes. The Audit Committee appoints the independent reserve consultants. The Audit Committee meets at least quarterly to review and approve interim financial statements prior to their release, as well as annually to review Suncor's annual financial statements and Management's Discussion and Analysis, Annual Information Form/Form 40-F, and annual reserves estimates, and recommend their approval to the Board of Directors. The internal auditors and the external auditor, PricewaterhouseCoopers LLP, have unrestricted access to the company, the Audit Committee and the Board of Directors.

Steven W. Williams | Alister Cowan
Chief Executive Officer | Executive Vice President and Chief Financial Officer

February 28, 2019

2018 ANNUAL REPORT Suncor Energy Inc. 79

The following report is provided by management in respect of the company's internal control over financial reporting (as defined in Rule 13a-15(f) and 15d-15(f) under the U.S. Securities Exchange Act of 1934):

MANAGEMENT'S REPORT ON INTERNAL CONTROL
OVER FINANCIAL REPORTING

1.
  Management is responsible for establishing and maintaining adequate internal control over the company's financial reporting.
2.
  Management has used the Committee of Sponsoring Organizations of the Treadway Commission (COSO) framework (2013) in Internal Control – Integrated Framework to evaluate the effectiveness of the company's internal control over financial reporting.
3.
  Management has assessed the effectiveness of the company's internal control over financial reporting as at December 31, 2018, and has concluded that such internal control over financial reporting was effective as of that date. In addition, based on this assessment, management determined that there were no material weaknesses in internal control over financial reporting as at December 31, 2018. Because of inherent limitations, systems of internal control over financial reporting may not prevent or detect misstatements and even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.
4.
  The effectiveness of the company's internal control over financial reporting as at December 31, 2018 has been audited by PricewaterhouseCoopers LLP, independent auditor, as stated in their report which appears herein.

Steven W. Williams | Alister Cowan
Chief Executive Officer | Executive Vice President and Chief Financial Officer

February 28, 2019

80 2018 ANNUAL REPORT Suncor Energy Inc.

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Shareholders and Board of Directors of
Suncor Energy Inc.

Opinions on the Financial Statements and Internal Control over Financial Reporting

We have audited the accompanying Consolidated Balance Sheets of Suncor Energy Inc. and its subsidiaries, (together, the "Company") as of December 31, 2018 and 2017, and the related Consolidated Statements of Comprehensive Income, Changes in Equity and Cash Flows for the years then ended, including the related notes (collectively referred to as the "Consolidated Financial Statements"). We also have audited the Company's internal control over financial reporting as of December 31, 2018, based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission ("COSO").

In our opinion, the Consolidated Financial Statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2018 and 2017, and their financial performance and their cash flows for the years then ended in conformity with International Financial Reporting Standards as issued by the International Accounting Standards Board ("IFRS"). Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2018, based on criteria established in Internal Control – Integrated Framework (2013) issued by the COSO.

Basis for Opinions

The Company's management is responsible for these Consolidated Financial Statements, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management's Report on Internal Control over Financial Reporting. Our responsibility is to express opinions on the Company's Consolidated Financial Statements and on the Company's internal control over financial reporting based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) ("PCAOB") and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the Consolidated Financial Statements are free of material misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was maintained in all material respects.

Our audits of the Consolidated Financial Statements included performing procedures to assess the risks of material misstatement of the Consolidated Financial Statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the Consolidated Financial Statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the Consolidated Financial Statements. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

Definition and limitations of internal control over financial reporting

A company's internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and

2018 ANNUAL REPORT Suncor Energy Inc. 81

directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

Chartered Professional Accountants |
Calgary, Alberta, Canada |

February 28, 2019

We have served as the Company's auditor since 1972.

82 2018 ANNUAL REPORT Suncor Energy Inc.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

For the years ended December 31 ($ millions) |  | Notes |  | 2018 |  | 2017 |  |
|  |  |  | (restated – note 5) |  |
Revenues and Other Income |  |  |  |  |  |  |  |
| Operating revenues, net of royalties |  | 6 |  | 38 542 |  | 31 954 |  |
| Other income |  | 7 |  | 444 |  | 125 |  |
|  |  |  | 38 986 |  | 32 079 |  |
Expenses |  |  |  |  |  |  |  |
| Purchases of crude oil and products |  |  |  | 14 133 |  | 11 121 |  |
| Operating, selling and general |  | 8 and 24 |  | 10 573 |  | 9 188 |  |
| Transportation |  |  |  | 1 319 |  | 997 |  |
| Depreciation, depletion, amortization and impairment |  | 15 |  | 5 738 |  | 5 601 |  |
| Exploration |  |  |  | 122 |  | 104 |  |
| Gain on disposal of assets |  | 33, 34 and 36 |  | (24 | ) | (602 | ) |
| Financing expenses (income) |  | 9 |  | 2 142 |  | (246 | ) |
|  |  |  | 34 003 |  | 26 163 |  |
Earnings before Income Taxes |  |  |  | 4 983 |  | 5 916 |  |
Income Tax Expense |  | 10 |  |  |  |  |  |
| Current |  |  |  | 1 250 |  | 1 209 |  |
| Deferred |  |  |  | 440 |  | 249 |  |
|  |  |  | 1 690 |  | 1 458 |  |
Net Earnings |  |  |  | 3 293 |  | 4 458 |  |
Other Comprehensive Income (Loss) |  |  |  |  |  |  |  |
| Items That May be Subsequently Reclassified to Earnings: |  |  |  |  |  |  |  |
|  | Foreign currency translation adjustment |  |  |  | 267 |  | (198 | ) |
| Items That Will Not be Reclassified to Earnings: |  |  |  |  |  |  |  |
|  | Actuarial gain on employee retirement benefit plans, net of income taxes |  |  |  | 103 |  | 31 |  |
Other Comprehensive Income (Loss) |  |  |  | 370 |  | (167 | ) |
Total Comprehensive Income |  |  |  | 3 663 |  | 4 291 |  |
Per Common Share (dollars) |  | 11 |  |  |  |  |  |
| Net earnings – basic |  |  |  | 2.03 |  | 2.68 |  |
| Net earnings – diluted |  |  |  | 2.02 |  | 2.68 |  |
Cash dividends |  |  |  | 1.44 |  | 1.28 |  |

The accompanying notes are an integral part of the consolidated financial statements.

2018 ANNUAL REPORT Suncor Energy Inc. 83

CONSOLIDATED BALANCE SHEETS

($ millions) |  | Notes |  | December 31 2018 |  | December 31 2017 |
Assets |  |  |  |  |  |  |
| Current assets |  |  |  |  |  |  |
|  | Cash and cash equivalents |  | 12 |  | 2 221 |  | 2 672 |
|  | Accounts receivable |  |  |  | 3 206 |  | 3 281 |
|  | Inventories |  | 14 |  | 3 159 |  | 3 468 |
|  | Income taxes receivable |  |  |  | 114 |  | 156 |
| Total current assets |  |  |  | 8 700 |  | 9 577 |
| Property, plant and equipment, net |  | 15, 31-34 and 36 |  | 74 245 |  | 73 493 |
| Exploration and evaluation |  | 16 |  | 2 319 |  | 2 052 |
| Other assets |  | 17 |  | 1 126 |  | 1 211 |
| Goodwill and other intangible assets |  | 18 |  | 3 061 |  | 3 061 |
| Deferred income taxes |  | 10 |  | 128 |  | 100 |
| Total assets |  |  |  | 89 579 |  | 89 494 |
Liabilities and Shareholders' Equity |  |  |  |  |  |  |
| Current liabilities |  |  |  |  |  |  |
|  | Short-term debt |  | 19 |  | 3 231 |  | 2 136 |
|  | Current portion of long-term debt |  | 19 |  | 229 |  | 71 |
|  | Accounts payable and accrued liabilities |  |  |  | 5 647 |  | 6 203 |
|  | Current portion of provisions |  | 22 |  | 667 |  | 722 |
|  | Income taxes payable |  |  |  | 535 |  | 425 |
| Total current liabilities |  |  |  | 10 309 |  | 9 557 |
| Long-term debt |  | 19 |  | 13 890 |  | 13 372 |
| Other long-term liabilities |  | 20 and 35 |  | 2 346 |  | 2 412 |
| Provisions |  | 22 |  | 6 984 |  | 7 237 |
| Deferred income taxes |  | 10 |  | 12 045 |  | 11 533 |
| Equity |  |  |  | 44 005 |  | 45 383 |
| Total liabilities and shareholders' equity |  |  |  | 89 579 |  | 89 494 |

The accompanying notes are an integral part of the consolidated financial statements.

Approved on behalf of the Board of Directors:

Steven W. Williams |  | Patricia M. Bedient
Director |  | Director

February 27, 2019

84 2018 ANNUAL REPORT Suncor Energy Inc.

CONSOLIDATED STATEMENTS OF CASH FLOWS

For the years ended December 31 ($ millions) |  | Notes |  | 2018 |  | 2017 |  |
Operating Activities |  |  |  |  |  |  |  |
Net earnings |  |  |  | 3 293 |  | 4 458 |  |
Adjustments for: |  |  |  |  |  |  |  |
| Depreciation, depletion, amortization and impairment |  |  |  | 5 738 |  | 5 601 |  |
| Deferred income taxes |  |  |  | 440 |  | 249 |  |
| Accretion |  |  |  | 266 |  | 247 |  |
| Unrealized foreign exchange loss (gain) on U.S. dollar denominated debt |  |  |  | 1 090 |  | (771 | ) |
| Change in fair value of financial instruments and trading inventory |  |  |  | (179 | ) | 128 |  |
| Gain on disposal of assets |  | 33, 34 and 36 |  | (24 | ) | (474 | ) |
| Loss on extinguishment of long-term debt |  | 9 |  | 3 |  | 51 |  |
| Share-based compensation |  |  |  | (117 | ) | 31 |  |
| Exploration |  |  |  | 11 |  | 41 |  |
| Settlement of decommissioning and restoration liabilities |  |  |  | (469 | ) | (353 | ) |
| Other |  |  |  | 120 |  | (69 | ) |
| Decrease (increase) in non-cash working capital |  | 13 |  | 408 |  | (173 | ) |
Cash flow provided by operating activities |  |  |  | 10 580 |  | 8 966 |  |
Investing Activities |  |  |  |  |  |  |  |
Capital and exploration expenditures |  |  |  | (5 406 | ) | (6 551 | ) |
Acquisitions |  | 31, 32 and 36 |  | (1 230 | ) | (308 | ) |
Proceeds from disposal of assets |  |  |  | 84 |  | 1 611 |  |
Other investments |  | 36 |  | (170 | ) | (38 | ) |
Decrease in non-cash working capital |  | 13 |  | 25 |  | 267 |  |
Cash flow used in investing activities |  |  |  | (6 697 | ) | (5 019 | ) |
Financing Activities |  |  |  |  |  |  |  |
Net increase in short-term debt |  |  |  | 866 |  | 981 |  |
Net decrease in long-term debt |  | 19 |  | (186 | ) | (3 283 | ) |
Issuance of long-term debt |  | 19 |  | — |  | 905 |  |
Issuance of common shares under share option plans |  |  |  | 286 |  | 228 |  |
Purchase of common shares |  | 23 |  | (3 053 | ) | (1 413 | ) |
(Distributions) and proceeds from sale, relating to non-controlling interest |  | 35 |  | (6 | ) | 483 |  |
Dividends paid on common shares |  |  |  | (2 333 | ) | (2 124 | ) |
Cash flow used in financing activities |  |  |  | (4 426 | ) | (4 223 | ) |
Decrease in Cash and Cash Equivalents |  |  |  | (543 | ) | (276 | ) |
Effect of foreign exchange on cash and cash equivalents |  |  |  | 92 |  | (68 | ) |
Cash and cash equivalents at beginning of year |  |  |  | 2 672 |  | 3 016 |  |
Cash and Cash Equivalents at End of Year |  |  |  | 2 221 |  | 2 672 |  |
Supplementary Cash Flow Information |  |  |  |  |  |  |  |
Interest paid |  |  |  | 800 |  | 941 |  |
Income taxes paid |  |  |  | 645 |  | 557 |  |

The accompanying notes are an integral part of the consolidated financial statements.

2018 ANNUAL REPORT Suncor Energy Inc. 85

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY

($ millions) | Notes |  | Share Capital |  | Contributed Surplus |  | Accumulated Other Comprehensive Income |  | Retained Earnings |  | Total |  | Number of Common Shares (thousands) |  |
At December 31, 2016 |  |  | 26 942 |  | 588 |  | 1 007 |  | 16 093 |  | 44 630 |  | 1 667 914 |  |
Net earnings |  |  | — |  | — |  | — |  | 4 458 |  | 4 458 |  | — |  |
Foreign currency translation adjustment |  |  | — |  | — |  | (198 | ) | — |  | (198 | ) | — |  |
Actuarial gain on employee retirement benefit plans, net of income taxes of $19 |  |  | — |  | — |  | — |  | 31 |  | 31 |  | — |  |
Total comprehensive (loss) income |  |  | — |  | — |  | (198 | ) | 4 489 |  | 4 291 |  | — |  |
Issued under share option plans |  |  | 297 |  | (69 | ) | — |  | — |  | 228 |  | 6 223 |  |
Purchase of common shares for cancellation | 23 |  | (536 | ) | — |  | — |  | (877 | ) | (1 413 | ) | (33 154 | ) |
Change in liability for share purchase commitment | 23 |  | (97 | ) | — |  | — |  | (180 | ) | (277 | ) | — |  |
Share-based compensation |  |  | — |  | 48 |  | — |  | — |  | 48 |  | — |  |
Dividends paid on common shares |  |  | — |  | — |  | — |  | (2 124 | ) | (2 124 | ) | — |  |
At December 31, 2017 |  |  | 26 606 |  | 567 |  | 809 |  | 17 401 |  | 45 383 |  | 1 640 983 |  |
Net earnings |  |  | — |  | — |  | — |  | 3 293 |  | 3 293 |  | — |  |
Foreign currency translation adjustment |  |  | — |  | — |  | 267 |  | — |  | 267 |  | — |  |
Actuarial gain on employee retirement benefit plans, net of income taxes of $39 |  |  | — |  | — |  | — |  | 103 |  | 103 |  | — |  |
Total comprehensive income |  |  | — |  | — |  | 267 |  | 3 396 |  | 3 663 |  | — |  |
Issued under share option plans |  |  | 358 |  | (73 | ) | — |  | — |  | 285 |  | 7 927 |  |
Purchase of common shares for cancellation | 23 |  | (1 040 | ) | — |  | — |  | (2 013 | ) | (3 053 | ) | (64 426 | ) |
Change in liability for share purchase commitment | 23 |  | (14 | ) | — |  | — |  | 28 |  | 14 |  | — |  |
Share-based compensation |  |  | — |  | 46 |  | — |  | — |  | 46 |  | — |  |
Dividends paid on common shares |  |  | — |  | — |  | — |  | (2 333 | ) | (2 333 | ) | — |  |
At December 31, 2018 |  |  | 25 910 |  | 540 |  | 1 076 |  | 16 479 |  | 44 005 |  | 1 584 484 |  |

The accompanying notes are an integral part of the consolidated financial statements.

86 2018 ANNUAL REPORT Suncor Energy Inc.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

1. REPORTING ENTITY AND DESCRIPTION OF THE BUSINESS

Suncor Energy Inc. (Suncor or the company) is an integrated energy company headquartered in Canada. Suncor's operations include oil sands development and upgrading, onshore and offshore oil and gas production, petroleum refining, and product marketing primarily under the Petro-Canada® brand.

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

2. BASIS OF PREPARATION

(a) Statement of Compliance

These consolidated financial statements have been prepared in accordance with International Financial Reporting Standards (IFRS) as issued by the International Accounting Standards Board (IASB) and Canadian generally accepted accounting principles (GAAP) as contained within Part 1 of the Canadian Institute of Chartered Professional Accountants Handbook.

Suncor's accounting policies are based on IFRS issued and outstanding for all periods presented in these consolidated financial statements. These consolidated financial statements were approved by the Board of Directors on February 27, 2019.

(b) Basis of Measurement

The consolidated financial statements are prepared on a historical cost basis except as detailed in the accounting policies disclosed in note 3. The accounting policies described in note 3 have been applied consistently to all periods presented in these consolidated financial statements.

(c) Functional Currency and Presentation Currency

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 judgments used in the preparation of the consolidated financial statements are described in note 4.

3. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

(a) Principles of Consolidation

The company consolidates its interests in entities it controls. Control comprises the power to govern an entity's financial and operating policies to obtain benefits from its activities, and is a matter of judgment. All intercompany balances and transactions are eliminated on consolidation.

(b) Joint Arrangements

Joint arrangements represent arrangements in which two or more parties have joint control established by a contractual agreement. Joint control only exists when decisions about the activities that most significantly affect the returns of the investee are unanimous. Joint arrangements can be classified as either a joint operation or a joint venture. The classification of joint arrangements requires judgment. In determining the classification of its joint arrangements, the company considers the contractual rights and obligations of each investor and whether the legal structure of the joint arrangement gives the entity direct rights to the assets and obligations for the liabilities.

Where the company has rights to the assets and obligations for the liabilities of a joint arrangement, such arrangement is classified as a joint operation and the company's proportionate share of the joint operation's assets, liabilities, revenues and expenses are included in the consolidated financial statements, on a line-by-line basis.

Where the company has rights to the net assets of an arrangement, the arrangement is classified as a joint venture and accounted for using the equity method of accounting. Under the equity method, the company's initial investment is recognized at cost and subsequently adjusted for the company's share of the joint venture's income or loss, less distributions received.

2018 ANNUAL REPORT Suncor Energy Inc. 87

(c) Foreign Currency Translation

Functional currencies of the company's individual entities are the currency of the primary economic environment in which the entity operates. Transactions in foreign currencies are translated to the appropriate functional currency at foreign exchange rates that approximate those on the date of the transaction. Monetary assets and liabilities denominated in foreign currencies are translated to the appropriate functional currency at foreign exchange rates as at the balance sheet date. Foreign exchange differences arising on translation are recognized in net earnings. Non-monetary assets that are measured in a foreign currency at historical cost are translated using the exchange rate at the date of the transaction.

In preparing the company's consolidated financial statements, the financial statements of each entity are translated into Canadian dollars. The assets and liabilities of foreign operations are translated into Canadian dollars at exchange rates as at the balance sheet date. Revenues and expenses of foreign operations are translated into Canadian dollars using foreign exchange rates that approximate those on the date of the underlying transaction. Foreign exchange differences are recognized in Other Comprehensive Income.

If the company or any of its entities disposes of its entire interest in a foreign operation, or loses control, joint control, or significant influence over a foreign operation, the accumulated foreign currency translation gains or losses related to the foreign operation are recognized in net earnings.

(d) Revenues

Revenue from the sale of crude oil, natural gas, natural gas liquids, purchased products and refined petroleum products is recorded when title passes to the customer and collection is reasonably assured, in accordance with specified contract terms, and is based on the consideration that the company expects to receive for the transfer of the goods to the customer.

Revenue from properties in which the company has an interest with other producers is recognized on the basis of the company's net working interest. For operations not pursuant to production sharing contracts (PSCs), crude oil and natural gas sold below or above the company's working-interest share of production results in production underlifts or overlifts, respectively. Underlifts are recorded as a receivable at market value with a corresponding increase to revenue, while overlifts are recorded as a payable at market value with a corresponding decrease to revenue. Changes in the value of underlifted or overlifted barrels are recognized in revenue when the barrels are settled. Revenue from oil and natural gas production is recorded net of royalty expense.

International operations conducted pursuant to PSCs are reflected in the consolidated financial statements based on the company's working interest. Each PSC establishes the exploration, development and operating costs the company is required to fund and establishes specific terms for the company to recover these costs and to share in the production profits. Cost recovery is generally limited to a specified percentage of production during each fiscal year (Cost Recovery Oil). Any Cost Recovery Oil remaining after costs have been recovered is referred to as Excess Petroleum and is shared between the company and the respective government. Assuming collection is reasonably assured, the company's share of Cost Recovery Oil and Excess Petroleum are reported as revenue when the sale of product to a third party occurs. Revenue also includes income taxes paid on the company's behalf by government joint venture partners.

(e) Cash and Cash Equivalents

Cash and cash equivalents consist primarily of cash in banks, term deposits, certificates of deposit and all other highly liquid investments at the time of purchase.

(f) Inventories

Inventories of crude oil and refined products, other than inventories held for trading purposes, are valued at the lower of cost, using the first-in, first-out method, and net realizable value. Costs include direct expenditures incurred in bringing an item or product to its existing condition and location. Materials and supplies are valued at the lower of average cost and net realizable value.

Inventories held for trading purposes in the company's energy trading operations are carried at fair value less costs of disposal, and any changes in fair value are recognized within Other Income.

(g) Assets Held for Sale

Assets and associated liabilities are classified as held for sale if their carrying amounts are expected to be recovered through a disposition rather than through continued use. The assets or disposal groups are measured at the lower of their carrying amount or estimated fair value less costs of disposal. Impairment losses on initial classification as well as subsequent gains or losses on remeasurement are recognized in Depreciation, Depletion, Amortization and Impairment. When the assets or

88 2018 ANNUAL REPORT Suncor Energy Inc.

disposal groups are sold, the gains or losses on the sale are recognized in Gain on Disposal of Assets. Assets classified as held for sale are not depreciated, depleted or amortized.

(h) Exploration and Evaluation Assets

The costs to acquire non-producing oil and gas properties or licences to explore, drill exploratory wells and the costs to evaluate the commercial potential of underlying resources, including related borrowing costs, are initially capitalized as Exploration and Evaluation assets. Certain exploration costs, including geological, geophysical and seismic expenditures and delineation on oil sands properties, are charged to Exploration expense as incurred.

Exploration and Evaluation assets are subject to technical, commercial and management review to confirm the continued intent to develop and extract the underlying resources. If an area or exploration well is no longer considered commercially viable, the related capitalized costs are charged to Exploration expense.

When management determines with reasonable certainty that an Exploration and Evaluation asset will be developed, as evidenced by the classification of proved or probable reserves and the appropriate internal and external approvals, the asset is transferred to Property, Plant and Equipment.

(i) Property, Plant and Equipment

Property, Plant and Equipment are initially recorded at cost.

The costs to acquire developed or producing oil and gas properties, and to develop oil and gas properties, including completing geological and geophysical surveys and drilling development wells, and the costs to construct and install development infrastructure, such as wellhead equipment, well platforms, well pairs, offshore platforms and subsea structures, are capitalized as oil and gas properties within Property, Plant and Equipment.

The costs to construct, install and commission, or acquire, oil and gas production equipment, including oil sands upgraders, extraction plants, mine equipment, processing and power generation facilities, utility plants, and all renewable energy, refining, and marketing assets, are capitalized as plant and equipment within Property, Plant and Equipment.

Stripping activity required to access oil sands mining resources incurred in the initial development phase is capitalized as part of the construction cost of the mine. Stripping costs incurred in the production phase are charged to expense as they normally relate to production for the current period.

The costs of planned major inspection, overhaul and turnaround activities that maintain Property, Plant and Equipment and benefit future years of operations are capitalized. Recurring planned maintenance activities performed on shorter intervals are expensed as operating costs. Replacements outside of a major inspection, overhaul or turnaround are capitalized when it is probable that future economic benefits will be realized by the company and the associated carrying amount of the replaced component is derecognized.

Leases that transfer substantially all the benefits and risks of ownership of the leased asset to the company are recorded as finance lease assets within Property, Plant and Equipment. Costs for all other leases are recorded within Purchases of Crude Oil and Products, Operating, Selling and General, and/or Transportation expense as incurred. The expense line item classification is determined based on the business activity associated with the leased asset.

Borrowing costs relating to assets that take over one year to construct are capitalized as part of the asset. Capitalization of borrowing costs ceases when the asset is in the location and condition necessary for its intended use, and is suspended when construction of an asset is ceased for extended periods.

(j) Depreciation, Depletion and Amortization

Exploration and Evaluation assets are not subject to depreciation, depletion and amortization. Once transferred to oil and gas properties within Property, Plant and Equipment and commercial production commences, these costs are depleted on a unit-of-production basis over proved developed reserves, with the exception of exploration and evaluation costs associated with oil sands mines, which are depreciated on a straight-line basis over the life of the mine, and property acquisition costs, which are depleted over proved reserves.

Capital expenditures are not depreciated or depleted until assets are substantially complete and ready for their intended use.

Costs to develop oil and gas properties other than certain oil sands mining assets, including costs of dedicated infrastructure, such as well pads and wellhead equipment, are depleted on a unit-of-production basis over proved developed reserves. A portion of these costs may not be depleted if they relate to undeveloped reserves. Costs related to offshore facilities are depleted over proved and probable reserves. Costs to develop and construct oil sands mines are depreciated on a straight-line basis over the life of the mine.

2018 ANNUAL REPORT Suncor Energy Inc. 89

Major components of Property, Plant and Equipment are depreciated on a straight-line basis over their expected useful lives.

Oil sands upgraders, extraction plants and mine facilities |  | 20 to 40 years
Oil sands mine equipment |  | 5 to 15 years
Oil sands in situ processing facilities |  | 30 years
Power generation and utility plants |  | 30 to 40 years
Refineries and other processing plants |  | 20 to 40 years
Marketing and other distribution assets |  | 10 to 40 years

The costs of major inspection, overhaul and turnaround activities that are capitalized are depreciated on a straight-line basis over the period to the next scheduled activity, which varies from two to five years.

Depreciation, depletion and amortization rates are reviewed annually or when events or conditions occur that impact capitalized costs, reserves or estimated service lives.

Finance lease assets within Property, Plant and Equipment are depreciated on a straight-line basis over the shorter of the estimated useful life of the leased asset or the lease term.

(k) Goodwill and Other Intangible Assets

The company accounts for business combinations using the acquisition method. The excess of the purchase price over the fair value of the identifiable net assets represents goodwill, and is allocated to the cash generating units (CGUs) or groups of CGUs expected to benefit from the business combination.

Other intangible assets include acquired customer lists and brand value.

Goodwill and brand value have indefinite useful lives and are not subject to amortization. Customer lists are amortized over their expected useful lives, which range from five to ten years. Expected useful lives of other intangible assets are reviewed on an annual basis.

(l) Impairment of Assets

Non-Financial Assets

Property, Plant and Equipment and Exploration and Evaluation assets are reviewed quarterly to assess whether there is any indication of impairment. Goodwill and intangible assets that have an indefinite useful life are tested for impairment annually. Exploration and Evaluation assets are also tested for impairment immediately prior to being transferred to Property, Plant and Equipment.

If any indication of impairment exists, an estimate of the asset's recoverable amount is calculated as the higher of the fair value less costs of disposal and value-in-use. In determining fair value less costs of disposal, recent market transactions are considered, if available. In the absence of such transactions, an appropriate valuation model is used. Value-in-use is assessed using the present value of the expected future cash flows of the relevant asset. If the asset does not generate cash inflows that are largely independent of those from other assets or groups of assets, the asset is tested as part of a CGU, which is the smallest identifiable group of assets that generates cash inflows that are largely independent of the cash inflows from other assets or groups of assets. An impairment loss is the amount by which the carrying amount of the individual asset or CGU exceeds its recoverable amount.

Impairments may be reversed for all CGUs and individual assets, other than goodwill, if there has been a change in the estimates and judgments used to determine the asset's recoverable amount. If such indication exists, the carrying amount of the CGU or asset is increased to its revised recoverable amount which cannot exceed the carrying amount that would have been determined, net of depletion, depreciation and amortization, had no impairment been recognized.

Impairments and impairment reversals are recognized within Depreciation, Depletion, Amortization and Impairment.

Financial Assets

At each reporting date, the company assesses whether there is evidence indicating that financial assets measured at amortized cost may be impaired. If a financial asset measured at amortized cost is determined to be impaired, the impairment is recognized in Operating, Selling and General expense.

90 2018 ANNUAL REPORT Suncor Energy Inc.

(m) Provisions

Provisions are recognized by the company when it has a legal or constructive obligation as a result of past events, it is probable that an outflow of economic resources will be required to settle the obligation and a reliable estimate can be made of the amount of the obligation.

Provisions are recognized for decommissioning and restoration obligations associated with the company's Exploration and Evaluation assets and Property, Plant and Equipment. Provisions for decommissioning and restoration obligations are measured at the present value of management's best estimate of the future cash flows required to settle the present obligation, using the credit-adjusted risk-free interest rate. The value of the obligation is added to the carrying amount of the associated asset and amortized over the useful life of the asset. The provision is accreted over time through Financing Expense with actual expenditures charged against the accumulated obligation. Changes in the future cash flow estimates resulting from revisions to the estimated timing or amount of undiscounted cash flows are recognized as a change in the decommissioning and restoration provision and related asset.

(n) Income Taxes

The company follows the liability method of accounting for income taxes whereby deferred income taxes are recorded for the effect of differences between the accounting and income tax basis of an asset or liability. Deferred income tax assets and liabilities are measured using enacted or substantively enacted income tax rates as at the balance sheet date that are anticipated to apply to taxable income in the years in which temporary differences are anticipated to be recovered or settled. Changes to these balances are recognized in net earnings or in Other Comprehensive Income in the period they occur. Investment tax credits are recorded as a reduction to the related expenditures.

The company recognizes the financial statement impact of a tax filing position when it is probable, based on the technical merits, that the position will be sustained upon audit. The company assesses possible outcomes and their associated probabilities. If the company determines payment is probable, it measures the tax provision at the best estimate of the amount of tax payable.

(o) Pensions and Other Post-Retirement Benefits

The company sponsors defined benefit pension plans, defined contribution pension plans and other post-retirement benefits.

The cost of pension benefits earned by employees in the defined contribution pension plan is expensed as incurred. The cost of defined benefit pension plans and other post-retirement benefits are actuarially determined using the projected unit credit method based on present pay levels and management's best estimates of demographic and financial assumptions. Pension benefits earned during the current year are recorded in Operating, Selling and General expense. Interest costs on the net unfunded obligation are recorded in Financing Expense. Any actuarial gains or losses are recognized immediately through Other Comprehensive Income and transferred directly to Retained Earnings.

The liability recognized on the balance sheet is the present value of the defined benefit obligations net of the fair value of plan assets.

(p) Share-Based Compensation Plans

Under the company's share-based compensation plans, share-based awards may be granted to executives, employees and non-employee directors. Compensation expense is recorded in Operating, Selling and General expense.

Share-based compensation awards that settle in cash or have the option to settle in cash or shares are accounted for as cash-settled plans. These are measured at fair value each reporting period using the Black-Scholes options pricing model. The expense is recognized over the vesting period, with a corresponding adjustment to the outstanding liability. When awards are surrendered for cash, the cash settlement paid reduces the outstanding liability. When awards are exercised for common shares, consideration paid by the holder and the previously recognized liability associated with the options are recorded to Share Capital.

Stock options that give the holder the right to purchase common shares are accounted for as equity-settled plans. The expense is based on the fair value of the options at the time of grant using the Black-Scholes options pricing model and is recognized over the vesting periods of the respective options. A corresponding increase is recorded to Contributed Surplus. Consideration paid to the company on exercise of options is credited to Share Capital and the associated amount in Contributed Surplus is reclassified to Share Capital.

(q) Financial Instruments

The company classifies its financial instruments into one of the following categories: fair value through profit or loss (FVTPL), fair value through other comprehensive income, or at amortized cost. This determination is made at initial recognition. All

2018 ANNUAL REPORT Suncor Energy Inc. 91

financial instruments are initially recognized at fair value on the balance sheet, net of any transaction costs except for financial instruments classified as fair value through profit and loss, where transaction costs are expensed as incurred. Subsequent measurement of financial instruments is based on their classification. The company classifies its derivative financial instruments as FVTPL, cash and cash equivalents and accounts receivable as financial assets at amortized cost, and accounts payable and accrued liabilities, debt, and other long-term liabilities as financial liabilities at amortized cost.

In circumstances where the company consolidates a subsidiary in which there are other owners with a non-controlling interest and the subsidiary has a non-discretionary obligation to distribute cash based on a predetermined formula to the non-controlling owners, the non-controlling interest is classified as a financial liability rather than equity in accordance with IAS 32 Financial Instruments: Presentation. The non-controlling interest liability is classified as an amortized cost liability and is presented within Other Long-Term Liabilities. The balance is accreted based on current period interest expense recorded using the effective interest method and decreased based on distributions made to the non-controlling owners.

The company uses derivative financial instruments, such as physical and financial contracts, either to manage certain exposures to fluctuations in interest rates, commodity prices and foreign exchange rates, as part of its overall risk management program. Earnings impacts from derivatives used to manage a particular risk are reported as part of Other Income in the related operating segment. Gains or losses from trading activities are reported in Other Income as part of the Corporate, Energy Trading and Eliminations segment.

