10-K

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-K

☑ ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF

THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 2020

or

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF

THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from             to                

Commission file number 0-12014

IMPERIAL OIL LIMITED

(Exact name of registrant as specified in its charter)

CANADA (State or other jurisdiction of incorporation or organization)	98-0017682 (I.R.S. Employer Identification No.)
505 QUARRY PARK BOULEVARD S.E., CALGARY, AB, CANADA (Address of principal executive offices)	T2C 5N1 (Postal Code)

1-800-567-3776

(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:

Title of each class	Trading symbol	Name of each exchange on which registered
None		None
Securities registered pursuant to Section 12(g) of the Act: Common Shares (without par value)
(Title of Class)

Indicate by check mark if the registrant is a well-known seasoned issuer (as defined in Rule 405 of the Securities Act).

Yes ✓ No......

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Securities Exchange Act of 1934.    Yes...... No ✓

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ✓ No......

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ✓ No......

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer”, “accelerated filer”, “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Securities Exchange Act of 1934.

Large accelerated filer ✓	Smaller reporting company......
Accelerated filer......	Emerging growth company......
Non-accelerated filer......

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act……

Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ✓

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12 b-2 of the Securities Exchange Act of 1934). Yes..... No ✓

As of the last business day of the 2020 second fiscal quarter, the aggregate market value of the voting stock held by non-affiliates of the registrant was Canadian $4,873,811,386 based upon the reported last sale price of such stock on the Toronto Stock Exchange on that date.

The number of common shares outstanding, as of February 16, 2021, was 734,076,755.

Table of contents		Page
PART I		5
Item 1.	Business	5
	Upstream	6
	Disclosure of reserves	6
	Proved undeveloped reserves	8
	Oil and gas production, production prices and production costs	9
	Drilling and other exploratory and development activities	11
	Present activities	13
	Delivery commitments	14
	Oil and gas properties, wells, operations and acreage	15
	Downstream	17
	Supply	17
	Transportation	17
	Refining	17
	Distribution	17
	Marketing	18
	Chemical	18
	Human capital resources	19
	Competition	19
	Government regulations	20
	The company online	22
Item 1A.	Risk factors	23
Item 1B.	Unresolved staff comments	30
Item 2.	Properties	30
Item 3.	Legal proceedings	30
Item 4.	Mine safety disclosures	30
PART II		31
Item 5.	Market for registrant’s common equity, related stockholder matters and issuer purchases of equity securities	31
Item 6.	Selected financial data	32
Item 7.	Management’s discussion and analysis of financial condition and results of operations	32
Item 7A.	Quantitative and qualitative disclosures about market risk	32
Item 8.	Financial statements and supplementary data	33
Item 9.	Changes in and disagreements with accountants on accounting and financial disclosure	33
Item 9A.	Controls and procedures	33
Item 9B.	Other information	33
PART III		34
Item 10.	Directors, executive officers and corporate governance	34
Item 11.	Executive compensation	34
Item 12.	Security ownership of certain beneficial owners and management and related stockholder matters	35
Item 13.	Certain relationships and related transactions, and director independence	36
Item 14.	Principal accountant fees and services	37
PART IV		38
Item 15.	Exhibits, financial statement schedules	38
Item 16.	Form 10-K summary	39
SIGNATURES		40
Financial section		41
Proxy information section		113

All dollar amounts set forth in this report are in Canadian dollars, except where otherwise indicated.

Note that numbers may not add due to rounding.

The following table sets forth (i) the rates of exchange for the Canadian dollar, expressed in United States (U.S.) dollars, in effect at the end of each of the periods indicated, (ii) the average of exchange rates in effect on the last day of each month during such periods, and (iii) the high and low exchange rates during such periods, in each case based on the noon buying rate in New York City for wire transfers in Canadian dollars as certified for customs purposes by the Federal Reserve Bank of New York.

dollars	2020		2019		2018		2017		2016
Rate at end of period		0.7841		0.7715		0.7329		0.7989		0.7448
Average rate during period		0.7458		0.7558		0.7693		0.7714		0.7559
High		0.7865		0.7715		0.8143		0.8243		0.7972
Low		0.6878		0.7358		0.7326		0.7275		0.6853

On February 16, 2021, the noon buying rate in New York City for wire transfers in Canadian dollars as certified for customs purposes by the Federal Reserve Bank of New York was $0.7878 U.S. = $1.00 Canadian.

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Forward-looking statements

Statements of future events or conditions in this report, including projections, targets, expectations, estimates, and business plans are forward-looking statements. Forward-looking statements can be identified by words such as believe, anticipate, intend, propose, plan, goal, seek, project, predict, target, estimate, expect, strategy, outlook, schedule, future, continue, likely, may, should, will and similar references to future periods. Forward-looking statements in this report include, but are not limited to, references to estimates, development, timing and recovery of reserves; the improvement of recovery through experimental operations; the development drilling program at Cold Lake; the timing, cost, efficiency and production of the Aspen project and expansion project at Cold Lake; the continued evaluation of other oil sands leases and unconventional assets; the company’s focus on key oil sands assets and the most attractive portions of its unconventional portfolio; future activities with respect to Beaufort Sea licences; Kearl 2021 production outlook and growth initiatives; the ability of rail infrastructure to mitigate pipeline capacity constraints; human capital resources strategy and impact; anticipated capital, exploration and operating expenditures, including with respect to environmental protection; expected full year capital expenditures of about $1.2 billion for 2021; continued evaluation of the company’s share purchase program; being well positioned to participate in future investments and reduce commodity price risk; the company’s long-term business outlook including demand, supply and energy mix and pathways to recovery from the impacts of COVID-19; segment growth, competitive strategies and benefits from an integrated business model; Cold Lake 2021 production outlook and focus on base performance in the near-term; continued monitoring of curtailment regulations including with respect to rail shipments and pace of the Aspen project; potential impacts from environmental risks, carbon policy and climate related regulations; the impact of Downstream strategies and competitive position; the benefits to the Chemical business from integration with the Sarnia refinery and relationship with ExxonMobil; market uncertainty and the extent of ongoing effects of the COVID-19 pandemic on economic activity and supply and demand; the intention to continue applying for the Canada Emergency Wage Subsidy; the impact of measures implemented by the company in response to COVID-19; capital structure and financial strength as a competitive advantage, for risk mitigation and meeting funding requirements; earnings sensitivities; risks associated with use of derivative instruments; the impact of any pending litigation, accounting standards and unrecognized tax benefits; standardized measures of discounted future cash flows; and the impact of the Strathcona cogeneration project.

Forward-looking statements are based on the company’s current expectations, estimates, projections and assumptions at the time the statements are made. Actual future financial and operating results, including expectations and assumptions concerning demand growth and energy source, supply and mix; commodity prices, foreign exchange rates and general market conditions; production rates, growth and mix; project plans, timing, costs, technical evaluations and capacities, and the company’s ability to effectively execute on these plans and operate its assets; production life, resource recoveries and reservoir performance; the performance of third-party service providers; applicable laws and government policies, including taxation, climate change, production curtailment and restrictions in response to COVID-19; evolution of COVID-19 and its impacts on Imperial’s ability to operate its assets, including the possible shutdown of facilities due to COVID-19 outbreaks; the company’s ability to effectively execute on its business continuity plans and pandemic response activities; cost savings; the adoption and impact of new facilities or technologies, including on capital efficiency, production and reductions to greenhouse gas emissions intensity; refinery utilization and product sales; financing sources and capital structure; and capital and environmental expenditures could differ materially depending on a number of factors. These factors include global, regional or local changes in supply and demand for oil, natural gas, and petroleum and petrochemical products and resulting price, differential and margin impacts; transportation for accessing markets; political or regulatory events, including changes in law or government policy, applicable royalty rates, tax laws, production curtailment and actions in response to COVID-19; the receipt, in a timely manner, of regulatory and third-party approvals; third-party opposition to operations, projects and infrastructure; environmental risks inherent in oil and gas exploration and production activities; environmental regulation, including climate change and greenhouse gas regulation and changes to such regulation; currency exchange rates; availability and allocation of capital; availability and performance of third-party service providers, including in light of restrictions related to COVID-19; unanticipated technical or operational difficulties; management effectiveness and disaster response preparedness, including business continuity plans in response to COVID-19; commercial negotiations; project management and schedules and timely completion of projects; reservoir analysis and performance; unexpected technological developments; the results of research programs and new technologies, and ability to bring new technologies to commercial scale on a cost-competitive basis; operational hazards and risks; cybersecurity incidents; general economic conditions, including the occurrence and duration of economic recessions; the ability to develop or acquire additional reserves; and other factors

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discussed in Item 1A risk factors and Item 7 management’s discussion and analysis of financial condition and results of operations of this annual report on Form 10-K.

Forward-looking statements are not guarantees of future performance and involve a number of risks and uncertainties, some that are similar to other oil and gas companies and some that are unique to Imperial Oil Limited. Imperial Oil Limited’s actual results may differ materially from those expressed or implied by its forward-looking statements and readers are cautioned not to place undue reliance on them. Imperial Oil Limited undertakes no obligation to update any forward-looking statements contained herein, except as required by applicable law.

The term “project” as used in this report can refer to a variety of different activities and does not necessarily have the same meaning as in any government payment transparency reports.

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PART I

Item 1.     Business

Imperial Oil Limited was incorporated under the laws of Canada in 1880 and was continued under the Canada Business Corporations Act (the “CBCA”) by certificate of continuance dated April 24, 1978. The head and principal office of the company is located at 505 Quarry Park Boulevard S.E., Calgary, Alberta, Canada T2C 5N1. Exxon Mobil Corporation (“ExxonMobil”) owns approximately 69.6 percent of the outstanding shares of the company. In this report, unless the context otherwise indicates, reference to the “company” or “Imperial” includes Imperial Oil Limited and its subsidiaries, and reference to ExxonMobil includes Exxon Mobil Corporation and its affiliates, as appropriate.

The company is one of Canada’s largest integrated oil companies. It is active in all phases of the petroleum industry in Canada, including the exploration for, and production and sale of, crude oil and natural gas. In Canada, it is a major producer of crude oil, the largest petroleum refiner and a leading marketer of petroleum products. It is also a major producer of petrochemicals.

The company’s operations are conducted in three main segments: Upstream, Downstream and Chemical. Upstream operations include the exploration for, and production of, crude oil, natural gas, synthetic oil and bitumen. Downstream operations consist of the transportation and refining of crude oil, blending of refined products and the distribution and marketing of those products. Chemical operations consist of the manufacturing and marketing of various petrochemicals.

Financial information about segments and geographic areas for the company is contained in the “Financial section” of this report under note 3 to the consolidated financial statements: “Business segments”.

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Upstream

Disclosure of reserves

Summary of oil and gas reserves at year-end

The table below summarizes the net proved reserves for the company, as at December 31, 2020, as detailed in the “Supplemental information on oil and gas exploration and production activities” part of the “Financial section”, starting on page 41 of this report.

All of the company’s reported reserves are located in Canada. The company has reported proved reserves based on the average of the first-day-of-the-month price for each month during the last 12-month period ending December 31. Natural gas is converted to an oil-equivalent basis at six million cubic feet per one thousand barrels. No major discovery or other favourable or adverse event has occurred since December 31, 2020 that would cause a significant change in the estimated proved reserves as of that date.

	Liquids (a)		Natural gas		Synthetic oil		Bitumen		Total oil-equivalent basis
	millions of barrels		billions of cubic feet		millions of barrels		millions of barrels		millions of barrels
Net proved reserves:
Developed		7		167		311		76		422
Undeveloped		-		1		133		5		138
Total net proved		7		168		444		81		560

(a) Liquids include crude oil, condensate and natural gas liquids (NGLs). NGL proved reserves are not material and are therefore included under liquids.

The estimation of proved reserve volumes, which is based on the requirement of reasonable certainty, is an ongoing process based on rigorous technical evaluations, commercial and market assessments, detailed analysis of well information such as flow rates and reservoir pressures, and development and production costs, among other factors. Furthermore, the company only records proved reserves for projects which have received significant funding commitments by management made toward the development of the reserves. Although the company is reasonably certain that proved reserves will be produced, the timing and amount recovered can be affected by a number of factors, including completion and optimization of development projects, reservoir performance, regulatory approvals, government policies, consumer preferences, changes in the amount and timing of capital investments, royalty frameworks and significant changes in oil and gas price levels. In addition, proved reserves could be affected by an extended period of low prices which could reduce the level of the company’s capital spending and also impact its partners’ capacity to fund their share of joint projects.

As a result of low prices during 2020, under the U.S. Securities and Exchange Commission definition of proved reserves, certain quantities of bitumen that qualified as proved reserves in prior years did not qualify as proved reserves at year-end 2020. Amounts no longer qualifying as proved reserves include 2.2 billion barrels of bitumen at Kearl and 0.6 billion barrels of bitumen at Cold Lake. Among the factors that could result in portions of these amounts being recognized again as proved reserves at some point in the future are a recovery in the SEC price basis, a further decline in costs, and / or operating efficiencies.

Under the terms of certain contractual arrangements or government royalty regimes, lower prices can also increase proved reserves attributed to Imperial. The company does not expect its operations to be affected by the downward revision of reported proved reserves as disclosed under the U.S. Securities and Exchange Commission (SEC) definition.

6

Technologies used in establishing proved reserves estimates

Imperial’s proved reserves in 2020 were based on estimates generated through the integration of available and appropriate geological, engineering and production data, utilizing well established technologies that have been demonstrated in the field to yield repeatable and consistent results.

Data used in these integrated assessments included information obtained directly from the subsurface via wellbores, such as well logs, reservoir core samples, fluid samples, static and dynamic pressure information, production test data, and surveillance and performance information. The data utilized also included subsurface information obtained through indirect measurements, including seismic data, calibrated with available well control information. The tools used to interpret the data included proprietary seismic processing software, proprietary reservoir modeling and simulation software, and commercially available data analysis packages.

In some circumstances, where appropriate analog reservoirs were available, reservoir parameters from these analogs were used to increase the quality of and confidence in the reserves estimates.

Preparation of reserves estimates

Imperial has a dedicated reserves management group that is separate from the base operating organization. Primary responsibilities of this group include oversight of the reserves estimation process for compliance with the U.S. Securities and Exchange Commission rules and regulations, review of annual changes in reserves estimates and the reporting of Imperial’s proved reserves. This group also maintains the official reserves estimates for Imperial’s proved reserves. In addition, this group provides training to personnel involved in the reserve estimation and reporting processes within Imperial.

The reserves management group maintains a central database containing the company’s official reserves estimates. Appropriate controls, including limitations on database access and update capabilities, are in place to ensure data integrity within this central database. An annual review of the system’s controls is performed by internal audit. Key components of the reserves estimation process include technical evaluations, commercial and market assessments, analysis of well and field performance, and long standing approval guidelines. No changes may be made to reserves estimates in the central database, including the addition of any new initial reserves estimates or subsequent revisions, unless those changes have been thoroughly reviewed and evaluated by duly authorized personnel within the base operating organization. In addition, changes to reserves estimates that exceed certain thresholds require further review and endorsement by the operating organization and the reserves management group, culminating in reviews with and approval by senior management and the company’s board of directors.

The internal qualified reserves evaluator is a professional geoscientist registered in Alberta, Canada and has 22 years of petroleum industry experience, including 16 years of reserves related experience. The position provides leadership to the internal reserves management group and is responsible for filing a reserves report with the Canadian securities regulatory authorities. The company’s internal reserves evaluation staff consists of 31 persons with an average of 11 years of relevant technical experience in evaluating reserves, of whom 26 persons are qualified reserves evaluators for purposes of Canadian securities regulatory requirements. The company’s internal reserves evaluation management team is made up of 17 persons with an average of 11 years of relevant experience in evaluating and managing the evaluation of reserves.

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Proved undeveloped reserves

As at December 31, 2020, approximately 25 percent of the company’s proved reserves were proved undeveloped reflecting volumes of 138 million oil-equivalent barrels. Proved undeveloped reserves are associated with Syncrude and Cold Lake. This compared to 397 million oil-equivalent barrels of proved undeveloped reserves reported at the end of 2019. The decrease of 259 million oil-equivalent barrels of proved undeveloped reserves includes a decrease of 335 million oil-equivalent barrels at Cold Lake and a decrease of 57 million oil-equivalent barrels at the Montney and Duvernay unconventional assets, partially offset by an increase of 133 million oil-equivalent barrels at Syncrude. Conversion of proved undeveloped reserves into proved developed was 6 million oil-equivalent barrels in 2020, associated with Cold Lake and the Montney and Duvernay unconventional assets.

Proved undeveloped reserves that have remained undeveloped for five years or more represent about 4 percent (5 million oil-equivalent barrels) of proved undeveloped reserves and are associated with ongoing development programs at Cold Lake. These undeveloped reserves are planned to be developed in a staged approach to align with operational capacity and efficient capital spending commitment over the life of the asset. The company is reasonably certain that these proved reserves will be produced; however the timing and amount recovered can be affected by a number of factors including completion and optimization of development projects, reservoir performance, regulatory approvals, government policies, consumer preferences, changes in the amount and timing of capital investments, royalty frameworks and significant changes in oil and gas price levels.

One of the company’s requirements to report resources as proved reserves is that management has made significant funding commitments towards the development of the reserves. The company has a disciplined investment strategy and many major fields require a long lead-time in order to be developed. The company made investments of about $209 million during the year to progress the development of proved undeveloped reserves at Cold Lake, the Montney and Duvernay unconventional assets and at Syncrude. These investments represented about 37 percent of the $561 million in total reported Upstream capital and exploration expenditures. Investments made by the company to develop quantities which no longer meet the SEC definition of proved reserves as a result of low prices during 2020 are included in these capital and exploration expenditures.

8

Oil and gas production, production prices and production costs

Reference is made to the portion of the “Financial section” entitled “Management’s discussion and analysis of financial condition and results of operations” on page 45 of this report for a narrative discussion on the material changes.

Average daily production of oil

The company’s average daily oil production by final products sold during the three years ended December 31, 2020 was as follows. All reported production volumes were from Canada.

thousands of barrels per day (a)		2020		2019		2018
Bitumen:
Kearl:	- gross (b)		158		145		146
	- net (c)		155		140		135
Cold Lake:	- gross (b)		132		140		147
	- net (c)		124		114		120
Total bitumen:	- gross (b)		290		285		293
	- net (c)		279		254		255
Synthetic oil (d):	- gross (b)		69		73		62
	- net (c)		68		65		60
Liquids (e):	- gross (b)		13		16		6
	- net (c)		12		14		7
Total:	- gross (b)		372		374		361
	- net (c)		359		333		322

(a) Volume per day metrics are calculated by dividing the volume for the period by the number of calendar days in the period.

(b) Gross production is the company’s share of production (excluding purchases) before deduction of the mineral owners’ or governments’ share or both.

(c) Net production is gross production less the mineral owners’ or governments’ share or both.

(d) The company’s synthetic oil production volumes were from the company’s share of production volumes in the Syncrude joint venture.

(e) Liquids include crude oil, condensate and NGLs.

Average daily production and production available for sale of natural gas

The company’s average daily production and production available for sale of natural gas during the three years ended December 31, 2020 are set forth below. All reported production volumes were from Canada. All gas volumes in this report are calculated at a pressure base of 14.73 pounds per square inch absolute at 60 degrees Fahrenheit. Reference is made to the portion of the “Financial section” entitled “Management’s discussion and analysis of financial condition and results of operations” on page 45 of this report for a narrative discussion on the material changes.

millions of cubic feet per day (a)	2020		2019		2018
Gross production (b) (c)		154		145		129
Net production (c) (d) (e)		150		144		126
Net production available for sale (f)		115		108		94

(a) Volume per day metrics are calculated by dividing the volume for the period by the number of calendar days in the period.

(b) Gross production is the company’s share of production (excluding purchases) before deduction of the mineral owners’ or governments’ share or both.

(c) Production of natural gas includes amounts used for internal consumption with the exception of the amounts reinjected.

(d) Net production is gross production less the mineral owners’ or governments’ share or both.

(e) Net production reported in the above table is consistent with production quantities in the net proved reserves disclosure.

(f) Includes sales of the company’s share of net production and excludes amounts used for internal consumption.