Certain physical commodity contracts, when used for trading purposes, are deemed to be derivative financial instruments for accounting purposes. Physical commodity contracts entered into for the purpose of receipt or delivery in accordance with the company's expected purchase, sale or usage requirements are not considered to be derivative financial instruments.

Derivatives embedded in other financial instruments or other host contracts are recorded as separate derivatives when their risks and characteristics are not closely related to those of the host contract.

(r) Hedging Activities

The company may apply hedge accounting to arrangements that qualify for designated hedge accounting treatment. Documentation is prepared at the inception of a hedge relationship in order to qualify for hedge accounting. Designated hedges are assessed at each reporting date to determine if the relationship between the derivative and the underlying hedged item accomplishes the company's risk management objectives for financial and non-financial risk exposures.

If the derivative is designated as a fair value hedge, changes in the fair value of the derivative and in the fair value of the underlying hedged item are recognized in net earnings. If the derivative is designated as a cash flow hedge, the effective portions of the changes in fair value of the derivative are initially recorded in Other Comprehensive Income and are recognized in net earnings when the hedged item is realized. Ineffective portions of changes in the fair value of cash flow hedges are recognized in net earnings immediately. Changes in the fair value of a derivative designated in a fair value or cash flow hedge are recognized in the same line item as the underlying hedged item.

The company did not apply hedge accounting to any of its derivative instruments during 2017 or 2018.

(s) Share Capital

Common shares are classified as equity. Incremental costs directly attributable to the issuance of common shares are recognized as a deduction from equity, net of any tax effects. When the company repurchases its own common shares, share capital is reduced by the average carrying value of the shares repurchased. The excess of the purchase price over the average carrying value is recognized as a deduction from Retained Earnings. Shares are cancelled upon repurchase.

(t) Dividend Distributions

Dividends on common shares are recognized in the period in which the dividends are declared by the company's Board of Directors.

(u) Earnings per Share

Basic earnings per share is calculated by dividing the net earnings for the period by the weighted average number of common shares outstanding during the period.

Diluted earnings per share is calculated by adjusting the weighted average number of common shares outstanding for dilutive common shares related to the company's share-based compensation plans. The number of shares included is computed using the treasury stock method. As these awards can be exchanged for common shares of the company, they are considered potentially dilutive and are included in the calculation of the company's diluted net earnings per share if they have a dilutive impact in the period.

92 2018 ANNUAL REPORT Suncor Energy Inc.

(v) Emissions Obligations

Emissions obligations are measured at the weighted average cost per unit of emissions expected to be incurred in the compliance period and are recorded in the period in which the emissions occur.

Purchases of emissions rights are recognized as Other Assets on the balance sheet and are measured at historical cost. Emissions rights received by way of grant are recorded at a nominal amount.

4. SIGNIFICANT ACCOUNTING ESTIMATES AND JUDGMENTS

The preparation of financial statements in accordance with IFRS requires management to make estimates and judgments that affect reported assets, liabilities, revenues, expenses, gains, losses, and disclosures of contingencies. These estimates and judgments are subject to change based on experience and new information. The financial statement areas that require significant estimates and judgments are as follows:

Oil and Gas Reserves

Measurements of depletion, depreciation, impairment, and decommissioning and restoration obligations are determined in part based on the company's estimate of oil and gas reserves. The estimation of reserves is an inherently complex process and involves the exercise of professional judgment. All reserves have been evaluated at December 31, 2018 by independent qualified reserves evaluators. Oil and gas reserves estimates are based on a range of geological, technical and economic factors, including projected future rates of production, projected future commodity prices, engineering data, and the timing and amount of future expenditures, all of which are subject to uncertainty. Estimates reflect market and regulatory conditions existing at December 31, 2018, which could differ significantly from other points in time throughout the year, or future periods. Changes in market and regulatory conditions and assumptions can materially impact the estimation of net reserves.

Oil and Gas Activities

The company is required to apply judgment when designating the nature of oil and gas activities as exploration, evaluation, development or production, and when determining whether the costs of these activities shall be expensed or capitalized.

Exploration and Evaluation Costs

Certain exploration and evaluation costs are initially capitalized with the intent to establish commercially viable reserves. The company is required to make judgments about future events and circumstances and applies estimates to assess the economic viability of extracting the underlying resources. The costs are subject to technical, commercial and management review to confirm the continued intent to develop the project. Level of drilling success or changes to project economics, resource quantities, expected production techniques, production costs and required capital expenditures are important judgments when making this determination. Management uses judgment to determine when these costs are reclassified to Property, Plant and Equipment based on several factors, including the existence of reserves, appropriate approvals from regulatory bodies and the company's internal project approval process.

Determination of Cash Generating Units (CGUs)

A CGU is the lowest grouping of integrated assets that generate identifiable cash inflows that are largely independent of the cash inflows of other assets or groups of assets. The allocation of assets into CGUs requires significant judgment and interpretations with respect to the integration between assets, the existence of active markets, similar exposure to market risks, shared infrastructure, and the way in which management monitors the operations.

Asset Impairment and Reversals

Management applies judgment in assessing the existence of impairment and impairment reversal indicators based on various internal and external factors.

The recoverable amount of CGUs and individual assets is determined based on the higher of fair value less costs of disposal or value-in-use calculations. The key estimates the company applies in determining the recoverable amount normally include estimated future commodity prices, expected production volumes, future operating and development costs, discount rates, tax rates, and refining margins. In determining the recoverable amount, management may also be required to make judgments regarding the likelihood of occurrence of a future event. Changes to these estimates and judgments will affect the recoverable amounts of CGUs and individual assets and may then require a material adjustment to their related carrying value.

2018 ANNUAL REPORT Suncor Energy Inc. 93

Decommissioning and Restoration Costs

The company recognizes liabilities for the future decommissioning and restoration of Exploration and Evaluation assets and Property, Plant and Equipment based on estimated future decommissioning and restoration costs. Management applies judgment in assessing the existence and extent as well as the expected method of reclamation of the company's decommissioning and restoration obligations at the end of each reporting period. Management also uses judgment to determine whether the nature of the activities performed is related to decommissioning and restoration activities or normal operating activities.

Actual costs are uncertain and estimates may vary as a result of changes to relevant laws and regulations related to the use of certain technologies, the emergence of new technology, operating experience, prices and closure plans. The estimated timing of future decommissioning and restoration may change due to certain factors, including reserves life. Changes to estimates related to future expected costs, discount rates, inflation assumptions, and timing may have a material impact on the amounts presented.

Employee Future Benefits

The company provides benefits to employees, including pensions and other post-retirement benefits. The cost of defined benefit pension plans and other post-retirement benefits received by employees is estimated based on actuarial valuation methods that require professional judgment. Estimates typically used in determining these amounts include, as applicable, rates of employee turnover, future claim costs, discount rates, future salary and benefit levels, the return on plan assets, mortality rates and future medical costs. Changes to these estimates may have a material impact on the amounts presented.

Other Provisions

The determination of other provisions, including, but not limited to, provisions for royalty disputes, onerous contracts, litigation and constructive obligations, is a complex process that involves judgment about the outcomes of future events, the interpretation of laws and regulations, and estimates on the timing and amount of expected future cash flows and discount rates.

Income Taxes

Management evaluates tax positions, annually or when circumstances require, which involves judgment and could be subject to differing interpretations of applicable tax legislation. The company recognizes a tax provision when a payment to tax authorities is considered probable. However, the results of audits and reassessments and changes in the interpretations of standards may result in changes to those positions and, potentially, a material increase or decrease in the company's assets, liabilities and net earnings.

Deferred Income Taxes

Deferred tax assets are recognized when it is considered probable that deductible temporary differences will be recovered in the foreseeable future. To the extent that future taxable income and the application of existing tax laws in each jurisdiction differ significantly from the company's estimate, the ability of the company to realize the deferred tax assets could be impacted.

Deferred tax liabilities are recognized when there are taxable temporary differences that will reverse and result in a future outflow of funds to a taxation authority. The company records a provision for the amount that is expected to be settled, which requires judgment as to the ultimate outcome. Deferred tax liabilities could be impacted by changes in the company's judgment of the likelihood of a future outflow and estimates of the expected settlement amount, timing of reversals, and the tax laws in the jurisdictions in which the company operates.

Fair Value of Financial Instruments

The fair value of a financial instrument is determined, whenever possible, based on observable market data. If not available, the company uses third-party models and valuation methodologies that utilize observable market data that includes forward commodity prices, foreign exchange rates and interest rates to estimate the fair value of financial instruments, including derivatives. 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.

Functional Currency

The designation of the functional currency of the company and each of its subsidiaries is a management judgment based on the composition of revenue and costs in the locations in which it operates.

94 2018 ANNUAL REPORT Suncor Energy Inc.

Fair Value of Share-Based Compensation

The fair values of equity-settled and cash-settled share-based payment awards are estimated using the Black-Scholes options pricing model. These estimates depend on certain assumptions, including share price, volatility, risk-free interest rate, the term of the awards, the forfeiture rate and the annual dividend yield, which, by their nature, are subject to measurement uncertainty.

5. NEW IFRS STANDARDS

(a) Adoption of New IFRS Standards

Impact of the application of IFRS 9

Effective January 1, 2018, the company adopted IFRS 9 Financial Instruments (IFRS 9) which replaces the multiple classification and measurement models for financial assets under IAS 39 Financial Instruments (IAS 39) with a new model that has two measurement categories: amortized cost and fair value, either through profit/loss (FVTPL) or through other comprehensive income. This determination is made at initial recognition. For financial liabilities, the new standard retains most of the IAS 39 requirements; however, the main change arises in cases where the company chooses to designate a financial liability as FVTPL. In these situations, the portion of the fair value change related to the company's own credit risk is recognized in other comprehensive income rather than net earnings. As a result of adopting IFRS 9, the company's financial assets classified as loans and receivables at December 31, 2017 have been reclassified to financial assets at amortized cost; however, there is no impact to the measurement of these financial assets. There were no changes to the classifications of the company's financial liabilities. The classification and measurement guidance was adopted retrospectively in accordance with the transitional provisions of IFRS 9.

The company also adopted the new hedge accounting guidance in IFRS 9. The new hedge accounting guidance replaces strict quantitative tests of effectiveness with less restrictive assessments of how well the hedging instrument accomplishes the company's risk management objectives for financial and non-financial risk exposures. IFRS 9 also allows the company to hedge risk components of non-financial items which meet certain measurability or identifiable characteristics. The company did not apply hedge accounting to any of its derivative instruments during 2018.

After adoption of IFRS 9, the company's accounting policies are substantially the same as at December 31, 2017 and there were no impacts to the company's financial statements, except for the change in financial asset categories as discussed above.

Impact of the application of IFRS 15

On January 1, 2018, the company adopted IFRS 15 Revenue from Contracts with Customers (IFRS 15), which sets out guidelines for the recognition of revenue, using the retrospective method,.

IFRS 15 replaces IAS 18 Revenue and presents a new single model for recognition of revenue from contracts with customers. The model features a contract-based five-step analysis of transactions to determine the nature of an entity's obligation to perform and whether, how much, and when revenue is recognized.

Under IFRS 15, the revenue from the sale of commodities and other operating revenue the company earns represent contractual arrangements with customers. The company recognizes revenue when title of the product is transferred to the buyer and collection is reasonably assured in accordance with specified contract terms. All operating revenue is generally earned at a point in time and is based on the consideration that the company expects to receive for the transfer of the goods to the customers.

The company has reviewed its sources of revenue and major contracts with customers using the guidance found in IFRS 15 and determined there are no material changes to the timing and measurement of the company's revenue in the reporting period, as compared to the provisions of the previous standard. In accordance with the new standard, the company assessed its principal versus agent requirements and the impact was a decrease in revenue, with a corresponding decrease to Operating, Selling and General expense and Transportation expense, resulting in no impact on the company's consolidated net earnings.

2018 ANNUAL REPORT Suncor Energy Inc. 95

Adjustments to Consolidated Statements of Comprehensive Income

($ millions, decrease) |  | For the twelve months ended December 31 2017 IFRS 15 |  |
Revenues and Other Income |  |  |  |
| Operating revenues, net of royalties |  | (97 | ) |
Expenses |  |  |  |
| Operating, selling and general |  | (57 | ) |
| Transportation |  | (40 | ) |
Net Earnings |  | — |  |
Total Comprehensive Income |  | — |  |

(b) Recently Announced Accounting Pronouncements

The standards, amendments and interpretations that are issued, but not yet effective up to the date of authorization of the company's consolidated financial statements, and that may have an impact on the disclosures and financial position of the company are disclosed below. The company intends to adopt these standards, amendments and interpretations when they become effective.

IFRS 16 Leases

In January 2016, the IASB issued IFRS 16 Leases (IFRS 16) which replaces the existing leasing standard IAS 17 Leases and requires the recognition of leases on the balance sheet, with optional exemptions for short-term leases where the term is twelve months or less and for leases of low-value items. IFRS 16 effectively removes the classification of leases as either finance or operating leases and treats all leases as finance leases for lessees. The accounting treatment for lessors remains essentially unchanged, with the requirement to classify leases as either finance or operating.

The company will adopt the standard on the effective date of January 1, 2019 and has selected the modified retrospective transition approach. The company has also elected to apply the optional exemption for short-term leases. The company has completed the implementation of an information technology solution, including uploading of data for identified leases into its leasing system. All contracts have been reviewed, new business processes have been developed and internal controls have been implemented.

IFRS 16 will have an impact on the following components of the consolidated financial statements of the company:

Consolidated Balance Sheets: IFRS 16 requires the recognition of lease liabilities and right of use (ROU) assets for all leases except for the optional exemptions for low-value assets and short-term leases. The company will recognize the lease liability at the present value of the remaining lease payments discounted using the company's incremental borrowing rate upon adoption of the new standard. Upon transition, the company will measure the ROU assets equal to the lease liability, adjusted by the amount of any prepaid payments or onerous contracts recognized in the December 31, 2018 consolidated financial statements. The company will recognize additional ROU assets and lease liabilities of approximately $1.8 billion, subject to finalization of reviews, as of January 1, 2019.

Consolidated Statements of Comprehensive Income: Adoption of IFRS 16 will result in an increase to Depreciation, Depletion and Amortization expense due to the recognition of ROU assets, an increase to Financing expense from the unwinding of the discounted value of the lease liabilities and a decrease to Operating, Selling and General expense, Purchases of Crude Oil and Products expense, and Transportation expense. Based on the company's leases at January 1, 2019, this standard will not have a material impact on consolidated net earnings.

Consolidated Statements of Cash Flows: Due to the change in the presentation of former operating lease expenses, Cash flow from operating activities will increase due to the decrease in Operating, Selling and General expense, Purchases of Crude Oil and Products expense, and Transportation expense, partially offset by increased Financing expense, which represents an operating activity for the company. Cash flow from financing activities will decrease due to the addition of principal payments for former operating leases. The overall impact to cash flow for the company will be unchanged.

96 2018 ANNUAL REPORT Suncor Energy Inc.

Uncertainty over Income Tax Treatments

In June 2017, the IASB issued IFRIC 23 Uncertainty over Income Tax Treatments. The interpretation clarifies the accounting for current and deferred tax liabilities and assets in circumstances in which there is uncertainty over income tax treatments. The interpretation requires an entity to consider whether it is probable that a taxation authority will accept an uncertain tax treatment. If the entity considers it to be not probable that a taxation authority will accept an uncertain tax provision the interpretation requires the entity to use the most likely amount or the expected value. The amendments are to be applied retrospectively and are effective for annual periods beginning on or after January 1, 2019, with earlier application permitted. The adoption of this amendment will not have any impact on the company's consolidated financial statements.

6. SEGMENTED INFORMATION

The company's operating segments are reported based on the nature of their products and services and management responsibility. The following summary describes the operations in each of the segments:

•
  Oil Sands includes the company's operations in the Athabasca oil sands in Alberta to develop and produce bitumen, synthetic crude oil and related products, through the recovery and upgrading of bitumen from mining and in situ operations. This segment also includes the company's joint interest in the Fort Hills partnership, partnership in the East Tank Farm blending and storage facility, as well as its ownership interest in the Syncrude oil sands mining and upgrading joint operation, located near Fort McMurray, Alberta. The individual operating segments related to mining operations, in situ, Fort Hills and Syncrude have been aggregated into one reportable segment (Oil Sands) due to the similar nature of their business activities, including the production of bitumen, and the single geographic area and regulatory environment in which they operate.
•
  Exploration and Production (E&P) includes offshore activity in East Coast Canada, with interests in the Hibernia, Terra Nova, White Rose and Hebron oilfields, the exploration and production of crude oil and natural gas at Buzzard and Golden Eagle Area Development, as well as development of the North Sea Rosebank Project, all in the United Kingdom (U.K.) and the development of the Oda and Fenja fields in Norway, and in Libya and Syria. Due to unrest in Syria, the company has declared force majeure under its contractual obligations, and Suncor's operations in Syria have been suspended indefinitely. Production in Libya remains partially shutin due to political unrest, and the timing of a return to normal operations continues to be uncertain.
•
  Refining and Marketing includes the refining of crude oil products, and the distribution and marketing of these and other purchased products through retail stations located in Canada and the United States (U.S.), as well as a previously owned lubricants plant located in Eastern Canada which was sold on February 1, 2017 (note 33).

The company also reports activities not directly attributable to an operating segment under Corporate, Energy Trading and Eliminations. This includes investments in renewables projects.

Intersegment sales of crude oil and natural gas are accounted for at market values and included, for segmented reporting, in revenues of the segment making the transfer and expenses of the segment receiving the transfer. Intersegment balances are eliminated on consolidation. Intersegment profit will not be recognized until the related product has been sold to third parties.

2018 ANNUAL REPORT Suncor Energy Inc. 97

For the years ended December 31 |  | Oil Sands |  | Exploration and Production |  | Refining and Marketing |  | Corporate, Energy Trading and Eliminations |  | Total |  |
($ millions) |  | 2018 |  | 2017 |  | 2018 |  | 2017 |  | 2018 |  | 2017 |  | 2018 |  | 2017 |  | 2018 |  | 2017 |  |
|  | (restated – note 5) |  |  |  |  |  | (restated – note 5) |  | (restated – note 5) |  | (restated – note 5) |  |
Revenues and Other Income |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Gross revenues |  | 12 039 |  | 9 723 |  | 3 869 |  | 3 487 |  | 23 655 |  | 19 612 |  | 29 |  | 63 |  | 39 592 |  | 32 885 |  |
Intersegment revenues |  | 3 704 |  | 3 551 |  | — |  | — |  | 69 |  | 92 |  | (3 773 | ) | (3 643 | ) | — |  | — |  |
Less: Royalties |  | (398 | ) | (355 | ) | (652 | ) | (576 | ) | — |  | — |  | — |  | — |  | (1 050 | ) | (931 | ) |
Operating revenues, net of royalties |  | 15 345 |  | 12 919 |  | 3 217 |  | 2 911 |  | 23 724 |  | 19 704 |  | (3 744 | ) | (3 580 | ) | 38 542 |  | 31 954 |  |
Other income (loss) |  | 288 |  | 86 |  | (71 | ) | (14 | ) | 21 |  | 73 |  | 206 |  | (20 | ) | 444 |  | 125 |  |
|  | 15 633 |  | 13 005 |  | 3 146 |  | 2 897 |  | 23 745 |  | 19 777 |  | (3 538 | ) | (3 600 | ) | 38 986 |  | 32 079 |  |
Expenses |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Purchases of crude oil and products |  | 1 563 |  | 623 |  | — |  | — |  | 16 656 |  | 14 011 |  | (4 086 | ) | (3 513 | ) | 14 133 |  | 11 121 |  |
Operating, selling and general |  | 7 570 |  | 6 257 |  | 503 |  | 422 |  | 1 979 |  | 1 950 |  | 521 |  | 559 |  | 10 573 |  | 9 188 |  |
Transportation |  | 1 144 |  | 827 |  | 85 |  | 86 |  | 137 |  | 110 |  | (47 | ) | (26 | ) | 1 319 |  | 997 |  |
Depreciation, depletion, amortization and impairment |  | 4 024 |  | 3 782 |  | 967 |  | 1 028 |  | 683 |  | 685 |  | 64 |  | 106 |  | 5 738 |  | 5 601 |  |
Exploration |  | 44 |  | 15 |  | 78 |  | 89 |  | — |  | — |  | — |  | — |  | 122 |  | 104 |  |
(Gain) loss on asset exchange and disposal of assets |  | (108 | ) | (50 | ) | 91 |  | — |  | (7 | ) | (455 | ) | — |  | (97 | ) | (24 | ) | (602 | ) |
Financing expenses (income) |  | 320 |  | 180 |  | 46 |  | 36 |  | 7 |  | 15 |  | 1 769 |  | (477 | ) | 2 142 |  | (246 | ) |
|  | 14 557 |  | 11 634 |  | 1 770 |  | 1 661 |  | 19 455 |  | 16 316 |  | (1 779 | ) | (3 448 | ) | 34 003 |  | 26 163 |  |
Earnings (Loss) before Income Taxes |  | 1 076 |  | 1 371 |  | 1 376 |  | 1 236 |  | 4 290 |  | 3 461 |  | (1 759 | ) | (152 | ) | 4 983 |  | 5 916 |  |
Income Tax Expense (Recovery) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Current |  | (128 | ) | 192 |  | 680 |  | 617 |  | 1 098 |  | 941 |  | (400 | ) | (541 | ) | 1 250 |  | 1 209 |  |
Deferred |  | 351 |  | 170 |  | (112 | ) | (113 | ) | 39 |  | (138 | ) | 162 |  | 330 |  | 440 |  | 249 |  |
|  | 223 |  | 362 |  | 568 |  | 504 |  | 1 137 |  | 803 |  | (238 | ) | (211 | ) | 1 690 |  | 1 458 |  |
Net Earnings (Loss) |  | 853 |  | 1 009 |  | 808 |  | 732 |  | 3 153 |  | 2 658 |  | (1 521 | ) | 59 |  | 3 293 |  | 4 458 |  |
Capital and Exploration Expenditures |  | 3 546 |  | 5 059 |  | 946 |  | 824 |  | 856 |  | 634 |  | 58 |  | 34 |  | 5 406 |  | 6 551 |  |

98 2018 ANNUAL REPORT Suncor Energy Inc.

Disaggregation of Revenue from Contracts with Customers and Intersegment Revenue

The company derives revenue from the transfer of goods mainly at a point in time in the following major commodities, revenue streams and geographical regions:

For the twelve months ended December 31 | 2018 |  | 2017 |  |
($ millions) | North America |  | International |  | Total |  | North America |  | International |  | Total |  |
Oil Sands |  |  |  |  |  |  |  |  |  |  |  |  |
| SCO and diesel | 11 659 |  | — |  | 11 659 |  | 11 244 |  | — |  | 11 244 |  |
| Bitumen | 4 084 |  | — |  | 4 084 |  | 2 030 |  | — |  | 2 030 |  |
| 15 743 |  | — |  | 15 743 |  | 13 274 |  | — |  | 13 274 |  |
Exploration and Production |  |  |  |  |  |  |  |  |  |  |  |  |
| Crude oil and natural gas liquids | 1 741 |  | 2 112 |  | 3 853 |  | 1 326 |  | 2 133 |  | 3 459 |  |
| Natural gas | 3 |  | 13 |  | 16 |  | 10 |  | 18 |  | 28 |  |
| 1 744 |  | 2 125 |  | 3 869 |  | 1 336 |  | 2 151 |  | 3 487 |  |
Refining and Marketing |  |  |  |  |  |  |  |  |  |  |  |  |
| Gasoline | 10 819 |  | — |  | 10 819 |  | 9 075 |  | — |  | 9 075 |  |
| Distillate | 9 698 |  | — |  | 9 698 |  | 7 800 |  | — |  | 7 800 |  |
| Other | 3 207 |  | — |  | 3 207 |  | 2 829 |  | — |  | 2 829 |  |
| 23 724 |  | — |  | 23 724 |  | 19 704 |  | — |  | 19 704 |  |
Corporate, Energy Trading and Eliminations | (3 744 | ) | — |  | (3 744 | ) | (3 580 | ) | — |  | (3 580 | ) |
Total Revenue from Contracts with Customers | 37 467 |  | 2 125 |  | 39 592 |  | 30 734 |  | 2 151 |  | 32 885 |  |

Geographical Information

Operating Revenues, net of Royalties

($ millions) |  | 2018 |  | 2017 |
|  | (restated – note 5) |
Canada |  | 30 418 |  | 25 551 |
United States |  | 5 999 |  | 4 252 |
Other foreign |  | 2 125 |  | 2 151 |
|  | 38 542 |  | 31 954 |

Non-Current Assets(1)

($ millions) |  | December 31 2018 |  | December 31 2017 |
Canada |  | 76 708 |  | 76 091 |
United States |  | 1 889 |  | 1 712 |
Other foreign |  | 2 154 |  | 2 014 |
|  | 80 751 |  | 79 817 |

(1)
  Excludes deferred income tax assets.

2018 ANNUAL REPORT Suncor Energy Inc. 99

7. OTHER INCOME

Other income consists of the following:

($ millions) |  | 2018 |  | 2017 |  |
Energy trading activities |  |  |  |  |  |
| Unrealized gains (losses) recognized in earnings |  | 129 |  | (37 | ) |
| Gains (losses) on inventory valuation |  | 13 |  | (39 | ) |
Risk management activities(1) |  | 126 |  | (19 | ) |
Investment and interest income |  | 34 |  | 162 |  |
Insurance proceeds(2) |  | 120 |  | 76 |  |
Change in value of pipeline commitments and other |  | 22 |  | (18 | ) |
|  | 444 |  | 125 |  |

(1)
  Includes fair value changes related to short-term derivative contracts in the Oil Sands and Refining and Marketing segments.
(2)
  2018 includes business interruption and property damage insurance proceeds for Syncrude and 2017 includes property damage insurance proceeds for Syncrude, in each case within the Oil Sands segment.

8. OPERATING, SELLING AND GENERAL

Operating, Selling and General expense consists of the following:

($ millions) |  | 2018 |  | 2017 |
|  | (restated – note 5) |
Contract services(1) |  | 4 552 |  | 3 551 |
Employee costs(1) |  | 3 263 |  | 3 290 |
Materials |  | 765 |  | 706 |
Energy |  | 1 095 |  | 1 121 |
Equipment rentals and leases |  | 360 |  | 279 |
Travel, marketing and other |  | 538 |  | 241 |
|  | 10 573 |  | 9 188 |

(1)
  The company incurred $8.3 billion of contract services and employee costs for the year ended December 31, 2018 (2017 – $7.3 billion), of which $7.8 billion (2017 – $6.8 billion) was recorded in Operating, Selling and General expense and $0.5 billion was recorded as Property, Plant and Equipment (2017 – $0.5 billion). Employee costs include salaries, benefits and share-based compensation.

9. FINANCING (INCOME) EXPENSES

($ millions) |  | 2018 |  | 2017 |  |
Interest on debt and finance leases |  | 897 |  | 945 |  |
Capitalized interest at 5.4% (2017 – 5.5%) |  | (156 | ) | (729 | ) |
| Interest expense |  | 741 |  | 216 |  |
| Interest on partnership liability (note 35) |  | 56 |  | 5 |  |
| Interest on pension and other post-retirement benefits |  | 56 |  | 58 |  |
| Accretion |  | 266 |  | 247 |  |
| Foreign exchange loss (gain) on U.S. dollar denominated debt |  | 1 090 |  | (771 | ) |
| Foreign exchange and other |  | (70 | ) | (52 | ) |
| Loss on extinguishment of long-term debt |  | 3 |  | 113 |  |
| Realized gain on foreign currency hedges |  | — |  | (62 | ) |
|  | 2 142 |  | (246 | ) |

100 2018 ANNUAL REPORT Suncor Energy Inc.

10. INCOME TAXES

Income Tax Expense (Recovery)

($ millions) |  | 2018 |  | 2017 |  |
Current: |  |  |  |  |  |
| Current year |  | 1 270 |  | 1 150 |  |
| Adjustments to current income tax of prior years |  | (20 | ) | 59 |  |
Deferred: |  |  |  |  |  |
| Origination and reversal of temporary differences |  | 345 |  | 476 |  |
| Adjustments in respect of deferred income tax of prior years |  | 13 |  | (70 | ) |
| Changes in tax rates and legislation |  | — |  | (106 | ) |
| Movement in unrecognized deferred income tax assets |  | 82 |  | (51 | ) |
Total income tax expense |  | 1 690 |  | 1 458 |  |

Reconciliation of Effective Tax Rate

The provision for income taxes reflects an effective tax rate that differs from the statutory tax rate. A reconciliation of the difference is as follows:

($ millions) |  | 2018 |  | 2017 |  |
Earnings before income tax |  | 4 983 |  | 5 916 |  |
Canadian statutory tax rate |  | 27.04% |  | 27.01% |  |
Statutory tax |  | 1 347 |  | 1 598 |  |
Add (deduct) the tax effect of: |  |  |  |  |  |
| Non-taxable component of capital losses (gains) |  | 146 |  | (90 | ) |
| Share-based compensation and other permanent items |  | 31 |  | (1 | ) |
| Assessments and adjustments |  | (7 | ) | (11 | ) |
| Impact of income tax rate and legislative changes |  | — |  | (106 | ) |
| Foreign tax rate differential |  | 111 |  | 180 |  |
| Non-taxable component of acquisitions and dispositions |  | (14 | ) | (41 | ) |
| Movement in unrecognized deferred income tax assets |  | 82 |  | (51 | ) |
| Other |  | (6 | ) | (20 | ) |
Total income tax expense |  | 1 690 |  | 1 458 |  |
Effective tax rate |  | 33.9% |  | 24.6% |  |

2018 ANNUAL REPORT Suncor Energy Inc. 101

Deferred Income Tax Balances

The significant components of the company's deferred income tax (assets) liabilities and deferred income tax expense (recovery) are comprised of the following:

|  | Deferred Income Tax Expense (Recovery) |  | Deferred Income Tax Liability (Asset) |  |
($ millions) |  | 2018 |  | 2017 |  | December 31 2018 |  | December 31 2017 |  |
Property, plant and equipment |  | 484 |  | 157 |  | 14 705 |  | 14 252 |  |
Decommissioning and restoration provision |  | 46 |  | 19 |  | (1 854 | ) | (1 910 | ) |
Employee retirement benefit plans |  | 15 |  | (5 | ) | (585 | ) | (639 | ) |
Tax loss carry-forwards |  | (63 | ) | — |  | (172 | ) | (109 | ) |
Other |  | (42 | ) | 78 |  | (177 | ) | (161 | ) |
Net deferred income tax expense and liability |  | 440 |  | 249 |  | 11 917 |  | 11 433 |  |

Change in Deferred Income Tax Balances

($ millions) |  | 2018 |  | 2017 |  |
Net deferred income tax liability, beginning of year |  | 11 433 |  | 11 180 |  |
Recognized in deferred income tax expense |  | 440 |  | 249 |  |
Recognized in other comprehensive income |  | 39 |  | 19 |  |
Foreign exchange, disposition and other |  | 5 |  | (15 | ) |
Net deferred income tax liability, end of year |  | 11 917 |  | 11 433 |  |

Deferred Tax in Shareholders' Equity

($ millions) |  | 2018 |  | 2017 |
Deferred Tax in Other Comprehensive Income |  |  |  |  |
| Actuarial gain on employment retirement benefit plans |  | 39 |  | 19 |
Total income tax expense reported in equity |  | 39 |  | 19 |

Deferred income tax assets are recognized for tax loss carry-forwards to the extent that the realization of the related tax benefit is probable based on estimated future earnings. Suncor has not recognized a $153 million (2017 – $75 million) deferred income tax asset on $1 134 million (2017 – $556 million) of capital losses related to foreign exchange on U.S. dollar denominated debt, which can only be utilized against future capital gains.

No deferred tax liability has been recognized at December 31, 2018, on temporary differences of approximately $9.7 billion (2017 – $9.6 billion) associated with earnings retained in our investments in foreign subsidiaries, as the company is able to control the timing of the reversal of these differences. Based on current plans, repatriation of funds in excess of foreign reinvestment will not result in material additional income tax expense. Deferred distribution taxes associated with international business operations have not been recorded.

In the fourth quarter of 2017, the U.S. government enacted a decrease in the federal corporate tax rate from 35% to 21% effective January 1, 2018. As a result, the company revalued its deferred income tax balances, resulting in a deferred income tax recovery of $124 million.

In the fourth quarter of 2017, the Government of British Columbia (B.C.) enacted an increase to the provincial corporate income tax rate from 11% to 12%. As a result, the company revalued its deferred income tax balances, resulting in a deferred income tax expense of $18 million.

102 2018 ANNUAL REPORT Suncor Energy Inc.

11. EARNINGS PER COMMON SHARE

($ millions) |  | 2018 |  | 2017 |  |
Net earnings |  | 3 293 |  | 4 458 |  |
Dilutive impact of accounting for awards as equity-settled(1) |  | — |  | (1 | ) |
Net earnings – diluted |  | 3 293 |  | 4 457 |  |
(millions of common shares) |  |  |  |  |  |
Weighted average number of common shares |  | 1 623 |  | 1 661 |  |
Dilutive securities: |  |  |  |  |  |
| Effect of share options |  | 6 |  | 4 |  |
Weighted average number of diluted common shares |  | 1 629 |  | 1 665 |  |
(dollars per common share) |  |  |  |  |  |
Basic earnings per share |  | 2.03 |  | 2.68 |  |
Diluted earnings per share |  | 2.02 |  | 2.68 |  |

(1)
  Cash payment alternatives are accounted for as cash-settled plans. As these awards can be exchanged for common shares of the company, they are considered potentially dilutive and are included in the calculation of the company's diluted net earnings per share if they have a dilutive impact in the period. Accounting for these awards as equity-settled was determined to have a dilutive impact for the year ended December 31, 2017.

12. CASH AND CASH EQUIVALENTS

($ millions) |  | December 31 2018 |  | December 31 2017 |
Cash |  | 1 285 |  | 1 184 |
Cash equivalents |  | 936 |  | 1 488 |
|  | 2 221 |  | 2 672 |

13. SUPPLEMENTAL CASH FLOW INFORMATION

The decrease (increase) in non-cash working capital is comprised of:

($ millions) |  | 2018 |  | 2017 |  |
Accounts receivable |  | 219 |  | (79 | ) |
Inventories |  | 316 |  | (268 | ) |
Accounts payable and accrued liabilities |  | (503 | ) | 68 |  |
Current portion of provisions |  | (110 | ) | (48 | ) |
Income taxes payable (net) |  | 511 |  | 421 |  |
|  | 433 |  | 94 |  |
Relating to: |  |  |  |  |  |
| Operating activities |  | 408 |  | (173 | ) |
| Investing activities |  | 25 |  | 267 |  |
|  | 433 |  | 94 |  |

2018 ANNUAL REPORT Suncor Energy Inc. 103

Reconciliation of movements of liabilities to cash flows arising from financing activities:

($ millions) | Short-Term Debt |  | Current Portion of Long-Term Debt |  | Long-Term Debt |  | Partnership Liability |  | Dividends Payable |  |
At December 31, 2017 | 2 136 |  | 71 |  | 13 372 |  | 483 |  | — |  |
Changes from financing cash flows: |  |  |  |  |  |  |  |  |  |  |
| Net issuance of commercial paper | 866 |  | — |  | — |  | — |  | — |  |
| Repayment of long-term debt | — |  | (109 | ) | — |  | — |  | — |  |
| Realized foreign exchange losses | 131 |  | 1 |  | — |  | — |  | — |  |
| Dividends paid on common shares | — |  | — |  | — |  | — |  | (2 333 | ) |
| Payments of finance lease liabilities | — |  | — |  | (74 | ) | — |  | — |  |
| Distributions to non-controlling interest | — |  | — |  | — |  | (6 | ) | — |  |
Non-cash changes: |  |  |  |  |  |  |  |  |  |  |
| Dividends declared on common shares | — |  | — |  | — |  | — |  | 2 333 |  |
| Unrealized foreign exchange losses | 98 |  | 9 |  | 851 |  | — |  | — |  |
| Deferred financing costs | — |  | — |  | (14 | ) | — |  | — |  |
| Modification to finance lease liabilities | — |  | — |  | 12 |  | — |  | — |  |
| Reclassification from long-term debt to current portion of long-term debt | — |  | 257 |  | (257 | ) | — |  | — |  |
At December 31, 2018 | 3 231 |  | 229 |  | 13 890 |  | 477 |  | — |  |

14. INVENTORIES

($ millions) |  | December 31 2018 |  | December 31 2017 |
Crude oil |  | 1 177 |  | 1 203 |
Refined products |  | 1 033 |  | 1 268 |
Materials, supplies and merchandise |  | 702 |  | 664 |
Energy trading commodity inventories |  | 247 |  | 333 |
|  | 3 159 |  | 3 468 |

During 2018, product inventories of $14.8 billion (2017 – $11.6 billion) were recorded as an expense. There was no write-down of crude oil (2017 – nil) and no write-down of materials, supplies and merchandise in 2018 (2017 – nil million). Energy trading commodity inventories are measured at fair value less costs of disposal based on Level 1 and Level 2 fair value inputs.

104 2018 ANNUAL REPORT Suncor Energy Inc.

15. PROPERTY, PLANT AND EQUIPMENT

($ millions) |  | Oil and Gas Properties |  | Plant and Equipment |  | Total |  |
Cost |  |  |  |  |  |  |  |
At December 31, 2016 |  | 34 141 |  | 73 537 |  | 107 678 |  |
| Additions |  | 1 235 |  | 5 875 |  | 7 110 |  |
| Acquisitions (note 32) |  | 25 |  | 310 |  | 335 |  |
| Changes in decommissioning and restoration |  | 821 |  | 22 |  | 843 |  |
| Disposals and derecognition |  | — |  | (884 | ) | (884 | ) |
| Foreign exchange adjustments |  | (13 | ) | (256 | ) | (269 | ) |
| Reclassified from assets held for sale (note 34) |  | — |  | 35 |  | 35 |  |
At December 31, 2017 |  | 36 209 |  | 78 639 |  | 114 848 |  |
| Additions |  | 1 221 |  | 3 958 |  | 5 179 |  |
| Transfers from exploration and evaluation |  | 31 |  | — |  | 31 |  |
| Acquisitions (notes 31, 32 and 36) |  | 289 |  | 948 |  | 1 237 |  |
| Changes in decommissioning and restoration |  | 85 |  | (22 | ) | 63 |  |
| Disposals and derecognition |  | (375 | ) | (4 785 | ) | (5 160 | ) |
| Foreign exchange adjustments |  | 385 |  | 291 |  | 676 |  |
At December 31, 2018 |  | 37 845 |  | 79 029 |  | 116 874 |  |
Accumulated provision |  |  |  |  |  |  |  |
At December 31, 2016 |  | (16 062 | ) | (20 357 | ) | (36 419 | ) |
| Depreciation and depletion |  | (1 916 | ) | (3 514 | ) | (5 430 | ) |
| Disposals and derecognition |  | — |  | 368 |  | 368 |  |
| Foreign exchange adjustments |  | 3 |  | 126 |  | 129 |  |
| Reclassified from assets held for sale (note 34) |  | — |  | (3 | ) | (3 | ) |
At December 31, 2017 |  | (17 975 | ) | (23 380 | ) | (41 355 | ) |
| Depreciation and depletion |  | (1 739 | ) | (3 849 | ) | (5 588 | ) |
| Disposals and derecognition |  | 255 |  | 4 545 |  | 4 800 |  |
| Foreign exchange adjustments |  | (324 | ) | (162 | ) | (486 | ) |
At December 31, 2018 |  | (19 783 | ) | (22 846 | ) | (42 629 | ) |
Net property, plant and equipment |  |  |  |  |  |  |  |
| December 31, 2017 |  | 18 234 |  | 55 259 |  | 73 493 |  |
| December 31, 2018 |  | 18 062 |  | 56 183 |  | 74 245 |  |

|  | December 31, 2018 |  | December 31, 2017 |
($ millions) |  | Cost |  | Accumulated Provision |  | Net Book Value |  | Cost |  | Accumulated Provision |  | Net Book Value |
Oil Sands |  | 80 295 |  | (22 654 | ) | 57 641 |  | 79 625 |  | (22 664 | ) | 56 961 |
Exploration and Production |  | 21 867 |  | (14 075 | ) | 7 792 |  | 21 007 |  | (12 990 | ) | 8 017 |
Refining and Marketing |  | 13 627 |  | (5 092 | ) | 8 535 |  | 13 137 |  | (4 906 | ) | 8 231 |
Corporate, Energy Trading and Eliminations |  | 1 085 |  | (808 | ) | 277 |  | 1 079 |  | (795 | ) | 284 |
|  | 116 874 |  | (42 629 | ) | 74 245 |  | 114 848 |  | (41 355 | ) | 73 493 |

2018 ANNUAL REPORT Suncor Energy Inc. 105

At December 31, 2018, the balance of assets under construction and not subject to depreciation or depletion was $4.7 billion (December 31, 2017 – $15.9 billion).

At December 31, 2018, Property, Plant and Equipment included finance leases with a net book value of $1.4 billion (December 31, 2017 – $1.4 billion).

16. EXPLORATION AND EVALUATION ASSETS

($ millions) |  | 2018 |  | 2017 |  |
Beginning of year |  | 2 052 |  | 2 038 |  |
Acquisitions and additions (Note 31) |  | 316 |  | 53 |  |
Transfers to oil and gas assets |  | (31 | ) | — |  |
Dry hole expenses |  | (11 | ) | (41 | ) |
Disposals |  | (16 | ) | — |  |
Amortization |  | (1 | ) | (1 | ) |
Foreign exchange adjustments |  | 10 |  | 3 |  |
End of year |  | 2 319 |  | 2 052 |  |

17. OTHER ASSETS

($ millions) |  | December 31 2018 |  | December 31 2017 |
Investments |  | 237 |  | 224 |
Prepaids and other |  | 889 |  | 987 |
|  | 1 126 |  | 1 211 |

Prepaids and other includes long-term accounts receivable related to deposits paid on Notices of Reassessments that have been received from the Canada Revenue Agency (CRA) and are unlikely to be settled within one year.

18. GOODWILL AND OTHER INTANGIBLE ASSETS

|  | Oil Sands |  | Refining and Marketing |  |  |  |
($ millions) |  | Goodwill |  | Goodwill |  | Brand Name |  | Customer Lists |  | Total |  |
At December 31, 2016 |  | 2 752 |  | 148 |  | 166 |  | 9 |  | 3 075 |  |
Disposal (note 33) |  | — |  | (8 | ) | (4 | ) | (1 | ) | (13 | ) |
Additions |  | — |  | — |  | — |  | 2 |  | 2 |  |
Amortization |  | — |  | — |  | — |  | (3 | ) | (3 | ) |
At December 31, 2017 |  | 2 752 |  | 140 |  | 162 |  | 7 |  | 3 061 |  |
Additions |  | — |  | — |  | — |  | 4 |  | 4 |  |
Amortization |  | — |  | — |  | — |  | (4 | ) | (4 | ) |
At December 31, 2018 |  | 2 752 |  | 140 |  | 162 |  | 7 |  | 3 061 |  |

The company performed a goodwill impairment test at December 31, 2018 on its Oil Sands CGUs. Recoverable amounts were based on fair value less costs of disposal calculated using the present value of the CGUs' expected future cash flows. The primary sources of cash flow information are derived from business plans approved by executives of the company, which

106 2018 ANNUAL REPORT Suncor Energy Inc.

were developed based on macroeconomic factors such as forward price curves for benchmark commodities, inflation rates and industry supply-demand fundamentals. When required, the projected cash flows in the business plans have been updated to reflect current market assessments of key assumptions, including long-term forecasts of commodity prices, inflation rates, foreign exchange rates and discount rates specific to the asset (Level 3 fair value inputs).

Cash flow forecasts are also based on past experience, historical trends and third-party evaluations of the company's reserves and resources to determine production profiles and volumes, operating costs, maintenance and capital expenditures. Production profiles, reserves volumes, operating costs, maintenance and capital expenditures are consistent with the estimates approved through the company's annual reserves evaluation process and determine the duration of the underlying cash flows used in the discounted cash flow test.

Future cash flow estimates are discounted using after-tax risk-adjusted discount rates. The discount rates are calculated based on the weighted average cost of capital of a group of relevant peers that is considered to represent the rate of return that would be required by a typical market participant for similar assets. The after-tax discount rate applied to cash flow projections was 8% (2017 – 8%). The company based its cash flow projections on an average West Texas Intermediate price of US$58.00 per barrel in 2019, US$70.40 per barrel in 2020, US$75.30 per barrel in 2021, US$80.10 per barrel in 2022 and then escalating at an average of 3% per year from 2023 to 2024 and at an average of 2% thereafter, adjusted for applicable quality and location differentials depending on the underlying CGU. The forecast cash flow period ranged from 20 years to 50 years based on the reserves life of the respective CGU. As a result of this analysis, management did not identify impairment within any of the CGUs comprising the Oil Sands operating segment and the associated allocated goodwill.

The company also performed a goodwill impairment test of its Refining and Marketing CGUs. The recoverable amounts are based on the fair value less costs of disposal calculated using the present value of the CGUs' expected future cash flows, based primarily on the business plan and historical results adjusted for current economic conditions, and escalated using an inflation rate of 2% of revenue and operating costs. The after-tax discount rates applied to the cash flow projection were between 10% and 12% (2017 – between 10% and 12%). As a result of this analysis, no impairment was identified within the operating segment or the associated allocated goodwill.

19. DEBT AND CREDIT FACILITIES

Debt and credit facilities are comprised of the following:

Short-Term Debt

($ millions) |  | December 31 2018 |  | December 31 2017 |
Commercial paper(1) |  | 3 231 |  | 2 136 |

(1)
  The commercial paper is supported by a revolving credit facility with a syndicate of lenders. The company is authorized to issue commercial paper to a maximum of $5.0 billion having a term not to exceed 365 days. The weighted average interest rate as at December 31, 2018 was 2.88% (December 31, 2017 – 1.56%).

2018 ANNUAL REPORT Suncor Energy Inc. 107

Long-Term Debt

($ millions) |  | December 31 2018 |  | December 31 2017 |  |
Fixed-term debt(2)(3) |  |  |  |  |  |
| 7.75% Notes, due 2019 (US$140)(4) |  | 191 |  | 288 |  |
| 3.10% Series 5 Medium Term Notes, due 2021 |  | 749 |  | 749 |  |
| 9.25% Debentures, due 2021 (US$300) |  | 431 |  | 406 |  |
| 9.40% Notes, due 2021 (US$220)(4)(5) |  | 315 |  | 298 |  |
| 4.50% Notes, due 2022 (US$182)(4) |  | 234 |  | 212 |  |
| 3.60% Notes, due 2024 (US$750) |  | 1 020 |  | 936 |  |
| 3.00% Series 5 Medium Term Notes, due 2026 |  | 698 |  | 698 |  |
| 7.875% Debentures, due 2026 (US$275) |  | 393 |  | 365 |  |
| 8.20% Notes, due 2027 (US$59)(4) |  | 87 |  | 81 |  |
| 7.00% Debentures, due 2028 (US$250) |  | 346 |  | 319 |  |
| 7.15% Notes, due 2032 (US$500) |  | 681 |  | 626 |  |
| 5.35% Notes, due 2033 (US$300) |  | 379 |  | 344 |  |
| 5.95% Notes, due 2034 (US$500) |  | 680 |  | 625 |  |
| 5.95% Notes, due 2035 (US$600) |  | 786 |  | 718 |  |
| 5.39% Series 4 Medium Term Notes, due 2037 |  | 599 |  | 599 |  |
| 6.50% Notes, due 2038 (US$1 150) |  | 1 565 |  | 1 439 |  |
| 6.80% Notes, due 2038 (US$900) |  | 1 249 |  | 1 151 |  |
| 6.85% Notes, due 2039 (US$750) |  | 1 021 |  | 938 |  |
| 6.00% Notes, due 2042 (US$152)(4) |  | 158 |  | 140 |  |
| 4.34% Series 5 Medium Term Notes, due 2046 |  | 300 |  | 300 |  |
| 4.00% Notes, due 2047 (US$750)(6) |  | 1 018 |  | 936 |  |
Total unsecured long-term debt |  | 12 900 |  | 12 168 |  |
Finance leases(7) |  | 1 260 |  | 1 319 |  |
Deferred financing costs |  | (41 | ) | (44 | ) |
|  | 14 119 |  | 13 443 |  |
Current portion of long-term debt |  |  |  |  |  |
| Finance leases |  | (38 | ) | (71 | ) |
| Long-term debt |  | (191 | ) | — |  |
|  | (229 | ) | (71 | ) |
Total long-term debt |  | 13 890 |  | 13 372 |  |

(2)
  The value of debt includes the unamortized balance of premiums or discounts.
(3)
  Certain securities are redeemable at the option of the company.
(4)
  Debt acquired through the acquisition of Canadian Oil Sands Limited (COS).
(5)
  Subsequent to the acquisition of COS, Moody's Investors Service downgraded COS long-term senior debt rating from Baa3 (negative outlook) to Ba3 (stable outlook). This triggered a change in the coupon rate of the note from 7.9% to 9.4%.
(6)
  During the fourth quarter of 2017, the company issued US$750 million of senior unsecured notes maturing on November 15, 2047. The notes have a coupon of 4.00% and were priced at $99.498 per note for an effective yield of 4.029%. Interest is paid semi-annually.
(7)
  Interest rates range from 2.9% to 16.5% and maturity dates range from 2027 to 2062.

During the fourth quarter of 2018, the company completed an early retirement of US$83 million (book value of $109 million) of subsidiary debt acquired through the acquisition of COS with a coupon of 7.75% originally scheduled to mature on

108 2018 ANNUAL REPORT Suncor Energy Inc.

May 15, 2019 for US$88 million ($116 million). The early retirement payment included US$3 million ($4 million) of accrued interest, resulting in a debt extinguishment loss of $3 million ($2 million after-tax).

During the second quarter of 2017, the company redeemed its US$1.250 billion (book value of $1.700 billion) senior unsecured notes originally scheduled to mature on June 1, 2018 for US$1.344 billion ($1.830 billion), including US$31 million ($42 million) of accrued interest. In conjunction with the early retirement of the notes, the company also realized gains of $62 million on foreign currency hedges, resulting in an overall debt extinguishment loss of $25 million ($10 million after-tax).

During the fourth quarter of 2017, the company redeemed its US$600 million (book value of $771 million) senior unsecured notes with a coupon of 6.05% originally scheduled to mature on May 15, 2018 for US$614 million ($788 million), including US$3 million ($4 million) of accrued interest. The company also redeemed its $700 million senior unsecured Series 4 Medium Term notes with a coupon of 5.80% originally scheduled to mature on May 22, 2018 for $715 million, including $3 million of accrued interest. The company realized an overall debt extinguishment loss of $26 million ($18 million after-tax).

Scheduled Debt Repayments

Scheduled principal repayments as at December 31, 2018 for finance leases, short-term debt and long-term debt are as follows:

($ millions) |  | Repayment |
2019 |  | 3 459 |
2020 |  | 39 |
2021 |  | 1 501 |
2022 |  | 295 |
2023 |  | 53 |
Thereafter |  | 12 108 |
|  | 17 455 |

Credit Facilities

A summary of available and unutilized credit facilities is as follows:

($ millions) |  | 2018 |  |
Fully revolving and expires in 2021 |  | 4 000 |  |
Fully revolving and expires in 2020 |  | 2 729 |  |
Fully revolving and expires in 2019/2020 |  | 1 537 |  |
Can be terminated at any time at the option of the lenders |  | 132 |  |
Total credit facilities |  | 8 398 |  |
Credit facilities supporting outstanding commercial paper |  | (3 231 | ) |
Credit facilities supporting standby letters of credit(1) |  | (1 269 | ) |
Total unutilized credit facilities(2) |  | 3 898 |  |

(1)
  To reduce costs, the company supported certain credit facilities with $108 million cash collateral as at December 31, 2018 (December 31, 2017 – $733 million).
(2)
  Available credit facilities for liquidity purposes at December 31, 2018 decreased to $3.608 billion, compared to $4.489 billion at December 31, 2017.

2018 ANNUAL REPORT Suncor Energy Inc. 109

20. OTHER LONG-TERM LIABILITIES

($ millions) |  | December 31 2018 |  | December 31 2017 |
Pensions and other post-retirement benefits (note 21) |  | 1 420 |  | 1 369 |
Share-based compensation plans (note 24) |  | 259 |  | 361 |
Partnership liability (note 35) |  | 470 |  | 483 |
Deferred revenue |  | 46 |  | 49 |
Libya Exploration and Production Sharing Agreement (EPSA) signature bonus(1) |  | 83 |  | 77 |
Other |  | 68 |  | 73 |
|  | 2 346 |  | 2 412 |

(1)
  As part of the 2009 acquisition of Petro-Canada, the company assumed the remaining US$500 million obligation for a signature bonus relating to Petro-Canada's ratification of six EPSAs in Libya. At December 31, 2018, the carrying amount of the Libya EPSAs signature bonus was $85 million (December 31, 2017 – $79 million). The current portion is $2 million (December 31, 2017 – $2 million) and is recorded in Accounts Payable and Accrued Liabilities.

21. PENSIONS AND OTHER POST-RETIREMENT BENEFITS

The company's defined benefit pension plans provide pension benefits at retirement based on years of service and final average earnings (if applicable). These obligations are met through funded registered retirement plans and through unregistered supplementary pensions that are funded through retirement compensation arrangements, and/or paid directly to recipients. The company's contributions to the funded plans are deposited with independent trustees who act as custodians of the plans' assets, as well as the disbursing agents of the benefits to recipients. Plan assets are managed by a pension committee on behalf of beneficiaries. The committee retains independent managers and advisors.

Asset-liability matching studies are performed by a third-party consultant to set the asset mix by quantifying the risk-and-return characteristics of possible asset mix strategies. Investment and contribution policies are integrated within this study, and areas of focus include asset mix as well as interest rate sensitivity.

Funding of the registered retirement plans complies with applicable regulations that require actuarial valuations of the pension funds at least once every three years in Canada and every year in the United States. The most recent valuations for the registered Canadian plans were performed as at January 31, 2017, and for the International plans were performed as at December 31, 2016. The company uses a measurement date of December 31 to value the plan assets and remeasure the accrued benefit obligation for accounting purposes.

The company's other post-retirement benefits programs are unfunded and include certain health care and life insurance benefits provided to retired employees and eligible surviving dependants.

The company reports its share of Syncrude's defined benefit and defined contribution pension plans and Syncrude's other post-retirement benefits plan.

The company also provides a number of defined contribution plans, including a U.S. 401(k) savings plan, that provide for an annual contribution of 5% to 11.5% of each participating employee's pensionable earnings.

110 2018 ANNUAL REPORT Suncor Energy Inc.

Defined Benefit Obligations and Funded Status

|  | Pension Benefits |  | Other Post-Retirement Benefits |  |
($ millions) |  | 2018 |  | 2017 |  | 2018 |  | 2017 |  |
Change in benefit obligation |  |  |  |  |  |  |  |  |  |
| Benefit obligation at beginning of year |  | 6 717 |  | 6 280 |  | 597 |  | 587 |  |
| Obligations acquired through acquisition (note 31) |  | 185 |  | — |  | 8 |  | — |  |
| Current service costs |  | 235 |  | 193 |  | 13 |  | 14 |  |
| Plan participants' contributions |  | 15 |  | 14 |  | — |  | — |  |
| Benefits paid |  | (296 | ) | (294 | ) | (23 | ) | (21 | ) |
| Interest costs |  | 236 |  | 236 |  | 21 |  | 22 |  |
| Disposal (note 33) |  | — |  | (69 | ) | — |  | (9 | ) |
| Foreign exchange |  | 14 |  | (2 | ) | 1 |  | (1 | ) |
| Settlements |  | 5 |  | 7 |  | — |  | — |  |
| Actuarial remeasurement: |  |  |  |  |  |  |  |  |  |
|  | Experience (gain) loss arising on plan liabilities |  | (26 | ) | 2 |  | (18 | ) | (12 | ) |
|  | Actuarial gain arising from changes in demographic assumptions |  | (1 | ) | (4 | ) | — |  | (9 | ) |
|  | Actuarial (gain) loss arising from changes in financial assumptions |  | (354 | ) | 354 |  | (42 | ) | 26 |  |
Benefit obligation at end of year |  | 6 730 |  | 6 717 |  | 557 |  | 597 |  |
Change in plan assets |  |  |  |  |  |  |  |  |  |
| Fair value of plan assets at beginning of year |  | 5 799 |  | 5 356 |  | — |  | — |  |
| Assets acquired through acquisition (note 31) |  | 153 |  | — |  | — |  | — |  |
| Employer contributions |  | 182 |  | 160 |  | — |  | — |  |
| Plan participants' contributions |  | 15 |  | 14 |  | — |  | — |  |
| Benefits paid |  | (273 | ) | (269 | ) | — |  | — |  |
| Disposal (note 33) |  | — |  | (71 | ) | — |  | — |  |
| Foreign exchange |  | 14 |  | (3 | ) | — |  | — |  |
| Settlements |  | 5 |  | 7 |  | — |  | — |  |
| Administrative costs |  | (2 | ) | (2 | ) | — |  | — |  |
| Income on plan assets |  | 201 |  | 200 |  | — |  | — |  |
| Actuarial remeasurement: |  |  |  |  |  |  |  |  |  |
|  | Return on plan assets (less than) greater than discount rate |  | (299 | ) | 407 |  | — |  | — |  |
Fair value of plan assets at end of year |  | 5 795 |  | 5 799 |  | — |  | — |  |
Net unfunded obligation |  | 935 |  | 918 |  | 557 |  | 597 |  |

Of the total net unfunded obligations as at December 31, 2018, 60% relates to Canadian pension plans and other post-retirement benefits obligation (excluding Syncrude) (December 31, 2017 – 67%). The weighted average duration of the defined benefit obligation under the Canadian pension plans and other post-retirement plans (excluding Syncrude) is 13.70 years (2017 – 13.91 years).

2018 ANNUAL REPORT Suncor Energy Inc. 111

The net unfunded obligation is recorded in Accounts Payable and Accrued Liabilities and Other Long-Term Liabilities (note 20) in the Consolidated Balance Sheets.

|  | Pension Benefits |  | Other Post-Retirement Benefits |
($ millions) |  | 2018 |  | 2017 |  | 2018 |  | 2017 |
Analysis of amount charged to earnings: |  |  |  |  |  |  |  |  |
| Current service costs |  | 235 |  | 193 |  | 13 |  | 14 |
| Interest costs |  | 35 |  | 36 |  | 21 |  | 22 |
Defined benefit plans expense |  | 270 |  | 229 |  | 34 |  | 36 |
Defined contribution plans expense |  | 77 |  | 74 |  | — |  | — |
Total benefit plans expense charged to earnings |  | 347 |  | 303 |  | 34 |  | 36 |

Components of defined benefit costs recognized in Other Comprehensive Income:

|  | Pension Benefits |  | Other Post-Retirement Benefits |  |
($ millions) |  | 2018 |  | 2017 |  | 2018 |  | 2017 |  |
Return on plan assets (excluding amounts included in net interest expense) |  | 299 |  | (407 | ) | — |  | — |  |
Experience (gain) loss arising on plan liabilities |  | (26 | ) | 2 |  | (18 | ) | (12 | ) |
Actuarial (gain) loss arising from changes in financial assumptions |  | (354 | ) | 354 |  | (42 | ) | 26 |  |
Actuarial gain arising from changes in demographic assumptions |  | (1 | ) | (4 | ) | — |  | (9 | ) |
Actuarial (gain) loss recognized in other comprehensive income |  | (82 | ) | (55 | ) | (60 | ) | 5 |  |

Actuarial Assumptions

The cost of the defined benefit pension plans and other post-retirement benefits received by employees is actuarially determined using the projected unit credit method of valuation that includes employee service to date and present pay levels, as well as the projection of salaries and service to retirement.

The significant weighted average actuarial assumptions were as follows:

|  | Pension Benefits |  | Other Post-Retirement Benefits |
(%) |  | December 31 2018 |  | December 31 2017 |  | December 31 2018 |  | December 31 2017 |
Discount rate |  | 3.80 |  | 3.40 |  | 3.90 |  | 3.40 |
Rate of compensation increase |  | 3.00 |  | 3.00 |  | 3.00 |  | 3.00 |

The discount rate assumption is based on the interest rate on high-quality bonds with maturity terms equivalent to the benefit obligations.

The defined benefit obligation reflects the best estimate of the mortality of plan participants both during and after their employment. The mortality assumption is based on a standard mortality table adjusted for actual experience over the past five years.

In order to measure the expected cost of other post-retirement benefits, it was assumed for 2018 that the health care costs would increase annually by 6.50% per person (2017 – 6.50%). This rate will remain constant until 2019 and then will decrease 0.5% annually to 5% by 2022, and remain at that level thereafter.

112 2018 ANNUAL REPORT Suncor Energy Inc.

Assumed discount rates and health care cost trend rates may have a significant effect on the amounts reported for pensions and other post-retirement benefits obligations for the company's Canadian plans. A change of these assumptions would have the following effects:

|  | Pension Benefits |
($ millions) |  | Increase |  | Decrease |
1% change in discount rate |  |  |  |  |
| Effect on the aggregate service and interest costs |  | (23 | ) | 30 |
| Effect on the benefit obligations |  | (874 | ) | 1 127 |

|  | Other Post-Retirement Benefits |  |
($ millions) |  | Increase |  | Decrease |  |
1% change in discount rate |  |  |  |  |  |
| Effect on the benefit obligations |  | (65 | ) | 81 |  |
1% change in health care cost |  |  |  |  |  |
| Effect on the aggregate service and interest costs |  | 1 |  | (1 | ) |
| Effect on the benefit obligations |  | 27 |  | (23 | ) |

Plan Assets and Investment Objectives

The company's long-term investment objective is to secure the defined pension benefits while managing the variability and level of its contributions. The portfolio is rebalanced periodically, as required, to the plans' target asset allocation as prescribed in the Statement of Investment Policies and Procedures approved by the Board of Directors. Plan assets are restricted to those permitted by legislation, where applicable. Investments are made through pooled, mutual, segregated or exchange traded funds.

The company's weighted average pension plan asset allocations, based on market values as at December 31, are as follows:

(%) |  | 2018 |  | 2017 |
Equities, comprised of: |  |  |  |  |
| – Canada |  | 13 |  | 18 |
| – United States |  | 17 |  | 19 |
| – Foreign |  | 18 |  | 19 |
|  | 48 |  | 56 |
Fixed income, comprised of: |  |  |  |  |
| – Canada |  | 43 |  | 39 |
Real estate, comprised of: |  |  |  |  |
| – Canada |  | 9 |  | 5 |
Total |  | 100 |  | 100 |

Equity securities do not include any direct investments in Suncor shares. The fair value of equity and fixed income securities is based on the trading price of the underlying fund. The fair value of real estate investments is based on independent third-party appraisals.

During the year, the company made cash contributions of $182 million (2017 – $160 million) to its defined benefit pension plans, of which $2 million (2017 – $3 million) was contributed to the solvency reserve account in Alberta. The company expects to make cash contributions to its defined benefit pension plans in 2019 of $172 million.

2018 ANNUAL REPORT Suncor Energy Inc. 113

22. PROVISIONS

($ millions) |  | Decommissioning and Restoration(1) |  | Royalties |  | Other(2) |  | Total |  |
At December 31, 2016 |  | 6 746 |  | 307 |  | 270 |  | 7 323 |  |
Liabilities incurred |  | 494 |  | 29 |  | 34 |  | 557 |  |
Change in discount rate |  | 255 |  | — |  | — |  | 255 |  |
Changes in estimates |  | 92 |  | (89 | ) | (6 | ) | (3 | ) |
Liabilities settled |  | (353 | ) | (7 | ) | (42 | ) | (402 | ) |
Accretion |  | 247 |  | — |  | — |  | 247 |  |
Asset acquisitions |  | 5 |  | — |  | — |  | 5 |  |
Foreign exchange |  | (21 | ) | — |  | (2 | ) | (23 | ) |
At December 31, 2017 |  | 7 465 |  | 240 |  | 254 |  | 7 959 |  |
Less: current portion |  | (434 | ) | (240 | ) | (48 | ) | (722 | ) |
|  | 7 031 |  | — |  | 206 |  | 7 237 |  |
At December 31, 2017 |  | 7 465 |  | 240 |  | 254 |  | 7 959 |  |
Liabilities incurred |  | 345 |  | 9 |  | 101 |  | 455 |  |
Change in discount rate |  | (663 | ) | — |  | — |  | (663 | ) |
Changes in estimates |  | 114 |  | (67 | ) | (16 | ) | 31 |  |
Liabilities settled |  | (469 | ) | (84 | ) | (25 | ) | (578 | ) |
Accretion |  | 266 |  | — |  | — |  | 266 |  |
Asset acquisitions |  | 133 |  | — |  | — |  | 133 |  |
Foreign exchange |  | 48 |  | — |  | — |  | 48 |  |
At December 31, 2018 |  | 7 239 |  | 98 |  | 314 |  | 7 651 |  |
Less: current portion |  | (538 | ) | (98 | ) | (31 | ) | (667 | ) |
|  | 6 701 |  | — |  | 283 |  | 6 984 |  |

(1)
  Represents decommissioning and restoration provisions associated with the retirement of Property, Plant and Equipment and Exploration and Evaluation assets. The total undiscounted amount of estimated future cash flows required to settle the obligations at December 31, 2018 was approximately $13.0 billion (December 31, 2017 – $12.2 billion). A weighted average credit-adjusted risk-free interest rate of 4.20% was used to discount the provision recognized at December 31, 2018 (December 31, 2017 – 3.70%). The credit-adjusted risk-free interest rate used reflects the expected time frame of the provisions. Payments to settle the decommissioning and restoration provisions occur on an ongoing basis and will continue over the lives of the operating assets, which can exceed 50 years.
(2)
  Includes legal, environmental and lease inducement provisions.