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Total average daily oil-equivalent basis production

The company’s total average daily production expressed in an oil-equivalent basis is set forth below, with natural gas converted to an oil-equivalent basis at six million cubic feet per one thousand barrels.

thousands of barrels per day (a)	2020		2019		2018
Total production oil-equivalent basis:
- gross (b)		398		398		383
- net (c)		384		357		343

(a) Volume per day metrics are calculated by dividing the volume for the period by the number of calendar days in the period.

(b) Gross production is the company’s share of production (excluding purchases) before deduction of the mineral owners’ or governments’ share or both.

(c) Net production is gross production less the mineral owners’ or governments’ share or both.

Average unit sales price

The company’s average unit sales price and average unit production costs by product type for the three years ended December 31, 2020 were as follows.

Canadian dollars per barrel	2020		2019		2018
Bitumen		25.69		50.02		37.56
Synthetic oil		49.76		74.47		70.66
Liquids (a)		27.40		42.91		40.20
Canadian dollars per thousand cubic feet
Natural gas		1.90		2.05		2.43

(a) Liquids include crude oil, condensate and NGLs.

In 2020, Imperial’s average Canadian dollar realizations for bitumen decreased primarily due to a decrease in Western Canada Select. The company’s average Canadian dollar realizations for synthetic crude decreased generally in line with West Texas Intermediate, adjusted for changes in exchange rates and transportation costs.

In 2019, Imperial’s average Canadian dollar realizations for bitumen increased, supported primarily by an increase in Western Canada Select and lower diluent costs. The company’s average Canadian dollar realizations for synthetic crude increased relative to West Texas Intermediate, primarily due to the narrowing of the western Canadian light crude differential.

Average unit production costs

Canadian dollars per barrel	2020		2019		2018
Bitumen		25.73		31.53		29.39
Synthetic oil		45.51		54.44		60.34
Total oil-equivalent basis (a)		28.73		34.82		35.28

(a) Includes liquids, bitumen, synthetic oil and natural gas.

In 2020, bitumen unit production costs were lower, primarily driven by higher Kearl production due to improved reliability and reduced downtime related to the addition of supplemental crushing facilities in 2020, and cost saving activities in response to market conditions.

In 2020, synthetic oil unit production costs were lower, primarily driven by cost saving activities in response to market conditions.

In 2019, bitumen unit production costs were higher, primarily driven by Kearl costs associated with improving reliability and mine performance, and increased mine material movement.

In 2019, synthetic oil unit production costs were lower, primarily driven by higher production due to the absence of the site-wide power disruption at Syncrude in 2018 and lower maintenance costs.

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Drilling and other exploratory and development activities

The company has been involved in the exploration for and development of crude oil and natural gas in Canada only.

Wells drilled

The following table sets forth the net exploratory and development wells that were drilled or participated in by the company during the three years ended December 31, 2020.

wells	2020		2019		2018
Net productive exploratory		-		-		-
Net dry exploratory		-		-		-
Net productive development		29		28		19
Net dry development		-		-		1
Total		29		28		20

In 2020, wells drilled to add productive capacity include 28 development wells at Cold Lake and 1 well associated with the Montney and Duvernay unconventional assets.

In 2019, wells drilled to add productive capacity include 14 development wells at Cold Lake and 14 wells associated with the Montney and Duvernay unconventional assets.

In 2018, wells drilled to add productive capacity include 10 development wells at Cold Lake and 9 wells associated with the Montney and Duvernay unconventional assets.

Wells drilling

At December 31, 2020, the company was participating in the drilling of the following exploratory and development wells within the Montney and Duvernay unconventional assets. All wells were located in Canada.

	2020
wells		Gross	Net
Total		18	9

Exploratory and development activities regarding oil and gas resources

Cold Lake

To maintain production at Cold Lake, capital expenditures for additional production wells and associated facilities are required periodically. In 2020, additional wells were drilled on existing phases. In 2021, a development drilling program is planned within the approved development area to add productive capacity.

The company also conducts experimental pilot operations to improve recovery of bitumen from wells by means of new drilling, production or recovery techniques.

Aspen, Cold Lake expansion and other oil sands activities

The company filed a regulatory application for a new in-situ oil sands project at Aspen in December 2013, using steam-assisted gravity drainage (SAGD) technology to develop the project in three phases producing about 45,000 barrels per day before royalties, per phase. In 2015, the company amended the regulatory application to develop the Aspen project using solvent-assisted, steam-assisted gravity drainage (SA-SAGD) technology. The technology significantly improves capital efficiency and lowers greenhouse gas intensity versus the existing SAGD technologies. The project is proposed to be executed in two phases producing about 75,000 barrels per day before royalties, per phase.

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In October 2018, regulatory approval for the Aspen in-situ project was received from the Alberta Energy Regulator. The first phase of the project was approved by the company’s board and appropriated for $2.6 billion. Construction began late in the fourth quarter of 2018. In March 2019, the company slowed the pace of development given market uncertainty stemming from the Government of Alberta’s temporary mandatory production curtailment regulations and other industry competitiveness challenges. Aspen’s project pace will be continuously evaluated, although major investment remains on hold. Aspen remains an important development project for Imperial.

In March 2016, Imperial filed a regulatory application for an expansion project at Cold Lake to develop the Grand Rapids interval using SA-SAGD technology. The project is proposed to produce 50,000 barrels per day, before royalties. In August 2018, regulatory approval for the expansion project at Cold Lake was received from the Alberta Energy Regulator. The company continues to progress the project with a slower pace.

Work progresses on technical evaluations to support potential Clarke Creek, Corner, Clyden and Chard in-situ development regulatory applications.

The company also has interests in other oil sands leases in the Athabasca region of northern Alberta. Evaluation wells completed on these leased areas established the presence of bitumen. The company continues to evaluate these leases to determine their potential for future development.

Montney and Duvernay

The company has ramped down development drilling in its Montney and Duvernay unconventional assets in the western provinces. Imperial has re-assessed the long-term development plans of its unconventional portfolio in Alberta and no longer plans to further develop a significant portion of this portfolio. The assets that will not be developed are non-core, non-producing, undeveloped assets. This decision is consistent with Imperial’s strategy of focusing its upstream resources and efforts on its key oil sands assets as well as on only the most attractive portions of its unconventional portfolio. The decision resulted in a non-cash, after-tax impairment charge of $1,171 million in 2020, thereby reducing the carrying value of those assets to fair value. The company retains its interest in these resources. Imperial continues to produce from its developed acreage.

Beaufort Sea

In 2007, the company acquired a 50 percent interest in an exploration licence in the Beaufort Sea. As part of the evaluation, a 3-D seismic survey was conducted in 2008 and the company has since carried out data collection programs to support environmental studies and safe exploration drilling operations. In 2010, the company executed an agreement to cross-convey interests with another company to acquire a 25 percent interest in an additional Beaufort Sea exploration licence. As a result of that agreement, the company operates both licences and its interest in the original licence was reduced to 25 percent. In 2013, the company and its joint venture partners filed a project description, initiating the formal regulatory review of the project. In 2016, the Federal Government of Canada declared Arctic waters off limits to new offshore oil and gas licences for five years subject to review at the end of that period. Existing licences were not impacted.

In June 2019, the Federal Government approved selective changes to the Canada Petroleum Resources Act to provide an indefinite prohibition and freeze of the existing licences through the completion of the Beaufort Sea Regional Environmental Assessment (BR-SEA) review. The Federal Government continues to consult with stakeholders as part of the BR-SEA to address regional social, environmental, economic and spill response impacts of natural resource development in the Arctic. The company continues to hold the licences while maintaining community engagement and participation in the BR-SEA process.

Exploratory and development activities regarding oil and gas resources extracted by mining methods

The company continues to evaluate other undeveloped, mineable oil sands acreage in the Athabasca region.

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Present activities

Review of principal ongoing activities

Kearl

Kearl is a joint venture established to recover shallow deposits of oil sands using open-pit mining methods to extract the crude bitumen, which is processed through extraction and froth treatment trains. The company holds a 70.96 percent participating interest in the joint venture and ExxonMobil Canada Properties holds the other 29.04 percent. The product, a blend of bitumen and diluent, is typically shipped to the company’s refineries, Exxon Mobil Corporation refineries and to other third parties. Diluent is natural gas condensate or other light hydrocarbons added to the crude bitumen to facilitate transportation by pipeline and rail.

During 2020, the company’s share of Kearl’s net bitumen production was about 155,000 barrels per day and gross production was about 158,000 barrels per day.

Kearl’s supplemental crushing facilities started operations in late 2019, with ramp-up of all units through early 2020. These facilities have further improved reliability, reduced planned downtime, lowered unit costs and enabled the asset to achieve higher volumes. As disclosed in the company’s 2019 Form 10-K, the original production target in 2020 for Kearl was 240,000 barrels per day (about 170,000 barrels Imperial’s share). As a result of market conditions, the company adjusted planned maintenance and turnaround activity, and revised its full-year guidance for Kearl total gross production to 220,000 barrels per day (about 156,000 barrels Imperial’s share). In 2020, Kearl achieved record annual total gross production of 222,000 barrels per day (158,000 barrels Imperial’s share). Imperial continues to progress initiatives to enable the asset to achieve 255,000 barrels per day of total gross production in 2021 (about 181,000 barrels Imperial’s share).

As a result of low prices during 2020, under the SEC definition of proved reserves, certain quantities of bitumen that qualified as proved reserves in prior years did not qualify as proved reserves at year-end 2020. Amounts no longer qualifying as proved reserves include 2.2 billion barrels of bitumen at Kearl. Among the factors that could result in portions of these amounts being recognized again as proved reserves at some point in the future are a recovery in the SEC price basis, a further decline in costs, and / or operating efficiencies. Under the terms of certain contractual arrangements or government royalty regimes, lower prices can also increase proved reserves attributed to Imperial. The company does not expect its operations to be affected by the downward revision of reported proved reserves as disclosed under the U.S. SEC definition.

Cold Lake

Cold Lake is an in-situ heavy oil bitumen operation. The product, a blend of bitumen and diluent, is typically shipped to the company’s refineries, Exxon Mobil Corporation refineries and to other third parties.

During 2020, net bitumen production at Cold Lake was about 124,000 barrels per day and gross production was about 132,000 barrels per day.

As a result of low prices during 2020, under the SEC definition of proved reserves, certain quantities of bitumen that qualified as proved reserves in prior years did not qualify as proved reserves at year-end 2020. Amounts no longer qualifying as proved reserves include 0.6 billion barrels of bitumen at Cold Lake. Among the factors that could result in portions of these amounts being recognized again as proved reserves at some point in the future are a recovery in the SEC price basis, a further decline in costs, and / or operating efficiencies. Under the terms of certain contractual arrangements or government royalty regimes, lower prices can also increase proved reserves attributed to Imperial. The company does not expect its operations to be affected by the downward revision of reported proved reserves as disclosed under the U.S. SEC definition.

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Syncrude

Syncrude is a joint venture established to recover shallow deposits of oil sands using open-pit mining methods to extract crude bitumen, and then upgrade it to produce a high-quality, light (32 degrees API), sweet, synthetic crude oil. The company holds a 25 percent participating interest in the joint venture. The produced synthetic crude oil is typically shipped to the company’s refineries, Exxon Mobil Corporation refineries and to other third parties.

In 2020, the company’s share of Syncrude’s net production of synthetic crude oil was about 68,000 barrels per day and gross production was about 69,000 barrels per day.

The Province of Alberta, in its capacity as lessor of Kearl, Cold Lake, and Syncrude oil sands leases, is entitled to a royalty on production. Royalties are subject to the oil sands royalty regulations which are based upon a sliding scale determined largely by the price of crude oil.

Delivery commitments

The company has no material commitments to provide a fixed and determinable quantity of oil or gas under existing contracts and agreements.

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Oil and gas properties, wells, operations and acreage

Production wells

The company’s production of liquids, bitumen and natural gas is derived from wells located exclusively in Canada. The total number of wells capable of production, in which the company had interests at December 31, 2020 and December 31, 2019, is set forth in the following table. The statistics in the table are determined in part from information received from other operators.

Year ended December 31, 2020

Year ended December 31, 2019

Crude oil

Natural gas

Crude oil

Natural gas

wells

Gross (a)

Net (b)

Gross (a)

Net (b)

Gross (a)

Net (b)

Gross (a)

Net (b)

Total (c)

4,660

4,610

2,767

898

4,646

4,603

2,801

911

(a) Gross wells are wells in which the company owns a working interest.

(b) Net wells are the sum of the fractional working interest owned by the company in gross wells, rounded to the nearest whole number.

(c) Multiple completion wells are permanently equipped to produce separately from two or more distinctly different geological formations. At year-end 2020, the company had an interest in 12 gross wells with multiple completions (2019 - 12 gross wells).

Land holdings

At December 31, 2020 and December 31, 2019, the company held the following oil and gas rights, and bitumen and synthetic oil leases, all of which are located in Canada, specifically in the western provinces, in the Canada lands and in the Atlantic offshore.

		Developed				Undeveloped				Total
thousands of acres		2020		2019		2020		2019		2020		2019
Western provinces (a):
Liquids and gas	- gross (b)		1,043		1,056		697		771		1,740		1,827
	- net (c)		510		516		388		432		898		948
Bitumen	- gross (b)		197		197		594		601		791		798
	- net (c)		182		182		265		269		447		451
Synthetic oil	- gross (b)		119		118		100		136		219		254
	- net (c)		30		29		25		34		55		63
Canada lands (d):
Liquids and gas	- gross (b)		2		4		1,803		1,831		1,805		1,835
	- net (c)		2		2		495		498		497		500
Atlantic offshore:
Liquids and gas	- gross (b)		65		65		267		267		332		332
	- net (c)		6		6		36		36		42		42
Total (e):	- gross (b)		1,426		1,440		3,461		3,606		4,887		5,046
	- net (c)		730		735		1,209		1,269		1,939		2,004

(a) Western provinces include British Columbia and Alberta.

(b) Gross acres include the interests of others.

(c) Net acres exclude the interests of others.

(d) Canada lands include the Arctic Islands, Beaufort Sea / Mackenzie Delta, and other Northwest Territories and Yukon regions (Yukon - 2019 only).

(e) Certain land holdings are subject to modification under agreements whereby others may earn interests in the company’s holdings by performing certain exploratory work (farm-out) and whereby the company may earn interests in others’ holdings by performing certain exploratory work (farm-in).

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Western provinces

The company’s bitumen leases include about 171,000 net acres of oil sands leases near Cold Lake and an area of about 34,000 net acres at Kearl. The company also has about 68,000 net acres of undeveloped, mineable oil sands acreage in the Athabasca region. In addition, the company has interests in other bitumen oil sands leases in the Athabasca areas totalling about 174,000 net acres, which include about 62,000 net acres of oil sands leases in the Clyden area, about 34,000 net acres of oil sands leases in the Aspen area, about 30,000 net acres of oil sands leases in the Corner area, about 18,000 net acres in the Chard area and about 29,000 net acres in the Clarke Creek area. The 174,000 net acres are suitable for in-situ recovery techniques.

The company’s share of Syncrude joint venture leases covering about 55,000 net acres accounts for the entire synthetic oil acreage. Oil sands leases have an exploration period of 15 years and are continued beyond that point by payment of escalating rentals or by production. The majority of the acreage in Cold Lake, Kearl and Syncrude is continued by production.

The company holds interests in an additional 898,000 net acres of developed and undeveloped land in the western provinces related to crude oil and natural gas, including about 387,000 net acres associated with the company’s unconventional portfolio in Alberta. Imperial has re-assessed the long-term development of its unconventional portfolio and no longer plans to further develop a significant portion of this portfolio.

Crude oil and natural gas leases and licences from the western provinces have exploration periods ranging from two to 15 years and are continued beyond that point by proven production capability.

Canada lands

Land holdings in Canada lands primarily include exploration licence (EL) acreage in the Beaufort Sea of about 252,000 net acres and significant discovery licence (SDL) acreage in the Mackenzie Delta and

Beaufort Sea areas of about 183,000 net acres.

Exploration licences on Canada lands have a finite term. If a significant discovery is made, a SDL may be granted that holds the acreage under the SDL indefinitely, subject to certain conditions.

The company’s net acreage in Canada lands is either continued by production or held through ELs and SDLs.

Atlantic offshore

Exploration licences on Atlantic offshore have a finite term. The Atlantic offshore acreage is continued by production licences or held by SDLs.

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Downstream

Supply

The company supplements its own production of crude oil, condensate and petroleum products with substantial purchases from a number of other sources at negotiated market prices. Purchases are made under both spot and term contracts from domestic and foreign sources, including ExxonMobil.

Transportation

Imperial currently transports the company’s crude oil production and third-party crude oil required to supply refineries by contracted pipelines, common carrier pipelines and rail. To mitigate uncertainty associated with the timing of industry pipeline projects and pipeline capacity constraints, the company has developed rail infrastructure. The Edmonton rail terminal has total capacity to ship up to 210,000 barrels per day of crude oil.

Refining

The company owns and operates three refineries, which process predominantly Canadian crude oil. The company purchases finished products to supplement its refinery production.

The approximate average daily volumes of refinery throughput during the three years ended December 31, 2020, and the daily rated capacities of the refineries as at December 31, 2020, were as follows.

	Refinery throughput (a)						Rated capacities (b)
	Year ended December 31						at December 31
thousands of barrels per day	2020		2019		2018		2020
Strathcona, Alberta		170		183		173		196
Sarnia, Ontario		86		86		109		119
Nanticoke, Ontario		84		84		110		113
Total		340		353		392		428

(a) Refinery throughput is the volume of crude oil and feedstocks that is processed in the refinery atmospheric distillation units.

(b) Rated capacities are based on definite specifications as to types of crude oil and feedstocks that are processed in the refinery atmospheric distillation units, the products to be obtained and the refinery process, adjusted to include an estimated allowance for normal maintenance shutdowns. Accordingly, actual capacities may be higher or lower than rated capacities due to changes in refinery operation and the type of crude oil available for processing.

Refinery throughput averaged 340,000 barrels per day in 2020, compared to 353,000 barrels per day in 2019. Capacity utilization was 80 percent, compared to 83 percent in 2019. Lower throughput was driven by reduced demand due to the COVID-19 pandemic, partially offset by lower refinery turnaround activity and reliability events, including impacts from the Sarnia fractionation tower incident which occurred in April 2019.

Refinery throughput averaged 353,000 barrels per day in 2019, compared to 392,000 barrels per day in 2018. Capacity utilization was 83 percent, compared to 93 percent in 2018. Reduced throughput was mainly due to higher planned turnaround activities and impacts from the Sarnia fractionation tower incident which occurred in April 2019.

Distribution

The company maintains a nationwide distribution system, to move petroleum products to market by pipeline, tanker, rail and road transport. The company owns and operates fuel terminals across the country, as well as natural gas liquids and products pipelines in Alberta, Manitoba and Ontario and has interests in the capital stock of two products pipeline companies.

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Marketing

The company markets petroleum products throughout Canada under well-known brand names, most notably Esso and Mobil, to all types of customers.

Imperial supplies petroleum products to the motoring public through Esso and Mobil-branded sites and independent marketers. At the end of 2020, there were about 2,400 sites operating under a branded wholesaler model whereby Imperial supplies fuel to independent third parties who own and operate sites in alignment with Esso and Mobil brand standards.

Imperial also sells petroleum products, including fuel, asphalt and lubricants, to large industrial and transportation customers, independent marketers, resellers, as well as other refiners. The company serves agriculture, residential heating and commercial markets through branded fuel and lubricant resellers.

The approximate daily volumes of net petroleum products (excluding purchases / sales contracts with the same counterparty) sold during the three years ended December 31, 2020, are set out in the following table.

thousands of barrels per day	2020		2019		2018
Gasolines		215		249		255
Heating, diesel and jet fuels		146		167		183
Heavy fuel oils		20		21		26
Lube oils and other products		40		38		40
Net petroleum product sales		421		475		504

In 2020, lower sales were primarily driven by reduced demand due to the COVID-19 pandemic.

In 2019, lower sales volumes were mainly due to lower refinery throughput.

Chemical

The company’s Chemical operations manufacture and market benzene, aromatic and aliphatic solvents, plasticizer intermediates and polyethylene resin. Its petrochemical and polyethylene manufacturing operations are located in Sarnia, Ontario, adjacent to the company’s petroleum refinery.

The company’s total petrochemical sales volumes during the three years ended December 31, 2020, were as follows.

thousands of tonnes	2020		2019		2018
Total petrochemical sales		749		732		807

In 2020, sales volumes increased primarily due to higher sales of intermediates.