Sensitivities

Changes to the discount rate would have the following impact on Decommissioning and Restoration liabilities:

As at December 31 |  | 2018 |  | 2017 |  |
1% Increase |  | (1 099 | ) | (1 218 | ) |
1% Decrease |  | 1 521 |  | 1 758 |  |

114 2018 ANNUAL REPORT Suncor Energy Inc.

23. SHARE CAPITAL

Authorized

Common Shares

The company is authorized to issue an unlimited number of common shares without nominal or par value.

Preferred Shares

The company is authorized to issue an unlimited number of senior and junior preferred shares in series, without nominal or par value.

Normal Course Issuer Bid

On April 26, 2017, the company announced its intention to commence a Normal Course Issuer Bid (the 2017 NCIB) to repurchase common shares through the facilities of the Toronto Stock Exchange (the TSX), New York Stock Exchange (the NYSE) and/or alternative trading platforms. Pursuant to the 2017 NCIB, the company was permitted to purchase for cancellation up to approximately 50,079,795 of its common shares between May 2, 2017 and May 1, 2018.

On May 1, 2018, the company announced its intention to renew the 2017 NCIB (the 2018 NCIB) to continue to repurchase common shares through the facilities of the TSX, the NYSE and/or alternative trading platforms. Pursuant to the 2018 NCIB, the company was permitted to purchase for cancellation up to 52,285,330 of its common shares between May 4, 2018 and May 3, 2019. On November 14, 2018, Suncor announced an amendment to the 2018 NCIB, effective as of November 19, 2018, which allows the company to increase the maximum number of common shares that may be repurchased between May 4, 2018 and May 3, 2019 to 81,695,830. Subsequent to the end of the year, Suncor's Board of Directors approved a further share repurchase program of up to $2.0 billion.

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

($ millions except as noted) |  | 2018 |  | 2017 |
Share repurchase activities (thousands of common shares) |  |  |  |  |
| Shares repurchased |  | 64 426 |  | 33 154 |
Amounts charged to |  |  |  |  |
| Share capital |  | 1 040 |  | 536 |
| Retained earnings |  | 2 013 |  | 877 |
Share repurchase cost |  | 3 053 |  | 1 413 |
Average repurchase cost per share |  | 47.38 |  | 42.61 |

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 period:

($ millions) |  | December 31 2018 |  | December 31 2017 |
Amounts charged to |  |  |  |  |
| Share capital |  | 111 |  | 97 |
| Retained earnings |  | 152 |  | 180 |
Liability for share purchase commitment |  | 263 |  | 277 |

2018 ANNUAL REPORT Suncor Energy Inc. 115

24. SHARE-BASED COMPENSATION

Share-Based Compensation Expense

Reflected in the Consolidated Statements of Comprehensive Income within Operating, Selling and General expense are the following share-based compensation amounts:

($ millions) |  | 2018 |  | 2017 |
Equity-settled plans |  | 46 |  | 48 |
Cash-settled plans |  | 181 |  | 334 |
Total share-based compensation expense |  | 227 |  | 382 |

Liability Recognized for Share-Based Compensation

Reflected in the Consolidated Balance Sheets within accounts payable and accrued liabilities and other long-term liabilities are the following fair value amounts for the company's cash-settled plans:

($ millions) |  | 2018 |  | 2017 |
Current liability |  | 286 |  | 344 |
Long-term liability (note 20) |  | 259 |  | 361 |
Total Liability |  | 545 |  | 705 |

The intrinsic value of the vested awards at December 31, 2018 was $328 million (December 31, 2017 – $399 million).

Stock Option Plans

Suncor grants stock option awards as a form of retention and incentive compensation.

(a) Active Stock Option Plan

Stock options granted by the company on or after August 1, 2010 provide the holder with the right to purchase common shares at the market price on the grant date, subject to fulfilling vesting terms. This plan replaced the pre-merger stock option plan of legacy Suncor and legacy Petro-Canada. Options granted have a seven-year life, vest annually over a three-year period and are accounted for as equity-settled awards.

The weighted average fair value of options granted during the period and the weighted average assumptions used in their determination are as noted below:

|  | 2018 |  | 2017 |
Annual dividend per share |  | $1.44 |  | $1.28 |
Risk-free interest rate |  | 2.03% |  | 1.09% |
Expected life |  | 5 years |  | 5 years |
Expected volatility |  | 24% |  | 25% |
Weighted average fair value per option |  | $6.73 |  | $6.42 |

The expected life is based on historical stock option exercise data and current expectations. The expected volatility considers the historical volatility in the price of Suncor's common shares over a period similar to the life of the options, and is indicative of future trends.

(b) Discontinued Stock Option Plans

Executive and Key Contributor Stock Options

Options granted under these plans generally have a seven- to ten-year life and vest over a three-year period. These plans were in place prior to August 1, 2009, at the time of the merger between Petro-Canada and Suncor, and are accounted for as equity-settled awards.

116 2018 ANNUAL REPORT Suncor Energy Inc.

Suncor Energy Inc. Stock Options with Tandem Stock Appreciation Rights

Options granted between August 1, 2009 and July 31, 2010, have a seven-year life and vest annually over a three-year period. Each option included a tandem stock appreciation right (TSAR), allowing the option holder the right to receive a cash payment equal to the excess of the market price of Suncor's common shares at the time of exercise over the exercise price of the option. These awards are accounted for as cash-settled. All options granted under this plan expired at December 31, 2017.

The following table presents a summary of the activity related to Suncor's stock option plans:

|  | 2018 |  | 2017 |
|  | Number (thousands) |  | Weighted Average Exercise Price ($) |  | Number (thousands) |  | Weighted Average Exercise Price ($) |
Outstanding, beginning of year |  | 31 110 |  | 36.96 |  | 31 442 |  | 35.98 |
Granted |  | 7 231 |  | 43.19 |  | 7 401 |  | 42.04 |
Exercised for cash payment |  | — |  | — |  | (6 | ) | 32.00 |
Exercised as options for common shares |  | (7 927 | ) | 35.95 |  | (6 223 | ) | 36.65 |
Forfeited/expired |  | (1 479 | ) | 47.88 |  | (1 504 | ) | 42.21 |
Outstanding, end of year |  | 28 935 |  | 38.25 |  | 31 110 |  | 36.96 |
Exercisable, end of year |  | 15 374 |  | 36.10 |  | 17 363 |  | 36.53 |

Options are exercised regularly throughout the year. Therefore, the weighted average share price during the year of $46.99 (2017 – $41.09) is representative of the weighted average share price at the date of exercise.

For the options outstanding at December 31, 2018, the exercise price ranges and weighted average remaining contractual lives are shown below:

|  | Outstanding |  | Exercisable |
Exercise Prices ($) |  | Number (thousands) |  | Weighted Average Remaining Contractual Life (years) |  | Weighted Average Exercise Price ($) |  | Number (thousands) |  | Weighted Average Exercise Price ($) |
24.50-34.99 |  | 7 821 |  | 3 |  | 30.90 |  | 5 589 |  | 31.16 |
35.00-39.99 |  | 7 214 |  | 3 |  | 37.74 |  | 7 195 |  | 37.74 |
40.00-44.99 |  | 13 714 |  | 6 |  | 42.53 |  | 2 590 |  | 42.19 |
45.00-49.99 |  | 58 |  | 7 |  | 47.82 |  | — |  | — |
50.00-54.27 |  | 128 |  | 7 |  | 52.40 |  | — |  | — |
Total |  | 28 935 |  | 4 |  | 38.25 |  | 15 374 |  | 36.10 |

Common shares authorized for issuance by the Board of Directors that remain available for the granting of future options:

(thousands) |  | 2018 |  | 2017 |
|  | 21 929 |  | 28 972 |

2018 ANNUAL REPORT Suncor Energy Inc. 117

Share Unit Plans

Suncor grants share units as a form of retention and incentive compensation. Share unit plans are accounted for as cash-settled awards.

(a) Performance Share Units (PSUs)

A PSU is a time-vested award entitling employees to receive varying degrees of cash (0% – 200% of the company's share price at time of vesting) contingent upon Suncor's total shareholder return (stock price appreciation and dividend income) relative to a peer group of companies. PSUs vest approximately three years after the grant date.

(b) Restricted Share Units (RSUs)

A RSU is a time-vested award entitling employees to receive cash calculated based on an average of the company's share price leading up to vesting. RSUs vest approximately three years after the grant date.

(c) Deferred Share Units (DSUs)

A DSU is redeemable for cash or a common share for a period of time after a unitholder ceases employment or Board membership. The DSU Plan is limited to executives and members of the Board of Directors. Members of the Board of Directors receive an annual grant of DSUs as part of their compensation and may elect to receive their fees in cash only or in increments of 50% or 100% allocated to DSUs. Executives may elect to receive their annual incentive bonus in cash only or in increments of 25%, 50%, 75% or 100% allocated to DSUs.

The following table presents a summary of the activity related to Suncor's share unit plans:

(thousands) |  | PSU |  | RSU |  | DSU |  |
Outstanding, December 31, 2016 |  | 2 413 |  | 18 158 |  | 1 218 |  |
| Granted |  | 1 570 |  | 5 009 |  | 202 |  |
| Redeemed for cash |  | (1 663 | ) | (6 354 | ) | (118 | ) |
| Forfeited/expired |  | (53 | ) | (741 | ) | — |  |
Outstanding, December 31, 2017 |  | 2 267 |  | 16 072 |  | 1 302 |  |
| Granted |  | 1 553 |  | 4 796 |  | 192 |  |
| Redeemed for cash |  | (1 623 | ) | (5 962 | ) | (189 | ) |
| Forfeited/expired |  | — |  | (314 | ) | — |  |
Outstanding, December 31, 2018 |  | 2 197 |  | 14 592 |  | 1 305 |  |

Stock Appreciation Rights (SARs)

A SAR entitles the holder to receive a cash payment equal to the difference between the stated exercise price and the market price of the company's common shares on the date the SAR is exercised, and is accounted for as a cash-settled award.

SARs have a seven-year life and vest annually over a three-year period.

The following table presents a summary of the activity related to Suncor's SARs plan:

|  | 2018 |  | 2017 |
|  | Number (thousands) |  | Weighted Average Exercise Price ($) |  | Number (thousands) |  | Weighted Average Exercise Price ($) |
Outstanding, beginning of year |  | 387 |  | 36.38 |  | 485 |  | 34.90 |
Granted |  | 108 |  | 43.09 |  | 107 |  | 42.05 |
Exercised |  | (126 | ) | 35.65 |  | (176 | ) | 35.59 |
Forfeited/expired |  | (6 | ) | 38.36 |  | (29 | ) | 37.32 |
Outstanding, end of year |  | 363 |  | 38.60 |  | 387 |  | 36.38 |
Exercisable, end of year |  | 170 |  | 36.57 |  | 162 |  | 35.39 |

118 2018 ANNUAL REPORT Suncor Energy Inc.

25. FINANCIAL INSTRUMENTS AND RISK MANAGEMENT

The company's financial instruments consist of cash and cash equivalents, accounts receivable, derivative contracts, substantially all accounts payable and accrued liabilities, debt, and certain portions of other assets and other long-term liabilities.

Non-Derivative Financial Instruments

The fair values of cash and cash equivalents, accounts receivable, short-term debt, and accounts payable and accrued liabilities approximate their carrying values due to the short-term maturities of those instruments.

The company's long-term debt and long-term financial liabilities are recorded at amortized cost using the effective interest method. At December 31, 2018, the carrying value of fixed-term debt accounted for under amortized cost was $12.9 billion (December 31, 2017 – $12.1 billion) and the fair value at December 31, 2018 was $14.2 billion (December 31, 2017 – $14.7 billion). The estimated fair value of long-term debt is based on pricing sourced from market data, which is considered a Level 2 fair value input.

Suncor entered into a partnership with Fort McKay First Nation (FMFN) and Mikisew Cree First Nation (MCFN) where FMFN and MCFN acquired a combined 49% partnership interest in the East Tank Farm Development. The partnership liability is recorded at amortized cost using the effective interest method. At December 31, 2018, the carrying value of the Partnership liability accounted for under amortized cost was $477 million (December 31, 2017 – $483 million) (note 35).

Derivative Financial Instruments

(a) Non-Designated Derivative Financial Instruments

•
  Energy Trading Derivatives – The company's Energy Trading group uses physical and financial energy derivative contracts, including swaps, forwards and options to earn trading revenues.
•
  Risk Management Derivatives – The company periodically enters into derivative contracts in order to manage exposure to interest rates, commodity price and foreign exchange movements and which are a component of the company's overall risk management program.

The changes in the fair value of non-designated Energy Trading and Risk Management derivatives are as follows:

($ millions) |  | Energy Trading |  | Risk Management |  | Total |  |
Fair value outstanding at December 31, 2016 |  | (36 | ) | (18 | ) | (54 | ) |
| Cash Settlements – (received) paid during the year |  | (12 | ) | 17 |  | 5 |  |
| Unrealized losses recognized in earnings during the year (note 7) |  | (37 | ) | (19 | ) | (56 | ) |
Fair value outstanding at December 31, 2017 |  | (85 | ) | (20 | ) | (105 | ) |
| Cash Settlements – received during the year |  | (43 | ) | (47 | ) | (90 | ) |
| Unrealized gains recognized in earnings during the year (note 7) |  | 129 |  | 126 |  | 255 |  |
Fair value outstanding at December 31, 2018 |  | 1 |  | 59 |  | 60 |  |

(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

2018 ANNUAL REPORT Suncor Energy Inc. 119

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 December 31, 2018, 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 instrument assets and liabilities and assets available for sale measured at fair value for each hierarchy level as at December 31, 2018 and 2017.

($ millions) |  | Level 1 |  | Level 2 |  | Level 3 |  | Total Fair Value |  |
| Accounts receivable |  | 21 |  | 53 |  | — |  | 74 |  |
| Accounts payable |  | (74 | ) | (105 | ) | — |  | (179 | ) |
Balance at December 31, 2017 |  | (53 | ) | (52 | ) | — |  | (105 | ) |
| Accounts receivable |  | 63 |  | 152 |  | — |  | 215 |  |
| Accounts payable |  | (43 | ) | (112 | ) | — |  | (155 | ) |
Balance at December 31, 2018 |  | 20 |  | 40 |  | — |  | 60 |  |

During the year ended December 31, 2018, there were no transfers between Level 1 and Level 2 fair value measurements.

Offsetting Financial Assets and Liabilities

The company enters into arrangements that allow for offsetting of derivative financial instruments and accounts receivable (payable), which are presented on a net basis on the balance sheet, as shown in the table below as at December 31, 2018 and 2017.

Financial Assets

($ millions) |  | Gross Assets |  | Gross Liabilities Offset |  | Net Amounts Presented |
Derivatives |  | 1 126 |  | (1 052 | ) | 74 |
Accounts receivable |  | 2 405 |  | (1 252 | ) | 1 153 |
Balance at December 31, 2017 |  | 3 531 |  | (2 304 | ) | 1 227 |
Derivatives |  | 1 599 |  | (1 384 | ) | 215 |
Accounts receivable |  | 1 837 |  | (882 | ) | 955 |
Balance at December 31, 2018 |  | 3 436 |  | (2 266 | ) | 1 170 |

Financial Liabilities

($ millions) |  | Gross Liabilities |  | Gross Assets Offset |  | Net Amounts Presented |  |
Derivatives |  | (1 231 | ) | 1 052 |  | (179 | ) |
Accounts payable |  | (2 270 | ) | 1 252 |  | (1 018 | ) |
Balance at December 31, 2017 |  | (3 501 | ) | 2 304 |  | (1 197 | ) |
Derivatives |  | (1 539 | ) | 1 384 |  | (155 | ) |
Accounts payable |  | (1 798 | ) | 882 |  | (916 | ) |
Balance at December 31, 2018 |  | (3 337 | ) | 2 266 |  | (1 071 | ) |

120 2018 ANNUAL REPORT Suncor Energy Inc.

Risk Management

The company is exposed to a number of different risks arising from financial instruments. These risk factors include market risks, comprising commodity price risk, foreign currency risk and interest rate risk, as well as liquidity risk and credit risk.

The company maintains a formal governance process to manage its financial risks. The company's Commodity Risk Management Committee (CRMC) is charged with the oversight of the company's trading and credit risk management activities. Trading activities are defined as activities intended to manage risk associated with open price exposure of specific volumes in transit or storage, enhance the company's operations, and enhance profitability through informed market calls, market diversification, economies of scale, improved transportation access, and leverage of assets, both physical and contractual. The CRMC, acting under the authority of the company's Board of Directors, meets regularly to monitor limits on risk exposures, review policy compliance and validate risk-related methodologies and procedures.

The nature of the risks faced by the company and its policies for managing such risks remains unchanged from December 31, 2017.

1) Market Risk

Market risk is the risk or uncertainty arising from market price movements and their impact on the future performance of the business. The market price movements that could adversely affect the value of the company's financial assets, liabilities and expected future cash flows include commodity price risk, foreign currency exchange risk and interest rate risk.

(a) Commodity Price Risk

Suncor's financial performance is closely linked to crude oil prices (including pricing differentials for various product types) and, to a lesser extent, natural gas and refined product prices. The company may reduce its exposure to commodity price risk through a number of strategies. These strategies include entering into option contracts to limit exposure to changes in crude oil prices during transportation.

An increase of US$10.00 per barrel of crude oil as at December 31, 2018 would decrease pre-tax earnings for the company's outstanding derivative financial instruments by approximately $39 million (2017 – $196 million).

(b) Foreign Currency Exchange Risk

The company is exposed to foreign currency exchange risk on revenues, capital expenditures, or financial instruments that are denominated in a currency other than the company's functional currency (Canadian dollars). As crude oil is priced in U.S. dollars, fluctuations in US$/Cdn$ exchange rates may have a significant impact on revenues. This exposure is partially offset through the issuance of U.S. dollar denominated debt. A 1% strengthening in the Cdn$ relative to the US$ as at December 31, 2018 would increase pre-tax earnings related to the company's debt by approximately $167 million (2017 – $142 million).

(c) Interest Rate Risk

The company is exposed to interest rate risk as changes in interest rates may affect future cash flows and the fair values of its financial instruments. The primary exposure is related to its revolving-term debt of commercial paper and future debt issuances.

To manage the company's exposure to interest rate volatility, the company may periodically enter into interest rate swap contracts to fix the interest rate of future debt issuances. As at December 31, 2018, the company had no outstanding forward starting swaps. The weighted average interest rate on total debt for the year ended December 31, 2018 was 5.4% (2017 – 5.7%).

The company's net earnings are sensitive to changes in interest rates on the floating rate portion of the company's debt, which are offset by cash balances. To the extent interest expense is not capitalized, if interest rates applicable to floating rate instruments increased by 1%, it is estimated that the company's pre-tax earnings would decrease by approximately $10 million (2017 – increase by approximately $6 million). This assumes that the amount and mix of fixed and floating rate debt remains unchanged from December 31, 2018. The proportion of floating interest rate exposure at December 31, 2018 was 18.6% of total debt outstanding (2017 – 14.9%).

2) Liquidity Risk

Liquidity risk is the risk that Suncor will not be able to meet its financial obligations when due. The company mitigates this risk by forecasting spending requirements as well as cash flow from operating activities, and maintaining sufficient cash, credit facilities, and debt shelf prospectuses to meet these requirements. Suncor's cash and cash equivalents and total credit facilities at December 31, 2018 were $2.2 billion and $8.4 billion, respectively. Of Suncor's $8.4 billion in total credit facilities,

2018 ANNUAL REPORT Suncor Energy Inc. 121

$3.9 billion were available at December 31, 2018. In addition, Suncor has $3.0 billion of unused capacity under a Canadian debt shelf prospectus and an unused capacity of US$3.0 billion under a U.S. debt shelf prospectus.

Surplus cash is invested into a range of short-dated money market securities. Investments are only permitted in high credit quality government or corporate securities. Diversification of these investments is managed through counterparty credit limits.

The following table shows the timing of cash outflows related to trade and other payables and debt.

|  | December 31, 2017 |
($ millions) |  | Trade and Other Payables(1) |  | Gross Derivative Liabilities(2) |  | Debt(3) |
Within one year |  | 6 024 |  | 1 231 |  | 3 027 |
1 to 3 years |  | 38 |  | — |  | 1 949 |
3 to 5 years |  | 38 |  | — |  | 3 184 |
Over 5 years |  | — |  | — |  | 20 160 |
|  | 6 100 |  | 1 231 |  | 28 320 |

|  | December 31, 2018 |
($ millions) |  | Trade and Other Payables(1) |  | Gross Derivative Liabilities(2) |  | Debt(3) |
Within one year |  | 5 492 |  | 1 539 |  | 4 314 |
1 to 3 years |  | 42 |  | — |  | 3 362 |
3 to 5 years |  | 42 |  | — |  | 1 827 |
Over 5 years |  | — |  | — |  | 20 611 |
|  | 5 576 |  | 1 539 |  | 30 114 |

(1)
  Trade and other payables exclude net derivative liabilities of $155 million (2017 – $179 million).
(2)
  Gross derivative liabilities of $1 539 million (2017 – $1 231 million) are offset by gross derivative assets of $1 384 million (2017 – $1 052 million), resulting in a net amount of $155 million (2017 – $179 million).
(3)
  Debt includes short-term debt, long-term debt, finance leases and interest payments on fixed-term debt and commercial paper.

3) Credit Risk

Credit risk is the risk that a customer or counterparty will fail to perform an obligation or fail to pay amounts due, causing a financial loss. The company's credit policy is designed to ensure there is a standard credit practice throughout the company to measure and monitor credit risk. The policy outlines delegation of authority, the due diligence process required to approve a new customer or counterparty and the maximum amount of credit exposure per single entity. Before transactions begin with a new customer or counterparty, its creditworthiness is assessed, a credit rating and a maximum credit limit are assigned. The assessment process is outlined in the credit policy and considers both quantitative and qualitative factors. The company constantly monitors the exposure to any single customer or counterparty along with the financial position of the customer or counterparty. If it is deemed that a customer or counterparty has become materially weaker, the company will work to reduce the credit exposure and lower the assigned credit limit. Regular reports are generated to monitor credit risk and the Credit Committee meets quarterly to ensure compliance with the credit policy and review the exposures.

A substantial portion of the company's accounts receivable are with customers in the oil and gas industry and are subject to normal industry credit risk. At December 31, 2018, substantially all of the company's trade receivables were current.

The company may be exposed to certain losses in the event that counterparties to derivative financial instruments are unable to meet the terms of the contracts. The company's exposure is limited to those counterparties holding derivative contracts owing to the company at the reporting date. At December 31, 2018, the company's exposure was $1 599 million (December 31, 2017 – $1 126 million).

122 2018 ANNUAL REPORT Suncor Energy Inc.

26. CAPITAL STRUCTURE FINANCIAL POLICIES

The company's primary capital management strategy is to maintain a conservative balance sheet, which supports a solid investment grade credit rating profile. This objective affords the company the financial flexibility and access to the capital it requires to execute on its growth objectives.

The company's capital is primarily monitored by reviewing the ratios of net debt to funds from operations(1) and total debt to total debt plus shareholders' equity.

Net debt to funds from operations is calculated as short-term debt plus total long-term debt less cash and cash equivalents, divided by funds from operations for the year then ended.

Total debt to total debt plus shareholders' equity is calculated as short-term debt plus total long-term debt divided by short-term debt plus total long-term debt plus shareholders' equity. This financial covenant under the company's various banking and debt agreements shall not be greater than 65%.

The company's financial covenant is reviewed regularly and controls are in place to maintain compliance with the covenant. The company complied with financial covenants for the years ended December 31, 2018 and 2017. The company's financial measures, as set out in the following schedule, were unchanged from 2017. The company believes that achieving its capital target helps to provide the company access to capital at a reasonable cost by maintaining solid investment grade credit ratings. The company operates in a fluctuating business environment and ratios may periodically fall outside of management's targets. The company addresses these fluctuations by capital expenditure reductions and sales of non-core assets to ensure net debt achieves management's targets.

($ millions) |  | Capital Measure Target |  | December 31, 2018 |  | December 31, 2017 |
Components of ratios |  |  |  |  |  |  |
| Short-term debt |  |  |  | 3 231 |  | 2 136 |
| Current portion of long-term debt |  |  |  | 229 |  | 71 |
| Long-term debt |  |  |  | 13 890 |  | 13 372 |
|  | Total debt |  |  |  | 17 350 |  | 15 579 |
| Less: Cash and cash equivalents |  |  |  | 2 221 |  | 2 672 |
|  | Net debt |  |  |  | 15 129 |  | 12 907 |
| Shareholders' equity |  |  |  | 44 005 |  | 45 383 |
| Total capitalization (total debt plus shareholders' equity) |  |  |  | 61 355 |  | 60 962 |
| Funds from operations(1) |  |  |  | 10 172 |  | 9 139 |
Net debt to funds from operations |  | <3.0 times |  | 1.5 |  | 1.4 |
Total debt to total debt plus shareholders' equity |  |  |  | 28% |  | 26% |

(1)
  Funds from operations is calculated as cash flow from operating activities before changes in non-cash working capital, and is a non-GAAP financial measure.

2018 ANNUAL REPORT Suncor Energy Inc. 123

27. JOINT ARRANGEMENTS

Joint Operations

The company's material joint operations as at December 31 are set out below:

Material Joint Operations |  | Principal Activity |  | Country of Incorporation and Principal Place of Business |  | Ownership % 2018 |  | Ownership % 2017 |
Oil Sands |  |  |  |  |  |  |  |  |
Operated by Suncor: |  |  |  |  |  |  |  |  |
| Fort Hills Energy Limited Partnership |  | Oil sands development |  | Canada |  | 54.11 |  | 53.06 |
Non-operated: |  |  |  |  |  |  |  |  |
| Syncrude |  | Oil sands development |  | Canada |  | 58.74 |  | 53.74 |
Exploration and Production |  |  |  |  |  |  |  |  |
Operated by Suncor: |  |  |  |  |  |  |  |  |
| Terra Nova |  | Oil and gas production |  | Canada |  | 37.68 |  | 37.68 |
Non-operated: |  |  |  |  |  |  |  |  |
| Buzzard |  | Oil and gas production |  | United Kingdom |  | 29.89 |  | 29.89 |
| Fenja Development JV |  | Oil and gas production |  | Norway |  | 17.50 |  | — |
| Golden Eagle Area Development |  | Oil and gas production |  | United Kingdom |  | 26.69 |  | 26.69 |
| Hibernia and the Hibernia South Extension Unit |  | Oil and gas production |  | Canada |  | 19.19-20.00 |  | 19.19-20.00 |
| Hebron |  | Oil and gas production |  | Canada |  | 21.03 |  | 21.03 |
| Harouge Oil Operations |  | Oil and gas production |  | Libya |  | 49.00 |  | 49.00 |
| North Sea Rosebank Project |  | Oil and gas production |  | United Kingdom |  | 40.00 |  | 30.00 |
| Oda |  | Oil and gas production |  | Norway |  | 30.00 |  | 30.00 |
| White Rose and the White Rose Extensions |  | Oil and gas production |  | Canada |  | 26.13-27.50 |  | 26.13-27.50 |

Joint Ventures and Associates

The company does not have any joint ventures or associates that are considered individually material. Summarized aggregate financial information of the joint ventures and associates, which are all included in the company's Exploration and Production and Refining and Marketing operations, are shown below:

|  | Joint ventures |  | Associates |  |
($ millions) |  | 2018 |  | 2017 |  | 2018 |  | 2017 |  |
Net earnings (loss) |  | 11 |  | 1 |  | (19 | ) | (3 | ) |
Other comprehensive income |  | — |  | — |  | — |  | — |  |
Total comprehensive income (loss) |  | 11 |  | 1 |  | (19 | ) | (3 | ) |
Carrying amount as at December 31 |  | 75 |  | 51 |  | 110 |  | 89 |  |

124 2018 ANNUAL REPORT Suncor Energy Inc.

28. SUBSIDIARIES

Material subsidiaries, each of which is wholly owned, either directly or indirectly, by the company as at December 31, 2018 are shown below:

Material Subsidiaries |  | Principal Activity |
Canadian Operations |  |  |
Suncor Energy Oil Sands Limited Partnership |  | This partnership holds most of the company's Oil Sands operations assets. |
Suncor Energy Ventures Corporation |  | A subsidiary which indirectly owns a 36.74% ownership in the Syncrude joint operation previously owned by COS. |
Suncor Energy Ventures Partnership |  | A subsidiary which owns a 22% ownership in the Syncrude joint operation. |
Suncor Energy Products Partnership |  | This partnership holds substantially all of the company's Canadian refining and marketing assets. |
Suncor Energy Marketing Inc. |  | Through this subsidiary, production from the upstream Canadian businesses is marketed. This subsidiary also administers Suncor's energy trading activities and power business, markets certain third-party products, procures crude oil feedstock and natural gas for its downstream business, and procures and markets natural gas liquids (NGLs) and liquefied petroleum gas (LPG) for its downstream business. |
U.S. Operations |  |  |
Suncor Energy (U.S.A.) Marketing Inc. |  | A subsidiary that procures and markets third-party crude oil, in addition to procuring crude oil feedstock for the company's refining operations. |
Suncor Energy (U.S.A.) Inc. |  | A subsidiary through which the company's U.S. refining and marketing operations are conducted. |
International Operations |  |  |
Suncor Energy UK Limited |  | A subsidiary through which the majority of the company's North Sea operations are conducted. |

The table does not include wholly owned subsidiaries that are immediate holding companies of the operating subsidiaries. For certain foreign operations of the company, there are restrictions on the sale or transfer of production licences, which would require approval of the applicable foreign government.

2018 ANNUAL REPORT Suncor Energy Inc. 125

29. RELATED PARTY DISCLOSURES

Related Party Transactions

The company enters into transactions with related parties in the normal course of business, which includes purchases of feedstock, distribution of refined products, and sale of refined products and byproducts. These transactions are with joint ventures and associated entities in the company's Refining and Marketing operations, including pipeline, refined product and petrochemical companies. A summary of the significant related party transactions as at and for the year ended December 31, 2018 and 2017 are as follows:

($ millions) |  | 2018 |  | 2017 |
Sales(1) |  | 723 |  | 590 |
Purchases |  | 237 |  | 223 |
Accounts receivable |  | 33 |  | 44 |
Accounts payable and accrued liabilities |  | 15 |  | 28 |

(1)
  Includes sales to Parachem Chemicals Inc. of $338 million (2017 – $301 million).

Compensation of Key Management Personnel

Compensation of the company's Board of Directors and members of the Executive Leadership Team for the years ended December 31 is as follows:

($ millions) |  | 2018 |  | 2017 |
Salaries and other short-term benefits |  | 15 |  | 12 |
Pension and other post-retirement benefits |  | 5 |  | 5 |
Share-based compensation |  | 32 |  | 49 |
|  | 52 |  | 66 |

30. COMMITMENTS, CONTINGENCIES AND GUARANTEES

(a) Commitments

Future payments under the company's commitments, including service arrangements for pipeline transportation agreements and for various premises, service stations and other property and equipment, are as follows:

|  | Payment Due by Period |
($ millions) |  | 2019 |  | 2020 |  | 2021 |  | 2022 |  | 2023 |  | 2024 and Beyond |  | Total |
Commitments |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
| Product transportation and storage |  | 1 053 |  | 948 |  | 1 058 |  | 1 181 |  | 1 149 |  | 13 211 |  | 18 600 |
| Energy services |  | 139 |  | 136 |  | 173 |  | 116 |  | 118 |  | 183 |  | 865 |
| Exploration work commitments |  | 33 |  | — |  | 44 |  | — |  | — |  | 490 |  | 567 |
| Other |  | 358 |  | 283 |  | 135 |  | 75 |  | 69 |  | 195 |  | 1 115 |
Operating leases |  | 346 |  | 304 |  | 266 |  | 203 |  | 156 |  | 1 182 |  | 2 457 |
|  | 1 929 |  | 1 671 |  | 1 676 |  | 1 575 |  | 1 492 |  | 15 261 |  | 23 604 |

The operating leases noted above will be captured in the IFRS 16 transition adjustment effective January 1, 2019, except for short-term leases (see note 5). The operating leases expire at various dates through 2058. For the year ended December 31, 2018, operating lease expense was $324 million (2017 – $400 million).

In addition to the commitments in the above table, the company has other obligations for goods and services and raw materials entered into in the normal course of business, which may terminate on short notice. Such obligations include commodity purchase obligations which are transacted at market prices.

126 2018 ANNUAL REPORT Suncor Energy Inc.

(b) Contingencies

Legal and Environmental Contingent Liabilities

The company is defendant and plaintiff in a number of legal actions that arise in the normal course of business. The company believes that any liabilities that might arise pertaining to such matters would not have a material effect on its consolidated financial position.

The company may also have environmental contingent liabilities, beyond decommissioning and restoration liabilities (recognized in note 22), which are reviewed individually and are reflected in the company's consolidated financial statements if material and more likely than not to be incurred. These contingent environmental liabilities primarily relate to the mitigation of contamination at sites where the company has had operations. For any unrecognized environmental contingencies, the company believes that any liabilities that might arise pertaining to such matters would not have a material effect on its consolidated financial position.

Costs attributable to these commitments and contingencies are expected to be incurred over an extended period of time and to be funded from the company's cash flow from operating activities. Although the ultimate impact of these matters on net earnings cannot be determined at this time, the impact is not expected to be material.

Operational Risk

The company also has exposure to some operational risks, which is reduced by maintaining an insurance program.

The company carries property damage and business interruption insurance with varying coverage limits and deductible amounts based on the asset. As of December 31, 2018, Suncor's insurance program included coverage of up to US$1.2 billion for oil sands risks, up to US$0.975 billion for offshore risks and up to US$1.2 billion for refining risks. These limits are all net of deductible amounts or waiting periods and subject to certain price and daily volume limits. The company also has primary property insurance for up to US$400 million, also net of the deductible that covers all of Suncor's physical assets.

(c) Guarantees

At December 31, 2018, the company provides loan guarantees to certain retail licensees and wholesale marketers. Suncor's maximum potential amount payable under these loan guarantees is $125 million.

The company has also agreed to indemnify holders of all notes and debentures and the company's credit facility lenders (see note 19) for added costs relating to withholding taxes. Similar indemnity terms apply to certain facility and equipment leases. There is no limit to the maximum amount payable under these indemnification agreements. The company is unable to determine the maximum potential amount payable as government regulations and legislation are subject to change without notice. Under these agreements, the company has the option to redeem or terminate these contracts if additional costs are incurred.

The company also has guaranteed its working-interest share of certain joint operation undertakings related to transportation services agreements entered into with third parties. The guaranteed amount is limited to the company's share in the joint arrangement. As at December 31, 2018, the probability is remote that these guarantee commitments will impact the company.

2018 ANNUAL REPORT Suncor Energy Inc. 127

31. ACQUISITION OF ADDITIONAL OWNERSHIP INTEREST IN THE SYNCRUDE PROJECT

On February 23, 2018, Suncor completed the purchase of an additional 5% working interest in the Syncrude project from Mocal Energy Limited for $923 million cash. Suncor's share in the Syncrude project has increased to 58.74%.

The acquisition has been accounted for as a business combination using the acquisition method. The preliminary purchase price allocation is based on management's best estimates of fair values of Syncrude's assets and liabilities as at February 23, 2018.

($ millions) |  |  |  |
Accounts receivable |  | 2 |  |
Inventory |  | 15 |  |
Property, plant and equipment |  | 998 |  |
Exploration and evaluation |  | 163 |  |
Total assets acquired |  | 1 178 |  |
Accounts payable and accrued liabilities |  | (51 | ) |
Employee future benefits |  | (33 | ) |
Decommissioning provision |  | (169 | ) |
Deferred income taxes |  | (2 | ) |
Total liabilities assumed |  | (255 | ) |
Net assets acquired |  | 923 |  |

The fair values of accounts receivable and accounts payable approximate their carrying values due to the short-term maturity of the instruments. The fair value of materials and supplies inventory approximates book value due to short-term turnover rates. The fair values of property, plant and equipment, and the decommissioning provision were determined using an expected future cash flow approach. Key assumptions used in the calculations were discount rates, future commodity prices and costs, timing of development activities, projections of oil reserves, and cost estimates to abandon and reclaim the mine and facilities.

The additional working interest in Syncrude contributed $270 million to gross revenues and a $7 million net loss to consolidated net earnings from the acquisition date to December 31, 2018.

Had the acquisition occurred on January 1, 2018, the additional working interest would have contributed an additional $64 million to gross revenues and $4 million to consolidated net earnings, which would have resulted in gross revenues of $39.66 billion and consolidated net earnings of $3.30 billion for the twelve months ended December 31, 2018.

32. FORT HILLS

On December 21, 2017, the Fort Hills partners resolved their commercial dispute and reached an agreement. As a result, Suncor acquired an additional 2.26% interest in the project for consideration of $308 million. Subsequently, in the first quarter of 2018, Suncor acquired an additional 1.05% interest in the Fort Hills project for consideration of $145 million. Suncor's share in the project has increased to 54.11% and Teck Resources Limited's share has increased to 21.31% with Total E&P Canada Ltd.'s share decreasing to 24.58%.

33. SALE OF LUBRICANTS BUSINESS

On February 1, 2017, the company completed the previously announced sale of its lubricants business for proceeds of $1.1 billion before closing adjustments and other closing costs. The sale of this business resulted in an after-tax gain of $354 million, including a current tax expense of $101 million and a deferred tax recovery of $11 million, in the Refining and Marketing segment.

128 2018 ANNUAL REPORT Suncor Energy Inc.

34. SALE OF CEDAR POINT

The company sold its interest in the Cedar Point wind facility in southwest Ontario for proceeds of $291 million before closing adjustments and other closing costs, with an effective date of January 1, 2017. The disposition resulted in an after-tax gain of $83 million, including a current tax expense of $29 million and a deferred tax recovery of $15 million, in the Corporate, Energy Trading and Eliminations segment.

35. EAST TANK FARM DEVELOPMENT PARTNERSHIP (ETFD)

The ETFD consists of bitumen storage, blending and cooling facilities, and connectivity to third-party pipelines and began operations on July 14, 2017. ETFD will be solely responsible for moving the product of the Fort Hills joint operation to market. On November 22, 2017, the company completed the sale of a 49% ownership interest in the ETFD to the FMFN and the MCFN for gross proceeds of $503 million. Suncor retained a 51% ownership interest and remains as operator of the assets. The assets are held by a limited partnership, which has a non-discretionary obligation to distribute the variable monthly residual cash in ETFD to the partners. Therefore, the company recorded a liability within Other Long-Term Liabilities to reflect the 49% non-controlling interest of the third parties. As a result, the company continues to consolidate 100% of the results of the Partnership. During the year ended December 31, 2018, the company paid $62 million (2017 – $25 million) in distributions to the partners, of which $56 million (2017 – $5 million) was allocated to interest expense and $6 million (2017 – $20 million) to the principal.

36. OTHER TRANSACTIONS

On September 29, 2018, Suncor along with the other working-interest partners in the Joslyn Oil Sands Mining project, agreed to sell 100% of their respective working interests to Canadian Natural Resources Limited for gross proceeds of $225 million, $82.7 million net to Suncor. Suncor held a 36.75% working interest in Joslyn prior to the transaction. The working-interest partners received cash proceeds of $100 million ($36.8 million net to Suncor) upon closing, with the remaining $125 million ($45.9 million net to Suncor) to be received in equal instalments over the next five years. As a result, Suncor has recorded a long-term receivable of $36.7 million within the Other Assets line item and the first instalment of $9.2 million is recorded within the Accounts Receivable line item. The transaction resulted in a gain of $83 million in the Oil Sands segment.

On May 31, 2018, the company completed the previously announced transaction to acquire a 17.5% interest in the Fenja development project in Norway from Faroe Petroleum Norge AS for acquisition costs of US$55 million (approximately $70 million), plus interim settlement costs of $22 million under the acquisition method. This project was sanctioned by its owners in December 2017.

On March 23, 2018, Suncor completed an exchange of its northeast B.C. mineral landholdings, including associated production, and consideration of $52 million for a 37% equity interest in Canbriam Energy Inc. (Canbriam) (a private natural gas company). The investment is accounted for using the equity method of accounting. In the fourth quarter of 2018, the company wrote down its interest in Canbriam as a result of the company's assessment of expected future commodity prices and net cash flows, for a net loss in the year of $90 million after-tax. The remaining carrying value of the company's interest in Canbriam is nil.

37. SUBSEQUENT EVENT

Subsequent to the end of the year, the company received $300 million in risk mitigation proceeds for its Libyan assets (approximately $260 million after-tax). The proceeds may be subject to a provisional repayment, which is dependent on the future performance and cash flows from Suncor's Libyan assets.

2018 ANNUAL REPORT Suncor Energy Inc. 129

SUPPLEMENTAL FINANCIAL AND OPERATING INFORMATION

QUARTERLY FINANCIAL SUMMARY
(unaudited)

|  | For the Quarter Ended |  |  |  | For the Quarter Ended |  |  |  |
($ millions except per share amounts) |  | Mar 31 2018 |  | June 30 2018 |  | Sept 30 2018 |  | Dec 31 2018 |  | Total Year 2018 |  | Mar 31 2017 |  | June 30 2017 |  | Sept 30 2017 |  | Dec 31 2017 |  | Total Year 2017 |  |
Revenues and other income(A) |  | 8 750 |  | 10 428 |  | 10 863 |  | 8 945 |  | 38 986 |  | 7 812 |  | 7 247 |  | 8 006 |  | 9 014 |  | 32 079 |  |
Net earnings (loss) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Oil Sands |  | 82 |  | 368 |  | 796 |  | (393 | ) | 853 |  | 302 |  | (277 | ) | 314 |  | 670 |  | 1 009 |  |
Exploration and Production |  | 395 |  | 311 |  | 217 |  | (115 | ) | 808 |  | 172 |  | 182 |  | 161 |  | 217 |  | 732 |  |
Refining and Marketing |  | 806 |  | 685 |  | 939 |  | 723 |  | 3 153 |  | 829 |  | 346 |  | 597 |  | 886 |  | 2 658 |  |
Corporate, Energy Trading and Eliminations |  | (494 | ) | (392 | ) | (140 | ) | (495 | ) | (1 521 | ) | 49 |  | 184 |  | 217 |  | (391 | ) | 59 |  |
|  | 789 |  | 972 |  | 1 812 |  | (280 | ) | 3 293 |  | 1 352 |  | 435 |  | 1 289 |  | 1 382 |  | 4 458 |  |
Operating earnings (loss)(B) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Oil Sands |  | 82 |  | 368 |  | 736 |  | (393 | ) | 793 |  | 302 |  | (277 | ) | 314 |  | 615 |  | 954 |  |
Exploration and Production |  | 262 |  | 311 |  | 217 |  | 108 |  | 898 |  | 172 |  | 182 |  | 161 |  | 231 |  | 746 |  |
Refining and Marketing |  | 806 |  | 685 |  | 939 |  | 723 |  | 3 153 |  | 475 |  | 346 |  | 597 |  | 746 |  | 2 164 |  |
Corporate, Energy Trading and Eliminations |  | (165 | ) | (174 | ) | (335 | ) | 142 |  | (532 | ) | (137 | ) | (52 | ) | (205 | ) | (282 | ) | (676 | ) |
|  | 985 |  | 1 190 |  | 1 557 |  | 580 |  | 4 312 |  | 812 |  | 199 |  | 867 |  | 1 310 |  | 3 188 |  |
Funds from (used in) operations(B) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Oil Sands |  | 979 |  | 1 446 |  | 1 844 |  | 601 |  | 4 870 |  | 1 109 |  | 573 |  | 1 276 |  | 1 780 |  | 4 738 |  |
Exploration and Production |  | 502 |  | 545 |  | 455 |  | 367 |  | 1 869 |  | 481 |  | 438 |  | 375 |  | 431 |  | 1 725 |  |
Refining and Marketing |  | 965 |  | 884 |  | 1 119 |  | 826 |  | 3 794 |  | 575 |  | 504 |  | 827 |  | 935 |  | 2 841 |  |
Corporate, Energy Trading and Eliminations |  | (282 | ) | (13 | ) | (279 | ) | 213 |  | (361 | ) | (141 | ) | 112 |  | (6 | ) | (130 | ) | (165 | ) |
Total Funds from operations |  | 2 164 |  | 2 862 |  | 3 139 |  | 2 007 |  | 10 172 |  | 2 024 |  | 1 627 |  | 2 472 |  | 3 016 |  | 9 139 |  |
| Change in non-cash working capital |  | (1 440 | ) | (416 | ) | 1 231 |  | 1 033 |  | 408 |  | (396 | ) | 44 |  | 440 |  | (261 | ) | (173 | ) |
Cash flow provided by operating activities |  | 724 |  | 2 446 |  | 4 370 |  | 3 040 |  | 10 580 |  | 1 628 |  | 1 671 |  | 2 912 |  | 2 755 |  | 8 966 |  |
Per common share |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Net earnings (loss) – basic |  | 0.48 |  | 0.60 |  | 1.12 |  | (0.18 | ) | 2.03 |  | 0.81 |  | 0.26 |  | 0.78 |  | 0.84 |  | 2.68 |  |
Net earnings (loss) – diluted |  | 0.48 |  | 0.59 |  | 1.11 |  | (0.18 | ) | 2.02 |  | 0.81 |  | 0.26 |  | 0.78 |  | 0.84 |  | 2.68 |  |
Operating earnings – basic(B) |  | 0.60 |  | 0.73 |  | 0.96 |  | 0.36 |  | 2.65 |  | 0.49 |  | 0.12 |  | 0.52 |  | 0.79 |  | 1.92 |  |
Cash dividends – basic |  | 0.36 |  | 0.36 |  | 0.36 |  | 0.36 |  | 1.44 |  | 0.32 |  | 0.32 |  | 0.32 |  | 0.32 |  | 1.28 |  |
Funds from operations – basic(B) |  | 1.32 |  | 1.75 |  | 1.94 |  | 1.26 |  | 6.27 |  | 1.21 |  | 0.98 |  | 1.49 |  | 1.83 |  | 5.50 |  |
Cash flow provided by operating activities – basic |  | 0.44 |  | 1.50 |  | 2.70 |  | 1.90 |  | 6.54 |  | 0.98 |  | 1.00 |  | 1.75 |  | 1.67 |  | 5.40 |  |

|  | For the Twelve Months Ended |  | For the Twelve Months Ended |
|  | Mar 31 2018 |  | Jun 30 2018 |  | Sep 30 2018 |  | Dec 31 2018 |  | Mar 31 2017 |  | Jun 30 2017 |  | Sep 30 2017 |  | Dec 31 2017 |
Return on capital employed(B) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
– excluding major projects in progress (%) |  | 7.8 |  | 9.5 |  | 10.4 |  | 8.2 |  | 4.4 |  | 6.2 |  | 7.0 |  | 8.6 |
– including major projects in progress (%) |  | 6.5 |  | 8.3 |  | 9.7 |  | 8.0 |  | 3.5 |  | 4.9 |  | 5.5 |  | 6.7 |

(A)
  Prior periods have been restated due to IFRS 15 adoption; see note 5 in the consolidated financial statements.
(B)
  Non-GAAP financial measures. See the Operating Summary Information – Non-GAAP Financial Measures section of this Annual Report.

  See accompanying footnotes and definitions to the operating summaries.

130 2018 ANNUAL REPORT Suncor Energy Inc.

QUARTERLY OPERATING SUMMARY
(unaudited)

|  | For the Quarter Ended |  |  |  | For the Quarter Ended |  |  |
Oil Sands |  | Mar 31 2018 |  | June 30 2018 |  | Sept 30 2018 |  | Dec 31 2018 |  | Total Year 2018 |  | Mar 31 2017 |  | June 30 2017 |  | Sept 30 2017 |  | Dec 31 2017 |  | Total Year 2017 |
Total Production (mbbls/d) |  | 571.7 |  | 547.6 |  | 651.7 |  | 740.8 |  | 628.6 |  | 590.6 |  | 413.6 |  | 628.4 |  | 621.2 |  | 563.7 |
Oil Sands operations |  |  |  |  |  |  |  |  |
Production (mbbls/d) |  |  |  |  |  |  |  |  |
| Upgraded product (sweet SCO, sour SCO and diesel) |  | 279.4 |  | 237.9 |  | 330.1 |  | 273.4 |  | 280.3 |  | 332.8 |  | 288.6 |  | 324.4 |  | 324.9 |  | 317.7 |
| Non-upgraded bitumen |  | 125.4 |  | 121.0 |  | 146.0 |  | 159.3 |  | 138.0 |  | 115.7 |  | 64.0 |  | 144.9 |  | 121.9 |  | 111.7 |
Oil Sands operations production |  | 404.8 |  | 358.9 |  | 476.1 |  | 432.7 |  | 418.3 |  | 448.5 |  | 352.6 |  | 469.3 |  | 446.8 |  | 429.4 |
Bitumen production (mbbls/d) |  |  |  |  |  |  |  |  |
| Mining |  | 241.6 |  | 195.4 |  | 323.4 |  | 278.3 |  | 258.8 |  | 311.1 |  | 293.1 |  | 328.1 |  | 296.7 |  | 305.4 |
| In Situ – Firebag |  | 205.8 |  | 201.9 |  | 211.0 |  | 197.2 |  | 204.0 |  | 202.8 |  | 110.9 |  | 203.6 |  | 208.5 |  | 181.5 |
| In Situ – MacKay River |  | 35.1 |  | 34.4 |  | 37.1 |  | 37.0 |  | 36.0 |  | 35.6 |  | 30.0 |  | 30.8 |  | 28.3 |  | 31.1 |
Total bitumen production |  | 482.5 |  | 431.7 |  | 571.5 |  | 512.5 |  | 498.8 |  | 549.5 |  | 434.0 |  | 562.5 |  | 533.5 |  | 518.0 |
Sales (mbbls/d) |  |  |  |  |  |  |  |  |
| Light sweet crude oil |  | 84.2 |  | 59.6 |  | 129.5 |  | 110.2 |  | 96.1 |  | 124.9 |  | 104.4 |  | 105.9 |  | 95.5 |  | 107.9 |
| Diesel |  | 20.4 |  | 32.4 |  | 34.7 |  | 27.6 |  | 28.8 |  | 30.3 |  | 29.6 |  | 30.4 |  | 21.1 |  | 27.5 |
| Light sour crude oil |  | 178.2 |  | 159.0 |  | 162.8 |  | 150.7 |  | 162.6 |  | 176.4 |  | 160.1 |  | 183.2 |  | 214.4 |  | 183.6 |
| Upgraded product (SCO and diesel) |  | 282.8 |  | 251.0 |  | 327.0 |  | 288.5 |  | 287.5 |  | 331.6 |  | 294.1 |  | 319.5 |  | 331.0 |  | 319.0 |
| Non-upgraded bitumen |  | 118.2 |  | 113.7 |  | 131.4 |  | 172.0 |  | 134.0 |  | 104.9 |  | 86.0 |  | 120.3 |  | 130.7 |  | 110.6 |
Sales |  | 401.0 |  | 364.7 |  | 458.4 |  | 460.5 |  | 421.5 |  | 436.5 |  | 380.1 |  | 439.8 |  | 461.7 |  | 429.6 |
Cash operating costs – Average(1)(B) ($/bbl)* |  |  |  |  |  |  |  |  |
Cash costs |  | 25.05 |  | 27.45 |  | 21.05 |  | 22.80 |  | 23.85 |  | 20.15 |  | 25.70 |  | 20.40 |  | 22.55 |  | 21.95 |
Natural gas |  | 1.80 |  | 1.20 |  | 0.95 |  | 1.70 |  | 1.40 |  | 2.40 |  | 2.10 |  | 1.20 |  | 1.65 |  | 1.85 |
|  | 26.85 |  | 28.65 |  | 22.00 |  | 24.50 |  | 25.25 |  | 22.55 |  | 27.80 |  | 21.60 |  | 24.20 |  | 23.80 |
Cash operating costs – Mining bitumen production only(1)(B)(C) ($/bbl) |  |  |  |  |  |  |  |  |
Cash costs |  | 26.50 |  | 32.15 |  | 20.35 |  | 23.65 |  | 25.20 |  | 18.45 |  | 19.70 |  | 19.15 |  | 22.70 |  | 20.00 |
Natural gas |  | 0.65 |  | 0.30 |  | 0.15 |  | 0.35 |  | 0.35 |  | 0.60 |  | 0.60 |  | 0.25 |  | 0.45 |  | 0.45 |
|  | 27.15 |  | 32.45 |  | 20.50 |  | 24.00 |  | 25.55 |  | 19.05 |  | 20.30 |  | 19.40 |  | 23.15 |  | 20.45 |
Cash operating costs – In Situ bitumen production only(1)(B) ($/bbl) |  |  |  |  |  |  |  |  |
Cash costs |  | 6.55 |  | 6.10 |  | 6.20 |  | 5.75 |  | 6.15 |  | 7.00 |  | 10.95 |  | 6.75 |  | 6.20 |  | 7.35 |
Natural gas |  | 3.00 |  | 1.80 |  | 1.85 |  | 2.55 |  | 2.30 |  | 4.00 |  | 4.00 |  | 2.20 |  | 2.65 |  | 3.15 |
|  | 9.55 |  | 7.90 |  | 8.05 |  | 8.30 |  | 8.45 |  | 11.00 |  | 14.95 |  | 8.95 |  | 8.85 |  | 10.50 |
Fort Hills |  |  |  |  |  |  |  |  |
Bitumen production (mbbls/d) |  | 29.8 |  | 70.9 |  | 69.4 |  | 98.5 |  | 67.4 |  | — |  | — |  | — |  | — |  | — |
Internally upgraded bitumen from froth (mbbls/d) |  | (5.2 | ) | — |  | — |  | — |  | (1.3 | ) | — |  | — |  | — |  | — |  | — |
Total Fort Hills Bitumen |  | 24.6 |  | 70.9 |  | 69.4 |  | 98.5 |  | 66.1 |  | — |  | — |  | — |  | — |  |  |
Bitumen Sales (mbbls/d) |  | 8.1 |  | 64.0 |  | 61.6 |  | 94.6 |  | 57.3 |  | — |  | — |  | — |  | — |  | — |
Fort Hills Cash operating costs(1)(B) ($/bbl)* |  |  |  |  |  |  |  |  |
Cash costs |  | 50.45 |  | 27.60 |  | 32.55 |  | 23.85 |  | 30.00 |  | — |  | — |  | — |  | — |  | — |
Natural gas |  | 3.20 |  | 0.95 |  | 0.90 |  | 1.00 |  | 1.20 |  | — |  | — |  | — |  | — |  | — |
|  | 53.65 |  | 28.55 |  | 33.45 |  | 24.85 |  | 31.20 |  | — |  | — |  | — |  | — |  | — |
Syncrude |  |  |  |  |  |  |  |  |
Sweet SCO Production (mbbls/d) |  | 142.3 |  | 117.8 |  | 106.2 |  | 209.6 |  | 144.2 |  | 142.1 |  | 61.0 |  | 159.1 |  | 174.4 |  | 134.3 |
Bitumen production (mbbls/d) |  | 173.3 |  | 142.7 |  | 130.9 |  | 240.7 |  | 172.0 |  | 170.0 |  | 82.4 |  | 193.7 |  | 207.5 |  | 163.6 |
Intermediate sour SCO (mbbls/d)(2) |  | 138.2 |  | 119.9 |  | 107.2 |  | 206.3 |  | 143.0 |  | 140.9 |  | 61.3 |  | 157.1 |  | 177.1 |  | 132.9 |
Syncrude cash operating costs(1)(B) ($/bbl)* |  |  |  |  |  |  |  |  |
Cash costs |  | 49.25 |  | 53.80 |  | 62.80 |  | 30.85 |  | 46.15 |  | 43.25 |  | 89.90 |  | 34.00 |  | 31.75 |  | 42.50 |
Natural gas |  | 1.50 |  | 2.45 |  | 1.05 |  | 0.90 |  | 1.10 |  | 1.90 |  | 7.90 |  | 1.00 |  | 1.05 |  | 1.55 |
|  | 50.75 |  | 56.25 |  | 63.85 |  | 31.75 |  | 47.25 |  | 45.15 |  | 97.80 |  | 35.00 |  | 32.80 |  | 44.05 |

(B)
  Non-GAAP financial measures. See the Operating Metrics Reconciliation and the Operating Summary Information – Non-GAAP Financial Measures sections of this Annual Report.
(C)
  Cash operating costs – Mining bitumen production per barrel costs have been restated.

  See accompanying footnotes and definitions to the operating summaries.

2018 ANNUAL REPORT Suncor Energy Inc. 131

QUARTERLY OPERATING SUMMARY (continued)
(unaudited)

|  | For the Quarter Ended |  |  |  | For the Quarter Ended |  |  |  |
Oil Sands Operating Netbacks(A)(B)(D) |  | Mar 31 2018 |  | June 30 2018 |  | Sept 30 2018 |  | Dec 31 2018 |  | Total Year 2018 |  | Mar 31 2017 |  | June 30 2017 |  | Sept 30 2017 |  | Dec 31 2017 |  | Total Year 2017 |  |
Bitumen ($/bbl) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
| Average price realized |  | 33.55 |  | 47.08 |  | 42.03 |  | 7.96 |  | 30.22 |  | 33.89 |  | 36.45 |  | 38.57 |  | 42.80 |  | 38.32 |  |
| Royalties |  | (0.90 | ) | (3.27 | ) | (3.20 | ) | (0.06 | ) | (1.70 | ) | (0.54 | ) | (0.69 | ) | (0.50 | ) | (1.02 | ) | (0.71 | ) |
| Transportation costs |  | (5.98 | ) | (4.24 | ) | (5.41 | ) | (5.53 | ) | (5.52 | ) | (6.57 | ) | (7.06 | ) | (3.78 | ) | (3.06 | ) | (4.85 | ) |
| Net operating expenses |  | (8.75 | ) | (7.37 | ) | (7.01 | ) | (7.61 | ) | (7.68 | ) | (9.98 | ) | (14.05 | ) | (8.26 | ) | (7.61 | ) | (9.59 | ) |
| Operating netback |  | 17.92 |  | 32.20 |  | 26.41 |  | (5.24 | ) | 15.32 |  | 16.80 |  | 14.65 |  | 26.03 |  | 31.11 |  | 23.17 |  |
SCO and diesel ($/bbl) |  |  |  |  |  |  |  |  |  |
| Average price realized |  | 74.65 |  | 85.06 |  | 86.71 |  | 46.07 |  | 73.07 |  | 66.29 |  | 64.23 |  | 59.76 |  | 70.55 |  | 65.28 |  |
| Royalties |  | (0.56 | ) | (2.60 | ) | (2.70 | ) | (0.91 | ) | (1.63 | ) | (0.59 | ) | (1.19 | ) | (1.03 | ) | (1.14 | ) | (0.98 | ) |
| Transportation costs |  | (4.14 | ) | (5.06 | ) | (3.76 | ) | (3.63 | ) | (4.10 | ) | (3.98 | ) | (3.72 | ) | (3.65 | ) | (3.87 | ) | (3.81 | ) |
| Net operating expenses – bitumen |  | (25.33 | ) | (27.52 | ) | (20.49 | ) | (23.72 | ) | (24.04 | ) | (19.78 | ) | (22.70 | ) | (20.29 | ) | (21.70 | ) | (21.08 | ) |
| Net operating expenses – upgrading |  | (6.05 | ) | (8.13 | ) | (5.03 | ) | (6.49 | ) | (6.32 | ) | (4.81 | ) | (5.60 | ) | (4.65 | ) | (4.90 | ) | (4.97 | ) |
| Operating netback |  | 38.57 |  | 41.75 |  | 54.73 |  | 11.32 |  | 36.98 |  | 37.13 |  | 31.02 |  | 30.14 |  | 38.94 |  | 34.44 |  |
Average Oil Sands operations ($/bbl) |  |  |  |  |  |  |  |  |  |
| Average price realized |  | 62.54 |  | 73.21 |  | 73.90 |  | 31.84 |  | 59.46 |  | 58.50 |  | 57.94 |  | 53.96 |  | 62.69 |  | 58.34 |  |
| Royalties |  | (0.66 | ) | (2.81 | ) | (2.84 | ) | (0.59 | ) | (1.70 | ) | (0.58 | ) | (1.07 | ) | (0.89 | ) | (1.11 | ) | (0.91 | ) |
| Transportation costs |  | (4.68 | ) | (4.80 | ) | (4.23 | ) | (4.34 | ) | (4.55 | ) | (4.60 | ) | (4.47 | ) | (3.68 | ) | (3.64 | ) | (4.08 | ) |
| Net operating expenses – bitumen and upgrading |  | (24.71 | ) | (26.83 | ) | (20.21 | ) | (21.78 | ) | (23.15 | ) | (21.07 | ) | (25.08 | ) | (20.38 | ) | (21.23 | ) | (21.82 | ) |
| Operating netback |  | 32.49 |  | 38.77 |  | 46.62 |  | 5.13 |  | 30.06 |  | 32.25 |  | 27.32 |  | 29.01 |  | 36.71 |  | 31.53 |  |
Fort Hills ($/bbl) |  |  |  |  |  |  |  |  |  |
| Average price realized |  | 40.58 |  | 60.81 |  | 64.33 |  | 30.57 |  | 48.48 |  | — |  | — |  | — |  | — |  | — |  |
| Royalties |  | (1.54 | ) | (0.73 | ) | (3.07 | ) | (1.41 | ) | (1.67 | ) | — |  | — |  | — |  | — |  | — |  |
| Transportation costs |  | (8.10 | ) | (8.95 | ) | (10.90 | ) | (10.31 | ) | (10.01 | ) | — |  | — |  | — |  | — |  | — |  |
| Net operating expenses – bitumen and upgrading |  | (106.07 | ) | (22.73 | ) | (30.69 | ) | (28.79 | ) | (30.32 | ) | — |  | — |  | — |  | — |  | — |  |
| Operating netback |  | (75.13 | ) | 28.40 |  | 19.67 |  | (9.94 | ) | 6.48 |  | — |  | — |  | — |  | — |  | — |  |
Syncrude ($/bbl) |  |  |  |  |  |  |  |  |  |
| Average price realized |  | 77.33 |  | 86.73 |  | 89.50 |  | 48.07 |  | 70.68 |  | 66.37 |  | 62.27 |  | 60.68 |  | 73.64 |  | 66.59 |  |
| Royalties |  | (1.57 | ) | (2.41 | ) | (2.49 | ) | (1.53 | ) | (1.90 | ) | (2.96 | ) | — |  | (3.18 | ) | (7.94 | ) | (4.32 | ) |
| Transportation costs |  | (0.48 | ) | (0.57 | ) | (0.70 | ) | (0.36 | ) | (0.49 | ) | (0.38 | ) | (1.83 | ) | (0.38 | ) | (0.36 | ) | (0.54 | ) |
| Net operating expenses – bitumen and upgrading |  | (45.30 | ) | (52.27 | ) | (62.61 | ) | (28.33 | ) | (43.81 | ) | (39.70 | ) | (90.72 | ) | (31.48 | ) | (28.81 | ) | (39.46 | ) |
| Operating netback |  | 29.98 |  | 31.48 |  | 23.70 |  | 17.85 |  | 24.48 |  | 23.33 |  | (30.28 | ) | 25.64 |  | 36.53 |  | 22.27 |  |

(A)
  Prior periods have been restated due to IFRS 15 adoption; see note 5 in the consolidated financial statements.
(B)
  Non-GAAP financial measures. See the Operating Metrics Reconciliation and the Operating Summary Information – Non-GAAP Financial Measures sections of this Annual Report.
(D)
  Netbacks are based on sales volumes.

  See accompanying footnotes and definitions to the operating summaries.

132 2018 ANNUAL REPORT Suncor Energy Inc.