In 2019, sales volumes decreased primarily due to lower aromatics and intermediates sales.

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Human capital resources

Imperial operates in a complex, competitive and changing business environment where decisions and risks play out over time horizons that are often decades in length. This long-term orientation underpins the company’s philosophy on talent development.

Talent development begins with recruiting exceptional candidates and continues with individually planned experiences and training designed to facilitate broad development and a deep understanding of our business across the business cycle. The company’s compensation is market competitive, long-term oriented, and highly differentiated by individual performance. In addition, benefits and workplace programs support the company’s talent management approach, and are designed to attract and retain employees for a long-term career. Overall, this multifaceted approach has resulted in strong employee retention.

Imperial views diversity as an opportunity. The company encourages and respects diversity of thought, ideas, and perspective in its workforce. The company considers diversity though all stages of employment including recruitment, training and development of its employees. Imperial’s goal is to reflect the mix and diversity of the communities where it operates, and it continues to focus on diverse representation at all levels of the organization.

The number of regular employees was about 5,800 at the end of 2020 (2019 - 6,000, 2018 - 5,700). Regular employees are defined as executive, management, professional, technical and wage employees who work full-time or part-time for the company and are covered by the company’s benefit plans and programs.

Competition

The Canadian energy and petrochemical industries are highly competitive. Competition exists in the search for and development of new sources of supply, the construction and operation of crude oil, natural gas and refined products pipelines and facilities and the refining, distribution and marketing of petroleum products and chemicals. The energy and petrochemical industries also compete with other industries in supplying the energy, fuel and chemical needs of both industrial and individual consumers.

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Government regulations

Petroleum, natural gas and oil sands rights

Most of the company’s petroleum, natural gas and oil sands rights were acquired from governments, either federal or provincial. These rights, in the form of leases or licences, are generally acquired for cash or work commitments. A lease or licence entitles the holder to explore for petroleum, natural gas and / or oil sands on the leased lands for a specified period.

In western provinces, the lease holder can produce the petroleum or natural gas discovered on the leased lands and retains the rights based on continued production. Oil sands leases are retained by meeting the minimum level of evaluation, payment of rentals, or by production.

The holder of a licence relating to Canada lands and the Atlantic offshore can apply for a SDL if a discovery is made. If granted, the SDL holds the lands indefinitely subject to certain conditions. The holder may then apply for a production licence in order to produce petroleum or natural gas from the licenced land.

Project approval

Approvals and licences from relevant provincial or federal governmental or regulatory bodies are required for the company to carry out, or make modifications to, its oil and gas activities. The project approval process for major projects can involve, among other things, environmental assessments (including relevant mitigation measures), stakeholder and Indigenous consultation and input regarding project concerns, and public hearings. Approval may be subject to various conditions and commitments arising through these processes.

In 2019, the Canadian government implemented a new environmental assessment framework in Canada under the Impact Assessment Act, which may impact the manner in which large energy projects are approved. Changes from the previous environmental assessment legislation include broader consideration for social, health, and gender-based impacts, the impact on Canada’s climate change commitments, reliance on strategic and regional assessments and adjusted regulatory review timelines.

Environmental protection

The company regards protecting the environment in connection with its various operations as a priority. The company is subject to extensive environmental regulations in Canada that apply to all phases of exploration, development, operation, and final closure. These requirements cover the management and monitoring of potential environmental impacts during active operations, including practices for land disturbance, wildlife protection, specifications for equipment operation and material storage and limitations on discharges to the environment. It also includes conducting environmental surveys and collecting continuous operational measurements and sampling to confirm that environmental practices are adequately protecting the environment. These regulations also specify the actions and requirements for final reclamation, abandonment and closure of facilities. The company works in cooperation with government agencies, industry associations and communities to address existing, and to anticipate potential, environmental protection issues. The company also maintains extensive operating procedures, processes and emergency response plans to address environmental risks at its operations.

As discussed in Item 1A. Risk factors in this report, compliance with existing and potential future government regulations, including environmental regulations, may have material effects on the capital expenditures, earnings, and competitive position of the company. Imperial takes new and ongoing measures throughout its operations each year to prevent and minimize the impact of its operations on air, land and water. These include significant investments in refining infrastructure and technology to manufacture clean fuels, continued evaluation and implementation of new technologies to reduce greenhouse gas emissions, adherence to federal and provincial greenhouse gas emissions reduction and reporting programs, enhanced water and land management, and expenditures for asset retirement obligations. In the past five years, the company has made capital and operating expenditures of about $3.3 billion on environmental protection and facilities. In 2020, the company’s environmental capital and operating expenditures totalled approximately $0.6 billion, which was spent primarily on activities to protect the air, land and water, including remediation projects. Capital and operating expenditures relating to environmental protection are expected to be about $1.1 billion in 2021.

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Crude oil

Production

The maximum allowable gross production of crude oil from wells in Canada is subject to limitations by various regulatory authorities on the basis of engineering and conservation principles.

Additionally, in December 2018, the Government of Alberta introduced temporary mandatory production curtailment regulations, which took effect on January 1, 2019. These regulations enable the government to impose production limits on large producers in Alberta. Mandatory production curtailments were eliminated effective December 2020, but the regulatory authority to impose curtailments remains in place. The duration of these regulations is uncertain.

Exports

Export contracts of more than one year for light crude oil and petroleum products and two years for heavy crude oil (including bitumen) require the prior approval of the Canada Energy Regulator (CER) and the Government of Canada. Export contracts of less than one year for light crude oil and petroleum products and two years for heavy crude oil (including bitumen) require an order from the CER.

Natural gas

Production

The maximum allowable gross production of natural gas from wells in Canada is subject to limitations by various regulatory authorities. These limitations are to ensure oil recovery is not adversely impacted by accelerated gas production practices. These limitations do not impact gas reserves, only the timing of production of the reserves and did not have a significant impact on Imperial’s 2020 gas production rates.

Exports

The Government of Canada has the authority to regulate the export price for natural gas. Exports of natural gas from Canada require approval by the CER and the Government of Canada. The Government of Canada allows the export of natural gas by CER order without volume limitation for terms not exceeding 24 months.

Royalties

The Government of Canada and the provinces in which the company produces crude oil and natural gas, impose royalties on production from lands where they own the mineral rights. Some producing provinces also receive revenue by imposing taxes on production from lands where they do not own the mineral rights.

Different royalties are imposed by the Government of Canada and each of the producing provinces. Royalties imposed on crude oil, natural gas and natural gas liquids vary depending on a number of parameters, including well production volumes, selling prices and recovery methods. For information with respect to royalties for Kearl, Cold Lake and Syncrude, see “Upstream” section entitled “Present activities” under Item 1 on page 13.

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Investment Canada Act

The Investment Canada Act requires Government of Canada approval, in certain cases, of the acquisition of control of a Canadian business by an entity that is not controlled by Canadians. The acquisition of natural resource properties may, in certain circumstances, be considered a transaction that constitutes an acquisition of control of a Canadian business requiring Government of Canada approval.

The Act also requires notification of the establishment of new unrelated businesses in Canada by entities not controlled by Canadians, but does not require Government of Canada approval except when the new business is related to Canada’s cultural heritage or national identity. The Government of Canada is also authorized to take any measures that it considers advisable to protect national security, including the outright prohibition of a foreign investment in Canada.

By virtue of the majority stock ownership of the company by ExxonMobil, the company is considered to be an entity which is not controlled by Canadians.

Competition Act

The Competition Bureau seeks to ensure that Canadian businesses and consumers prosper in a competitive and innovative marketplace. The Competition Bureau is responsible for the administration and enforcement of the Competition Act (the Act). A merger transaction, whether or not notifiable, is subject to examination by the Commissioner of the Competition Bureau to determine whether the merger will have, or is likely to have, the effect of preventing or lessening substantially competition in a definable market. The assessment of the competitive effects of a merger is made with reference to the factors identified under the Act.

An Advance Ruling Certificate (ARC) may be issued by the Commissioner to a party or parties to a proposed merger transaction who want to be assured that the transaction will not give rise to proceedings under section 92 of the Act. Section 102 of the Act provides that an ARC may be issued when the Commissioner is satisfied that there would not be sufficient grounds on which to apply to the Competition Tribunal for an order against a proposed merger. The issuance of an ARC is discretionary. An ARC cannot be issued for a transaction that has been completed, nor does an ARC ensure approval of the transaction by any agency other than the Competition Bureau.

The company online

The company’s website www.imperialoil.ca contains a variety of corporate and investor information, including the company’s annual report on Form 10-K, quarterly reports on Form 10-Q and current reports on Form 8-K and amendments to these reports. These reports are made available as soon as reasonably practicable after they are filed or furnished to the SEC. The SEC’s website, www.sec.gov, contains reports, proxy and information statements, interactive data files, and other information regarding issuers that are submitted and posted electronically with the SEC.

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Item 1A. Risk factors

Imperial’s financial and operating results are subject to a variety of risks inherent in oil, gas and petrochemical businesses. Many of these risk factors are not within Imperial’s control and could adversely affect Imperial’s business, financial and operating results, or financial position. These risk factors include:

Supply and demand

The oil, gas, fuels and petrochemical businesses are fundamentally commodity businesses. This means the company’s operations and earnings may be significantly affected by changes in oil, natural gas and petrochemical prices, and by changes in margins on refined products and petrochemicals. Crude oil, natural gas, petrochemical and petroleum product prices and margins depend on local, regional, and global events or conditions that affect supply and demand for the relevant commodity. Commodity prices have been volatile, and the company expects that volatility to continue. Any material decline in crude oil prices could have a material adverse effect on Imperial’s Upstream operations, financial position, proved reserves and the amount spent to develop reserves. On the other hand, a material increase in crude oil prices could have a material adverse effect on Imperial’s Downstream margins, depending on the market conditions for refined products.

The demand for energy and petrochemicals is generally linked closely with broad-based economic activities and levels of prosperity. The occurrence of recessions or other periods of low or negative economic growth will typically have a direct adverse impact on the company’s results. Other factors that may affect the demand for crude oil, gas, fuels and petrochemicals, and therefore could impact Imperial’s results include technological improvements in energy efficiency; seasonal weather patterns, which affect the demand for our products, including lower demand for gasoline, impacting Downstream results in the winter; increased competitiveness of, or government policy support for, alternative energy sources; new product quality regulations; technological changes or consumer preferences that alter fuel choices, such as technological advances in energy storage that make wind and solar more competitive for power generation; changes in consumer preferences for the company’s products, including consumer demand for alternative fueled or electric transportation or alternatives to plastic products; broad-based changes in personal income levels; and security or public health issues and responses such as epidemics and pandemics.

Commodity prices and margins also vary depending on a number of factors affecting supply. For example, increased supply from the development of new oil and gas supply sources and technologies to enhance recovery from existing sources tend to reduce commodity prices to the extent such supply increases are not offset by commensurate growth in demand. Similarly, increases in industry refining or petrochemical manufacturing capacity relative to demand tend to reduce margins on affected products. Crude oil, gas and petrochemical supply levels can also be affected by factors that reduce available supplies, such as adherence by member countries or others to Organization of the Petroleum Exporting Countries (OPEC) production quotas, government policies that restrict oil and gas production or increase associated costs, including the Government of Alberta curtailment regulations, the occurrence of wars, hostile actions, natural disasters, disruptions in competitors’ operations, or unexpected pipeline or rail constraints that may disrupt supplies. Technological change can also alter the relative costs for competitors to find, produce, and refine oil and gas and to manufacture petrochemicals.

The market price for western Canadian heavy crude oil is typically lower than light and medium grades of oil, principally due to the higher transportation and refining costs. Western Canadian crude oil may also be subject to limits on transportation capacity to markets. Future crude price differentials between western Canadian crude oil relative to prices in the U.S. Gulf Coast are uncertain and changes in the heavy or light crude oil differentials could have a material adverse effect on the company’s business. Increased differentials in 2018 also led the Government of Alberta to enact temporary mandatory production curtailment regulations in 2019. These regulations enable the government to impose production limits on large producers in Alberta such as Imperial. Although mandatory production curtailment decreased throughout 2019 and 2020, and was eliminated in December 2020, the regulatory authority to impose curtailments remains in place and there is the potential for curtailment to be re-imposed and increased. The duration of these regulations is uncertain, and could have an adverse effect on the company’s business. A significant portion of the company’s production is bitumen, which is blended with diluent for transportation and marketability of heavy crude oil. Increases to diluent prices, relative to heavy crude oil prices, could also have an adverse effect on the company’s business.

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Government and political factors

Imperial’s results can be adversely impacted by political, legal or regulatory developments affecting operations and markets. Changes in government policy or regulations, changes in law or interpretation of settled law, third-party opposition to company or infrastructure projects, and duration of regulatory reviews could impact Imperial’s existing operations and planned projects. This includes actions by regulators or other political actors to delay or deny necessary licenses and permits or restrict the operation of third-party infrastructure that the company relies on, such as pipelines to transport the company’s upstream production to market or that supply feedstock to the company’s refineries. Additionally, changes in environmental regulations, assessment processes or other laws and increasing and expanding stakeholder consultation (including Indigenous stakeholders), may increase the cost of compliance or reduce or delay available business opportunities and adversely impact the company’s results.

Other government and political factors that could adversely affect the company’s financial results include increases in taxes or government royalty rates (including retroactive claims) and changes in trade policies and agreements. Further, the adoption of regulations mandating efficiency standards, and the use of alternative fuels or uncompetitive fuel components could affect the company’s operations. Many governments are providing tax advantages and other subsidies to support alternative energy sources or are mandating the use of specific fuels or technologies. Governments and others are also promoting research into new technologies to reduce the cost and increase the scalability of alternative energy sources, and the success of these initiatives may decrease demand for the company’s products.

Governments may establish regulations with respect to the control of the company’s production, such as when increased price differentials in 2018 led the Government of Alberta to impose temporary mandatory production curtailment regulations effective 2019, as discussed in the Supply and demand section above. Government intervention in free markets may introduce unintended consequences such as market volatility and uncertainty, misallocation of resources, and erosion of investor confidence.

Environmental risks

All phases of the Upstream, Downstream and Chemical businesses are subject to environmental regulation pursuant to a variety of Canadian federal, provincial, territorial and municipal laws and regulations, as well as international conventions (collectively, “environmental legislation”).

Environmental legislation imposes, among other things, restrictions, liabilities and obligations in connection with the generation, handling, storage, transportation, treatment and disposal of hazardous substances and waste and in connection with spills, releases and emissions of various substances into the environment. As well, environmental regulations are imposed on the qualities and compositions of the products sold and imported. Changes to these requirements could adversely affect the company’s results by impacting commodity prices, increasing costs and reducing revenues.

Environmental legislation also requires that wells, facility sites and other properties associated with the company’s operations be operated, maintained, monitored, abandoned and reclaimed to the satisfaction of applicable regulatory authorities. This includes the requirement for specific approvals for many areas of interaction with the environment, such as land use, air quality, water use, biodiversity protection and waste, including mine tailings management. The failure to operate as anticipated and adhere to conditions, the delay or denial of approvals and changes to conditions or regulations could impact the company’s ability to operate its projects and facilities and adversely affect the company’s results.

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The implementation of, and compliance with, policies and regulations related to air, water and land, such as Alberta’s Lower Athabasca Regional Plan and Wetland Policy applicable to the company’s oil sands assets, could restrict development in current and future areas of operation. The company also depends on water obtained under licences for withdrawal, storage, reuse and discharge in both its Upstream and Downstream businesses, including future projects and expansions. Water use may be limited by regulatory requirements, seasonal fluctuations, competing demands, environmental sensitivities, increasingly stringent water management standards, and changes to conditions or availability of licences, which may restrict and adversely affect the company’s operations. Additionally, a number of air quality regulations and frameworks are being developed at the federal and provincial levels, and when implemented could impact existing and planned projects through increased capital and operating expenses including retrofits to existing equipment, and could adversely impact the company’s operations and financial results.

Federal and provincial legislation aimed at protecting sensitive, threatened or endangered wildlife, such as woodland caribou and species of migratory birds, may also increase restoration and offset costs and impact the company’s projects. If it is determined that such wildlife and their habitat are not sufficiently protected, governments or other parties may take actions to limit the pace or ability to develop in areas of Imperial’s current and future projects.

The company’s mining operations are subject to tailings management regulations that establish approval, monitoring, reporting and performance criteria for tailings ponds and management plans. Further, the absence or evolving nature of policies and regulations for the timing and closure of tailings ponds, including the approved technologies and methods for closure (such as the use of end pit lakes and water capped tailings), and dam safety directives, regulations, guides and abandonment requirements could have a material impact on conditions for approvals and ultimate mine closure costs. Additionally, successful management and closure requires the release of water to the environment, and although an Alberta water release policy and federal oil sands effluent regulations are being developed, the timing and impact of these regulations is uncertain and the absence of effective regulation could negatively impact the company’s operations and financial results.

In addition, certain types of operations, including exploration and development projects and significant changes to certain existing projects, may require the submission and approval of environmental impact assessments. In 2019, the Government of Canada implemented a new environmental assessment framework under the Impact Assessment Act, which expands assessment considerations beyond the environment to include social, health, economic, and gender-based impacts and the impact on Canada’s climate change commitments. It also includes a reliance on strategic and regional assessments and adjusted regulatory review timelines. The impact of this legislation is not fully apparent, but it may impact the cost, manner, duration and ability to advance large energy projects.

Compliance with environmental legislation can require significant expenditures and failure to comply with environmental legislation may result in the cessation of operations, imposition of fines and penalties and liability for clean-up costs and damages.

The costs of complying with environmental legislation in the future could have a material adverse effect on the company’s financial condition or results of operations. The company anticipates that changes in environmental legislation may require, among other things, reductions in emissions from its operations to the air and water and may result in increased capital expenditures. Changes in environmental legislation (including, but not limited to, application of regulations related to air, water, land, biodiversity and waste, including mine tailings) may increase the cost of compliance or reduce or delay available business opportunities. Future changes in environmental legislation could occur and result in stricter standards and enforcement, larger fines and liability, and increased capital expenditures and operating costs, which could have a material adverse effect on the company’s financial condition or results of operations.

There are operational risks inherent in oil and gas exploration and production activities, as well as the potential to incur substantial financial liabilities, if the company does not manage those risks effectively. The ability to insure such risks is limited by the capacity of the applicable insurance markets, which may not be sufficient to cover the likely cost of a major adverse operating event. Accordingly, the company’s primary focus is on prevention, including through its rigorous operations integrity management system. The company’s future results will depend on the continued effectiveness of these efforts.

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Climate change and greenhouse gas restrictions

Driven by concern over the risks of climate change, a number of provinces and the Government of Canada have adopted, are considering the adoption of, or have revised, regulatory frameworks to reduce greenhouse gas emissions or production and use of oil and gas. These include adoption of carbon emissions pricing, cap and trade regimes, carbon taxes, emissions limits, increased efficiency standards, low carbon fuel standards and incentives or mandates for renewable energy.

The Government of Canada has adopted the Paris Agreement on climate change, and set a goal to reduce greenhouse gas emissions economy-wide by 30 percent below 2005 levels by 2030. To implement these goals, the Government of Canada adopted the Greenhouse Gas Pollution Pricing Act (GGPPA), which sets a federal backstop carbon price Canada-wide through a carbon levy applied to fossil fuels ($20 per tonne starting in 2019 and increasing by $10 per tonne annually to $50 per tonne in 2022), and an output-based pricing system for large industrial emitters. Under the GGPPA, provinces are required to either adopt the GGPPA, or obtain equivalency by adopting a price-based system or cap and trade system. In December 2020, the Government of Canada proposed to increase the carbon price by $15 per year starting in 2023, rising to $170 per tonne in 2030. Further, in 2020 the Government of Canada proposed legislation to formalize Canada’s target to achieve net-zero emissions by 2050 and establish interim emissions reductions targets at five year intervals.