QUARTERLY OPERATING SUMMARY (continued)
(unaudited)

|  | For the Quarter Ended |  |  |  | For the Quarter Ended |  |  |  |
Exploration and Production |  | Mar 31 2018 |  | June 30 2018 |  | Sept 30 2018 |  | Dec 31 2018 |  | Total Year 2018 |  | Mar 31 2017 |  | June 30 2017 |  | Sept 30 2017 |  | Dec 31 2017 |  | Total Year 2017 |  |
Total Sales Volumes (mboe/d) |  | 121.9 |  | 110.2 |  | 96.5 |  | 83.1 |  | 102.8 |  | 136.8 |  | 130.3 |  | 112.6 |  | 104.8 |  | 120.8 |  |
Total Production (mboe/d) |  | 117.7 |  | 114.1 |  | 92.1 |  | 90.2 |  | 103.4 |  | 134.5 |  | 125.5 |  | 111.5 |  | 115.2 |  | 121.6 |  |
Production Volumes |  |  |  |  |  |  |  |  |  |
Exploration and Production Canada |  |  |  |  |  |  |  |  |  |
| East Coast Canada |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
|  | Terra Nova (mbbls/d) |  | 15.4 |  | 13.6 |  | 8.6 |  | 9.5 |  | 11.7 |  | 14.7 |  | 11.0 |  | 5.8 |  | 14.6 |  | 11.5 |  |
|  | Hibernia (mbbls/d) |  | 26.1 |  | 25.5 |  | 17.9 |  | 19.0 |  | 22.1 |  | 30.3 |  | 30.0 |  | 26.6 |  | 27.1 |  | 28.5 |  |
|  | White Rose (mbbls/d) |  | 8.8 |  | 6.0 |  | 8.0 |  | 3.7 |  | 6.6 |  | 13.1 |  | 12.9 |  | 9.0 |  | 10.6 |  | 11.4 |  |
|  | Hebron (mbbls/d) |  | 8.2 |  | 13.5 |  | 14.4 |  | 15.7 |  | 13.0 |  | — |  | — |  | — |  | 1.8 |  | 0.4 |  |
| North America Onshore (mboe/d) |  | 2.0 |  | — |  | — |  | — |  | 0.5 |  | 2.8 |  | 1.8 |  | 1.5 |  | 1.4 |  | 1.9 |  |
|  | 60.5 |  | 58.6 |  | 48.9 |  | 47.9 |  | 53.9 |  | 60.9 |  | 55.7 |  | 42.9 |  | 55.5 |  | 53.7 |  |
Exploration and Production International |  |  |  |  |  |  |  |  |  |
|  | Buzzard (mboe/d) |  | 40.4 |  | 39.4 |  | 29.6 |  | 27.7 |  | 34.2 |  | 49.0 |  | 45.3 |  | 44.3 |  | 36.6 |  | 43.8 |  |
|  | Golden Eagle (mboe/d) |  | 14.3 |  | 12.6 |  | 12.0 |  | 10.7 |  | 12.4 |  | 20.2 |  | 20.1 |  | 20.5 |  | 17.9 |  | 19.6 |  |
|  | United Kingdom (mboe/d) |  | 54.7 |  | 52.0 |  | 41.6 |  | 38.4 |  | 46.6 |  | 69.2 |  | 65.4 |  | 64.8 |  | 54.5 |  | 63.4 |  |
|  | Libya (mbbls/d)(3) |  | 2.5 |  | 3.5 |  | 1.6 |  | 3.9 |  | 2.9 |  | 4.4 |  | 4.4 |  | 3.8 |  | 5.2 |  | 4.5 |  |
|  | 57.2 |  | 55.5 |  | 43.2 |  | 42.3 |  | 49.5 |  | 73.6 |  | 69.8 |  | 68.6 |  | 59.7 |  | 67.9 |  |
Netbacks(B)(D) |  |  |  |  |  |  |  |  |  |
East Coast Canada ($/bbl) |  |  |  |  |  |  |  |  |  |
| Average price realized |  | 84.63 |  | 97.30 |  | 99.50 |  | 76.19 |  | 90.04 |  | 69.75 |  | 66.26 |  | 67.23 |  | 81.49 |  | 71.06 |  |
| Royalties |  | (14.34 | ) | (13.02 | ) | (18.75 | ) | (5.04 | ) | (13.31 | ) | (15.94 | ) | (14.05 | ) | (13.01 | ) | (13.21 | ) | (14.26 | ) |
| Transportation costs |  | (1.84 | ) | (2.24 | ) | (2.28 | ) | (2.71 | ) | (2.22 | ) | (1.72 | ) | (1.60 | ) | (2.13 | ) | (2.27 | ) | (1.90 | ) |
| Operating costs |  | (9.70 | ) | (11.21 | ) | (16.06 | ) | (23.71 | ) | (14.43 | ) | (9.28 | ) | (10.58 | ) | (14.72 | ) | (11.16 | ) | (11.24 | ) |
| Operating netback |  | 58.75 |  | 70.83 |  | 62.41 |  | 44.73 |  | 60.08 |  | 42.81 |  | 40.03 |  | 37.37 |  | 54.85 |  | 43.66 |  |
United Kingdom ($/boe) |  |  |  |  |  |  |  |  |  |
| Average price realized |  | 83.22 |  | 93.88 |  | 94.28 |  | 85.31 |  | 89.10 |  | 67.55 |  | 63.46 |  | 62.99 |  | 76.46 |  | 67.25 |  |
| Transportation costs |  | (2.14 | ) | (2.20 | ) | (2.22 | ) | (2.14 | ) | (2.18 | ) | (1.81 | ) | (1.88 | ) | (1.77 | ) | (1.80 | ) | (1.81 | ) |
| Operating costs |  | (5.36 | ) | (5.39 | ) | (6.04 | ) | (8.94 | ) | (6.27 | ) | (3.75 | ) | (4.57 | ) | (4.51 | ) | (5.89 | ) | (4.62 | ) |
| Operating netback |  | 75.72 |  | 86.29 |  | 86.02 |  | 74.23 |  | 80.65 |  | 61.99 |  | 57.01 |  | 56.71 |  | 68.77 |  | 60.82 |  |

(B)
  Non-GAAP financial measures. See the Operating Metrics Reconciliation and the Operating Summary Information – Non-GAAP Financial Measures sections of this Annual Report.
(D)
  Netbacks are based on sales volumes.

  See accompanying footnotes and definitions to the operating summaries.

2018 ANNUAL REPORT Suncor Energy Inc. 133

QUARTERLY OPERATING SUMMARY (continued)
(unaudited)

|  | For the Quarter Ended |  |  |  | For the Quarter Ended |  |  |
Refining and Marketing |  | Mar 31 2018 |  | June 30 2018 |  | Sept 30 2018 |  | Dec 31 2018 |  | Total Year 2018 |  | Mar 31 2017 |  | June 30 2017 |  | Sept 30 2017 |  | Dec 31 2017 |  | Total Year 2017 |
Refined product sales (mbbls/d) |  | 512.9 |  | 500.0 |  | 565.5 |  | 530.6 |  | 527.4 |  | 508.0 |  | 521.9 |  | 564.5 |  | 526.8 |  | 530.5 |
Crude oil processed (mbbls/d) |  | 453.5 |  | 344.1 |  | 457.2 |  | 467.9 |  | 430.8 |  | 429.9 |  | 435.5 |  | 466.8 |  | 432.4 |  | 441.2 |
Utilization of refining capacity (%) |  | 98 |  | 74 |  | 99 |  | 101 |  | 93 |  | 93 |  | 94 |  | 101 |  | 94 |  | 96 |
Refining margin(B)(E) ($/bbl) |  | 30.50 |  | 30.25 |  | 34.45 |  | 41.50 |  | 34.50 |  | 22.30 |  | 18.85 |  | 23.80 |  | 31.75 |  | 24.20 |
Refining operating expense(B) ($/bbl) |  | 4.90 |  | 6.25 |  | 5.00 |  | 5.45 |  | 5.35 |  | 5.50 |  | 5.05 |  | 4.50 |  | 5.25 |  | 5.05 |
Eastern North America |  |  |  |  |  |  |  |  |
| Refined product sales (mbbls/d) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
|  | Transportation fuels |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
|  | Gasoline |  | 113.6 |  | 117.8 |  | 122.0 |  | 117.8 |  | 117.8 |  | 112.8 |  | 114.8 |  | 121.2 |  | 121.1 |  | 117.5 |
|  | Distillate |  | 81.8 |  | 93.4 |  | 96.7 |  | 100.2 |  | 95.8 |  | 82.2 |  | 82.9 |  | 92.6 |  | 89.2 |  | 86.8 |
|  | Total transportation fuel sales |  | 195.4 |  | 211.2 |  | 218.7 |  | 218.0 |  | 213.6 |  | 195.0 |  | 197.7 |  | 213.8 |  | 210.3 |  | 204.3 |
|  | Petrochemicals |  | 14.1 |  | 11.8 |  | 9.0 |  | 10.3 |  | 11.3 |  | 15.5 |  | 12.2 |  | 10.6 |  | 10.5 |  | 12.2 |
|  | Asphalt |  | 13.1 |  | 13.3 |  | 20.5 |  | 15.2 |  | 15.5 |  | 12.6 |  | 18.0 |  | 20.6 |  | 15.8 |  | 16.8 |
|  | Other |  | 36.6 |  | 25.9 |  | 26.5 |  | 25.7 |  | 26.0 |  | 34.5 |  | 35.5 |  | 32.4 |  | 31.4 |  | 33.4 |
| Total refined product sales |  | 259.2 |  | 262.2 |  | 274.7 |  | 269.2 |  | 266.4 |  | 257.6 |  | 263.4 |  | 277.4 |  | 268.0 |  | 266.7 |
| Crude oil supply and refining |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
|  | Processed at refineries (mbbls/d) |  | 217.8 |  | 182.0 |  | 211.6 |  | 221.0 |  | 208.1 |  | 214.6 |  | 208.6 |  | 213.9 |  | 188.7 |  | 206.4 |
|  | Utilization of refining capacity (%) |  | 98 |  | 82 |  | 95 |  | 100 |  | 94 |  | 97 |  | 94 |  | 96 |  | 85 |  | 93 |
Western North America |  |  |  |  |  |  |  |  |
| Refined product sales (mbbls/d) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
|  | Transportation fuels |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
|  | Gasoline |  | 120.1 |  | 124.2 |  | 139.0 |  | 127.8 |  | 127.8 |  | 117.1 |  | 122.0 |  | 136.4 |  | 125.7 |  | 125.4 |
|  | Distillate |  | 109.9 |  | 88.3 |  | 121.0 |  | 109.5 |  | 107.6 |  | 110.1 |  | 108.3 |  | 119.9 |  | 111.7 |  | 112.5 |
|  | Total transportation fuel sales |  | 230.0 |  | 212.5 |  | 260.0 |  | 237.3 |  | 235.4 |  | 227.2 |  | 230.3 |  | 256.3 |  | 237.4 |  | 237.9 |
|  | Asphalt |  | 11.3 |  | 14.3 |  | 16.1 |  | 11.3 |  | 13.3 |  | 9.2 |  | 14.6 |  | 16.0 |  | 9.3 |  | 12.3 |
|  | Other |  | 12.4 |  | 11.0 |  | 14.7 |  | 12.8 |  | 12.3 |  | 14.0 |  | 13.6 |  | 14.8 |  | 12.1 |  | 13.6 |
| Total refined product sales |  | 253.7 |  | 237.8 |  | 290.8 |  | 261.4 |  | 261.0 |  | 250.4 |  | 258.5 |  | 287.1 |  | 258.8 |  | 263.8 |
| Crude oil supply and refining |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
|  | Processed at refineries (mbbls/d) |  | 235.7 |  | 162.1 |  | 245.6 |  | 246.9 |  | 222.7 |  | 215.3 |  | 226.9 |  | 252.9 |  | 243.7 |  | 234.8 |
|  | Utilization of refining capacity (%) |  | 98 |  | 68 |  | 102 |  | 103 |  | 93 |  | 90 |  | 95 |  | 105 |  | 102 |  | 98 |

(B)
  Non-GAAP financial measures. See the Operating Metrics Reconciliation and the Operating Summary Information – Non-GAAP Financial Measures sections of this Annual Report.
(E)
  Refining Margins are a non-GAAP measure and have been restated to remove the impact of risk management activities.

  See accompanying footnotes and definitions to the operating summaries.

134 2018 ANNUAL REPORT Suncor Energy Inc.

FIVE-YEAR FINANCIAL SUMMARY
(unaudited)

($ millions) |  | 2018 |  | 2017 |  | 2016 |  | 2015 |  | 2014 |  |
Revenues and other income(A) |  | 38 986 |  | 32 079 |  | 26 759 |  | 29 479 |  | 40 381 |  |
Net earnings (loss) |  |  |  |  |  |  |  |  |  |  |  |
Oil Sands |  | 853 |  | 1 009 |  | (1 149 | ) | (856 | ) | 1 776 |  |
Exploration and Production |  | 808 |  | 732 |  | 190 |  | (758 | ) | 653 |  |
Refining and Marketing |  | 3 153 |  | 2 658 |  | 1 890 |  | 2 306 |  | 1 767 |  |
Corporate, Energy Trading and Eliminations |  | (1 521 | ) | 59 |  | (486 | ) | (2 687 | ) | (1 497 | ) |
|  | 3 293 |  | 4 458 |  | 445 |  | (1 995 | ) | 2 699 |  |
Operating earnings (loss)(B) |  |  |  |  |  |  |  |  |  |  |  |
Oil Sands |  | 793 |  | 954 |  | (1 109 | ) | (111 | ) | 2 771 |  |
Exploration and Production |  | 898 |  | 746 |  | 10 |  | 7 |  | 857 |  |
Refining and Marketing |  | 3 153 |  | 2 164 |  | 1 890 |  | 2 274 |  | 1 767 |  |
Corporate, Energy Trading and Eliminations |  | (532 | ) | (676 | ) | (874 | ) | (705 | ) | (775 | ) |
|  | 4 312 |  | 3 188 |  | (83 | ) | 1 465 |  | 4 620 |  |
Funds from (used in) operations(B) |  |  |  |  |  |  |  |  |  |  |  |
Oil Sands |  | 4 870 |  | 4 738 |  | 2 669 |  | 2 835 |  | 5 400 |  |
Exploration and Production |  | 1 869 |  | 1 725 |  | 1 313 |  | 1 386 |  | 1 909 |  |
Refining and Marketing |  | 3 794 |  | 2 841 |  | 2 606 |  | 2 921 |  | 2 262 |  |
Corporate, Energy Trading and Eliminations |  | (361 | ) | (165 | ) | (600 | ) | (336 | ) | (513 | ) |
Total Funds from operations |  | 10 172 |  | 9 139 |  | 5 988 |  | 6 806 |  | 9 058 |  |
| Change in non-cash working capital |  | 408 |  | (173 | ) | (308 | ) | 78 |  | (122 | ) |
Cash flow provided by operating activities |  | 10 580 |  | 8 966 |  | 5 680 |  | 6 884 |  | 8 936 |  |
Capital and exploration expenditures (including capitalized interest) |  |  |  |  |  |  |  |  |  |  |  |
Oil Sands |  | 3 546 |  | 5 059 |  | 4 724 |  | 4 181 |  | 3 826 |  |
Exploration and Production |  | 946 |  | 824 |  | 1 139 |  | 1 459 |  | 1 819 |  |
Refining and Marketing |  | 856 |  | 634 |  | 685 |  | 821 |  | 1 024 |  |
Corporate, Energy Trading and Eliminations |  | 58 |  | 34 |  | 34 |  | 206 |  | 292 |  |
|  | 5 406 |  | 6 551 |  | 6 582 |  | 6 667 |  | 6 961 |  |
Total assets |  | 89 579 |  | 89 494 |  | 88 702 |  | 77 527 |  | 79 671 |  |

(A)
  Prior periods have been restated due to IFRS 15 adoption; see note 5 in the consolidated financial statements.
(B)
  Non-GAAP financial measures. See the Operating Metrics Reconciliation and the Operating Summary Information – Non-GAAP Financial Measures sections of this Annual Report.

  See accompanying footnotes and definitions to the operating summaries.

2018 ANNUAL REPORT Suncor Energy Inc. 135

FIVE-YEAR FINANCIAL SUMMARY (continued)
(unaudited)

($ millions) |  | 2018 |  | 2017 |  | 2016 |  | 2015 |  | 2014 |  |
Ending capital employed |  |  |  |  |  |  |  |  |  |  |  |
Short-term and long-term debt, less cash and cash equivalents |  | 15 129 |  | 12 907 |  | 14 414 |  | 11 254 |  | 7 834 |  |
Shareholders' equity |  | 44 005 |  | 45 383 |  | 44 630 |  | 39 039 |  | 41 603 |  |
|  | 59 134 |  | 58 290 |  | 59 044 |  | 50 293 |  | 49 437 |  |
Less capitalized costs related to major projects in progress |  | (1 412 | ) | (12 901 | ) | (10 147 | ) | (7 195 | ) | (6 203 | ) |
|  | 57 722 |  | 45 389 |  | 48 897 |  | 43 098 |  | 43 234 |  |
Total Suncor employees (number at year end) |  | 12 480 |  | 12 381 |  | 12 837 |  | 13 190 |  | 13 980 |  |
Dollars per common share |  |  |  |  |  |  |  |  |  |  |  |
| Net earnings (loss) |  | 2.03 |  | 2.68 |  | 0.28 |  | (1.38 | ) | 1.84 |  |
| Operating earnings (loss)(B) |  | 2.65 |  | 1.92 |  | (0.05 | ) | 1.01 |  | 3.15 |  |
| Cash dividends |  | 1.44 |  | 1.28 |  | 1.16 |  | 1.14 |  | 1.02 |  |
| Funds from operations(B) |  | 6.27 |  | 5.50 |  | 3.72 |  | 4.71 |  | 6.19 |  |
| Cash flow provided by operating activities – basic |  | 6.54 |  | 5.40 |  | 3.53 |  | 4.76 |  | 6.11 |  |
Ratios |  |  |  |  |  |  |  |  |  |  |  |
Return on capital employed (%)(B)(F) |  | 8.2 |  | 8.6 |  | 0.5 |  | 0.6 |  | 8.6 |  |
Return on capital employed (%)(B)(G) |  | 8.0 |  | 6.7 |  | 0.4 |  | 0.5 |  | 7.5 |  |
Debt to debt plus shareholders' equity (%)(H) |  | 28 |  | 26 |  | 28 |  | 28 |  | 24 |  |
Net debt to funds from operations (times)(B)(I) |  | 1.5 |  | 1.4 |  | 2.4 |  | 1.7 |  | 0.9 |  |
Interest coverage – funds from operations basis (times)(B)(J) |  | 14.1 |  | 11.2 |  | 6.5 |  | 9.3 |  | 15.5 |  |
Interest coverage – net earnings (loss) basis (times)(K) |  | 6.4 |  | 6.5 |  | 0.5 |  | (1.8 | ) | 6.6 |  |

(B)
  Non-GAAP financial measures. See the Operating Summary Information – Non-GAAP Financial Measures section of this Annual Report.
(F)
  Net earnings (loss) adjusted for after-tax interest expense and after-tax foreign exchange loss (gain) on U.S. denominated long-term debt for the twelve-month period ended, divided by average capital employed. Average capital employed is the sum of shareholders' equity and short-term debt plus long-term debt less cash and cash equivalents, less average capitalized costs related to major projects in progress, on a weighted average basis.
(G)
  Average capital employed including capitalized costs related to major projects in progress.
(H)
  Short-term debt plus long-term debt, divided by the sum of short-term debt, long-term debt and shareholders' equity.
(I)
  Short-term debt plus long-term debt less cash and cash equivalents, divided by funds from operations for the year then ended.
(J)
  Funds from operations plus current income taxes and interest expense, divided by the sum of interest expense and capitalized interest.
(K)
  Net earnings (loss) plus income taxes and interest expense, divided by the sum of interest expense and capitalized interest.

  See accompanying footnotes and definitions to the operating summaries.

136 2018 ANNUAL REPORT Suncor Energy Inc.

FIVE-YEAR OPERATING SUMMARY
(unaudited)

Oil Sands |  | 2018 |  | 2017 |  | 2016 |  | 2015 |  | 2014 |
Total Production (mbbls/d) |  | 628.6 |  | 563.7 |  | 504.9 |  | 463.4 |  | 421.9 |
Oil Sands Operations |  |  |  |  |  |  |  |  |  |  |
Production (mbbls/d) |  |  |  |  |  |  |  |  |  |  |
| Upgraded product (sweet SCO, sour SCO and diesel) |  | 280.3 |  | 317.7 |  | 258.9 |  | 320.1 |  | 289.1 |
| Non-upgraded bitumen |  | 138.0 |  | 111.7 |  | 115.9 |  | 113.5 |  | 101.8 |
Oil Sands operations production |  | 418.3 |  | 429.4 |  | 374.8 |  | 433.6 |  | 390.9 |
Bitumen production (mbbls/d) |  |  |  |  |  |  |  |  |  |  |
| Mining |  | 258.8 |  | 305.4 |  | 238 |  | 307.3 |  | 274.4 |
| In Situ – Firebag |  | 204.0 |  | 181.5 |  | 180.8 |  | 186.9 |  | 172.0 |
| In Situ – MacKay River |  | 36.0 |  | 31.1 |  | 27.6 |  | 30.7 |  | 27.0 |
Total bitumen production |  | 498.8 |  | 518.0 |  | 446.4 |  | 524.9 |  | 473.4 |
Sales (mbbls/d) |  |  |  |  |  |  |  |  |  |  |
| Light sweet crude oil |  | 96.1 |  | 107.9 |  | 87.3 |  | 107.0 |  | 99.7 |
| Diesel |  | 28.8 |  | 27.5 |  | 21.2 |  | 31.3 |  | 30.7 |
| Light sour crude oil |  | 162.6 |  | 183.6 |  | 153.4 |  | 182.5 |  | 158.9 |
| Upgraded product (SCO and diesel) |  | 287.5 |  | 319.0 |  | 261.9 |  | 320.8 |  | 289.3 |
| Non-upgraded bitumen |  | 134.0 |  | 110.6 |  | 117.4 |  | 107.7 |  | 101.4 |
Sales |  | 421.5 |  | 429.6 |  | 379.3 |  | 428.5 |  | 390.7 |
Cash operating costs – Average(1)(B) ($/bbl) |  |  |
Cash costs |  | 23.85 |  | 21.95 |  | 24.35 |  | 25.65 |  | 30.00 |
Natural gas |  | 1.40 |  | 1.85 |  | 2.15 |  | 2.20 |  | 3.80 |
|  | 25.25 |  | 23.80 |  | 26.50 |  | 27.85 |  | 33.80 |
Cash operating costs – Mining bitumen production only(1)(B)(C) ($/bbl) |
Cash costs |  | 25.20 |  | 20.00 |  | 23.75 |  | 21.95 |  | 25.90 |
Natural gas |  | 0.35 |  | 0.45 |  | 0.60 |  | 0.55 |  | 0.80 |
|  | 25.55 |  | 20.45 |  | 24.35 |  | 22.50 |  | 26.70 |
Cash operating costs – In Situ bitumen production only(1)(B) ($/bbl) |
Cash costs |  | 6.15 |  | 7.35 |  | 7.60 |  | 9.00 |  | 10.20 |
Natural gas |  | 2.30 |  | 3.15 |  | 3.30 |  | 3.80 |  | 6.45 |
|  | 8.45 |  | 10.50 |  | 10.90 |  | 12.80 |  | 16.65 |
Fort Hills |  |  |  |  |  |  |  |  |  |  |
Bitumen production (mbbls/d) |  | 67.4 |  | — |  | — |  | — |  | — |
Internally upgraded bitumen from froth (mbbls/d) |  | (1.3 | ) | — |  | — |  | — |  | — |
Total Fort Hills Bitumen |  | 66.10 |  | — |  | — |  | — |  | — |
|  | — |  |  |  |  |  |  |  |  |
Bitumen Sales (mbbls/d) |  | 57.3 |  |  |  |  |  |  |  |  |
Fort Hills Cash operating costs(1)(B) ($/bbl)* |  | — |  | — |  | — |  | — |  | — |
Cash costs |  | 30.00 |  | — |  | — |  | — |  | — |
Natural gas |  | 1.20 |  | — |  | — |  | — |  | — |
|  | 31.20 |  | — |  | — |  | — |  | — |
Syncrude |  |  |  |  |  |  |  |  |  |  |
Sweet SCO Production (mbbls/d) |  | 144.2 |  | 134.3 |  | 130.1 |  | 29.8 |  | 31.0 |
Cash operating costs(1)(B) ($/bbl)* |  |  |  |  |  |  |  |  |  |  |
Cash costs |  | 46.15 |  | 42.50 |  | 34.60 |  | 40.35 |  | 46.75 |
Natural gas |  | 1.10 |  | 1.55 |  | 1.35 |  | 1.65 |  | 2.40 |
|  | 47.25 |  | 44.05 |  | 35.95 |  | 42.00 |  | 49.15 |

(B)
  Non-GAAP financial measures. See the Operating Metrics Reconciliation and the Operating Summary Information – Non-GAAP Financial Measures sections of this Annual Report.
(C)
  Cash operating costs – Mining bitumen production per barrel costs have been restated.

  See accompanying footnotes and definitions to the operating summaries.

2018 ANNUAL REPORT Suncor Energy Inc. 137

FIVE-YEAR OPERATING SUMMARY (continued)
(unaudited)

Oil Sands Operating Netbacks(A)(B)(D) |  | 2018 |  | 2017 |  | 2016 |  | 2015 |  | 2014 |  |
Bitumen ($/bbl) |  |  |  |  |  |  |  |  |  |  |  |
| Average price realized |  | 30.22 |  | 38.32 |  | 23.86 |  | 31.20 |  | 64.67 |  |
| Royalties |  | (1.70 | ) | (0.71 | ) | (0.23 | ) | (0.41 | ) | (4.52 | ) |
| Transportation costs |  | (5.52 | ) | (4.85 | ) | (5.38 | ) | (6.26 | ) | (5.27 | ) |
| Net operating expenses |  | (7.68 | ) | (9.59 | ) | (11.25 | ) | (11.76 | ) | (15.30 | ) |
| Operating netback |  | 15.32 |  | 23.17 |  | 7.00 |  | 12.77 |  | 39.58 |  |
SCO and diesel ($/bbl) |  |  |  |  |  |  |  |  |  |  |  |
| Average price realized |  | 73.07 |  | 65.28 |  | 53.51 |  | 59.70 |  | 98.68 |  |
| Royalties |  | (1.63 | ) | (0.98 | ) | 0.50 |  | (0.65 | ) | (7.00 | ) |
| Transportation costs |  | (4.10 | ) | (3.81 | ) | (3.76 | ) | (3.36 | ) | (3.21 | ) |
| Net operating expenses – bitumen |  | (24.04 | ) | (21.08 | ) | (23.69 | ) | (23.71 | ) | (26.90 | ) |
| Net operating expenses – upgrading |  | (6.32 | ) | (4.97 | ) | (6.54 | ) | (7.18 | ) | (9.68 | ) |
| Operating netback |  | 36.98 |  | 34.44 |  | 20.02 |  | 24.80 |  | 51.89 |  |
Average Oil Sands operations ($/bbl) |  |  |  |  |  |  |  |  |  |  |  |
| Average price realized |  | 59.46 |  | 58.34 |  | 44.33 |  | 52.53 |  | 89.86 |  |
| Royalties |  | (1.70 | ) | (0.91 | ) | 0.28 |  | (0.59 | ) | (6.36 | ) |
| Transportation costs |  | (4.55 | ) | (4.08 | ) | (4.26 | ) | (4.09 | ) | (3.75 | ) |
| Net operating expenses – bitumen and upgrading |  | (23.15 | ) | (21.82 | ) | (24.37 | ) | (26.07 | ) | (31.04 | ) |
| Operating netback |  | 30.06 |  | 31.53 |  | 15.98 |  | 21.78 |  | 48.71 |  |
Fort Hills ($/bbl) |  |  |  |  |  |  |  |  |  |  |  |
| Average price realized |  | 48.48 |  | — |  | — |  | — |  | — |  |
| Royalties |  | (1.67 | ) | — |  | — |  | — |  | — |  |
| Transportation costs |  | (10.01 | ) | — |  | — |  | — |  | — |  |
| Net operating expenses – bitumen and upgrading |  | (30.32 | ) | — |  | — |  | — |  | — |  |
| Operating netback |  | 6.48 |  | — |  | — |  | — |  | — |  |
Syncrude ($/bbl) |  |  |  |  |  |  |  |  |  |  |  |
| Average price realized |  | 70.68 |  | 66.59 |  | 56.91 |  | 60.28 |  | 96.65 |  |
| Royalties |  | (1.90 | ) | (4.32 | ) | (1.90 | ) | (1.89 | ) | (6.70 | ) |
| Transportation costs |  | (0.49 | ) | (0.54 | ) | (0.53 | ) | (0.54 | ) | (0.59 | ) |
| Net operating expenses – bitumen and upgrading |  | (43.81 | ) | (39.46 | ) | (32.05 | ) | (35.69 | ) | (43.12 | ) |
| Operating netback |  | 24.48 |  | 22.27 |  | 22.43 |  | 22.16 |  | 46.24 |  |

(A)
  Prior periods have been restated due to IFRS 15 adoption (see note 5 in the consolidated financial statements) as well as the removal of the impact of risk management activities.
(B)
  Non-GAAP financial measures. See the Operating Metrics Reconciliation and the Operating Summary Information – Non-GAAP Financial Measures sections of this Annual Report.
(D)
  Netbacks are based on sales volumes.

  See accompanying footnotes and definitions to the operating summaries.

138 2018 ANNUAL REPORT Suncor Energy Inc.

FIVE-YEAR OPERATING SUMMARY (continued)
(unaudited)

Exploration and Production |  | 2018 |  | 2017 |  | 2016 |  | 2015 |  | 2014 |  |
Total Sales Volumes (mboe/d) |  | 102.8 |  | 120.8 |  | 119.3 |  | 110.6 |  | 107.5 |  |
Total Production (mboe/d) |  | 103.4 |  | 121.6 |  | 117.9 |  | 114.4 |  | 113.0 |  |
Production Volumes |  |  |  |  |  |  |  |  |  |  |  |
Exploration and Production Canada |  |  |  |  |  |  |  |  |  |  |  |
| East Coast Canada |  |  |  |  |  |  |  |  |  |  |  |
|  | Terra Nova (mbbls/d) |  | 11.7 |  | 11.5 |  | 12.4 |  | 13.5 |  | 17.3 |  |
|  | Hibernia (mbbls/d) |  | 22.1 |  | 28.5 |  | 26.8 |  | 18.1 |  | 23.1 |  |
|  | White Rose (mbbls/d) |  | 6.6 |  | 11.4 |  | 10.9 |  | 12.2 |  | 14.6 |  |
|  | Hebron (mbbls/d) |  | 13.0 |  | 0.4 |  | — |  | — |  | — |  |
| North America Onshore (mboe/d) |  | 0.5 |  | 1.9 |  | 2.8 |  | 3.2 |  | 3.6 |  |
|  | 53.9 |  | 53.7 |  | 52.9 |  | 47.0 |  | 58.6 |  |
Exploration and Production International |  |  |  |  |  |  |  |  |  |  |  |
| Production (mboe/d) |  |  |  |  |  |  |  |  |  |  |  |
|  | North Sea |  |  |  |  |  |  |  |  |  |  |  |
|  |  | Buzzard |  | 34.2 |  | 43.8 |  | 46.0 |  | 49.8 |  | 47.1 |  |
|  |  | Golden Eagle |  | 12.4 |  | 19.6 |  | 18.6 |  | 14.8 |  | 0.6 |  |
|  | Other International |  |  |  |  |  |  |  |  |  |  |  |
|  |  | Libya(3) |  | 2.9 |  | 4.5 |  | 0.4 |  | 2.8 |  | 6.7 |  |
|  | 49.5 |  | 67.9 |  | 65.0 |  | 67.4 |  | 54.4 |  |
Netbacks(B)(D) |  |  |  |  |  |  |  |  |  |  |  |
East Coast Canada ($/bbl) |  |  |  |  |  |  |  |  |  |  |  |
| Average price realized |  | 90.04 |  | 71.06 |  | 59.31 |  | 65.12 |  | 108.21 |  |
| Royalties |  | (13.31 | ) | (14.26 | ) | (10.64 | ) | (12.49 | ) | (25.97 | ) |
| Transportation costs |  | (2.22 | ) | (1.90 | ) | (1.91 | ) | (2.18 | ) | (1.97 | ) |
| Operating costs |  | (14.43 | ) | (11.24 | ) | (12.67 | ) | (14.15 | ) | (13.11 | ) |
| Operating netback |  | 60.08 |  | 43.66 |  | 34.09 |  | 36.30 |  | 67.16 |  |
United Kingdom ($/boe) |  |  |  |  |  |  |  |  |  |  |  |
| Average price realized |  | 89.10 |  | 67.25 |  | 53.91 |  | 63.85 |  | 106.96 |  |
| Transportation costs |  | (2.18 | ) | (1.81 | ) | (1.84 | ) | (2.41 | ) | (2.84 | ) |
| Operating costs |  | (6.27 | ) | (4.62 | ) | (5.62 | ) | (6.29 | ) | (6.42 | ) |
| Operating netback |  | 80.65 |  | 60.82 |  | 46.45 |  | 55.15 |  | 97.70 |  |

(B)
  Non-GAAP financial measures. See the Operating Metrics Reconciliation and the Operating Summary Information – Non-GAAP Financial Measures sections of this Annual Report.
(D)
  Netbacks are based on sales volumes.

  See accompanying footnotes and definitions to the operating summaries.

2018 ANNUAL REPORT Suncor Energy Inc. 139

FIVE-YEAR OPERATING SUMMARY (continued)
(unaudited)

Refining and Marketing |  | 2018 |  | 2017 |  | 2016 |  | 2015 |  | 2014 |
Refined product sales (mbbls/d) |  | 527.4 |  | 530.5 |  | 521.4 |  | 523.3 |  | 531.7 |
Crude oil processed (mbbls/d) |  | 430.8 |  | 441.2 |  | 428.6 |  | 432.1 |  | 427.5 |
Utilization of refining capacity (%) |  | 93 |  | 96 |  | 93 |  | 94 |  | 93 |
Refining margin ($/bbl)(B)(E) |  | 34.50 |  | 24.20 |  | 20.45 |  | 24.60 |  | 24.50 |
Refining operating expense ($/bbl)(B) |  | 5.35 |  | 5.05 |  | 5.10 |  | 5.10 |  | 6.00 |
Eastern North America |  |  |  |  |  |  |  |  |  |  |
| Refined product sales (mbbls/d) |  |  |  |  |  |  |  |  |  |  |
|  | Transportation fuels |  |  |  |  |  |  |  |  |  |  |
|  | Gasoline |  | 117.8 |  | 117.5 |  | 115.2 |  | 118.9 |  | 120.6 |
|  | Distillate |  | 95.8 |  | 86.8 |  | 76.3 |  | 91.1 |  | 81.9 |
|  | Total transportation fuel sales |  | 213.6 |  | 204.3 |  | 191.5 |  | 210.0 |  | 202.5 |
|  | Petrochemicals |  | 11.3 |  | 12.2 |  | 9.2 |  | 10.8 |  | 12.1 |
|  | Asphalt |  | 15.5 |  | 16.8 |  | 16.7 |  | 13.1 |  | 13.6 |
|  | Other |  | 26.0 |  | 33.4 |  | 35.9 |  | 28.9 |  | 32.5 |
| Total refined product sales |  | 266.4 |  | 266.7 |  | 253.3 |  | 262.8 |  | 260.7 |
| Crude oil supply and refining |  |  |  |  |  |  |  |  |  |  |
|  | Processed at refineries (mbbls/d) |  | 208.1 |  | 206.4 |  | 203.1 |  | 208.1 |  | 199.2 |
|  | Utilization of refining capacity (%) |  | 94 |  | 93 |  | 92 |  | 94 |  | 90 |
Western North America |  |  |  |  |  |  |  |  |  |  |
| Refined product sales (mbbls/d) |  |  |  |  |  |  |  |  |  |  |
|  | Transportation fuels |  |  |  |  |  |  |  |  |  |  |
|  | Gasoline |  | 127.8 |  | 125.4 |  | 129.1 |  | 127.3 |  | 122.8 |
|  | Distillate |  | 107.6 |  | 112.5 |  | 109.8 |  | 106.9 |  | 117.8 |
|  | Total transportation fuel sales |  | 235.4 |  | 237.9 |  | 238.9 |  | 234.2 |  | 240.6 |
|  | Asphalt |  | 13.3 |  | 12.3 |  | 11.8 |  | 11.9 |  | 10.6 |
|  | Other |  | 12.3 |  | 13.6 |  | 17.4 |  | 14.4 |  | 19.8 |
| Total refined product sales |  | 261.0 |  | 263.8 |  | 268.1 |  | 260.5 |  | 271.0 |
| Crude oil supply and refining |  |  |  |  |  |  |  |  |  |  |
|  | Processed at refineries (mbbls/d) |  | 222.7 |  | 234.8 |  | 225.5 |  | 224.0 |  | 228.3 |
|  | Utilization of refining capacity (%) |  | 93 |  | 98 |  | 94 |  | 93 |  | 95 |
| Retail outlets |  | 1 766 |  | 1 749 |  | 1 731 |  | 1 768 |  | 1 773 |

(B)
  Non-GAAP financial measures. See the Operating Metrics Reconciliation and the Operating Summary Information – Non-GAAP Financial Measures sections of this Annual Report.
(E)
  Refining Margins are a non-GAAP financial measure and have been restated to remove the impact of risk management activities.

  See accompanying footnotes and definitions to the operating summaries.

140 2018 ANNUAL REPORT Suncor Energy Inc.

OPERATING METRICS RECONCILIATION
(unaudited)

Oil Sands Netbacks(A)(B)
($ millions except per barrel amounts)

For the quarter ended December 31, 2018 |  | Bitumen |  | SCO and Diesel |  | Oil Sands Operations |  | Fort Hills |  | Syncrude |  | Other(4) |  | Oil Sands Segment |  |
| Operating revenues |  | 405 |  | 1 326 |  | 1 731 |  | 508 |  | 940 |  | (30 | ) | 3 149 |  |
| Other income |  | — |  | 76 |  | 76 |  | 111 |  | 93 |  | — |  | 280 |  |
| Purchases of crude oil and products |  | (267 | ) | (16 | ) | (283 | ) | (218 | ) | (14 | ) | — |  | (515 | ) |
| Gross realization adjustment(5) |  | (12 | ) | (164 | ) | (176 | ) | (136 | ) | (93 | ) |  |  |  |  |
Gross realizations |  | 126 |  | 1 222 |  | 1 348 |  | 265 |  | 926 |  |  |  |  |  |
Royalties |  | (1 | ) | (24 | ) | (25 | ) | (12 | ) | (30 | ) | — |  | (67 | ) |
| Transportation |  | (88 | ) | (116 | ) | (204 | ) | (106 | ) | (9 | ) | — |  | (319 | ) |
| Transportation adjustment(6) |  | — |  | 20 |  | 20 |  | 16 |  | 2 |  |  |  |  |  |
Net transportation expenses |  | (88 | ) | (96 | ) | (184 | ) | (90 | ) | (7 | ) |  |  |  |  |
| Operating, selling and general (OS&G) |  | (167 | ) | (949 | ) | (1 116 | ) | (291 | ) | (619 | ) | 30 |  | (1 996 | ) |
| OS&G adjustment(7) |  | 47 |  | 147 |  | 194 |  | 41 |  | 73 |  |  |  |  |  |
Net operating expenses |  | (120 | ) | (802 | ) | (922 | ) | (250 | ) | (546 | ) |  |  |  |  |
Gross (loss) profit |  | (83 | ) | 300 |  | 217 |  | (87 | ) | 343 |  |  |  |  |  |
Sales volumes (mbbls) |  | 15 825 |  | 26 545 |  | 42 370 |  | 8 706 |  | 19 286 |  |  |  |  |  |
Operating netback per barrel |  | (5.24 | ) | 11.32 |  | 5.13 |  | (9.94 | ) | 17.85 |  |  |  |  |  |

For the quarter ended September 30, 2018 |  | Bitumen |  | SCO and Diesel |  | Oil Sands Operations |  | Fort Hills |  | Syncrude |  | Other(4) |  | Oil Sands Segment |  |
| Operating revenues |  | 729 |  | 2 696 |  | 3 425 |  | 532 |  | 884 |  | (26 | ) | 4 815 |  |
| Other (loss) income |  | — |  | (8 | ) | (8 | ) | (2 | ) | 4 |  | — |  | (6 | ) |
| Purchases of crude oil and products |  | (211 | ) | (15 | ) | (226 | ) | (143 | ) | (10 | ) | 1 |  | (378 | ) |
| Gross realization adjustment(5) |  | (10 | ) | (63 | ) | (73 | ) | (23 | ) | (4 | ) |  |  |  |  |
Gross realizations |  | 508 |  | 2 610 |  | 3 118 |  | 364 |  | 874 |  |  |  |  |  |
Royalties |  | (39 | ) | (81 | ) | (120 | ) | (17 | ) | (24 | ) | — |  | (161 | ) |
| Transportation |  | (65 | ) | (152 | ) | (217 | ) | (78 | ) | (13 | ) | — |  | (308 | ) |
| Transportation adjustment(6) |  | — |  | 39 |  | 39 |  | 17 |  | 6 |  |  |  |  |  |
Net transportation expenses |  | (65 | ) | (113 | ) | (178 | ) | (61 | ) | (7 | ) |  |  |  |  |
| Operating, selling and general (OS&G) |  | (119 | ) | (915 | ) | (1 034 | ) | (214 | ) | (635 | ) | 29 |  | (1 854 | ) |
| OS&G adjustment(7) |  | 35 |  | 145 |  | 180 |  | 40 |  | 24 |  |  |  |  |  |
Net operating expenses |  | (84 | ) | (770 | ) | (854 | ) | (174 | ) | (611 | ) |  |  |  |  |
Gross profit |  | 320 |  | 1 646 |  | 1 966 |  | 112 |  | 232 |  |  |  |  |  |
Sales volumes (mbbls) |  | 12 092 |  | 30 080 |  | 42 172 |  | 5 664 |  | 9 769 |  |  |  |  |  |
Operating netback per barrel |  | 26.41 |  | 54.73 |  | 46.62 |  | 19.67 |  | 23.70 |  |  |  |  |  |

(A)
  Prior periods have been restated due to IFRS 15 adoption (see note 5 in the consolidated financial statements) as well as the removal of the impact of risk management activities.
(B)
  Non-GAAP financial measures. See the Operating Summary Information – Non-GAAP Financial Measures section of this Annual Report.

  See accompanying footnotes and definitions to the operating summaries.

2018 ANNUAL REPORT Suncor Energy Inc. 141

OPERATING METRICS RECONCILIATION (continued)
(unaudited)

Oil Sands Netbacks(A)(B)
($ millions except per barrel amounts)

For the quarter ended June 30, 2018 |  | Bitumen |  | SCO and Diesel |  | Oil Sands Operations |  | Fort Hills |  | Syncrude |  | Other(4) |  | Oil Sands Segment |  |
| Operating revenues |  | 703 |  | 2 020 |  | 2 723 |  | 558 |  | 938 |  | (39 | ) | 4 180 |  |
| Other income (loss) |  | 2 |  | (11 | ) | (9 | ) | (10 | ) | 36 |  | — |  | 17 |  |
| Purchases of crude oil and products |  | (204 | ) | (13 | ) | (217 | ) | (177 | ) | (8 | ) | 2 |  | (400 | ) |
| Gross realization adjustment(5) |  | (14 | ) | (54 | ) | (68 | ) | (16 | ) | (36 | ) |  |  |  |  |
Gross realizations |  | 487 |  | 1 942 |  | 2 429 |  | 355 |  | 930 |  |  |  |  |  |
Royalties |  | (34 | ) | (60 | ) | (94 | ) | (4 | ) | (26 | ) | — |  | (124 | ) |
| Transportation |  | (44 | ) | (148 | ) | (192 | ) | (87 | ) | (12 | ) | — |  | (291 | ) |
| Transportation adjustment(6) |  | — |  | 33 |  | 33 |  | 34 |  | 6 |  |  |  |  |  |
Net transportation expenses |  | (44 | ) | (115 | ) | (159 | ) | (53 | ) | (6 | ) |  |  |  |  |
| OS&G |  | (113 | ) | (981 | ) | (1 094 | ) | (184 | ) | (608 | ) | 38 |  | (1 848 | ) |
| OS&G adjustment(7) |  | 37 |  | 166 |  | 203 |  | 51 |  | 48 |  |  |  |  |  |
Net operating expenses |  | (76 | ) | (815 | ) | (891 | ) | (133 | ) | (560 | ) |  |  |  |  |
Gross profit |  | 333 |  | 952 |  | 1 285 |  | 165 |  | 338 |  |  |  |  |  |
Sales volumes (mbbls) |  | 10 351 |  | 22 838 |  | 33 189 |  | 5 828 |  | 10 718 |  |  |  |  |  |
Operating netback per barrel |  | 32.20 |  | 41.75 |  | 38.77 |  | 28.40 |  | 31.48 |  |  |  |  |  |

For the quarter ended March 31, 2018 |  | Bitumen |  | SCO and Diesel |  | Oil Sands Operations |  | Fort Hills |  | Syncrude |  | Other(4) |  | Oil Sands Segment |  |
| Operating revenues |  | 572 |  | 1 960 |  | 2 532 |  | 77 |  | 1 003 |  | (13 | ) | 3 599 |  |
| Other (loss) income |  | (4 | ) | — |  | (4 | ) | (2 | ) | 3 |  | — |  | (3 | ) |
| Purchases of crude oil and products |  | (211 | ) | (35 | ) | (246 | ) | (17 | ) | (16 | ) | 9 |  | (270 | ) |
| Gross realization adjustment(5) |  | — |  | (25 | ) | (25 | ) | (28 | ) | — |  |  |  |  |  |
Gross realizations |  | 357 |  | 1 900 |  | 2 257 |  | 30 |  | 990 |  |  |  |  |  |
Royalties |  | (10 | ) | (14 | ) | (24 | ) | (2 | ) | (20 | ) | — |  | (46 | ) |
| Transportation |  | (64 | ) | (126 | ) | (190 | ) | (26 | ) | (10 | ) | — |  | (226 | ) |
| Transportation adjustment(6) |  | — |  | 21 |  | 21 |  | 20 |  | 4 |  |  |  |  |  |
Net transportation expenses |  | (64 | ) | (105 | ) | (169 | ) | (6 | ) | (6 | ) |  |  |  |  |
| OS&G |  | (127 | ) | (945 | ) | (1 072 | ) | (143 | ) | (661 | ) | 4 |  | (1 872 | ) |
| OS&G adjustment(7) |  | 34 |  | 146 |  | 180 |  | 66 |  | 81 |  |  |  |  |  |
Net operating expenses |  | (93 | ) | (799 | ) | (892 | ) | (77 | ) | (580 | ) |  |  |  |  |
Gross profit (loss) |  | 190 |  | 982 |  | 1 172 |  | (55 | ) | 384 |  |  |  |  |  |
Sales volumes (mbbls) |  | 10 635 |  | 25 453 |  | 36 088 |  | 729 |  | 12 810 |  |  |  |  |  |
Operating netback per barrel |  | 17.92 |  | 38.57 |  | 32.49 |  | (75.13 | ) | 29.98 |  |  |  |  |  |

(A)
  Prior periods have been restated due to IFRS 15 adoption (see note 5 in the consolidated financial statements) as well as the removal of the impact of risk management activities.
(B)
  Non-GAAP financial measures. See the Operating Summary Information – Non-GAAP Financial Measures section of this Annual Report.

  See accompanying footnotes and definitions to the operating summaries.

142 2018 ANNUAL REPORT Suncor Energy Inc.

OPERATING METRICS RECONCILIATION (continued)
(unaudited)

Oil Sands Netbacks(A)(B)
($ millions except per barrel amounts)

For the quarter ended December 31, 2017 |  | Bitumen |  | SCO and Diesel |  | Oil Sands Operations |  | Syncrude |  | Other(4) |  | Oil Sands Segment |  |
| Operating revenues |  | 710 |  | 2 235 |  | 2 945 |  | 1 202 |  | 1 |  | 4 148 |  |
| Other (loss) income |  | (10 | ) | (8 | ) | (18 | ) | 79 |  | — |  | 61 |  |
| Purchases of crude oil and products |  | (179 | ) | (38 | ) | (217 | ) | (14 | ) | (2 | ) | (233 | ) |
| Gross realization adjustment(5) |  | (7 | ) | (40 | ) | (47 | ) | (85 | ) |  |  |  |  |
Gross realizations |  | 514 |  | 2 149 |  | 2 663 |  | 1 182 |  |  |  |  |  |
Royalties |  | (12 | ) | (35 | ) | (47 | ) | (128 | ) | — |  | (175 | ) |
| Transportation |  | (39 | ) | (144 | ) | (183 | ) | (18 | ) | — |  | (201 | ) |
| Transportation adjustment(6) |  | 3 |  | 26 |  | 29 |  | 12 |  |  |  |  |  |
Net transportation expenses |  | (36 | ) | (118 | ) | (154 | ) | (6 | ) |  |  |  |  |
| OS&G |  | (119 | ) | (958 | ) | (1 077 | ) | (536 | ) | (3 | ) | (1 616 | ) |
| OS&G adjustment(7) |  | 27 |  | 148 |  | 175 |  | 74 |  |  |  |  |  |
Net operating expenses |  | (92 | ) | (810 | ) | (902 | ) | (462 | ) |  |  |  |  |
Gross profit |  | 374 |  | 1 186 |  | 1 560 |  | 586 |  |  |  |  |  |
Sales volumes (mbbls) |  | 12 019 |  | 30 454 |  | 42 473 |  | 16 049 |  |  |  |  |  |
Operating netback per barrel |  | 31.11 |  | 38.94 |  | 36.71 |  | 36.53 |  |  |  |  |  |

For the quarter ended September 30, 2017 |  | Bitumen |  | SCO and Diesel |  | Oil Sands Operations |  | Syncrude |  | Other(4) |  | Oil Sands Segment |  |
| Operating revenues |  | 543 |  | 1 818 |  | 2 361 |  | 905 |  | 2 |  | 3 268 |  |
| Other (loss) income |  | (5 | ) | (2 | ) | (7 | ) | 1 |  | — |  | (6 | ) |
| Purchases of crude oil and products |  | (103 | ) | (18 | ) | (121 | ) | (12 | ) | (2 | ) | (135 | ) |
| Gross realization adjustment(5) |  | (10 | ) | (42 | ) | (52 | ) | (5 | ) |  |  |  |  |
Gross realizations |  | 425 |  | 1 756 |  | 2 181 |  | 889 |  |  |  |  |  |
Royalties |  | (5 | ) | (30 | ) | (35 | ) | (47 | ) | — |  | (82 | ) |
| Transportation |  | (46 | ) | (138 | ) | (184 | ) | (15 | ) | — |  | (199 | ) |
| Transportation adjustment(6) |  | 4 |  | 31 |  | 35 |  | 10 |  |  |  |  |  |
Net transportation expenses |  | (42 | ) | (107 | ) | (149 | ) | (5 | ) |  |  |  |  |
| OS&G |  | (115 | ) | (870 | ) | (985 | ) | (525 | ) | (3 | ) | (1 513 | ) |
| OS&G adjustment(7) |  | 24 |  | 137 |  | 161 |  | 63 |  |  |  |  |  |
Net operating expenses |  | (91 | ) | (733 | ) | (824 | ) | (462 | ) |  |  |  |  |
Gross profit |  | 287 |  | 886 |  | 1 173 |  | 375 |  |  |  |  |  |
Sales volumes (mbbls) |  | 11 075 |  | 29 390 |  | 40 465 |  | 14 636 |  |  |  |  |  |
Operating netback per barrel |  | 26.03 |  | 30.14 |  | 29.01 |  | 25.64 |  |  |  |  |  |

(A)
  Prior periods have been restated due to IFRS 15 adoption (see note 5 in the consolidated financial statements) as well as the removal of the impact of risk management activities.
(B)
  Non-GAAP financial measures. See the Operating Summary Information – Non-GAAP Financial Measures section of this Annual Report.

  See accompanying footnotes and definitions to the operating summaries.

2018 ANNUAL REPORT Suncor Energy Inc. 143

OPERATING METRICS RECONCILIATION (continued)
(unaudited)

Oil Sands Netbacks(A)(B)
($ millions except per barrel amounts)

For the quarter ended June 30, 2017 |  | Bitumen |  | SCO and Diesel |  | Oil Sands Operations |  | Syncrude |  | Other(4) |  | Oil Sands Segment |  |
| Operating revenues |  | 377 |  | 1 793 |  | 2 170 |  | 363 |  | 2 |  | 2 535 |  |
| Other income (loss) |  | 12 |  | (1 | ) | 11 |  | — |  | 6 |  | 17 |  |
| Purchases of crude oil and products |  | (101 | ) | (21 | ) | (122 | ) | (15 | ) | (2 | ) | (139 | ) |
| Gross realization adjustment(5) |  | (3 | ) | (53 | ) | (56 | ) | (2 | ) |  |  |  |  |
Gross realizations |  | 285 |  | 1 718 |  | 2 003 |  | 346 |  |  |  |  |  |
Royalties |  | (5 | ) | (32 | ) | (37 | ) | — |  | — |  | (37 | ) |
| Transportation |  | (55 | ) | (135 | ) | (190 | ) | (15 | ) | — |  | (205 | ) |
| Transportation adjustment(6) |  | — |  | 35 |  | 35 |  | 5 |  |  |  |  |  |
Net transportation expenses |  | (55 | ) | (100 | ) | (155 | ) | (10 | ) |  |  |  |  |
| OS&G |  | (126 | ) | (900 | ) | (1 026 | ) | (551 | ) | 2 |  | (1 575 | ) |
| OS&G adjustment(7) |  | 16 |  | 143 |  | 159 |  | 47 |  |  |  |  |  |
Net operating expenses |  | (110 | ) | (757 | ) | (867 | ) | (504 | ) |  |  |  |  |
Gross profit (loss) |  | 115 |  | 829 |  | 944 |  | (168 | ) |  |  |  |  |
Sales volumes (mbbls) |  | 7 827 |  | 26 764 |  | 34 590 |  | 5 549 |  |  |  |  |  |
Operating netback per barrel |  | 14.65 |  | 31.02 |  | 27.32 |  | (30.28 | ) |  |  |  |  |

For the quarter ended March 31, 2017 |  | Bitumen |  | SCO and Diesel |  | Oil Sands Operations |  | Syncrude |  | Other(4) |  | Oil Sands Segment |  |
| Operating revenues |  | 400 |  | 2 050 |  | 2 450 |  | 873 |  | — |  | 3 323 |  |
| Other income |  | 9 |  | 3 |  | 12 |  | 2 |  | — |  | 14 |  |
| Purchases of crude oil and products |  | (75 | ) | (22 | ) | (97 | ) | (19 | ) | — |  | (116 | ) |
| Gross realization adjustment(5) |  | (15 | ) | (53 | ) | (68 | ) | (7 | ) |  |  |  |  |
Gross realizations |  | 319 |  | 1 978 |  | 2 297 |  | 849 |  |  |  |  |  |
Royalties |  | (5 | ) | (18 | ) | (23 | ) | (38 | ) | — |  | (61 | ) |
| Transportation |  | (62 | ) | (146 | ) | (208 | ) | (14 | ) | — |  | (222 | ) |
| Transportation adjustment(6) |  | — |  | 28 |  | 28 |  | 9 |  |  |  |  |  |
Net transportation expenses |  | (62 | ) | (118 | ) | (180 | ) | (5 | ) |  |  |  |  |
| OS&G |  | (123 | ) | (875 | ) | (998 | ) | (583 | ) | 28 |  | (1 553 | ) |
| OS&G adjustment(7) |  | 29 |  | 141 |  | 170 |  | 76 |  |  |  |  |  |
Net operating expenses |  | (94 | ) | (734 | ) | (828 | ) | (507 | ) |  |  |  |  |
Gross profit |  | 158 |  | 1 108 |  | 1 266 |  | 299 |  |  |  |  |  |
Sales volumes (mbbls) |  | 9 444 |  | 29 844 |  | 39 288 |  | 12 788 |  |  |  |  |  |
Operating netback per barrel |  | 16.80 |  | 37.13 |  | 32.25 |  | 23.33 |  |  |  |  |  |

(A)
  Prior periods have been restated due to IFRS 15 adoption (see note 5 in the consolidated financial statements) as well as the removal of the impact of risk management activities.
(B)
  Non-GAAP financial measures. See the Operating Summary Information – Non-GAAP Financial Measures section of this Annual Report.

  See accompanying footnotes and definitions to the operating summaries.

144 2018 ANNUAL REPORT Suncor Energy Inc.

OPERATING METRICS RECONCILIATION (continued)
(unaudited)

Oil Sands Netbacks(A)(B)
($ millions except per barrel amounts)

For the year ended December 31, 2018 |  | Bitumen |  | SCO and Diesel |  | Oil Sands Operations |  | Fort Hills |  | Syncrude |  | Other(4) |  | Oil Sands Segment |  |
| Operating revenues |  | 2 409 |  | 8 002 |  | 10 411 |  | 1 675 |  | 3 765 |  | (108 | ) | 15 743 |  |
| Other (loss) income |  | (2 | ) | 57 |  | 55 |  | 97 |  | 136 |  | — |  | 288 |  |
| Purchases of crude oil and products |  | (893 | ) | (79 | ) | (972 | ) | (555 | ) | (48 | ) | 12 |  | (1 563 | ) |
| Gross realization adjustment(5) |  | (36 | ) | (306 | ) | (342 | ) | (203 | ) | (133 | ) |  |  |  |  |
Gross realizations |  | 1 478 |  | 7 674 |  | 9 152 |  | 1 014 |  | 3 720 |  |  |  |  |  |
Royalties |  | (84 | ) | (179 | ) | (263 | ) | (35 | ) | (100 | ) | — |  | (398 | ) |
| Transportation |  | (261 | ) | (542 | ) | (803 | ) | (297 | ) | (44 | ) | — |  | (1 144 | ) |
| Transportation adjustment(6) |  | — |  | 113 |  | 113 |  | 87 |  | 18 |  |  |  |  |  |
Net transportation expenses |  | (261 | ) | (429 | ) | (690 | ) | (210 | ) | (26 | ) |  |  |  |  |
| OS&G |  | (526 | ) | (3 790 | ) | (4 316 | ) | (832 | ) | (2 523 | ) | 101 |  | (7 570 | ) |
| OS&G adjustment(7) |  | 153 |  | 604 |  | 757 |  | 197 |  | 226 |  |  |  |  |  |
Net operating expenses |  | (373 | ) | (3 186 | ) | (3 559 | ) | (635 | ) | (2 297 | ) |  |  |  |  |
Gross profit |  | 760 |  | 3 880 |  | 4 640 |  | 134 |  | 1 297 |  |  |  |  |  |
Sales volumes (mbbls) |  | 48 903 |  | 104 916 |  | 153 819 |  | 20 927 |  | 52 583 |  |  |  |  |  |
Operating netback per barrel |  | 15.32 |  | 36.98 |  | 30.06 |  | 6.48 |  | 24.48 |  |  |  |  |  |

For the year ended December 31, 2017 |  | Bitumen |  | SCO and Diesel |  | Oil Sands Operations |  | Syncrude |  | Other(4) |  | Oil Sands Segment |  |
| Operating revenues |  | 2 031 |  | 7 898 |  | 9 929 |  | 3 341 |  | 4 |  | 13 274 |  |
| Other income (loss) |  | 9 |  | (9 | ) | — |  | 82 |  | 4 |  | 86 |  |
| Purchases of crude oil and products |  | (458 | ) | (99 | ) | (557 | ) | (61 | ) | (5 | ) | (623 | ) |
| Gross realization adjustment(5) |  | (36 | ) | (187 | ) | (223 | ) | (98 | ) |  |  |  |  |
Gross realizations |  | 1 546 |  | 7 603 |  | 9 149 |  | 3 264 |  |  |  |  |  |
Royalties |  | (28 | ) | (115 | ) | (143 | ) | (212 | ) | — |  | (355 | ) |
| Transportation |  | (202 | ) | (563 | ) | (765 | ) | (62 | ) | — |  | (827 | ) |
| Transportation adjustment(6) |  | 7 |  | 120 |  | 127 |  | 35 |  |  |  |  |  |
Net transportation expenses |  | (195 | ) | (443 | ) | (638 | ) | (27 | ) |  |  |  |  |
| OS&G |  | (484 | ) | (3 604 | ) | (4 088 | ) | (2 195 | ) | 26 |  | (6 257 | ) |
| OS&G adjustment(7) |  | 96 |  | 569 |  | 665 |  | 261 |  |  |  |  |  |
Net operating expenses |  | (388 | ) | (3 035 | ) | (3 423 | ) | (1 934 | ) |  |  |  |  |
Gross profit |  | 935 |  | 4 010 |  | 4 945 |  | 1 091 |  |  |  |  |  |
Sales volumes (mbbls) |  | 40 365 |  | 116 451 |  | 156 816 |  | 49 022 |  |  |  |  |  |
Operating netback per barrel |  | 23.17 |  | 34.44 |  | 31.53 |  | 22.27 |  |  |  |  |  |

(A)
  Prior periods have been restated due to IFRS 15 adoption (see note 5 in the consolidated financial statements) as well as the removal of the impact of risk management activities.
(B)
  Non-GAAP financial measures. See the Operating Summary Information – Non-GAAP Financial Measures section of this Annual Report.

  See accompanying footnotes and definitions to the operating summaries.

2018 ANNUAL REPORT Suncor Energy Inc. 145

OPERATING METRICS RECONCILIATION (continued)
(unaudited)

Oil Sands Netbacks(A)(B)
($ millions except per barrel amounts)

For the year ended December 31, 2016 |  | Bitumen |  | SCO and Diesel |  | Oil Sands Operations |  | Syncrude |  | Other(4) |  | Oil Sands Segment |  |
| Operating revenues |  | 1 434 |  | 5 348 |  | 6 782 |  | 2 807 |  | — |  | 9 589 |  |
| Other income |  | 6 |  | 2 |  | 8 |  | 17 |  | 1 |  | 26 |  |
| Purchases of crude oil and products |  | (431 | ) | (60 | ) | (491 | ) | (57 | ) | — |  | (548 | ) |
| Gross realization adjustment(5) |  | 17 |  | (162 | ) | (145 | ) | (57 | ) |  |  |  |  |
Gross realizations |  | 1 026 |  | 5 128 |  | 6 154 |  | 2 710 |  |  |  |  |  |
Royalties |  | (10 | ) | 48 |  | 38 |  | (90 | ) | — |  | (52 | ) |
| Transportation |  | (231 | ) | (452 | ) | (683 | ) | (50 | ) | — |  | (733 | ) |
| Transportation adjustment(6) |  | — |  | 92 |  | 92 |  | 25 |  |  |  |  |  |
Net transportation expenses |  | (231 | ) | (360 | ) | (591 | ) | (25 | ) |  |  |  |  |
| OS&G |  | (595 | ) | (3 468 | ) | (4 063 | ) | (1 749 | ) | 35 |  | (5 777 | ) |
| OS&G adjustment(7) |  | 112 |  | 568 |  | 680 |  | 223 |  |  |  |  |  |
Net operating expenses |  | (483 | ) | (2 900 | ) | (3 383 | ) | (1 526 | ) |  |  |  |  |
Gross profit |  | 302 |  | 1 916 |  | 2 218 |  | 1 069 |  |  |  |  |  |
Sales volumes (mbbls) |  | 42 973 |  | 95 852 |  | 138 825 |  | 47 614 |  |  |  |  |  |
Operating netback per barrel |  | 7.00 |  | 20.02 |  | 15.98 |  | 22.43 |  |  |  |  |  |

For the year ended December 31, 2015 |  | Bitumen |  | SCO and Diesel |  | Oil Sands Operations |  | Syncrude |  | Other(4) |  | Oil Sands Segment |  |
| Operating revenues |  | 1 480 |  | 7 282 |  | 8 762 |  | 673 |  | — |  | 9 435 |  |
| Other income |  | 49 |  | 96 |  | 145 |  | — |  | 1 |  | 146 |  |
| Purchases of crude oil and products |  | (228 | ) | (75 | ) | (303 | ) | (16 | ) | — |  | (319 | ) |
| Gross realization adjustment(5) |  | (75 | ) | (314 | ) | (389 | ) | 5 |  |  |  |  |  |
Gross realizations |  | 1 226 |  | 6 989 |  | 8 215 |  | 662 |  |  |  |  |  |
Royalties |  | (16 | ) | (77 | ) | (93 | ) | (21 | ) | — |  | (114 | ) |
Transportation |  | (246 | ) | (496 | ) | (742 | ) | (6 | ) | — |  | (748 | ) |
| Transportation adjustment(6) |  | — |  | 103 |  | 103 |  | — |  |  |  |  |  |
Net transportation expenses |  | (246 | ) | (393 | ) | (639 | ) | (6 | ) |  |  |  |  |
| OS&G |  | (577 | ) | (4 195 | ) | (4 772 | ) | (471 | ) | 23 |  | (5 220 | ) |
| OS&G adjustment(7) |  | 115 |  | 580 |  | 695 |  | 77 |  |  |  |  |  |
Net operating expenses |  | (462 | ) | (3 615 | ) | (4 077 | ) | (394 | ) |  |  |  |  |
Gross profit |  | 502 |  | 2 904 |  | 3 406 |  | 241 |  |  |  |  |  |
Sales volumes (mbbls) |  | 39 297 |  | 117 094 |  | 156 391 |  | 10 875 |  |  |  |  |  |
Operating netback per barrel |  | 12.77 |  | 24.80 |  | 21.78 |  | 22.16 |  |  |  |  |  |

(A)
  Prior periods have been restated due to IFRS 15 adoption (see note 5 in the consolidated financial statements) as well as the removal of the impact of risk management activities.
(B)
  Non-GAAP financial measures. See the Operating Summary Information – Non-GAAP Financial Measures section of this Annual Report.