The Government of Alberta has obtained federal equivalency for its Technology Innovation and Emissions Reduction Regulation (TIER) that came into effect in 2020 and applies to facilities with CO2 emissions in excess of 100,000 tonnes per year. TIER is designed to reduce emissions by putting a price on 10 percent of a facility’s emissions in 2020, increasing by 1 percent per year, with pricing for 2020 set at $30 per tonne. Further, the Alberta Oil Sands Emissions Limit Act sets a limit of 100 megatonnes of CO2 per year of emissions in the oil sands sector, but oil sands emissions remain below the limit and it is not yet possible to predict the impact of this act on the company’s future oil sands operations in Alberta. With respect to other provinces, with Ontario cancelling the cap and trade program in 2018, the company’s operations in Ontario are subject to the federal carbon levy and output based pricing system. British Columbia has carbon pricing in place for all emissions, with pricing currently at $40 per tonne and rising by $5 per tonne in April, 2021. Increases in carbon pricing could adversely impact the company’s operations and financial results unless the company can adapt its operations.

There are also various low carbon fuel standards being developed or applicable to the company’s products. The Government of Canada is progressing draft regulations for the Clean Fuel Standard, which will require the reduction in carbon intensity of liquid fuels supplied in Canada starting in 2022. The standard is expected to build upon the existing federal renewable fuels regulations that require fuel producers and importers to have a specified amount of renewable fuel in gasoline and diesel. Similarly, British Columbia introduced a Low Carbon Fuel Standard in 2013, which increased to a 10 percent carbon intensity reduction requirement by 2020. The British Columbia government has announced a draft policy to reduce the carbon intensity of fuels by a further 20 percent by 2030. Compliance can be achieved by either blending renewable fuels with low carbon intensity or by purchasing credits.

In 2019, the Government of Canada enacted the Impact Assessment Act, which links environmental assessment approvals to climate change-related goals, and has also discussed a goal of establishing legally-binding policies for being carbon-neutral by 2050. Changes and policies related to this act could adversely impact the company’s ability to progress new oil sands projects.

International accords and underlying regional and national regulations covering climate change and greenhouse gas emissions continue to evolve with uncertain timing and outcome, making it difficult to predict their business impact. Such laws and policies could make Imperial’s products more expensive and less competitive, reduce or delay available business opportunities, reduce demand for hydrocarbons, and shift hydrocarbon demand toward lower greenhouse gas emission energy sources. Current and pending greenhouse gas regulations or policies may also increase compliance and abatement costs including taxes and levies, increase abandonment and reclamation obligations, lengthen project evaluation and implementation times, impact reserves evaluations and affect operations. Increased costs may not be recoverable in the market place, could negatively affect our returns and could reduce the global competitiveness of the company’s crude oil, natural gas and refined products. Governments may also impose restrictions on production of oil and gas to the extent they view such measures as a viable approach for pursuing national and global energy and climate policies. Concern over the risks of climate change may lead governments to make laws applicable to the energy industry progressively more stringent over time.

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Political and other actors and their agents are also increasingly seeking to advance climate change objectives indirectly, such as by seeking to reduce the availability of or increase the cost for financing and investment in the oil and gas sector and taking actions intended to promote changes in business strategy for oil and gas companies.

Currency

Prices for commodities produced by the company are commonly benchmarked in U.S. dollars. The majority of Imperial’s sales and purchases are related to these industry U.S. dollar benchmarks. As the company records and reports its financial results in Canadian dollars, to the extent that the value of the Canadian dollar strengthens, the company’s reported earnings will be negatively affected. The company does not currently make use of derivative instruments to offset exposures associated with foreign currency.

Other business risks

Imperial is reliant on a number of key chemicals, catalysts and third-party service providers, including input and output commodity transportation (pipelines, rail, trucking, marine) and utilities providing services, including electricity and water, to various company operations. The lack of availability, capacity or proximity with respect to pipeline facilities and railcars could negatively impact Imperial’s ability to produce at capacity levels. Transportation disruptions, including those caused by events unrelated to the company’s operations, could adversely affect the company’s price realizations, refining operations and sales volumes. This includes outages of key third-party infrastructure, such as pipelines servicing the company’s oil sands assets or pipelines supplying feedstock to its refineries, which could impact the company’s ability to operate its assets or limit the ability to deliver production and products to market. A third-party utilities outage could have an adverse impact on the company’s operations and ability to produce.

The company also enters into contractual relationships with suppliers, partners and other counterparties to procure and sell goods and services, and the company’s operations, market position and financial condition may be adversely impacted if these counterparties do not fulfil their obligations. Imperial may also be adversely affected by the outcome of litigation resulting from its operations or by government enforcement proceedings alleging non-compliance with applicable laws or regulations. Litigation is subject to uncertainty and success is not guaranteed, and the company may incur significant expenses and devote significant resources in defending litigation.

Management effectiveness

In addition to external economic and political factors, Imperial’s future business results also depend on the company’s ability to manage successfully those factors that are at least in part within its control. The extent to which Imperial manages these factors will impact its performance relative to competition. For projects in which the company is not the operator, Imperial depends on the management effectiveness of one or more co-venturers whom the company does not control.

Project management

The nature of the company’s Upstream, Downstream and Chemical businesses depend on complex, long-term, and capital intensive projects that require a high degree of project management expertise to maximize efficiency. This includes development, engineering, construction, commissioning and ongoing operational activities and expertise. The company’s results are affected by its ability to develop and operate projects and facilities as planned and by events or conditions that affect the advancement, operation, cost or results of such projects or facilities. These risks include the company’s ability to obtain the necessary environmental and other regulatory approvals; changes in regulations; the ability to model and optimize reservoir performance; changes in resources and operating costs including the availability and cost of materials, equipment and qualified personnel; the impact of general economic, business and market conditions; and the company’s ability to respond effectively to unforeseen technical difficulties that could delay project start-up or cause unscheduled downtime.

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Operational efficiency

An important component of Imperial’s competitive performance, especially given the commodity based nature of Imperial’s business, is the ability to operate efficiently, including the company’s ability to manage expenses and improve production yields on an ongoing basis. This requires continuous management focus, including technological improvements, cost control, productivity enhancements and regular reappraisal of the company’s asset portfolio. The company’s operations and results also depend on key personnel and subject matter expertise, the recruitment, development and retention of high caliber employees, and the availability of skilled labour.

Research and development and technical change

Imperial relies upon the research and development organizations of the company and ExxonMobil, with whom the company conducts shared research. Innovation and technology are important to maintain the company’s competitive position, especially in light of the technological nature of Imperial’s business and the need for continuous efficiency improvement. The company’s research and development organizations must be able to adapt to a changing market and policy environment, including developing technologies to help reduce greenhouse gas emissions intensity. To remain competitive, the company must also continuously adapt and capture the benefits of new technologies including growing the company’s capabilities to utilize digital data technologies to gain new business insights. There are risks associated with projects that rely on new technology, including that the results of implementing the new technology may differ from simulated, piloted or expected results. The failure to develop and adopt new technology may have an adverse impact on the company’s operations, ability to meet regulatory requirements and operational commitments and targets (including environmental sustainability and reduction of greenhouse gas emissions), and financial results.

Safety, business controls and environmental risk management

The scope and nature of the company’s operations present a variety of significant hazards and risks, including operational hazards and risks such as explosions, fires, pipeline ruptures and crude oil spills. Imperial’s operations are also subject to the additional hazards of pollution, releases of toxic gas and environmental hazards and risks, such as severe weather, and geological events. The company’s results depend on management’s ability to minimize these inherent risks, to effectively control business activities and to minimize the potential for human error. Imperial applies rigorous management systems, including a combined program of effective operations integrity management, ongoing upgrades, key equipment replacements, and comprehensive inspection and surveillance. The company also maintains a disciplined framework of internal controls and applies a controls management system for monitoring compliance with this framework. The company’s upstream and downstream operations may experience loss of production, slowdowns or shutdowns and increased costs due to the failure of interdependent systems, and substantial liabilities and other adverse impacts could result if the company’s management systems and controls do not function as intended.

Cybersecurity

Imperial is regularly subject to attempted cybersecurity disruptions from a variety of threat actors, including state-sponsored actors. Imperial’s defensive preparedness includes multi-layered technological capabilities for prevention and detection of cybersecurity disruptions; non-technological measures such as threat information sharing with governmental and industry groups; internal training and awareness campaigns including routine testing of employee awareness via mock threats; and an emphasis on resiliency including business response and recovery.

If the measures the company is taking to protect against cybersecurity disruptions prove to be insufficient or if the company’s proprietary data is otherwise not protected, the company as well as its customers, employees or third parties could be adversely affected. Cybersecurity disruptions could cause physical harm to people or the environment; damage or destroy assets; compromise business systems; result in proprietary information being altered, lost or stolen; result in employee, customer or third-party information being compromised; or otherwise disrupt the company’s business operations. Imperial could incur significant costs to remedy the effects of a major cybersecurity disruption, in addition to costs in connection with resulting regulatory actions, litigation or reputational harm.

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Preparedness

The company’s operations may be disrupted by severe weather events, natural disasters, human error, and similar events. Imperial’s ability to mitigate the adverse impacts of these events depends in part upon the effectiveness of its rigorous disaster preparedness and response planning, as well as business continuity planning.

COVID-19

As a result of COVID-19, governments in many countries, including Canada, have mandated quarantines, closures, stay-at-home orders and travel restrictions that have had a significant impact on demand for the company’s products. While these effects are expected to be temporary, the resurgence of cases of COVID-19 has led to a highly uncertain business environment. Although there has been some movement toward pre-pandemic activity levels, the duration of the business disruptions internationally and related financial impact cannot be reasonably estimated at this time and continued or new restrictions could continue to impact the demand for petroleum products.

Imperial’s future business results, including cash flows and financing needs, will be affected by the extent and duration of these conditions and the effectiveness of responsive actions that the company and others take, including our actions to reduce capital and operating expenses and government actions to address the COVID-19 pandemic. The impact of COVID-19 could also have an effect on the financial markets and result in an increase to the cost of capital due to risk. The company’s results will also be affected by any resulting negative impacts on national and global economies and markets from a prolonged decrease of economic activity.

The company has had positive COVID-19 cases, but these cases have not had a material impact on its operations or business. The company has initiated numerous emergency response and business continuity plans, and a substantial portion of the company’s workforce has implemented remote working arrangements. However, if the company’s mitigation and response efforts prove insufficient, then large outbreaks of epidemics, pandemics or other health crises such as COVID-19 at operating sites, particularly in remote locations and where work camps are utilized, could materially impact the company’s personnel and its operations, reducing productivity and increasing costs.

The company could also be impacted by disruption to supply chains, methods of distribution and key third-party service providers, which could impact the ability to produce or sell its products, as well as increase the costs associated with its operations and decrease revenues and margins.

The COVID-19 pandemic continues to evolve, with changing case numbers and the potential for additional public health restrictions. Although vaccines are being developed and approved for use, their availability and effectiveness is uncertain, especially in light of the emergence of new mutations of the virus. The impact of the pandemic remains difficult to predict.

Reputation

Imperial’s reputation is an important corporate asset. An operating incident, significant cybersecurity disruption, change in consumer views concerning the company’s products, or other adverse events, such as those described in Item 1A, may have a negative impact on Imperial’s reputation, which in turn could make it more difficult for the company to compete successfully for new opportunities or obtain necessary regulatory approvals, or could reduce consumer demand for the company’s branded products. Imperial’s reputation may also be harmed by events which negatively affect the image of the industry as a whole, including public and investor perception of Alberta oil sands in relation to greenhouse gas emissions and environmental impact.

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Reserves

The company’s future production and cash flows from bitumen, synthetic oil, liquids and natural gas reserves are highly dependent upon the company’s success in exploiting its current reserves. To maintain production and cash flows, the company must continue to replace produced reserves as they are depleted, which can be accomplished through exploration discovery of new resources, appraisal and investments in developing discovered resources, or acquisition of reserves. To the extent cash flows from operations are insufficient to fund capital expenditures and external sources of capital become limited or unavailable, the company’s ability to make the necessary capital investments to maintain and grow oil and natural gas reserves will be adversely impacted. In addition, the company may be unable to find and develop or acquire additional reserves to replace oil and natural gas production at acceptable costs.

Estimates of economically recoverable oil and natural gas reserves and future net cash flows involve many uncertainties, including factors beyond the company’s control. Key factors with uncertainty include: geological and engineering estimates, including that additional information obtained through seismic and drilling programs, reservoir analysis and production and operational history may result in revisions to reserves; the assumed effects of regulation or changes to regulation by government agencies, including royalty frameworks and environmental regulations (such as the regulation of greenhouse gas emissions, which could impose significant compliance costs on the company, require new technology, or impact the economic viability of certain projects); future commodity prices, where low commodity prices may affect reserves development; abandonment and reclamation costs, including reclamation and tailings requirements for mining operations; and operating costs. Actual production, revenues, taxes and royalties, development costs, abandonment and reclamation costs, and operating expenditures with respect to reserves will likely vary from such estimates, and such variances could be material.

Item 1B. Unresolved staff comments

None.

Item 2. Properties

Reference is made to Item 1 above.

Item 3. Legal proceedings

Imperial has elected to use a $1 million threshold for disclosing environmental proceedings.

Item 4. Mine safety disclosures

Not applicable.    

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PART II

Item 5. Market for registrant’s common equity, related stockholder matters and issuer purchases of equity securities

Market information

The company’s common shares are listed and trade on the Toronto Stock Exchange in Canada, and have unlisted trading privileges and trade on the NYSE American LLC in the United States. The symbol for the company’s common shares on these exchanges is IMO.

As of February 16, 2021 there were 10,094 holders of record of common shares of the company.

Information for security holders outside Canada

Cash dividends paid to shareholders resident in countries with which Canada has an income tax convention are usually subject to a Canadian non-resident withholding tax of 15 percent, but may vary from one tax convention to another.

The withholding tax is reduced to 5 percent on dividends paid to a corporation resident in the U.S. that owns at least 10 percent of the voting shares of the company.

The company is a qualified foreign corporation for purposes of the reduced U.S. capital gains tax rates, which are applicable to dividends paid by U.S. domestic corporations and qualified foreign corporations.

There is no Canadian tax on gains from selling shares or debt instruments owned by non-residents not carrying on business in Canada, as long as the shareholder does not, in any given 60 month period, own 25 percent or more of the shares of the company.

Canada has approved several positions with respect to the Multilateral Convention to Implement Tax Treaty Related Measures to Prevent Base Erosion and Profit Shifting (“MLI”), which may impact the taxability of dividends and capital gains in Canada if the shareholder’s country of residence has also approved these same positions of the MLI.

Between October 1, 2020 and December 31, 2020, pursuant to the company’s restricted stock unit plan, 6,975 shares were issued to employees or former employees outside the U.S. in reliance on Regulation S under the Securities Act.    

Securities authorized for issuance under equity compensation plans

Sections of the company’s management proxy circular are contained in the “Proxy information section”, starting on page 113. The company’s management proxy circular is prepared in accordance with Canadian securities regulations.

Reference is made to the section under the “Company executives and executive compensation”:

● Entitled “Performance graph” within the “Compensation discussion and analysis” section on page 173 of this report; and

● Entitled “Equity compensation plan information”, within the “Compensation discussion and analysis”, on page 178 of this report.

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Issuer purchases of equity securities

	Total number of shares purchased		Average price paid per share (Canadian dollars)		Total number of shares purchased as part of publicly announced plans or programs		Maximum number of shares that may yet be purchased under the plans or programs (a)
October 2020
(October 1 - October 31)		-		-		-		50,000
November 2020
(November 1 - November 30)		-		-		-		50,000
December 2020
(December 1 - December 31)		6,975		24.34		6,975		43,025

(a) On June 23, 2020, the company announced by news release that it had received final approval from the Toronto Stock Exchange for a limited normal course issuer bid. The program is used primarily to eliminate dilution from shares issued in conjunction with Imperial’s restricted stock unit plan, and enables the company to purchase up to a maximum of 50,000 common shares during the period June 29, 2020 to June 28, 2021. This maximum includes shares purchased under the normal course issuer bid and from Exxon Mobil Corporation concurrent with, but outside of the normal course issuer bid. As in the past, Exxon Mobil Corporation has advised the company that it intends to participate to maintain its ownership percentage at approximately 69.6 percent. The program will end should the company purchase the maximum allowable number of shares, or on June 28, 2021.

The company will continue to evaluate its share purchase program in the context of its overall capital activities.

Item 6. Selected financial data

millions of Canadian dollars	2020			2019		2018		2017		2016
Revenues		22,284			34,002		34,964		29,125		25,049
Net income (loss)		(1,857	)		2,200		2,314		490		2,165
Total assets at year-end		38,031			42,187		41,456		41,601		41,654
Long-term debt at year-end		4,957			4,961		4,978		5,005		5,032
Total debt at year-end		5,184			5,190		5,180		5,207		5,234
Other long-term obligations at year-end		4,100			3,637		2,943		3,780		3,656
Canadian dollars
Net income (loss) per common share - basic		(2.53	)		2.88		2.87		0.58		2.55
Net income (loss) per common share - diluted		(2.53	)		2.88		2.86		0.58		2.55
Dividends per common share - declared		0.88			0.85		0.73		0.63		0.59

Reference is made to the table setting forth exchange rates for the Canadian dollar, expressed in U.S. dollars, on page 2 of this report.

Item 7. Management’s discussion and analysis of financial condition and results of operations

Reference is made to the section entitled “Management’s discussion and analysis of financial condition and results of operations” in the “Financial section”, starting on page 45 of this report.

Item 7A. Quantitative and qualitative disclosures about market risk

Reference is made to the section entitled “Market risks and other uncertainties” in the “Financial section”, starting on page 61 of this report. All statements other than historical information incorporated in this Item 7A are forward-looking statements. The actual impact of future market changes could differ materially due to, among other things, factors discussed in this report.

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Item 8. Financial statements and supplementary data

Reference is made to the table of contents in the “Financial section” on page 41 of this report:

● Consolidated financial statements, together with the report thereon of PricewaterhouseCoopers LLP (PwC) dated February 24, 2021 beginning with the section entitled “Report of independent registered public accounting firm” on page 70 and continuing through note 18, “Other comprehensive income (loss) information” on page 106;

● “Supplemental information on oil and gas exploration and production activities” (unaudited) starting on page 107; and

● “Quarterly financial data” on page 112.

Item 9. Changes in and disagreements with accountants on accounting and financial disclosure

None.

Item 9A. Controls and procedures

As indicated in the certifications in Exhibit 31 of this report, the company’s principal executive officer and principal financial officer have evaluated the company’s disclosure controls and procedures as of December 31, 2020. Based on that evaluation, these officers have concluded that the company’s disclosure controls and procedures are effective in ensuring that information required to be disclosed by the company in the reports that it files or submits under the Securities Exchange Act of 1934, as amended, is accumulated and communicated to them in a manner that allows for timely decisions regarding required disclosures and are effective in ensuring that such information is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms.

Reference is made to page 69 of this report for “Management’s report on internal control over financial reporting” and page 70 for the “Report of independent registered public accounting firm” on the company’s internal control over financial reporting as of December 31, 2020.

There has not been any change in the company’s internal control over financial reporting during the last fiscal quarter that has materially affected, or is reasonably likely to materially affect, the company’s internal control over financial reporting.

Item 9B. Other information

None.

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PART III

Item 10. Directors, executive officers and corporate governance

Sections of the company’s management proxy circular are contained in the “Proxy information section”, starting on page 113. The company’s management proxy circular is prepared in accordance with Canadian securities regulations.

The company currently has seven directors. The articles of the company require that the board have between five and fifteen directors. Each director is elected to hold office until the close of the next annual meeting. Each of the seven individuals listed in the section entitled “Nominees for director” on pages 114 to 117 of this report have been nominated for election at the annual meeting of shareholders to be held May 4, 2021. All of the nominees, with the exception of M.R. Crocker, are now directors and have been since the dates indicated. D.C. Brownell is a current director and has chosen not to stand for re-election.

Reference is made to the section under “Nominees for director”:

● “Director nominee tables”, on pages 114 to 117 of this report;

Reference is made to the sections under “Corporate governance disclosure”:

● “Skills and experience of our board members and nominees”, on page 121 of this report.

● “Other public company directorships of our board members and nominees”, on page 125 of this report.

● The table entitled “Audit committee” under “Board and committee structure”, on page 132 of this report;

● “Ethical business conduct”, starting on page 144 of this report; and

● “Largest shareholder”, on page 148 of this report.

Reference is made to the sections under “Company executives and executive compensation”:

● “Named executive officers of the company” and “Other executive officers of the company”, on pages 150 to 152 of this report.

Item 11. Executive compensation

Sections of the company’s management proxy circular are contained in the “Proxy information section”, starting on page 113. The company’s management proxy circular is prepared in accordance with Canadian securities regulations.

Reference is made to the sections under “Corporate governance disclosure”:

● “Director compensation”, on pages 136 to 142 of this report; and

● “Share ownership guidelines of independent directors and chairman, president and chief executive officer”, on page 143 of this report.

Reference is made to the following sections under “Company executives and executive compensation”:

● “Letter to shareholders from the executive resources committee on executive compensation”, starting on page 153 of this report; and

● “Compensation discussion and analysis”, on pages 156 to 180 of this report.

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Item 12. Security ownership of certain beneficial owners and management and related stockholder matters

Sections of the company’s management proxy circular are contained in the “Proxy information section”, starting on page 113. The company’s management proxy circular is prepared in accordance with Canadian securities regulations.

Reference is made to the section under “Company executives and executive compensation” entitled “Equity compensation plan information”, within the “Compensation discussion and analysis” section, on page 178 of this report.

Reference is made to the section under “Corporate governance disclosure” entitled “Largest shareholder”, on page 148 of this report.

Reference is also made to the security ownership information for directors and executive officers of the company under the preceding Items 10 and 11. The compensation of the directors and executive officers of the company for the year-ended December 31, 2020 is described in the sections under “Nominees for director” starting on page 114, “Director compensation” starting on page 136 and “Company executives and executive compensation” starting on page 150. The following table shows the number of Imperial Oil Limited and Exxon Mobil Corporation common shares owned and restricted stock units held by each named executive officer, and the incumbent directors and executive officers as a group, as of February 16, 2021.

	Imperial Oil Limited				Exxon Mobil Corporation
Named executive officer	Common shares (a)		Restricted stock units (b)		Common shares (a)		Restricted stock units (b)
B.W. Corson		-		156,400		87,758		116,100
D.E. Lyons		-		61,200		9,480		19,550
T.B. Redburn		3,571		101,500		-		-
S.P. Younger		-		16,200		7,703		25,800
B.A. Jolly		29,491		63,150		-		-
Incumbent directors and executive officers as a group (17 people)		126,660		509,925		117,742		252,200

(a) No common shares are beneficially owned by reason of exercisable options. None of these individuals owns more than 0.01 percent of the outstanding shares of Imperial Oil Limited or Exxon Mobil Corporation. The directors and officers as a group own approximately 0.02 percent of the outstanding shares of Imperial Oil Limited, and less than 0.01 percent of the outstanding shares of Exxon Mobil Corporation. Information not being within the knowledge of the company has been provided by the directors and the executive officers individually.

(b) Restricted stock units do not carry voting rights prior to the issuance of shares on settlement of the awards.

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Item 13. Certain relationships and related transactions, and director independence

Sections of the company’s management proxy circular are contained in the “Proxy information section”, starting on page 113. The company’s management proxy circular is prepared in accordance with Canadian securities regulations.

Reference is made to the section under “Corporate governance disclosure” entitled “Independence of our board members and nominees”, on page 122 of this report.

Reference is made to the section under “Corporate governance disclosure” entitled “Transactions with Exxon Mobil Corporation”, on page 148 of this report.

D.C. Brownell is deemed a non-independent member of the board of directors and the executive resources committee, public policy and corporate responsibility committee, nominations and corporate governance committee and community collaboration and engagement committee under the relevant standards. As an employee of Exxon Mobil Corporation, D.C. Brownell is independent of the company’s management and is able to assist these committees by reflecting the perspective of the company’s shareholders.

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Item 14. Principal accountant fees and services

Auditor information

The audit committee of the board of directors recommends that PwC be reappointed as the auditor of the company until the close of the next annual meeting. PwC has been the auditor of the company for more than five years and are located in Calgary, Alberta. PwC is a participating audit firm with the Canadian Public Accountability Board.

Auditor fees

The aggregate fees of PwC for professional services rendered for the audit of the company’s financial statements and other services for the fiscal years ended December 31, 2020 and December 31, 2019 were as follows:

thousands of Canadian dollars	2020		2019
Audit fees		1,910		1,782
Audit-related fees		92		94
Tax fees		-		-
All other fees		-		-
Total fees		2,002		1,876

Audit fees included the audit of the company’s annual financial statements, internal control over financial reporting, and a review of the first three quarterly financial statements in 2020. Audit-related fees consisted of other assurance services including the audit of the company’s retirement plan and royalty statement audits for oil and gas producing entities. The company did not engage the auditor for any other services.

The audit committee formally and annually evaluates the performance of the external auditor, recommends the external auditor to be appointed by the shareholders, recommends their remuneration and oversees their work. The audit committee also approves the proposed current year audit program of the external auditor, assesses the results of the program after the end of the program period and approves in advance any non-audit services to be performed by the external auditor after considering the effect of such services on their independence.

All of the services rendered by the auditor to the company were approved by the audit committee.

Auditor independence

The audit committee continually discusses with PwC their independence from the company and from management. PwC have confirmed that they are independent with respect to the company within the meaning of the Rules of Professional Conduct of the Chartered Professional Accountants of Alberta, the Public Company Accounting Oversight Board (United States) (PCAOB) and the rules of the U.S. Securities and Exchange Commission. The company has concluded that the auditor’s independence has been maintained.

37

PART IV

Item 15.   Exhibits, financial statement schedules

Reference is made to the table of contents in the “Financial section” on page 41 of this report.

The following exhibits, numbered in accordance with Item 601 of Regulation S-K, are filed as part of this report:

(3)	(i)	Restated certificate and articles of incorporation of the company (Incorporated herein by reference to Exhibit (3.1) to the company’s Form 8-K filed on May 3, 2006 (File No. 0-12014)).
	(ii)	By-laws of the company (Incorporated herein by reference to Exhibit (3)(ii) to the company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2003 (File No. 0-12014)).
(4)	(vi)	Description of capital stock. (Incorporated herein by reference to Exhibit (4)(vi) of the company’s Annual Report on Form 10-K for the year ended December 31, 2019 (File No. 0-12014)).
(10)     (ii)		(1)  Syncrude Ownership and Management Agreement, dated February 4, 1975 (Incorporated herein by reference to Exhibit 13(b) of the company’s Registration Statement on Form S-1, as filed with the Securities and Exchange Commission on August 21, 1979 (File No. 2-65290)). (2)  Letter Agreement, dated February 8, 1982, between the Government of Canada and Esso Resources Canada Limited, amending Schedule “C” to the Syncrude Ownership and Management Agreement filed as Exhibit (10)(ii)(2) (Incorporated herein by reference to Exhibit (20) of the company’s Annual Report on Form 10-K for the year ended December 31, 1981 (File No. 2-9259)). (3)  Amendment to Syncrude Ownership and Management Agreement, dated March 10, 1982 (Incorporated herein by reference to Exhibit (10)(ii)(14) of the company’s Annual Report on Form 10-K for the year ended December 31, 1989 (File No. 0-12014)). (4)  Alberta Cold Lake Transition Agreement, effective January 1, 2000, relating to the royalties payable in respect of the Cold Lake production project and terminating the Alberta Cold Lake Crown Agreement dated June 25, 1984. (Incorporated herein by reference to Exhibit (10)(ii)(20) of the company’s Annual Report on Form 10-K for the year ended December 31, 2001 (File No. 0-12014)). (5)  Amendment to Syncrude Ownership and Management Agreement effective January 1, 2001 (Incorporated herein by reference to Exhibit (10)(ii)(22) of the company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2002 (File No. 0-12014)). (6)  Amendment to Syncrude Ownership and Management Agreement effective September 16, 1994 (Incorporated herein by reference to Exhibit (10)(ii)(23) of the company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2002 (File No. 0-12014)). (7)  Syncrude Bitumen Royalty Option Agreement, dated November 18, 2008, setting out the terms of the exercise by the Syncrude Joint Venture owners of the option contained in the existing Crown Agreement to convert to a royalty payable on the value of bitumen, effective January 1, 2009 (Incorporated herein by reference to Exhibit 1.01(10)(ii)(2) of the company’s Form 8-K filed on November 19, 2008 (File No. 0-12014)).
(iii)(A)		(1)  Form of Letter relating to Supplemental Retirement Income (Incorporated herein by reference to Exhibit (10)(c)(3) of the company’s Annual Report on Form 10-K for the year ended December 31, 1980 (File No. 2-9259)). (2)  Deferred Share Unit Plan for Nonemployee Directors. (Incorporated herein by reference to Exhibit (10)(iii)(A)(6) of the company’s Annual Report on Form 10-K for the year ended December 31, 1998 (File No. 0-12014)). (3)  Amended Restricted Stock Unit Plan with respect to Restricted Stock Units granted in 2011 and subsequent years, as amended effective November 14, 2011 (Incorporated herein by reference to Exhibit 9.01(c)[10(iii)(A)(1)] of the company’s Form 8-K filed on February 23, 2012 (File No. 0-12014)). (4)  Amended Restricted Stock Unit Plan with respect to Restricted Stock Units granted in 2016 and subsequent years, as amended effective October 26, 2016 (Incorporated herein by reference to Exhibit 9.01(c)[10(iii)(A)(1)] of the company’s Form 8-K filed on October 31, 2016 (File No. 0-12014)).

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	(5)  Amended Short Term Incentive Program with respect to awards granted in 2016 and subsequent years, as amended effective October 26, 2016 (Incorporated herein by reference to Exhibit 9.01(c)[10(iii)(A)(1)] of the company’s Form 8-K filed on October 31, 2016 (File No. 0-12014)). (6)  Amended Restricted Stock Unit Plan with respect to Restricted Stock Units granted in 2020 and subsequent years, as amended effective November 24, 2020.
(21)	Imperial Oil Resources Limited is incorporated in Canada, and is a wholly-owned subsidiary of the company. The names of all other subsidiaries of the company are omitted because, considered in the aggregate as a single subsidiary, they would not constitute a significant subsidiary as of December 31, 2020.
(31.1)	Certification by principal executive officer of Periodic Financial Report pursuant to Rule 13a-14(a).
(31.2)	Certification by principal financial officer of Periodic Financial Report pursuant to Rule 13a-14(a).
(32.1)	Certification by chief executive officer of Periodic Financial Report pursuant to Rule 13a-14(b) and 18 U.S.C. Section 1350.
(32.2)	Certification by chief financial officer of Periodic Financial Report pursuant to Rule 13a-14(b) and 18 U.S.C. Section 1350.
(101)	Interactive Data Files (formatted as Inline XBRL).
(104)	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).

Copies of Exhibits may be acquired upon written request of any shareholder to the vice president, investor relations, Imperial Oil Limited, 505 Quarry Park Boulevard S.E., Calgary, Alberta T2C 5N1, and payment of processing and mailing costs.

Item 16. Form 10-K summary

Not applicable.

39

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf on February 24, 2021 by the undersigned, thereunto duly authorized.

Imperial Oil Limited

by                /s/ Bradley W. Corson

(Bradley W. Corson)

Chairman, president and chief executive officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below on February 24, 2021 by the following persons on behalf of the registrant and in the capacities indicated.

Signature	Title
/s/ Bradley W. Corson (Bradley W. Corson)	Chairman, president and chief executive officer and director (Principal executive officer)
/s/ Daniel E. Lyons (Daniel E. Lyons)	Senior vice-president, finance and administration, and controller (Principal financial officer and principal accounting officer)
/s/ David C. Brownell (David C. Brownell)	Director
/s/ David W. Cornhill (David W. Cornhill)	Director
/s/ Krystyna T. Hoeg (Krystyna T. Hoeg)	Director
/s/ Miranda C. Hubbs (Miranda C. Hubbs)	Director
/s/ Jack M. Mintz (Jack M. Mintz)	Director
/s/ David S. Sutherland (David S. Sutherland)	Director

40

Financial section

Table of contents	Page
Financial information (U.S. GAAP)	42
Frequently used terms	43
Management’s discussion and analysis of financial condition and results of operations	45
Overview	45
Business environment and risk assessment	46
Results of operations	51
Liquidity and capital resources	57
Capital and exploration expenditures	60
Market risks and other uncertainties	61
Critical accounting estimates	63
Management’s report on internal control over financial reporting	69
Report of independent registered public accounting firm	70
Consolidated statement of income (U.S. GAAP)	74
Consolidated statement of comprehensive income (U.S. GAAP)	75
Consolidated balance sheet (U.S. GAAP)	76
Consolidated statement of shareholders’ equity (U.S. GAAP)	77
Consolidated statement of cash flows (U.S. GAAP)	78
Notes to consolidated financial statements	79
1. Summary of significant accounting policies	79
2. Accounting changes	85
3. Business segments	86
4. Income taxes	88
5. Employee retirement benefits	89
6. Other long-term obligations	94
7. Financial and derivative instruments	95
8. Share-based incentive compensation programs	97
9. Investment and other income	98
10. Litigation and other contingencies	98
11. Common shares	99
12. Miscellaneous financial information	100
13. Financing and additional notes and loans payable information	101
14. Leases	102
15. Long-term debt	104
16. Accounting for suspended exploratory well costs	104
17. Transactions with related parties	105
18. Other comprehensive income (loss) information	106
Supplemental information on oil and gas exploration and production activities (unaudited)	107
Quarterly financial data	112

41

Financial information (U.S. GAAP)
millions of Canadian dollars	2020			2019			2018			2017			2016
Revenues		22,284			34,002			34,964			29,125			25,049
Net income (loss):
Upstream		(2,318	)		1,348			(138	)		(706	)		(661	)
Downstream		553			961			2,366			1,040			2,754
Chemical		78			108			275			235			187
Corporate and other		(170	)		(217	)		(189	)		(79	)		(115	)
Net income (loss)		(1,857	)		2,200			2,314			490			2,165
Cash and cash equivalents at year-end		771			1,718			988			1,195			391
Total assets at year-end		38,031			42,187			41,456			41,601			41,654
Long-term debt at year-end		4,957			4,961			4,978			5,005			5,032
Total debt at year-end		5,184			5,190			5,180			5,207			5,234
Other long-term obligations at year-end		4,100			3,637			2,943			3,780			3,656
Shareholders’ equity at year-end		21,418			24,276			24,489			24,435			25,021
Cash flow from operating activities		798			4,429			3,922			2,763			2,015
Per share information (Canadian dollars)
Net income (loss) per common share - basic		(2.53	)		2.88			2.87			0.58			2.55
Net income (loss) per common share - diluted		(2.53	)		2.88			2.86			0.58			2.55
Dividends per common share - declared		0.88			0.85			0.73			0.63			0.59

42

Frequently used terms

Listed below are definitions of several of Imperial’s key business and financial performance measures. The definitions are provided to facilitate understanding of the terms and how they are calculated.

Capital employed

Capital employed is a measure of net investment. When viewed from the perspective of how capital is used by the business, it includes the company’s property, plant and equipment, and other assets, less liabilities, excluding both short-term and long-term debt. When viewed from the perspective of the sources of capital employed in total for the company, it includes total debt and equity. Both of these views include the company’s share of amounts applicable to equity companies, which the company believes should be included to provide a more comprehensive measurement of capital employed.

millions of Canadian dollars		2020			2019			2018
Business uses: asset and liability perspective
Total assets			38,031			42,187			41,456
Less:	Total current liabilities excluding notes and loans payable		(3,153	)		(4,366	)		(3,753	)
	Total long-term liabilities excluding long-term debt		(8,276	)		(8,355	)		(8,034	)
Add: Imperial’s share of equity company debt			26			24			23
Total capital employed			26,628			29,490			29,692
Total company sources: Debt and equity perspective
Notes and loans payable			227			229			202
Long-term debt			4,957			4,961			4,978
Shareholders’ equity			21,418			24,276			24,489
Add: Imperial’s share of equity company debt			26			24			23
Total capital employed			26,628			29,490			29,692

Return on average capital employed (ROCE)

ROCE is a financial performance ratio. From the perspective of the business segments, ROCE is annual business segment net income divided by average business segment capital employed (an average of the beginning and end-of-year amounts). Segment net income includes Imperial’s share of segment net income of equity companies, consistent with the definition used for capital employed, and excludes the cost of financing. The company’s total ROCE is net income excluding the after-tax cost of financing divided by total average capital employed. The company has consistently applied its ROCE definition for many years and views it as the best measure of historical capital productivity in a capital-intensive, long-term industry. Additional measures, which are more cash flow based, are used to make investment decisions.

millions of Canadian dollars	2020			2019		2018
Net income (loss)		(1,857	)		2,200		2,314
Financing (after-tax), including Imperial’s share of equity companies		52			66		77
Net income (loss) excluding financing		(1,805	)		2,266		2,391
Average capital employed		28,059			29,591		29,677
Return on average capital employed (percent) – corporate total		(6.4	)		7.7		8.1

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Cash flows from operating activities and asset sales

Cash flows from operating activities and asset sales is the sum of the net cash provided by operating activities and proceeds from asset sales reported in the Consolidated statement of cash flows. This cash flow reflects the total sources of cash both from operating the company’s assets and from the divesting of assets. The company employs a long-standing and regular disciplined review process to ensure that assets are contributing to the company’s strategic objectives. Assets are divested when they no longer meet these objectives or are worth considerably more to others. Because of the regular nature of this activity, the company believes it is useful for investors to consider sales proceeds together with cash provided by operating activities when evaluating cash available for investment in the business and financing activities, including shareholder distributions.

millions of Canadian dollars	2020		2019		2018
Cash flows from operating activities		798		4,429		3,922
Proceeds from asset sales		82		82		59
Total cash flows from operating activities and asset sales		880		4,511		3,981

Operating costs

Operating costs are the costs during the period to produce, manufacture, and otherwise prepare the company’s products for sale – including energy costs, staffing and maintenance costs. They exclude the cost of raw materials, taxes and interest expense and are on a before-tax basis. While the company is responsible for all revenue and expense elements of net income, operating costs represent the expenses most directly under the company’s control and therefore, are useful in evaluating the company’s performance.

Reconciliation of operating costs

millions of Canadian dollars	2020		2019		2018
From Imperial’s Consolidated statement of income
Total expenses		24,796		32,055		32,026
Less:
Purchases of crude oil and products		13,293		20,946		21,541
Federal excise tax and fuel charge		1,736		1,808		1,667
Financing		64		93		108
Subtotal		15,093		22,847		23,316
Imperial’s share of equity company expenses		64		76		74
Total operating costs		9,767		9,284		8,784
Components of operating costs
millions of Canadian dollars	2020		2019		2018
From Imperial’s Consolidated statement of income
Production and manufacturing		5,535		6,520		6,121
Selling and general		741		900		908
Depreciation and depletion (includes impairments)		3,293		1,598		1,555
Non-service pension and postretirement benefit		121		143		107
Exploration		13		47		19
Subtotal		9,703		9,208		8,710
Imperial’s share of equity company expenses		64		76		74
Total operating costs		9,767		9,284		8,784

44

Management’s discussion and analysis of financial condition and results of operations

Overview

The following discussion and analysis of Imperial’s financial results, as well as the accompanying financial statements and related notes to consolidated financial statements to which they refer, are the responsibility of the management of Imperial Oil Limited.

The company’s accounting and financial reporting fairly reflect its business model involving exploration for, and production of, crude oil and natural gas and manufacture, trade, transport and sale of crude oil, natural gas, petroleum products, petrochemicals and a variety of specialty products.

Imperial, with its resource base, financial strength, disciplined investment approach and technology portfolio, is well-positioned to participate in substantial investments to develop new Canadian energy supplies. The company’s integrated business model, with significant investments in Upstream, Downstream and Chemical segments, generally reduces the company’s risk from changes in commodity prices. While commodity prices depend on supply and demand and may be volatile on a short-term basis, Imperial’s investment decisions are grounded on fundamentals reflected in its long-term business outlook, and use a disciplined approach in selecting and pursuing the most attractive investment opportunities. The corporate plan is a fundamental annual management process that is the basis for setting operating and capital objectives, in addition to providing the economic assumptions used for investment evaluation purposes. Volume projections are based on individual field production profiles, which are also updated annually. Price ranges for crude oil, natural gas, refined products and chemical products are based on corporate plan assumptions developed annually and are utilized for investment evaluation purposes. Major investment opportunities are evaluated over a range of potential market conditions. Once major investments are made, a reappraisal process is completed to ensure relevant lessons are learned and improvements are incorporated into future projects.