  See accompanying footnotes and definitions to the operating summaries.

146 2018 ANNUAL REPORT Suncor Energy Inc.

OPERATING METRICS RECONCILIATION (continued)
(unaudited)

Oil Sands Netbacks(A)(B)
($ millions except per barrel amounts)

For the year ended December 31, 2014 |  | Bitumen |  | SCO and Diesel |  | Oil Sands Operations |  | Syncrude |  | Other(4) |  | Oil Sands Segment |  |
| Operating revenues |  | 2 753 |  | 10 794 |  | 13 547 |  | 1 122 |  | — |  | 14 669 |  |
| Other income |  | 92 |  | 23 |  | 115 |  | — |  | — |  | 115 |  |
| Purchases of crude oil and products |  | (334 | ) | (94 | ) | (428 | ) | (29 | ) | — |  | (457 | ) |
| Gross realization adjustment(5) |  | (119 | ) | (304 | ) | (423 | ) | — |  |  |  |  |  |
Gross realizations |  | 2 392 |  | 10 419 |  | 12 811 |  | 1 093 |  |  |  |  |  |
Royalties |  | (167 | ) | (739 | ) | (906 | ) | (76 | ) | — |  | (982 | ) |
Transportation |  | (195 | ) | (447 | ) | (642 | ) | (7 | ) | — |  | (649 | ) |
| Transportation adjustment(6) |  | — |  | 108 |  | 108 |  | — |  |  |  |  |  |
Net transportation expenses |  | (195 | ) | (339 | ) | (534 | ) | (7 | ) |  |  |  |  |
| OS&G |  | (688 | ) | (4 626 | ) | (5 314 | ) | (564 | ) | (62 | ) | (5 940 | ) |
| OS&G adjustment(7) |  | 122 |  | 766 |  | 888 |  | 77 |  |  |  |  |  |
Net operating expenses |  | (566 | ) | (3 860 | ) | (4 426 | ) | (487 | ) |  |  |  |  |
Gross profit |  | 1 464 |  | 5 481 |  | 6 945 |  | 523 |  |  |  |  |  |
Sales volumes (mbbls) |  | 36 994 |  | 105 588 |  | 142 582 |  | 11 302 |  |  |  |  |  |
Operating netback per barrel |  | 39.58 |  | 51.89 |  | 48.71 |  | 46.24 |  |  |  |  |  |

Syncrude Cash Operating Costs(B)
($ millions except per barrel amounts)

|  | For the quarter ended |  |
|  | Mar 31 2018 |  | June 30 2018 |  | Sept 30 2018 |  | Dec 31 2018 |  | Mar 31 2017 |  | June 30 2017 |  | Sept 30 2017 |  | Dec 31 2017 |  |
Syncrude OS&G |  | 661 |  | 608 |  | 635 |  | 619 |  | 583 |  | 551 |  | 525 |  | 536 |  |
Non-production costs(8) |  | (10 | ) | (5 | ) | (11 | ) | (7 | ) | (6 | ) | (8 | ) | (13 | ) | (10 | ) |
Syncrude cash operating costs |  | 651 |  | 603 |  | 624 |  | 612 |  | 577 |  | 543 |  | 512 |  | 526 |  |
Syncrude sales volumes (mbbls) |  | 12 810 |  | 10 718 |  | 9 769 |  | 19 286 |  | 12 788 |  | 5 549 |  | 14 636 |  | 16 049 |  |
Syncrude cash operating costs ($/bbl) |  | 50.75 |  | 56.25 |  | 63.85 |  | 31.75 |  | 45.15 |  | 97.80 |  | 35.00 |  | 32.80 |  |

|  | For the year ended |  |
|  | 2018 |  | 2017 |  | 2016 |  | 2015 |  | 2014 |  |
Syncrude OS&G |  | 2 523 |  | 2 195 |  | 1 749 |  | 471 |  | 564 |  |
Non-production costs(8) |  | (33 | ) | (37 | ) | (31 | ) | (14 | ) | (9 | ) |
Syncrude cash operating costs |  | 2 490 |  | 2 158 |  | 1 718 |  | 457 |  | 555 |  |
Syncrude sales volumes (mbbls) |  | 52 583 |  | 49 022 |  | 47 614 |  | 10 876 |  | 11 302 |  |
Syncrude cash operating costs ($/bbl) |  | 47.25 |  | 44.05 |  | 35.95 |  | 42.00 |  | 49.15 |  |

(A)
  Prior periods have been restated due to IFRS 15 adoption (see note 5 in the consolidated financial statements) as well as the removal of the impact of risk management activities.
(B)
  Non-GAAP financial measures. See the Operating Summary Information – Non-GAAP Financial Measures section of this Annual Report.

  See accompanying footnotes and definitions to the operating summaries.

2018 ANNUAL REPORT Suncor Energy Inc. 147

OPERATING METRICS RECONCILIATION (continued)
(unaudited)

Exploration and Production Netbacks(B)
($ millions except per barrel amounts)

|  | For the quarter ended December 31, 2018 |  | For the quarter ended December 31, 2017 |  |
|  | United Kingdom |  | East Coast Canada |  | Other(9) |  | E&P Segment |  | United Kingdom |  | East Coast Canada |  | Other(9) |  | E&P Segment |  |
Operating revenues |  | 301 |  | 286 |  | 184 |  | 771 |  | 383 |  | 328 |  | 238 |  | 949 |  |
Royalties |  | — |  | (19 | ) | (120 | ) | (139 | ) | — |  | (53 | ) | (147 | ) | (200 | ) |
Transportation |  | (8 | ) | (10 | ) | (1 | ) | (19 | ) | (9 | ) | (9 | ) | (2 | ) | (20 | ) |
OS&G |  | (39 | ) | (101 | ) | (14 | ) | (154 | ) | (36 | ) | (55 | ) | (10 | ) | (101 | ) |
Non-production costs(10) |  | 8 |  | 12 |  |  |  |  |  | 7 |  | 10 |  |  |  |  |  |
Gross realizations |  | 262 |  | 168 |  |  |  |  |  | 345 |  | 221 |  |  |  |  |  |
Sales volumes (mboe) |  | 3 531 |  | 3 758 |  |  |  |  |  | 5 011 |  | 4 023 |  |  |  |  |  |
Operating netback per barrel |  | 74.23 |  | 44.73 |  |  |  |  |  | 68.77 |  | 54.85 |  |  |  |  |  |

|  | For the quarter ended September 30, 2018 |  | For the quarter ended September 30, 2017 |  |
|  | United Kingdom |  | East Coast Canada |  | Other(9) |  | E&P Segment |  | United Kingdom |  | East Coast Canada |  | Other(9) |  | E&P Segment |  |
Operating revenues |  | 361 |  | 488 |  | 100 |  | 949 |  | 375 |  | 263 |  | 128 |  | 766 |  |
Royalties |  | — |  | (91 | ) | (74 | ) | (165 | ) | — |  | (51 | ) | (81 | ) | (132 | ) |
Transportation |  | (8 | ) | (12 | ) | — |  | (20 | ) | (11 | ) | (8 | ) | (2 | ) | (21 | ) |
OS&G |  | (27 | ) | (90 | ) | (8 | ) | (125 | ) | (31 | ) | (68 | ) | (10 | ) | (109 | ) |
Non-production costs(10) |  | 3 |  | 11 |  |  |  |  |  | 5 |  | 10 |  |  |  |  |  |
Gross realizations |  | 329 |  | 306 |  |  |  |  |  | 338 |  | 146 |  |  |  |  |  |
Sales volumes (mboe) |  | 3 827 |  | 4 905 |  |  |  |  |  | 5 963 |  | 3 906 |  |  |  |  |  |
Operating netback per barrel |  | 86.02 |  | 62.41 |  |  |  |  |  | 56.71 |  | 37.37 |  |  |  |  |  |

|  | For the quarter ended June 30, 2018 |  | For the quarter ended June 30, 2017 |  |
|  | United Kingdom |  | East Coast Canada |  | Other(9) |  | E&P Segment |  | United Kingdom |  | East Coast Canada |  | Other(9) |  | E&P Segment |  |
Operating revenues |  | 444 |  | 484 |  | 204 |  | 1 132 |  | 378 |  | 354 |  | 120 |  | 852 |  |
Royalties |  | — |  | (65 | ) | (122 | ) | (187 | ) | — |  | (75 | ) | (46 | ) | (121 | ) |
Transportation |  | (10 | ) | (11 | ) | (1 | ) | (22 | ) | (11 | ) | (9 | ) | (2 | ) | (22 | ) |
OS&G |  | (30 | ) | (69 | ) | (14 | ) | (113 | ) | (31 | ) | (65 | ) | (15 | ) | (111 | ) |
Non-production costs(10) |  | 4 |  | 13 |  |  |  |  |  | 4 |  | 9 |  |  |  |  |  |
Gross realizations |  | 408 |  | 352 |  |  |  |  |  | 340 |  | 214 |  |  |  |  |  |
Sales volumes (mboe) |  | 4 728 |  | 4 973 |  |  |  |  |  | 5 954 |  | 5 345 |  |  |  |  |  |
Operating netback per barrel |  | 86.29 |  | 70.83 |  |  |  |  |  | 57.01 |  | 40.03 |  |  |  |  |  |

(B)
  Non-GAAP financial measures. See the Operating Summary Information – Non-GAAP Financial Measures section of this Annual Report.

  See accompanying footnotes and definitions to the operating summaries.

148 2018 ANNUAL REPORT Suncor Energy Inc.

OPERATING METRICS RECONCILIATION (continued)
(unaudited)

Exploration and Production Netbacks(B)
($ millions except per barrel amounts)

|  | For the quarter ended March 31, 2018 |  | For the quarter ended March 31, 2017 |  |
|  | United Kingdom |  | East Coast Canada |  | Other(9) |  | E&P Segment |  | United Kingdom |  | East Coast Canada |  | Other(9) |  | E&P Segment |  |
Operating revenues |  | 409 |  | 478 |  | 130 |  | 1 017 |  | 421 |  | 379 |  | 120 |  | 920 |  |
Royalties |  | — |  | (82 | ) | (79 | ) | (161 | ) | — |  | (87 | ) | (36 | ) | (123 | ) |
Transportation |  | (11 | ) | (10 | ) | (3 | ) | (24 | ) | (11 | ) | (9 | ) | (3 | ) | (23 | ) |
OS&G |  | (32 | ) | (68 | ) | (10 | ) | (110 | ) | (28 | ) | (60 | ) | (13 | ) | (101 | ) |
Non-production costs(10) |  | 7 |  | 14 |  |  |  |  |  | 4 |  | 10 |  |  |  |  |  |
Gross realizations |  | 373 |  | 332 |  |  |  |  |  | 386 |  | 233 |  |  |  |  |  |
Sales volumes (mboe) |  | 4 920 |  | 5 647 |  |  |  |  |  | 6 228 |  | 5 432 |  |  |  |  |  |
Operating netback per barrel |  | 75.72 |  | 58.75 |  |  |  |  |  | 61.99 |  | 42.81 |  |  |  |  |  |

For the year ended December 31, 2018 |  | United Kingdom |  | East Coast Canada |  | Other(9) |  | E&P Segment |  |
Operating revenues |  | 1 515 |  | 1 736 |  | 618 |  | 3 869 |  |
Royalties |  | — |  | (257 | ) | (395 | ) | (652 | ) |
Transportation |  | (37 | ) | (43 | ) | (5 | ) | (85 | ) |
OS&G |  | (129 | ) | (328 | ) | (46 | ) | (503 | ) |
Non-production costs(10) |  | 23 |  | 50 |  |  |  |  |  |
Gross realizations |  | 1 372 |  | 1 158 |  |  |  |  |  |
Sales volumes (mboe) |  | 17 006 |  | 19 283 |  |  |  |  |  |
Operating netback per barrel |  | 80.65 |  | 60.08 |  |  |  |  |  |

For the year ended December 31, 2017 |  | United Kingdom |  | East Coast Canada |  | Other(9) |  | E&P Segment |  |
Operating revenues |  | 1 557 |  | 1 323 |  | 607 |  | 3 487 |  |
Royalties |  | — |  | (266 | ) | (310 | ) | (576 | ) |
Transportation |  | (42 | ) | (35 | ) | (9 | ) | (86 | ) |
OS&G |  | (127 | ) | (248 | ) | (47 | ) | (422 | ) |
Non-production costs(10) |  | 20 |  | 39 |  |  |  |  |  |
Gross realizations |  | 1 408 |  | 813 |  |  |  |  |  |
Sales volumes (mboe) |  | 23 157 |  | 18 623 |  |  |  |  |  |
Operating netback per barrel |  | 60.82 |  | 43.66 |  |  |  |  |  |

(B)
  Non-GAAP financial measures. See the Operating Summary Information – Non-GAAP Financial Measures section of this Annual Report.

  See accompanying footnotes and definitions to the operating summaries.

2018 ANNUAL REPORT Suncor Energy Inc. 149

OPERATING METRICS RECONCILIATION (continued)
(unaudited)

Exploration and Production Netbacks(A)(B)
($ millions except per barrel amounts)

For the year ended December 31, 2016 |  | United Kingdom |  | East Coast Canada |  | Other(9) |  | E&P Segment |  |
Operating revenues |  | 1 276 |  | 1 119 |  | 54 |  | 2 449 |  |
Royalties |  | — |  | (201 | ) | (12 | ) | (213 | ) |
Transportation |  | (44 | ) | (36 | ) | (11 | ) | (91 | ) |
OS&G |  | (151 | ) | (278 | ) | (54 | ) | (483 | ) |
Non-production costs(10) |  | 18 |  | 39 |  |  |  |  |  |
Gross realizations |  | 1 099 |  | 643 |  |  |  |  |  |
Sales volumes (mboe) |  | 23 653 |  | 18 849 |  |  |  |  |  |
Operating netback per barrel |  | 46.45 |  | 34.09 |  |  |  |  |  |

For the year ended December 31, 2015 |  | United Kingdom |  | East Coast Canada |  | Other(9) |  | E&P Segment |  |
Operating revenues |  | 1 505 |  | 1 019 |  | 101 |  | 2 625 |  |
Royalties |  | — |  | (195 | ) | (72 | ) | (267 | ) |
Transportation |  | (57 | ) | (34 | ) | (20 | ) | (111 | ) |
OS&G |  | (175 | ) | (258 | ) | (69 | ) | (502 | ) |
Non-production costs(10) |  | 27 |  | 36 |  |  |  |  |  |
Gross realizations |  | 1 300 |  | 568 |  |  |  |  |  |
Sales volumes (mboe) |  | 23 580 |  | 15 643 |  |  |  |  |  |
Operating netback per barrel |  | 55.15 |  | 36.30 |  |  |  |  |  |

For the year ended December 31, 2014 |  | United Kingdom |  | East Coast Canada |  | Other(9) |  | E&P Segment |  |
Operating revenues |  | 1 814 |  | 2 151 |  | 763 |  | 4 728 |  |
Royalties |  | — |  | (516 | ) | (156 | ) | (672 | ) |
Transportation |  | (48 | ) | (39 | ) | (16 | ) | (103 | ) |
OS&G |  | (119 | ) | (297 | ) | (142 | ) | (558 | ) |
Non-production costs(10) |  | 10 |  | 36 |  |  |  |  |  |
Gross realizations |  | 1 657 |  | 1 335 |  |  |  |  |  |
Sales volumes (mboe) |  | 16 954 |  | 19 875 |  |  |  |  |  |
Operating netback per barrel |  | 97.70 |  | 67.16 |  |  |  |  |  |

(A)
  Prior periods have been restated due to IFRS 15 adoption; see note 5 in the consolidated financial statements.
(B)
  Non-GAAP financial measures. See the Operating Summary Information – Non-GAAP Financial Measures section of this Annual Report.

  See accompanying footnotes and definitions to the operating summaries.

150 2018 ANNUAL REPORT Suncor Energy Inc.

OPERATING METRICS RECONCILIATION (continued)
(unaudited)

Refining and Marketing(A)(E)
($ millions except per barrel amounts)

|  | For the quarter ended |  |
|  | Mar 31 2018 |  | June 30 2018 |  | Sept 30 2018 |  | Dec 31 2018 |  | Mar 31 2017 |  | June 30 2017 |  | Sept 30 2017 |  | Dec 31 2017 |  |
Gross margin(11) |  | 1 773 |  | 1 628 |  | 1 972 |  | 1 695 |  | 1 328 |  | 1 102 |  | 1 456 |  | 1 807 |  |
Other (loss) income |  | (7 | ) | (14 | ) | 1 |  | 41 |  | 19 |  | 19 |  | 48 |  | (13 | ) |
Non-refining margin(12) |  | (413 | ) | (610 | ) | (407 | ) | 180 |  | (431 | ) | (329 | ) | (392 | ) | (394 | ) |
Refining margin(B) |  | 1 353 |  | 1 004 |  | 1 566 |  | 1 916 |  | 916 |  | 792 |  | 1 112 |  | 1 400 |  |
Refinery production (mbbls)(13) |  | 44 363 |  | 33 165 |  | 45 465 |  | 46 145 |  | 41 540 |  | 42 629 |  | 46 491 |  | 43 801 |  |
Refining margin ($/bbl) |  | 30.50 |  | 30.25 |  | 34.45 |  | 41.50 |  | 22.05 |  | 18.60 |  | 23.90 |  | 31.95 |  |
Last-in, first out (LIFO) Adjustment |  | (11 | ) | (96 | ) | — |  | 444 |  | (6 | ) | 33 |  | 16 |  | (139 | ) |
Adjusted LIFO Refining Margin(B) |  | 1 342 |  | 908 |  | 1 566 |  | 2 360 |  | 910 |  | 825 |  | 1 128 |  | 1 261 |  |
Adjusted LIFO refining margin ($/bbl)(B) |  | 30.25 |  | 27.40 |  | 34.45 |  | 51.15 |  | 21.95 |  | 19.30 |  | 24.25 |  | 28.75 |  |
OS&G |  | 480 |  | 478 |  | 499 |  | 522 |  | 503 |  | 448 |  | 467 |  | 532 |  |
Non-refining costs(14) |  | (262 | ) | (272 | ) | (272 | ) | (272 | ) | (274 | ) | (233 | ) | (258 | ) | (303 | ) |
Net operating expenses |  | 218 |  | 206 |  | 227 |  | 250 |  | 229 |  | 215 |  | 209 |  | 229 |  |
Refinery production (mbbls)(13) |  | 44 363 |  | 33 165 |  | 45 465 |  | 46 145 |  | 41 540 |  | 42 629 |  | 46 491 |  | 43 801 |  |
Refining operating expense ($/bbl) |  | 4.90 |  | 6.25 |  | 5.00 |  | 5.45 |  | 5.50 |  | 5.05 |  | 4.50 |  | 5.25 |  |

|  | For the year ended |  |
|  | 2018 |  | 2017 |  | 2016 |  | 2015 |  | 2014 |  |
Gross margin(11) |  | 7 068 |  | 5 692 |  | 5 506 |  | 5 987 |  | 5 431 |  |
Other income |  | 21 |  | 73 |  | 16 |  | 86 |  | 184 |  |
Non-refining margin(12) |  | (1 250 | ) | (1 546 | ) | (2 074 | ) | (1 854 | ) | (1 487 | ) |
Refining margin(B) |  | 5 839 |  | 4 219 |  | 3 448 |  | 4 219 |  | 4 128 |  |
Refinery production (mbbls)(13) |  | 169 138 |  | 174 461 |  | 168 798 |  | 171 581 |  | 168 536 |  |
Refining margin ($/bbl) |  | 34.50 |  | 24.20 |  | 20.45 |  | 24.60 |  | 24.50 |  |
LIFO Adjustment |  | 337 |  | (96 | ) | (63 | ) | 149 |  | 256 |  |
Adjusted LIFO Refining Margin(B) |  | 6 176 |  | 4 123 |  | 3 385 |  | 4 368 |  | 4 384 |  |
Adjusted LIFO refining margin ($/bbl)(B) |  | 36.50 |  | 23.65 |  | 20.05 |  | 25.45 |  | 26.00 |  |
OS&G |  | 1 979 |  | 1 950 |  | 2 147 |  | 2 164 |  | 2 441 |  |
Non-refining costs(14) |  | (1 078 | ) | (1 068 | ) | (1 287 | ) | (1 283 | ) | (1 436 | ) |
Refining operating expense |  | 901 |  | 882 |  | 860 |  | 881 |  | 1 005 |  |
Refinery production (mbbls)(13) |  | 169 138 |  | 174 461 |  | 168 798 |  | 171 581 |  | 168 536 |  |
Refining operating expense ($/bbl) |  | 5.35 |  | 5.05 |  | 5.10 |  | 5.10 |  | 6.00 |  |

(A)
  Prior periods have been restated due to IFRS 15 adoption; see note 5 in the consolidated financial statements.
(B)
  Non-GAAP financial measures. See the Operating Summary Information – Non-GAAP Financial Measures section of this Annual Report.
(E)
  Refining Margins are a non-GAAP financial measure and have been restated to remove the impact of risk management activities.

  See accompanying footnotes and definitions to the operating summaries.

2018 ANNUAL REPORT Suncor Energy Inc. 151

OPERATING SUMMARY INFORMATION

Non-GAAP Financial Measures

Certain financial measures in this Supplemental Financial and Operating Information – namely operating earnings (loss), funds from (used in) operations (previously referred to as cash flow from (used in) operations), return on capital employed (ROCE), Oil Sands operations cash operating costs (previously referred to as Oil Sands cash operating costs), Syncrude cash operating costs, Fort Hills cash operating costs, In Situ cash operating costs, mining cash operating costs, refining margin, refining operating expense and 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.

Operating earnings (loss), Oil Sands operations cash operating costs and Fort Hills cash operating costs for each quarter in 2018 and 2017 are defined in the Non-GAAP Financial Measures Advisory section and reconciled to the most directly comparable GAAP measures in the Consolidated Financial Information and Segment Results and Analysis sections in each respective quarterly Report to Shareholders issued by Suncor in respect of the relevant quarter (Quarterly Reports). Funds from (used in) operations and ROCE for each quarter in 2018 and 2017 are defined and reconciled to the most directly comparable GAAP measures in the Non-GAAP Financial Measures Advisory section of each respective Quarterly Report. Operating earnings (loss), funds from (used in) operations, ROCE and Oil Sands operations cash operating costs for the years ended December 31, 2015 and 2014 are defined and reconciled in Suncor's Management's Discussion and Analysis for the year ended December 31, 2016 and for the years ended December 31, 2018, 2017 and 2016 are defined and reconciled in Suncor's Management's Discussion and Analysis for the year ended December 31, 2018, which is contained in the annual report (the 2018 MD&A). Refining margin, refining operating expense and Syncrude cash operating costs for each quarter in 2018 and 2017 and for the years ended December 31, 2018, 2017, 2016, 2015 and 2014 are defined in the 2018 MD&A and reconciled to the most directly comparable GAAP measures in the Operating Metrics Reconciliation section of this Supplemental Financial and Operating Information. Netbacks for each quarter in 2018 and 2017 and for the years ended December 31, 2018, 2017, 2016, 2015 and 2014 are defined below and are reconciled to the most directly comparable GAAP measures in the Operating Metrics Reconciliation section of this Supplemental Financial and Operating Information. The remainder of the non-GAAP financial measures not otherwise mentioned in this paragraph are defined and reconciled in the 2018 MD&A.

Oil Sands 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) Netbacks

E&P 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 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 – Include cash costs that are defined as operating, selling and general expenses (excluding inventory changes and non-production costs), and are net of operating revenues associated with excess power from cogeneration units. Oil Sands operations cash operating costs are presented on a production basis by adjusting for inventory impacts, while Syncrude production volumes are equal to sales volumes.
(2)
  Syncrude's capacity to upgrade bitumen to an intermediary sour SCO is 350,000 bbls/d.
(3)
  Effective 2016, Libyan production volumes reflect the company's entitlement share of production sold in the period.
(4)
  Reflects non-producing Oil Sands assets and enterprise shared service allocations and recoveries.
(5)
  Reflects the impact of items not directly attributed to revenues received from the sale of proprietary crude and net non-proprietary activity at its deemed point of sale.
(6)
  Reflects adjustments for expenses or credits not directly related to the transportation of the crude product to its deemed point of sale. For Oil Sands operations bitumen and SCO, the point of sale is at the final customer, whereas Syncrude sweet SCO is deemed to be sold into the sweet synthetic crude oil pool in Edmonton, Alberta. Expenses or credits adjusted out of the netback transportation line include, but are not limited to, costs associated with the sale of non-proprietary product on pipelines with unutilized capacity under minimum volume commitment agreements.
(7)
  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 from cogeneration units.
(8)
  Reflects adjustments for operating, selling and general expenses not directly attributable to Syncrude production.
(9)
  Reflects other E&P assets, such as North America Onshore, Norway and Libya for which netbacks are not provided.
(10)
  Reflects adjustments for general and administrative costs not directly attributed to production.
(11)
  Operating revenues less purchases of crude oil and products.
(12)
  Reflects the gross margin associated with the company's supply, marketing and ethanol businesses, as well as a previously owned lubricants business.
(13)
  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.
(14)
  Reflects operating, selling and general costs associated with the company's supply, marketing, lubricants (previously owned) and ethanol businesses, as well as certain general and administrative costs not directly attributable to refinery production.

Explanatory Note

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

152 2018 ANNUAL REPORT Suncor Energy Inc.

Abbreviations

bbl | barrel
bbls/d | barrels of oil per day
mbbls | thousands of barrels
mbbls/d | thousands of barrels per day
boe | barrels of oil equivalent
boe/d | barrels of oil equivalent per day
mboe | thousands of barrels of oil equivalent
mboe/d | thousands of barrels of oil equivalent per day
m3/d | cubic metres per day
SCO | synthetic crude oil

Metric Conversion

Crude oil, refined products, etc. 1 m3 (cubic metre) = approx. 6.29 barrels

2018 ANNUAL REPORT Suncor Energy Inc. 153

SHARE TRADING INFORMATION
(unaudited)

Common shares are listed on the Toronto Stock Exchange and New York Stock Exchange under the symbol SU.

|  | For the Quarter Ended |  | For the Quarter Ended |
|  | Mar 31 2018 |  | June 30 2018 |  | Sept 30 2018 |  | Dec 31 2018 |  | Mar 31 2017 |  | June 30 2017 |  | Sept 30 2017 |  | Dec 31 2017 |
Share ownership |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Average number outstanding, weighted monthly (thousands)(a) |  | 1 633 816 |  | 1 627 222 |  | 1 611 116 |  | 1 584 484 |  | 1 668 710 |  | 1 667 968 |  | 1 659 027 |  | 1 649 587 |
Share price (dollars) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Toronto Stock Exchange |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
| High |  | 47.69 |  | 54.39 |  | 55.47 |  | 51.78 |  | 44.90 |  | 44.19 |  | 43.88 |  | 46.66 |
| Low |  | 40.49 |  | 43.26 |  | 49.65 |  | 35.53 |  | 39.65 |  | 37.72 |  | 36.09 |  | 41.88 |
| Close |  | 44.49 |  | 53.50 |  | 49.98 |  | 38.13 |  | 40.83 |  | 37.89 |  | 43.73 |  | 46.15 |
New York Stock Exchange – US$ |  |  |  |  |  |  |  |  |  |  |
| High |  | 38.39 |  | 41.82 |  | 42.55 |  | 40.08 |  | 33.47 |  | 32.48 |  | 35.16 |  | 36.92 |
| Low |  | 31.33 |  | 33.47 |  | 37.73 |  | 25.81 |  | 29.39 |  | 28.46 |  | 27.96 |  | 32.83 |
| Close |  | 34.54 |  | 40.68 |  | 38.69 |  | 27.97 |  | 30.75 |  | 29.20 |  | 35.03 |  | 36.72 |
Shares traded (thousands) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Toronto Stock Exchange |  | 196 070 |  | 207 263 |  | 156 451 |  | 282 618 |  | 182 999 |  | 165 718 |  | 155 540 |  | 152 378 |
New York Stock Exchange |  | 215 310 |  | 226 242 |  | 177 746 |  | 296 852 |  | 231 032 |  | 187 434 |  | 192 368 |  | 189 857 |
Per common share information (dollars) |  |  |  |  |  |  |  |  |  |  |
Net earnings (loss) attributable to common shareholders |  | 0.48 |  | 0.60 |  | 1.12 |  | (0.18 | ) | 0.81 |  | 0.26 |  | 0.78 |  | 0.84 |
Dividend per common share |  | 0.36 |  | 0.36 |  | 0.36 |  | 0.36 |  | 0.32 |  | 0.32 |  | 0.32 |  | 0.32 |

(a)
  The company had approximately 6,437 registered holders of record of common shares as at January 31, 2019.

Information for Security Holders Outside Canada

Cash dividends paid to shareholders resident in countries other than Canada (non-Canadian shareholders) are subject to Canadian withholding tax. The statutory rate of Canadian withholding tax on dividends is 25%, subject to reduction under an applicable tax treaty between Canada and another country. For example, under the tax treaty between Canada and the United States, the withholding tax rate is generally reduced to 15% on dividends paid to residents of the United States that are eligible for the benefit of that tax treaty. The Canada Revenue Agency has released forms, applicable after 2012, for non-Canadian shareholders to evidence entitlement to a reduced withholding tax rate under a tax treaty. The agents responsible for withholding tax on dividends will generally need to have a duly completed form from a non-Canadian shareholder on file by a particular dividend record date in order for such agents to withhold tax at an applicable treaty-reduced rate, rather than the full statutory rate of 25%. Non-Canadian shareholders are encouraged to contact their broker (or other applicable agent) regarding the completion and delivery of these forms.

As shareholders are responsible to ensure compliance with Canadian Tax laws and regulations, shareholders are strongly encouraged to seek professional tax and legal counsel with respect to any and all tax matters.

154 2018 ANNUAL REPORT Suncor Energy Inc.

LEADERSHIP AND BOARD MEMBERS AS AT DECEMBER 31, 2018

Leadership
Steve Williams Chief Executive Officer
Eric Axford Executive Vice President and Chief Sustainability Officer
Alister Cowan Executive Vice President and Chief Financial Officer
Paul Gardner Senior Vice President, Human Resources
Mark Little President and Chief Operating Officer
Mike MacSween Executive Vice President, Upstream
Janice Odegaard Senior Vice President, General Counsel and Corporate Secretary
Steve Reynish Executive Vice President, Strategy & Operations Services
Kris Smith Executive Vice President, Downstream

Board of Directors
Michael Wilson Chair of the Board Bragg Creek, Alberta
Steve Williams Chief Executive Officer Suncor Energy Inc. Calgary, Alberta
Patricia Bedient(1)(4) Chair, Audit Committee Sammamish, Washington
Mel Benson(3)(4) Calgary, Alberta
Dominic D'Alessandro(1)(2) Chair, Governance Committee Toronto, Ontario
John Gass(2)(3) Chair, Human Resources and Compensation Committee Palm Coast, Florida
Dennis Houston(3)(4) Spring, Texas
Brian MacDonald(1)(2) Naples, Florida
Maureen McCaw(1)(2) Edmonton, Alberta
Eira Thomas(3)(4) Chair, EH&S and Sustainable Development Committee West Vancouver, British Columbia

(1)
  Audit committee member
(2)
  Governance committee member
(3)
  Human resources and compensation committee member
(4)
  Environment, health, safety and sustainability development committee member

2018 ANNUAL REPORT Suncor Energy Inc. 155

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EXHIBIT 99.1 Suncor Energy Inc. 2018 Annual Report to Shareholders for the period ended December 31, 2018