The term “project” as used in this report can refer to a variety of different activities and does not necessarily have the same meaning as in any government payment transparency reports.

45

Business environment and risk assessment

Long-term business outlook

Given the uncertainty around the near-term impacts of COVID-19 on economic growth, energy demand and energy supply, and lack of precedent, the company is considering a range of recovery pathways to guide near-term plans. These pathways expect that energy demand will grow beyond 2019 levels as early as 2022 reflecting the phase out of COVID-19 impacts and re-establishment of long-term supply / demand fundamentals. The “Long-term business outlook” is based on Exxon Mobil Corporation’s Outlook for Energy, which combined with the near-term pathways is used to help inform the company’s long-term business strategies and investment plans.

By 2040, the world’s population is projected at around 9.1 billion people, or about 1.6 billion more than in 2018. Coincident with this population increase, the company expects worldwide economic growth to average close to 2.5 percent per year, with economic output growing by around 75 percent by 2040. As economies and populations grow, and as living standards improve for billions of people, the need for energy is expected to continue to rise. Even with significant efficiency gains, global energy demand is projected to rise by more than 10 percent from 2018 to 2040. This increase in energy demand is expected to be driven by developing countries (i.e., those that are not member nations of the Organization for Economic Co-operation and Development (OECD)). Canada is expected to see flat to modest local energy demand growth through to 2040 and will continue to be a large supplier of energy exports to help meet rising global energy needs.

As expanding prosperity helps drive global energy demand higher, increasing use of energy efficient technologies and practices, as well as lower-emission products will continue to help significantly reduce energy consumption and emissions per unit of economic output over time. Substantial efficiency gains are likely in all key aspects of the world’s economy through 2040, affecting energy requirements for power generation, transportation, industrial applications, and residential and commercial needs.

Global electricity demand is expected to increase approximately 50 percent from 2018 to 2040, with developing countries likely to account for about 85 percent of the increase. Consistent with this projection, power generation is expected to remain the largest and fastest growing major segment of global primary energy demand, supported by a wide variety of energy sources. The share of coal fired generation is likely to decline substantially and approach 20 percent of the world’s electricity in 2040, versus nearly 40 percent in 2018, in part as a result of policies to improve air quality as well as reduce greenhouse gas emissions to address the risks related to climate change. From 2018 to 2040, the amount of electricity supplied using natural gas, nuclear power, and renewables is likely to nearly double, accounting for the entire growth in electricity supplies and offsetting the reduction of coal. Electricity from wind and solar is likely to increase about 400 percent, helping total renewables (including other sources, i.e., hydropower) to account for about 80 percent of the increase in electricity supplies worldwide through 2040. Total renewables will likely reach about 50 percent of global electricity supplies by 2040. Natural gas and nuclear are also expected to increase shares over the period to 2040, reaching more than 25 percent and about 10 percent of global electricity supplies respectively by 2040. Supplies of electricity by energy type will reflect significant differences across regions reflecting a wide range of factors including the cost and availability of various energy supplies and policy developments.

Energy for transportation – including cars, trucks, ships, trains and airplanes – is expected to increase by about 20 percent from 2018 to 2040. Transportation energy demand is likely to account for over 60 percent of the growth in liquid fuels demand worldwide over this period. Light-duty vehicle demand for liquid fuels is projected to peak prior to 2025 and then decline to levels seen in the early-2010s by 2040 as the impact of better fuel economy and significant growth in electric cars, led by China, Europe, and the United States, work to offset growth in the worldwide car fleet of about 60 percent. By 2040, light-duty vehicles are expected to account for about 20 percent of global liquid fuels demand. During the same time period, nearly all the world’s commercial transportation fleets are likely to continue to run on liquid fuels, which are widely available and offer practical advantages in providing a large quantity of energy in small volumes.

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Liquid fuels provide the largest share of global energy supplies today reflecting broad-based availability, affordability, ease of transportation, and fitness as a practical solution to meet a wide variety of needs. By 2040, global demand for liquid fuels is projected to grow to approximately 110 million oil-equivalent barrels per day, an increase of about 9 percent from 2018. The non-OECD share of global liquid fuels demand is expected to increase to about 65 percent by 2040, as liquid fuels demand in the OECD is likely to decline by close to 15 percent. Much of the global liquid fuels demand today is met by crude production from traditional conventional sources; these supplies will remain important, and significant development activity is expected to offset much of the natural declines from these fields. At the same time, a variety of emerging supply sources – including tight oil, deepwater, oil sands, natural gas liquids and biofuels – are expected to grow to help meet rising demand. The world’s resource base is sufficient to meet projected demand through 2040 as technology advances continue to expand the availability of economic and lower carbon supply options. However, timely investments will remain critical to meeting global needs with reliable and affordable supplies.

Natural gas is a lower-emission, versatile and practical fuel for a wide variety of applications, and it is expected to grow the most of any primary energy type from 2018 to 2040, meeting about 50 percent of global energy demand growth. Global natural gas demand is expected to rise about 25 percent from 2018 to 2040, with about half of that increase coming from the Asia Pacific region. Significant growth in supplies of unconventional gas – the natural gas found in shale and other tight rock formations – will help meet these needs. In total, about 55 percent of the growth in natural gas supplies is expected to be from unconventional sources. At the same time, conventionally-produced natural gas is likely to remain the cornerstone of global supply, meeting more than two-thirds of worldwide demand in 2040. Liquefied natural gas (LNG) trade will expand significantly, meeting about 40 percent of the increase in global demand growth, with much of this supply expected to help meet rising demand in Asia Pacific.

The world’s energy mix is highly diverse and will remain so through 2040. Oil is expected to remain the largest source of energy with its share remaining close to 30 percent in 2040. Coal is currently the second largest source of energy, but it is likely to lose that position to natural gas in the next few years. The share of natural gas is expected to reach more than 25 percent by 2040, while the share of coal falls to about two thirds of the natural gas share. Nuclear power is projected to grow significantly, as many nations are likely to expand nuclear capacity to address rising electricity needs as well as energy security and environmental issues. Total renewable energy is likely to exceed 15 percent of global energy by 2040, with biomass, hydro and geothermal contributing a combined share of more than 10 percent. Total energy supplied from wind, solar and biofuels is expected to increase rapidly, growing over 350 percent from 2018 to 2040, when they will likely be just over 6 percent of the world energy mix.

The company anticipates that the world’s available oil and gas resource base will grow not only from new discoveries, but also from increases in previously discovered fields. Technology will underpin these increases. The investments to develop and supply resources to meet global demand through 2040 will be significant – even if demand remains flat. This reflects a fundamental aspect of the oil and natural gas business as the International Energy Agency (IEA) describes in its World Energy Outlook 2020. According to the IEA’s Stated Energy Policies Scenario, the investment required to meet oil and natural gas supply requirements worldwide over the period 2019 to 2040 will be about US$17 trillion (measured in 2019 dollars). In the IEA’s Sustainable Development Scenario, which is in line with the objectives of the Paris Agreement on climate change, the investment need would still accumulate to US$12 trillion.

47

International accords and underlying regional and national regulations covering greenhouse gas emissions continue to evolve with uncertain timing and outcome, making it difficult to predict their business impact. Imperial’s estimates of potential costs related to greenhouse gas emissions align with applicable provincial and federal regulations. Additionally, Imperial uses ExxonMobil’s Outlook for Energy as a foundation for estimating energy supply and demand requirements from various energy sources and uses, and the Outlook for Energy takes into account policies established to reduce energy related greenhouse gas emissions. The climate accord reached at the Conference of the Parties (COP 21) in Paris set many new goals, and many related policies are still emerging. The Outlook for Energy reflects an environment with increasingly stringent climate policies and is consistent with the aggregation of Nationally Determined Contributions (NDCs), which were submitted by signatories to the United Nations Framework Convention on Climate Change (UNFCCC) 2015 Paris Agreement. The Outlook for Energy seeks to identify potential impacts of climate related policies, which often target specific sectors. It estimates potential impacts of these policies on consumer energy demand by using various assumptions and tools – including, depending on the sector, application of a proxy cost of carbon or assessment of targeted policies (i.e., automotive fuel economy standards). As people and nations look for ways to reduce risks of global climate change, they will continue to need practical solutions that do not jeopardize the affordability or reliability of the energy they need. The company continues to monitor the updates to the NDCs that nations are expected to provide in preparation for COP 26 in Glasgow in November 2021 as well as other policy developments in light of net zero ambitions recently formulated by some nations, including Canada.

Practical solutions to the world’s energy and climate challenges will benefit from market competition in addition to well-informed, well-designed and transparent policy approaches that carefully weigh costs and benefits. Such policies are likely to help manage the risks of climate change while also enabling societies to pursue other high priority goals around the world – including clean air and water, access to reliable and affordable energy, and economic progress for all people. The company encourages sound policy solutions that reduce climate-related risks across the economy at the lowest societal cost. All practical and economically viable energy sources will need to be pursued to continue meeting global energy demand, recognizing the scale and variety of worldwide energy needs, as well as the importance of expanding access to modern energy to promote better standards of living for billions of people.

The information provided in the “Long-term business outlook” includes internal estimates and projections based upon ExxonMobil’s internal data and analyses, as well as publicly available information from external sources including the International Energy Agency.

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Upstream

Imperial produces crude oil and natural gas for sale predominantly into North American markets. Imperial’s Upstream business strategies guide the company’s exploration, development, production, research and gas marketing activities. These strategies include maximizing asset reliability, accelerating development and application of high impact technologies, maximizing value by capturing new business opportunities and managing the existing portfolio, as well as pursuing sustainable improvements in organizational efficiency and effectiveness. These strategies are underpinned by a relentless focus on operations integrity, commitment to innovative technologies, disciplined approach to investing and cost management, development of employees and investment in the communities within which the company operates.

Imperial has a significant oil and gas resource base and a large inventory of potential projects. The company continues to evaluate opportunities to support long-term growth. As future development projects bring new production online, Imperial expects growth from oil sands in-situ and mining, as well as unconventional resources, with the largest growth potential related to in-situ. Actual volumes will vary from year to year due to the factors described in Item 1A. “Risk factors”.

The upstream industry environment has a history of significant price volatility. Market demand and prices experienced a sharp decline in the first half of 2020 largely driven by the COVID-19 pandemic. Following this decline, prices improved in the second half of the year as supply and demand began to rebalance. Prices for most of the company’s crude oil sold are referenced to Western Canada Select (WCS) and West Texas Intermediate (WTI) oil markets. In January 2019, the Government of Alberta’s temporary mandatory production curtailment regulations came into effect. Although the mandatory production curtailment decreased throughout 2019 and 2020, and was eliminated in December 2020, the regulatory authority to impose curtailment remains in place and there is the potential for curtailment to be re-imposed and increased. The duration of these regulations is uncertain. Imperial continually monitors the effects of these regulations and evaluates opportunities, including crude shipments by rail and the pace of the development of its Aspen in-situ oil sands project, as economically justified.

Imperial believes prices over the long term will be driven by market supply and demand, with the demand side largely being a function of general economic activities, levels of prosperity, technology advances, consumer preference and government policies. On the supply side, prices may be significantly impacted by political events, logistics constraints, the actions of OPEC, governments and other factors. To manage the risks associated with price, Imperial evaluates annual plans and all major investments across a range of price scenarios.

In 2020, Imperial re-assessed the long-term development plans of its unconventional portfolio in Alberta and no longer plans to further develop a significant portion of this portfolio. The decision resulted in a non-cash, after-tax impairment charge of $1,171 million in 2020, thereby reducing the carrying value of those assets to fair value. The company retains its interest in these resources. These non-core assets are non-producing, undeveloped assets and the company does not expect any material future cash expenditures related to this impairment. This decision is consistent with Imperial’s strategy of focusing its upstream resources and efforts on its key oil sands assets as well as on only the most attractive portions of its unconventional portfolio. Imperial continues to produce from its developed acreage.

Kearl’s supplemental crushing facilities started operations in late 2019, with ramp-up of all units through early 2020. These facilities have further improved reliability, reduced planned downtime, lowered unit costs and enabled the asset to achieve higher volumes. As disclosed in the company’s 2019 Form 10-K, the original production target in 2020 for Kearl was 240,000 barrels per day (about 170,000 barrels Imperial’s share). As a result of market conditions, the company adjusted planned maintenance and turnaround activity, and revised its full-year guidance for Kearl total gross production to 220,000 barrels per day (about 156,000 barrels Imperial’s share). In 2020, Kearl achieved record annual total gross production of 222,000 barrels per day (158,000 barrels Imperial’s share). Imperial continues to progress initiatives to enable the asset to achieve 255,000 barrels per day of total gross production in 2021 (about 181,000 barrels Imperial’s share). In 2020, gross bitumen production at Cold Lake was impacted by ongoing steam management. The company plans to focus on base performance in the near-term and expects gross bitumen production at Cold Lake to average approximately 130,000 barrels per day in 2021.

As described in more detail in Item 1A. “Risk factors”, environmental risks and climate related regulations, and COVID-19 could have negative impacts on the upstream business.

49

Downstream

Imperial’s Downstream serves predominantly Canadian markets with refining, logistics and marketing assets. Imperial’s Downstream business strategies competitively position the company across a range of market conditions. These strategies include targeting industry leading performance in reliability, safety and operations integrity, as well as maximizing value from advanced technologies, capitalizing on integration across Imperial’s businesses, selectively investing for resilient and advantaged returns, operating efficiently and effectively, and providing quality, valued and differentiated products and services to customers.

Imperial owns and operates three refineries in Canada, with aggregate distillation capacity of 428,000 barrels per day. Refining margins are largely driven by differences in commodity prices and are a function of the difference between what a refinery pays for its raw materials (primarily crude oil) and the market prices for the range of products produced (primarily gasoline, heating oil, diesel oil, jet fuel, fuel oil and asphalt). Crude oil and many products are widely traded with published prices, including those quoted on the New York Mercantile Exchange. Prices for these commodities are determined by the global and regional marketplaces and are influenced by many factors, including global and regional supply / demand balances, inventory levels, industry refinery operations, import / export balances, currency fluctuations, seasonal demand, weather and political climate. Imperial’s integration across the value chain, from refining to marketing, enhances overall value across the fuels business.

In 2020, demand for petroleum products was significantly impacted by the COVID-19 pandemic, starting in the first half of the year. While there was some demand improvement in the second half of 2020, demand remained below 2019 levels. This unprecedented demand impact also adversely affected Imperial’s margins.

As described in more detail in Item 1A. “Risk factors”, proposed carbon policy and other climate related regulations, as well as continued biofuels mandates, could have negative impacts on the downstream business.

Imperial supplies petroleum products to the motoring public through Esso and Mobil-branded sites and independent marketers. At the end of 2020, there were about 2,400 sites operating under a branded wholesaler model whereby Imperial supplies fuel to independent third parties who own and operate sites in alignment with Esso and Mobil brand standards.

Chemical

North America continued to benefit from abundant supplies of natural gas and gas liquids, providing both low cost energy and feedstock for steam crackers. In 2020, margins were adversely impacted by continued industry capacity additions and effects related to COVID-19. Imperial maintains a competitive advantage through continued operational excellence, consistent product quality, investment and cost discipline, and integration of its chemical plant in Sarnia with the refinery. The company also benefits from its relationship with ExxonMobil’s North American chemical businesses, enabling Imperial to maintain a leadership position in its key market segments.

50

Results of operations

In 2020, the balance of supply and demand for petroleum and petrochemical products experienced two significant disruptive effects. On the demand side, the COVID-19 pandemic spread rapidly across Canada and the world resulting in substantial reductions in consumer and business activity and significantly reduced local and global demand for crude oil, natural gas, and petroleum products. This reduction in demand coincided with announcements of increased production in certain key oil-producing countries which led to increases in inventory levels and sharp declines in prices for crude oil, natural gas, and petroleum products. Market conditions continued to reflect considerable uncertainty throughout 2020 as consumer and business activity has exhibited some degree of recovery, but remained lower when compared to prior periods as a result of the pandemic. Despite actions taken by key oil-producing countries to reduce oversupply, and improved credit market conditions providing sufficient liquidity to credit-worthy companies, the unfavourable economic impacts appear increasingly likely to persist to some extent well into 2021.

In late March, the company announced significant reductions in 2020 capital and operating expense spending plans. Capital and exploration expenditures for 2020 were $874 million, in line with the company’s most recent guidance of $900 million, and less than half of 2019 expenditures. Capital expenditures in 2021 are expected to be approximately $1.2 billion. In addition, full-year production and manufacturing expenses were $985 million lower than the prior year. This decrease enabled the company to surpass its $500 million expense reduction commitment made in 2020 by nearly double.

The effect of COVID-19 and the current business environment on supply and demand patterns negatively impacted Imperial’s financial and operating results in 2020. Industry conditions seen in 2020 have led to lower realized prices for the company’s products and have resulted in substantially lower earnings and operating cash flow throughout 2020 in comparison to 2019. In response to these conditions, the company operated certain assets at reduced rates and adjusted planned maintenance and turnaround activities throughout the second and third quarters in an effort to reduce on-site staffing levels and to better balance production with demand. Refinery utilization rates and petroleum product sales were reduced through the second quarter of 2020, but saw some improvement in product demands in the second half of the year. The length and severity of COVID-19 impacts to demand and the current business environment are highly uncertain, with the future supply and demand patterns inherently difficult to predict.

In the second quarter of 2020, Canadian federal and provincial governments introduced plans and programs to support business and economic activities in response to the disruptive impacts from the COVID-19 pandemic. The Government of Canada implemented the Canada Emergency Wage Subsidy (CEWS) as part of its COVID-19 Economic Response Plan, and has extended the CEWS until June 2021. The company received wage subsidies under this program and, if eligible, intends to continue to apply for these wage subsidies. Additionally, in the fourth quarter, the Alberta government enacted an accelerated reduction in the corporate income tax rate to eight percent beginning July 1, 2020, compared with a previously legislated reduction to eight percent beginning January 1, 2022. The corporate income tax rate change did not have a significant impact on the company’s financial statements.

The company has taken steps, in line with federal and provincial guidelines and restrictions, to limit the spread of COVID-19 among employees, contractors and the broader community, while also maintaining operations to ensure reliable supply of products to customers as a provider of essential services. The company maintains robust business continuity plans, which have been activated to minimize the impact of COVID-19 on workforce productivity.

51

Consolidated

millions of Canadian dollars	2020			2019		2018
Net income (loss)		(1,857	)		2,200		2,314

2020

Net loss in 2020 was $1,857 million, or $2.53 per share on a diluted basis, compared to net income of $2,200 million or $2.88 per share in 2019. Current year results reflect a non-cash impairment charge of $1,171 million after-tax, related to the company’s decision to no longer develop a significant portion of its unconventional portfolio, and a favourable impact of about $115 million after-tax, associated with the Canada Emergency Wage Subsidy (CEWS), which includes Imperial’s proportionate share of a joint venture. Full-year 2019 results included a favourable impact of $662 million associated with the Alberta corporate income tax rate decrease.

2019

Net income in 2019 was $2,200 million, or $2.88 per share on a diluted basis, compared to net income of $2,314 million or $2.86 per share in 2018. 2019 results include a favourable impact, largely non-cash, of $662 million associated with the Alberta corporate income tax rate decrease. On June 28, 2019, the Alberta government enacted a 4 percent decrease in the provincial tax rate, from 12 percent to 8 percent by 2022.

Upstream

millions of Canadian dollars	2020			2019		2018
Net income (loss)		(2,318	)		1,348		(138	)

2020

Upstream recorded a net loss of $2,318 million for the year, compared to net income of $1,348 million in 2019. Results were negatively impacted by lower realizations of about $2,620 million, a non-cash impairment charge of $1,171 million, related to the company’s decision to no longer develop a significant portion of its unconventional portfolio, absence of a favourable impact of $689 million associated with the Alberta corporate income tax rate decrease in 2019, and lower volumes of about $130 million. These items were partially offset by lower royalties of about $540 million, lower operating expenses of about $250 million, favourable foreign exchange impacts of about $100 million, and about $70 million associated with the CEWS received by the company which includes Imperial’s proportionate share of a joint venture.

2019

Upstream net income was $1,348 million for the year, reflecting the favourable impact associated with the decreased Alberta corporate income tax rate of $689 million. Excluding this impact, 2019 net income was $659 million, up $797 million compared to a net loss of $138 million in 2018. Improved results reflect higher crude oil realizations of about $1,000 million, as well as higher volumes of about $350 million primarily at Syncrude and Norman Wells. Results were negatively impacted by higher royalties of about $230 million, higher operating expenses of about $190 million and lower Cold Lake volumes of about $120 million.

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Average realizations

Canadian dollars	2020		2019		2018
Bitumen (per barrel)		25.69		50.02		37.56
Synthetic oil (per barrel)		49.76		74.47		70.66
Conventional crude oil (per barrel)		29.34		51.81		41.84
Natural gas liquids (per barrel)		13.85		22.83		38.66
Natural gas (per thousand cubic feet)		1.90		2.05		2.43

2020

WTI averaged US$39.26 per barrel in 2020, down from US$57.03 per barrel in 2019. WCS averaged US$26.87 per barrel and US$44.29 per barrel for the same periods. The WTI / WCS differential narrowed to approximately US$12 per barrel in 2020, from around US$13 per barrel in 2019. The Canadian dollar averaged US$0.75 in 2020, essentially unchanged from 2019.

Imperial’s average Canadian dollar realizations for bitumen decreased in 2020 primarily due to a decrease in WCS. Bitumen realizations averaged $25.69 per barrel, compared to $50.02 per barrel in 2019. The company’s average Canadian dollar realizations for synthetic crude decreased generally in line with WTI, adjusted for changes in exchange rates and transportation costs. Synthetic crude realizations averaged $49.76 per barrel, compared to $74.47 per barrel in 2019.

2019

WTI averaged US$57.03 per barrel in 2019, down from US$65.03 per barrel in 2018. WCS averaged US$44.29 per barrel and US$38.71 per barrel for the same periods. The WTI / WCS differential narrowed to average approximately US$13 per barrel in 2019, from around US$26 per barrel in 2018. The Canadian dollar averaged US$0.75 in 2019, a decrease of US$0.02 from 2018.

Imperial’s average Canadian dollar realizations for bitumen increased in 2019, supported primarily by an increase in WCS and lower diluent costs. Bitumen realizations averaged $50.02 per barrel, up from $37.56 per barrel in 2018. The company’s average Canadian dollar realizations for synthetic crude increased relative to WTI, primarily due to the narrowing of the western Canadian light crude differential. Synthetic crude realizations averaged $74.47 per barrel, up from $70.66 per barrel in 2018.

53

Crude oil and natural gas liquids (NGL) - production and sales (a)
thousands of barrels per day	2020				2019				2018
	gross		net		gross		net		gross		net
Bitumen		290		279		285		254		293		255
Synthetic oil (b)		69		68		73		65		62		60
Conventional crude oil		11		10		14		13		5		5
Total crude oil production		370		357		372		332		360		320
NGLs available for sale		2		2		2		1		1		2
Total crude oil and NGL production		372		359		374		333		361		322
Bitumen sales, including diluent (c)		401				387				406
NGL sales		2				6				6
Natural gas - production and production available for sale (a)
millions of cubic feet per day	2020				2019				2018
	gross		net		gross		net		gross		net
Production (d) (e)		154		150		145		144		129		126
Production available for sale (f)				115				108				94

(a) Volume per day metrics are calculated by dividing the volume for the period by the number of calendar days in the period. Gross production is the company’s share of production (excluding purchases) before deduction of the mineral owners’ or governments’ share or both. Net production excludes those shares.

(b) The company’s synthetic oil production volumes were from the company’s share of production volumes in the Syncrude joint venture.

(c) Diluent is natural gas condensate or other light hydrocarbons added to crude bitumen to facilitate transportation to market by pipeline and rail.

(d) Gross production of natural gas includes amounts used for internal consumption with the exception of the amounts re-injected.

(e) Net production is gross production less the mineral owners’ or governments’ share or both. Net production reported in the above table is consistent with production quantities in the net proved reserves disclosure.

(f) Includes sales of the company’s share of net production and excludes amounts used for internal consumption.

2020

Total gross production of Kearl bitumen averaged 222,000 barrels per day in 2020 (158,000 barrels Imperial’s share), the highest annual production in the asset’s history, up from 205,000 barrels per day (145,000 barrels Imperial’s share) in 2019. Improved production was mainly due to the addition of supplemental crushing facilities in 2020, partially offset by the balancing of near term production with demand through the advancement and extension of planned turnaround activities.

Gross production of Cold Lake bitumen averaged 132,000 barrels per day in 2020, compared to 140,000 barrels per day in 2019.

During 2020, the company’s share of gross production from Syncrude averaged 69,000 barrels per day, compared to 73,000 barrels per day in 2019.

2019

Total gross production of Kearl bitumen averaged 205,000 barrels per day in 2019 (145,000 barrels Imperial’s share), compared to 206,000 barrels per day (146,000 barrels Imperial’s share) in 2018.

Gross production of Cold Lake bitumen averaged 140,000 barrels per day in 2019, compared to 147,000 barrels per day in 2018.

During 2019, the company’s share of gross production from Syncrude averaged 73,000 barrels per day, up from 62,000 barrels per day in 2018. Higher production was mainly due to the absence of production impacts from the 2018 power disruption.

54

Downstream

millions of Canadian dollars	2020		2019		2018
Net income (loss)		553		961		2,366

2020

Downstream net income was $553 million, compared to $961 million in 2019. Results were negatively impacted by lower margins of about $710 million, and lower sales volumes of about $290 million. These items were offset by lower operating expenses of about $190 million, lower turnaround impacts of about $190 million primarily related to reduced turnaround activity in the current year and improved reliability of about $180 million, primarily due to the absence of the Sarnia fractionation tower incident which occurred in April 2019.

2019

Downstream net income was $961 million, compared to $2,366 million in 2018. Earnings were negatively impacted by lower margins of about $1,130 million, reliability events of about $150 million, including the fractionation tower incident at Sarnia, higher net planned turnaround impacts of about $140 million, and lower sales volumes of about $130 million. These factors were partially offset by favourable foreign exchange impacts of about $90 million.

Refinery utilization
thousands of barrels per day (a)	2020		2019		2018
Total refinery throughput (b)		340		353		392
Refinery capacity at December 31		428		423		423
Utilization of total refinery capacity (percent)		80		83		93
Sales
thousands of barrels per day (a)	2020		2019		2018
Gasolines		215		249		255
Heating, diesel and jet fuels		146		167		183
Heavy fuel oils		20		21		26
Lube oils and other products		40		38		40
Net petroleum product sales		421		475		504

(a) Volume per day metrics are calculated by dividing the volume for the period by the number of calendar days in the period.

(b) Crude oil and feedstocks sent directly to atmospheric distillation units.

2020

Refinery throughput averaged 340,000 barrels per day in 2020, compared to 353,000 barrels per day in 2019. Capacity utilization was 80 percent, compared to 83 percent in 2019. Lower throughput was driven by reduced demand due to the COVID-19 pandemic, partially offset by lower refinery turnaround activity and reliability events, including impacts from the Sarnia fractionation tower incident which occurred in April 2019. Petroleum product sales were 421,000 barrels per day in 2020, compared to 475,000 barrels per day in 2019. Lower petroleum product sales were primarily driven by reduced demand due to the COVID-19 pandemic.

2019

Refinery throughput averaged 353,000 barrels per day in 2019, compared to 392,000 barrels per day in 2018. Capacity utilization was 83 percent, compared to 93 percent in 2018. Reduced throughput was mainly due to higher planned turnaround activities and impacts from the Sarnia fractionation tower incident. Petroleum product sales were 475,000 barrels per day in 2019, compared to 504,000 barrels per day in 2018. Lower petroleum product sales were mainly due to lower refinery throughput.

55

Chemical
millions of Canadian dollars	2020		2019		2018
Net income (loss)		78		108		275
Sales
thousands of tonnes	2020		2019		2018
Polymers and basic chemicals		574		575		602
Intermediate and others		175		157		205
Total petrochemical sales		749		732		807

2020

Chemical net income was $78 million in 2020, compared to $108 million in 2019, primarily reflecting lower margins.

2019

Chemical net income was $108 million in 2019, compared to $275 million in 2018, primarily due to lower margins.

Corporate and other
millions of Canadian dollars	2020			2019			2018
Net income (loss)		(170	)		(217	)		(189	)

2020

Corporate and other expenses were $170 million in 2020, compared to $217 million in 2019.

2019

Corporate and other expenses were $217 million in 2019, compared to $189 million in 2018.

56

Liquidity and capital resources

Sources and uses of cash

millions of Canadian dollars	2020			2019			2018
Cash provided by (used in)
Operating activities		798			4,429			3,922
Investing activities		(802	)		(1,704	)		(1,559	)
Financing activities		(943	)		(1,995	)		(2,570	)
Increase (decrease) in cash and cash equivalents		(947	)		730			(207	)
Cash and cash equivalents at end of year		771			1,718			988

The company issues long-term debt from time to time and maintains a commercial paper program. However, internally generated funds cover the majority of its financial requirements. Cash that may be temporarily surplus to the company’s immediate needs is carefully managed through counterparty quality and investment guidelines to ensure that it is secure and readily available to meet the company’s cash requirements and to optimize returns.

Cash flows from operating activities are highly dependent on crude oil and natural gas prices, as well as petroleum and chemical product margins. In addition, to provide for cash flow in future periods, the company needs to continually find and develop new resources, and continue to develop and apply new technologies to existing fields in order to maintain or increase production.

The company’s financial strength enables it to make large, long-term capital expenditures. Imperial’s portfolio of development opportunities and the complementary nature of its business segments help mitigate the overall risks for the company and its cash flows. Further, due to its financial strength, debt capacity and portfolio of opportunities, the risk associated with delay of any single project would not have a significant impact on the company’s liquidity or ability to generate sufficient cash flows for its operations and fixed commitments.

Funding of registered retirement plans complies with federal and provincial pension regulations, and the company makes contributions to the plans based on an independent actuarial valuation completed at least once every three years depending on funding status. The most recent valuation of the company’s registered retirement plans was completed as at December 31, 2019. The company contributed $195 million to the registered retirement plans in 2020. Future funding requirements are not expected to affect the company’s existing capital investment plans or its ability to pursue new investment opportunities.

Cash flow from operating activities

2020

Cash flow generated from operating activities was $798 million in 2020, compared to $4,429 million in 2019, primarily reflecting lower realizations in the Upstream and unfavourable working capital impacts.

2019

Cash flow generated from operating activities was $4,429 million in 2019, up from $3,922 million in 2018, primarily reflecting favourable working capital effects, partially offset by lower earnings excluding the impact associated with the Alberta corporate income tax rate decrease.

Cash flow from investing activities

2020

Investing activities used net cash of $802 million in 2020, compared to $1,704 million used in 2019, primarily reflecting lower additions to property, plant and equipment.

2019

Investing activities used net cash of $1,704 million in 2019, compared with $1,559 million used in 2018, primarily reflecting higher additions to property, plant and equipment.

57

Cash flow from financing activities

2020

Cash used in financing activities was $943 million in 2020, compared to $1,995 million used in 2019.

At the end of 2020, total debt outstanding was $5,184 million, compared with $5,190 million at the end of 2019.

In response to market conditions, during the second quarter of 2020, the company entered into a $500 million committed short-term line of credit to May 2021, and a $300 million committed short-term line of credit to June 2021. These facilities were in addition to existing credit facilities of $500 million. The company has not drawn on these facilities.

In November 2020, the company extended the maturity date of one of its existing $250 million committed short-term line of credit to November 2021. The company has not drawn on the facility.

The maturity date of the other existing $250 million credit facility remains unchanged at November 2021. The company has not drawn on the facility.

During 2020, the company, under its share purchase program, purchased about 9.8 million shares for $274 million. In response to market conditions, substantial purchases under the share purchase program were suspended on April 1, 2020.

Dividends paid in 2020 were $649 million. The per share dividend paid in 2020 was $0.88, up from $0.82 in 2019.

2019

Cash used in financing activities was $1,995 million in 2019, compared with $2,570 million used in 2018.

At the end of 2019, total debt outstanding was $5,190 million, compared with $5,180 million at the end of 2018.

In September 2019, the company extended the maturity date of its existing long-term, variable-rate, Canadian dollar loan from ExxonMobil to June 30, 2025. All other terms and conditions remained unchanged.

In November 2019, the company increased the capacity of its non-interest bearing, revolving demand loan with ExxonMobil from $75 million to $150 million. The loan represents ExxonMobil’s share of a working capital facility required to support purchasing, marketing, transportation and derivative arrangements for crude oil and diluent products undertaken by Imperial on behalf of ExxonMobil. At December 31, 2019 the company had borrowed $111 million under this arrangement.

In November 2019, the company extended the maturity date of its existing $250 million committed long-term line of credit to November 2021. The company has not drawn on the facility.

In December 2019, the company extended the maturity date of its existing $250 million committed short-term line of credit to December 2020. The company has not drawn on the facility.

During 2019, the company, under its share purchase program, purchased about 38.7 million shares for $1,373 million, including shares purchased from Exxon Mobil Corporation.

Dividends paid in 2019 were $631 million. The per share dividend paid in 2019 was $0.82, up from $0.70 in 2018.

58

Financial strength

The table below shows Imperial’s consolidated debt-to-capital ratio. The data demonstrates the company’s creditworthiness:

percent
At December 31	2020		2019		2018
Debt to capital (a)		19		18		18

(a) Debt, defined as the sum of “Notes and loans payable” and “Long-term debt” (page 76), divided by capital, defined as the sum of debt and “Total shareholders’ equity” (page 76).

Debt-related interest incurred in 2020, before capitalization of interest, was $102 million, compared with $138 million in 2019. The average effective interest rate on the company’s debt was 2.0 percent in 2020, compared with 2.7 percent in 2019.

The company’s financial strength represents a competitive advantage of strategic importance providing it the opportunity to readily access capital markets under the full range of market conditions and enables the company to take on large, long-term capital commitments in the pursuit of maximizing shareholder value.

Commitments

The following table shows the company’s commitments outstanding at December 31, 2020. It combines data from the Consolidated balance sheet and from individual notes to the consolidated financial statements, where appropriate.

			Payment due by period
millions of Canadian dollars	Note reference		2021		2022		2024		2026 and		Total
					to 2023		to 2025		beyond
Long-term debt excluding finance lease obligations (a)		15		-		4,447		-		-		4,447
Operating and finance leases (b)		14		152		174		117		1,080		1,523
Firm capital commitments (c)				133		20		-		162		315
Pension and other postretirement obligations (d)		5		223		121		127		1,692		2,163
Asset retirement obligations (e)		6		60		175		172		1,267		1,674
Other long-term purchase agreements (f)				786		1,610		1,341		8,380		12,117

(a) Long-term debt includes a loan from an affiliated company of ExxonMobil of $4,447 million. The payment by period for the related party long-term loan is estimated based on the right of the related party to cancel the loan on at least 370 days advance written notice.

(b) Minimum commitments for finance and operating leases, both commenced and non-commenced, are shown on an undiscounted basis. Leases are primarily associated with storage tanks, rail cars, marine vessels, transportation facilities and service agreements.

(c) Firm capital commitments represent legally-binding payment obligations to third parties where agreements specifying all significant terms have been executed for the construction and purchase of fixed assets and other permanent investments. In certain cases where the company executes contracts requiring commitments to a work scope, those commitments have been included to the extent that the amounts and timing of payments can be reliably estimated. Firm capital commitments related to capital projects are shown on an undiscounted basis.

(d) The amount by which the benefit obligations exceeded the fair value of fund assets for pension and other postretirement plans at year end. The payments by period include expected contributions to funded pension plans in 2021 and estimated benefit payments for unfunded plans in all years.

(e) Asset retirement obligations represent the fair value of legal obligations associated with site restoration on the retirement of assets with determinable useful lives.

(f) Other long-term purchase agreements are non-cancelable, or cancelable only under certain conditions and long-term commitments other than unconditional purchase obligations. They include primarily transportation services agreements, raw material supply and community benefits agreements.

Unrecognized tax benefits totalling $36 million have not been included in the company’s commitments table because the company does not expect there will be any cash impact from the final settlements as sufficient funds have been deposited with the Canada Revenue Agency. Further details on the unrecognized tax benefits can be found in note 4 to the financial statements on page 88.

59

Litigation and other contingencies

As discussed in note 10 to the consolidated financial statements on page 98, a variety of claims have been made against Imperial and its subsidiaries. Based on a consideration of all relevant facts and circumstances, the company does not believe the ultimate outcome of any currently pending lawsuits against the company will have a material adverse effect on the company’s operations, financial condition, or financial statements taken as a whole.

Additionally, as discussed in note 10, Imperial was contingently liable at December 31, 2020, for guarantees relating to performance under contracts. These guarantees do not have a material effect on the company’s operations, financial condition, or financial statements taken as a whole.

There are no events or uncertainties beyond those already included in reported financial information that would indicate a material change in future operating results or financial condition.

Capital and exploration expenditures

Capital and exploration expenditures represent the combined total of additions at cost to property, plant and equipment; exploration expenses on a before-tax basis from the Consolidated statement of income; and the company’s share of similar costs for equity companies. Capital and exploration expenditures exclude the purchase of carbon emission credits. While Imperial’s management is responsible for all investments and elements of net income, particular focus is placed on managing the controllable aspects of this group of expenditures.

millions of Canadian dollars	2020		2019
Upstream (a)		561		1,248
Downstream		251		484
Chemical		21		34
Corporate and other		41		48
Total		874		1,814
(a) Exploration expenses included.

Total capital and exploration expenditures were $874 million in 2020, a decrease of $940 million from 2019. In response to the challenges presented by the COVID-19 pandemic and decreases in commodity prices, in the first quarter of 2020 the company provided an updated capital outlook of $1.1 billion to $1.2 billion (from original guidance of $1.6 billion to $1.7 billion). In the third quarter of 2020, the company further updated this capital outlook to about $900 million.

For the Upstream segment, capital and exploration expenditures were $561 million in 2020, compared with $1,248 million in 2019. Investments were primarily related to sustaining activity in support of the company’s in-situ and oil sands assets.

For the Downstream segment, capital expenditures were $251 million in 2020, compared with $484 million in 2019. Investments were primarily for enhancing the company’s distribution network as well as refinery projects to improve reliability, feedstock flexibility, energy efficiency and environmental performance.

Total capital and exploration expenditures are expected to be approximately $1.2 billion in 2021. Actual spending could vary depending on the progress of individual projects.

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Market risks and other uncertainties

Crude oil, natural gas, petroleum product and chemical prices have fluctuated in response to changing market forces. The impacts of these price fluctuations on earnings from Upstream, Downstream and Chemical operations have varied.

Imperial’s earnings are influenced by North American crude oil benchmark prices as well as changes in the differentials between these benchmarks and western Canadian prices for light and heavy crude oil. Imperial’s integrated business model reduces the company’s risk from changes in commodity prices. For instance, when light and heavy differentials between North American crude benchmarks and western Canadian prices widen together, Imperial is able to mitigate the impact of widening differentials on the Upstream through integration with Downstream investments in refineries, pipeline commitments and the Edmonton rail terminal. As an example, the negative impact of a widening differential in the Upstream is more than offset by the benefit of lower feedstock costs in the Downstream.

At this time, Imperial is a net consumer of natural gas, used in Imperial’s Upstream operation and refineries. A decrease in the value of natural gas reduces Imperial’s operating expenses, thereby increasing Imperial’s earnings.

In the competitive downstream and chemical environments, earnings are primarily determined by margin capture rather than absolute price levels on products sold. Refining margins are a function of the difference between what a refiner pays for its raw materials (primarily crude oil) and the market prices for the range of products produced. These prices in turn depend on global and regional supply / demand balances, inventory levels, refinery operations, import / export balances and weather.

Industry crude oil and natural gas commodity prices and petroleum and chemical product prices are commonly benchmarked in U.S. dollars. The majority of Imperial’s sales and purchases are related to these industry U.S. dollar benchmarks. As the company records and reports its financial results in Canadian dollars, to the extent that the Canadian / U.S. dollar exchange rate fluctuates, the company’s earnings will be affected.

Imperial is exposed to changes in interest rates, primarily on its debt which carries floating interest rates. The impact of a quarter percent change in interest rates affecting Imperial’s debt would not be material to earnings or cash flow. Imperial has access to significant sources of long-term and short-term liquidity. Internally generated funds are expected to cover the majority of financial requirements, supplemented by long-term and short-term debt as needed.

The company’s potential exposure to commodity price and margin, and Canadian / U.S. dollar exchange rate fluctuations is summarized in the earnings sensitivities table, which shows the estimated annual effect, under current conditions, on the company’s after-tax net income. For any given period, the extent of actual benefit or detriment will be dependent on the price movements of individual types of crude oil and products, production and sales volumes, transportation capacity, costs and egress methods, and other factors. Accordingly, changes in benchmark prices for crude oil and crude oil differentials, and other factors listed in the table following, only provide broad indicators of changes in the earnings experienced in any particular period.

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Earnings sensitivities (a)

millions of Canadian dollars, after-tax
One dollar (U.S.) per barrel increase (decrease) in crude oil prices	+ (-)	110
One dollar (U.S.) per barrel increase (decrease) in light and heavy crude price differentials (b)	+ (-)	40
Ten cents per thousand cubic feet decrease (increase) in natural gas prices	+ (-)	9
One dollar (U.S.) per barrel increase (decrease) in refining 2-1-1 margins (c)	+ (-)	140
One cent (U.S.) per pound increase (decrease) in sales margins for polyethylene	+ (-)	7
One cent decrease (increase) in the value of the Canadian dollar versus the U.S. dollar	+ (-)	90

(a) Each sensitivity calculation shows the impact on net income resulting from a change in one factor, after-tax and royalties and holding all other factors constant. These sensitivities have been updated to reflect current market conditions. They may not apply proportionately to larger fluctuations.

(b) Light and heavy crude differentials represent the difference between WTI benchmark prices and western Canadian prices for light and heavy crudes.

(c) The 2-1-1 crack spread is an indicator of the refining margin generated by converting two barrels of crude oil into one barrel of gasoline and one barrel of diesel.

The demand for crude oil, natural gas, petroleum products and petrochemical products are generally linked closely with economic growth. The occurrence of recessions or other periods of low or negative economic growth, such as impacts due to the COVID-19 pandemic, will typically have a direct adverse impact on the company’s financial results. Although price levels of crude oil and natural gas may rise and fall significantly over the short to medium-term due to global economic conditions, political events, decisions by OPEC, governments and other factors, industry economics over the long-term will continue to be driven by market supply and demand. Accordingly, the company evaluates the viability of its major investments over a range of prices.

The global energy markets can give rise to extended periods in which market conditions are adverse to one or more of the company’s businesses. Such conditions, along with the capital-intensive nature of the industry and very long lead times associated with many of the company’s projects, underscore the importance of maintaining a strong financial position. Management views the company’s financial strength as a competitive advantage.

In general, segment results are not dependent on the ability to sell and / or purchase products to / from other segments. Where such intersegment sales take place, they are the result of efficiencies and competitive advantages from integrated business segments and refinery and chemical complexes. The company’s intersegment sales include crude oil produced by the Upstream and sold to the Downstream, as well as sales between refineries and the chemical plant related to raw materials, feedstocks and finished products. All intersegment sales are at market based prices. Refer to Note 3 for additional information on intersegment revenue.

The company has an active asset management program in which underperforming assets are either improved to acceptable levels or considered for divestment. The asset management program includes a disciplined, regular review to ensure that assets are contributing to the company’s strategic objectives.

Risk management

The company’s size, strong capital structure and the complementary nature of the Upstream, Downstream and Chemical businesses reduce the company’s enterprise-wide risk from changes in commodity prices and currency exchange rates. In addition, the company may use commodity-based contracts, including derivatives, to manage commodity price risk and for trading purposes. The company’s derivatives are not accounted for under hedge accounting. Credit risk associated with the company’s derivative position is mitigated by several factors, including the use of derivative clearing exchanges and the quality of and financial limits placed on derivative counterparties. No material market or credit risks to the company’s financial position, results of operations or liquidity exist as a result of the derivatives described in note 7 on page 95. The company maintains a system of controls that includes the authorization, reporting and monitoring of derivative activity.

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Critical accounting estimates

The company’s financial statements have been prepared in accordance with United States Generally Accepted Accounting Principles (U.S. GAAP). U.S. GAAP requires management to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. The company’s accounting and financial reporting fairly reflect its business model involving exploration for, and production of, crude oil and natural gas and manufacture, trade, transport and sale of crude oil, natural gas, petroleum products, petrochemicals and a variety of specialty products. Imperial does not use financing structures for the purpose of altering accounting outcomes or removing debt from the balance sheet. The company’s significant accounting policies are summarized in note 1 to the consolidated financial statements on page 79.

Oil and gas reserves

Evaluations of oil and natural gas reserves are important to the effective management of upstream assets. They are an integral part of investment decisions about oil and gas properties such as whether development should proceed.

The estimation of proved reserve volumes, which is based on the requirement of reasonable certainty, is an ongoing process based on rigorous technical evaluations, commercial and market assessments, detailed analysis of well information such as flow rates and reservoir pressures, and development and production costs, among other factors. The estimation of proved reserves is controlled by the company through long-standing approval guidelines. Reserves changes are made within a well-established, disciplined process driven by qualified geoscience and engineering professionals, assisted by the reserves management group which has significant technical experience, culminating in reviews with and approval by senior management and the company’s board of directors. Notably, the company does not use specific quantitative reserves targets to determine compensation. Key features of the reserves estimation process are covered in “Disclosure of reserves” in Item 1.

Oil and natural gas reserves include both proved and unproved reserves.

· Proved oil and natural gas reserves are determined in accordance with U.S. Securities and Exchange Commission (SEC) requirements. Proved reserves are those quantities of oil and natural gas which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible under existing economic and operating conditions and government regulations. Proved reserves are determined using the average of first-day-of-the-month oil and natural gas prices during the reporting year.

Proved reserves can be further subdivided into developed and undeveloped reserves. Proved developed reserves include amounts which are expected to be recovered through existing wells and facilities with existing equipment and operating methods. Proved undeveloped reserves include amounts expected to be recovered from new wells on undrilled proved acreage or from existing wells where a relatively major expenditure is required for completion. Proved undeveloped reserves are recognized only if a development plan has been adopted indicating that the reserves are scheduled to be drilled within five years, unless specific circumstances support a longer period of time.

The percentage of proved developed reserves was 75 percent of total proved reserves at year-end 2020, a reduction from 89 percent in 2019. Although the company is reasonably certain that proved reserves will be produced, the timing and amount recovered can be affected by a number of factors including completion and optimization of development projects, reservoir performance, regulatory approvals, government policies, consumer preferences, royalty frameworks and significant changes in oil and gas price levels.

· Unproved reserves are quantities of oil and natural gas with less than reasonable certainty of recoverability and include probable reserves. Probable reserves are reserves that, together with proved reserves, are as likely as not to be recovered.

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Revisions can include upward or downward changes in previously estimated volumes of proved reserves for existing fields due to the evaluation or re-evaluation of already available geologic, reservoir or production data; new geologic, reservoir or production data; or changes in the average of first-day-of-the-month oil and natural gas prices and / or costs that are used in the estimation of reserves. Revisions can also result from significant changes in either development strategy or production equipment / facility capacity.

At year-end 2016, downward revisions of proved developed and undeveloped bitumen reserves were a result of low prices. The entire 2.5 billion barrels of bitumen at Kearl and approximately 0.2 billion barrels of bitumen at Cold Lake no longer qualified as proved reserves under the U.S. Securities and Exchange Commission definition of proved reserves.

At year-end 2017, an additional 0.3 billion barrels of bitumen at Kearl and Cold Lake qualified as proved reserves resulting from improved prices in the year.

As a result of improved prices in 2018, an additional 2.3 billion barrels of bitumen at Kearl qualified as proved reserves at year-end 2018.

In 2019, downward revisions to proved bitumen reserves were driven by technical and development plan updates at Kearl, resulting in a decrease of 0.2 billion barrels, partially offset by an increase of 0.1 billion barrels at Cold Lake associated with an end of field life change driven by pricing. Downward revisions to proved synthetic oil reserves were a result of higher royalty obligations at Syncrude driven by pricing. Changes to liquids and natural gas proved reserves were the result of updated development plans at the Montney and Duvernay unconventional assets and the divestment of conventional properties.

In 2020, downward revisions of proved bitumen reserves were a result of low prices. The 2.2 billion barrels of bitumen at Kearl and 0.6 billion barrels of bitumen at Cold Lake no longer qualified as proved reserves under the U.S. Securities and Exchange Commission definition of proved reserves. Downward revisions to proved synthetic oil reserves were a result of lower prices, offset by the addition of proved undeveloped reserves associated with future development at Syncrude. Changes to the liquids and natural gas proved reserves were the result of updated development plans at the Montney and Duvernay unconventional assets and the divestment of conventional properties.

Under the terms of certain contractual arrangements or government royalty regimes, lower prices can also increase proved reserves attributable to Imperial. The company does not expect its operations to be affected by the downward revision of reported proved reserves as disclosed under the U.S. Securities and Exchange Commission (SEC) definition.

Unit-of-production depreciation

The calculation of unit-of-production depreciation is a critical accounting estimate that measures the depreciation of upstream assets. Oil and natural gas reserve volumes are used as the basis to calculate unit-of-production depreciation rates for most upstream assets. Depreciation is calculated by taking the ratio of asset cost to total proved reserves or proved developed reserves applied to the actual cost of production. The volumes produced and asset cost are known, while proved reserves are based on estimates that are subject to some variability.

In the event that the unit-of-production method does not result in an equitable allocation of cost over the economic life of an upstream asset, an alternative method is used. The straight-line method is used in limited situations where the expected life of the asset does not reasonably correlate with that of the underlying reserves. For example, certain assets used in the production of oil and natural gas have a shorter life than the reserves, and as such, the company uses straight-line depreciation to ensure the asset is fully depreciated by the end of its useful life.

To the extent that proved reserves for a property are substantially de-booked and that property continues to produce such that the resulting depreciation charge does not result in an equitable allocation of cost over the expected life, assets will be depreciated using a unit-of-production method based on reserves determined at the most recent SEC price which results in a more meaningful quantity of proved reserves, appropriately adjusted for production and technical changes. This approach was applied in 2017 and 2018, with the corresponding effect on depreciation expense being immaterial when compared to prior periods. This approach will also be applied in 2021 and the effect of this approach is anticipated to be immaterial compared to 2020. For 2019 and 2020, all properties had sufficient reserves at their relevant SEC prices which enabled equitable allocation of cost over the economic lives of the Upstream assets.

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Impact of oil and gas reserves and prices and margins on testing for impairment

The company tests assets or groups of assets for recoverability on an ongoing basis whenever events or changes in circumstances indicate the carrying amounts may not be recoverable. Among the events or changes in circumstances which could indicate that the carrying value of an asset or asset group may not be recoverable are the following:

· A significant decrease in the market price of a long-lived asset;

· A significant adverse change in the extent or manner in which an asset is being used or in its physical condition including a significant decrease in the company’s current and projected reserve volumes;

· A significant adverse change in legal factors or in the business climate that could affect the value, including a significant adverse action or assessment by a regulator;

· An accumulation of project costs significantly in excess of the amount originally expected;

· A current-period operating loss combined with a history and forecast of operating or cash flow losses; and

· A current expectation that, more likely than not, a long-lived asset will be sold or otherwise disposed of significantly before the end of its previously estimated useful life.

Asset valuation analysis, profitability reviews and other periodic control processes assist Imperial in assessing whether events or changes in circumstances indicate the carrying amounts of any of its assets may not be recoverable.

In general, Imperial does not view temporarily low prices or margins as an indication of impairment. Management believes prices over the long term must be sufficient to generate investments in energy supply to meet global demand. Although prices will occasionally drop significantly, industry prices over the long term will continue to be driven by market supply and demand fundamentals. On the supply side, industry production from mature fields is declining. This is being offset by investments to generate production from new discoveries, field developments and technological and efficiency advancements. OPEC investment activities and production policies also have an impact on world oil supplies. The demand side is largely a function of general economic activities and levels of prosperity. Because the lifespans of the company’s major assets are measured in decades, the value of these assets is predominantly based on long-term views of future commodity prices and development and production costs. During the lifespan of these major assets, the company expects that oil and gas prices will experience significant volatility, and consequently these assets will experience periods of higher earnings and periods of lower earnings, or even losses. In assessing whether events or changes in circumstances indicate the carrying value of an asset may not be recoverable, the company considers recent periods of operating losses in the context of its longer-term view of prices. While near-term prices are subject to wide fluctuations, longer-term price views are more stable and meaningful for purposes of assessing future cash flows.

When the industry experiences a prolonged and deep reduction in commodity prices, the market supply and demand conditions may result in changes to the company’s price or margin assumptions it uses for its capital investment decisions. To the extent those changes result in a significant reduction to its oil prices or natural gas prices or margin ranges, the company may consider that situation, in conjunction with other events or changes in circumstances such as a history of operating losses, as an indicator of potential impairment for certain assets.

In the upstream, the standardized measure of discounted cash flows included in the “Supplemental information on oil and gas exploration and production activities” is required to use prices based on the yearly average of first-day-of-the-month prices. These prices represent discrete points in time and could be higher or lower than the company’s price assumptions which are used for impairment assessments. The company believes the standardized measure does not provide a reliable estimate of the expected future cash flows to be obtained from the development and production of its oil and gas properties or of the value of its oil and gas reserves and therefore does not consider it relevant in determining whether events or changes in circumstances indicate the need for an impairment assessment.

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The company has a robust process to monitor for indicators of potential impairment across its asset groups throughout the year. This process is aligned with the requirements of ASC 360 and ASC 932, and relies on the company’s planning and budgeting cycle. If events or changes in circumstances indicate that the carrying value of an asset may not be recoverable, the company estimates the future undiscounted cash flows of the affected properties to judge the recoverability of carrying amounts. In performing this assessment, assets are grouped at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets. Cash flows used in recoverability assessments are based on the company’s assumptions which are developed in the annual planning and budgeting process, and are consistent with the criteria management uses to evaluate investment opportunities. These evaluations make use of the company’s assumptions of future capital allocations, crude oil and natural gas commodity prices, including price differentials, refining and chemical margins, volumes, development and operating costs, foreign currency exchange rates and inflation rates. Volumes are based on projected field and facility production profiles, throughput, or sales. Management’s estimate of upstream production volumes used for projected cash flows makes use of proved reserve quantities and may include risk-adjusted unproved reserve quantities. Cash flow estimates for impairment testing exclude the effects of derivative instruments.

An asset group is impaired if its estimated future undiscounted cash flows are less than the asset group’s carrying value. Impairments are measured by the amount by which the carrying value exceeds fair value. The assessment of fair value may be based on market prices if an active market exists for the asset group or may require the use of Level 3 inputs and assumptions that are based upon the views of a likely market participant. The principal parameters used to establish fair value can include estimates of acreage values and flowing production metrics from comparable market transactions, market-based estimates of historical cash flow multiples, and discounted cash flows. Inputs and assumptions used in discounted cash flow models include estimates of future production volumes, commodity prices which are consistent with the average of third-party industry experts and government agencies, drilling and development costs, and discount rates.

Significant unproved properties are assessed for impairment individually, and valuation allowances against the capitalized costs would be recorded based on the company’s future development plans, the estimated economic chance of success and the length of time that the company expects to hold the properties. Properties that are not individually significant are aggregated by groups and amortized based on development risk and average holding period.

In 2020, events or changes in circumstances indicated that the carrying amount of certain of the company’s long-lived assets may not be recoverable. Those situations primarily related to the annual review and approval of the company’s business and strategic plan. As part of this process the company assessed its full portfolio of assets which included its unconventional assets. Subsequently the company announced its decision to not further develop a significant portion of its unconventional portfolio in Alberta which resulted in a non-cash, after-tax impairment charge of $1,171 million in the company’s 2020 Upstream results, thereby reducing the carrying value of those assets to fair value. For certain other upstream properties, the undiscounted cash flows were compared to the carrying values and no other adjustments were necessary.

Factors which could put further assets at risk of impairment in the future include reductions in the company’s price outlooks, changes in the allocation of capital, and operating cost increases which exceed the pace of efficiencies or the pace of oil and natural gas price increases. However, due to the inherent difficulty in predicting future commodity prices, and the relationship between industry prices and costs, it is not practicable to reasonably estimate the existence or range of any potential future impairment charges related to the company’s long-lived assets.

Supplemental information regarding oil and gas results of operations, capitalized costs and reserves is provided following the notes to consolidated financial statements.

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Pension benefits

The company’s pension plan is managed in compliance with the requirements of governmental authorities and meets funding levels as determined by independent third-party actuaries. Pension accounting requires explicit assumptions regarding, among others, the discount rate for the benefit obligations, the expected rate of return on plan assets and the long-term rate of future compensation increases. All pension assumptions are reviewed annually by senior management. These assumptions are adjusted only as appropriate to reflect long-term changes in market rates and outlook. The long-term expected rate of return on plan assets of 4.5 percent used in 2020, compares to actual returns of 8.4 percent and 6.9 percent achieved over the last 10- and 20-year periods respectively, ending December 31, 2020. If different assumptions are used, the obligation and expense could increase or decrease as a result. As an indication of the company’s potential exposure to changes in the critical assumptions such as the expected rate of return on plan assets and the discount rate for measuring the benefits obligation, a reduction of 1 percent in the discount rate would increase the plan benefits obligation by approximately $2.2 billion. Similarly, a reduction of 1 percent in the long-term rate of return on plan assets would increase the annual pension expense by approximately $85 million before tax. At Imperial, differences between actual returns on plan assets and the long-term expected returns are not recorded in pension expense in the year the differences occur. Such differences are deferred, along with other actuarial gains and losses, and are amortized into pension expense over the expected average remaining service life of employees. Employee benefits expense represented about 2 percent of total expenses in 2020.

Asset retirement obligations and other environmental liabilities

Legal obligations associated with site restoration on the retirement of assets with determinable useful lives are recognized when they are incurred, which is typically at the time the assets are installed. The obligations are initially measured at fair value and discounted to present value. Over time, the discounted asset retirement obligation amount will be accreted for the change in its present value, with this effect included in production and manufacturing expenses. As payments to settle the obligations occur on an ongoing basis and will continue over the lives of the operating assets, which can exceed 25 years, the discount rate will be adjusted only as appropriate to reflect long-term changes in market rates and outlook. For 2020, the obligations were discounted at 6 percent and the accretion expense was $82 million, before-tax, which was significantly less than 1 percent of total expenses in the year. There would be no material impact on the company’s reported financial results if a different discount rate had been used.

Asset retirement obligations are not recognized for assets with an indeterminate useful life. Asset retirement obligations for these facilities generally become firm at the time the facilities are permanently shut down and dismantled. These obligations may include the costs of asset disposal and additional soil remediation. However, these sites have indeterminate lives based on plans for continued operations, and as such, the fair value of the conditional legal obligations cannot be measured, since it is impossible to estimate the future settlement dates of such obligations. For these and non-operating assets, the company accrues provisions for environmental liabilities when it is probable that obligations have been incurred and the amount can be reasonably estimated.

Asset retirement obligations and other environmental liabilities are based on engineering estimated costs, taking into account the anticipated method and extent of remediation consistent with legal requirements, current technology and the possible use of the location. Since these estimates are specific to the locations involved, there are many individual assumptions underlying the company’s total asset retirement obligations and provision for other environmental liabilities. While these individual assumptions can be subject to change, none of them is individually significant to the company’s reported financial results.

Suspended exploratory well costs

The company continues capitalization of exploratory well costs when the well has found a sufficient quantity of reserves to justify its completion as a producing well and the company is making sufficient progress assessing the reserves and the economic and operating viability of the project. Exploratory well costs not meeting these criteria are charged to expense. The facts and circumstances that support continued capitalization of suspended wells at year-end are disclosed in note 16 to the consolidated financial statements on page 104.

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Tax contingencies

The operations of the company are complex, and related tax interpretations, regulations and legislation are continually changing. Significant management judgment is required in the accounting for income tax contingencies and tax disputes because the outcomes are often difficult to predict.

The benefits of uncertain tax positions that the company has taken or expects to take in its income tax returns are recognized in the financial statements if management concludes that it is more likely than not that the position will be sustained with the tax authorities. For a position that is likely to be sustained, the benefit recognized in the financial statements is measured at the largest amount that is greater than 50 percent likely of being realized. A reserve is established for the difference between a position taken or expected to be taken in an income tax return and the amount recognized in the financial statements. The company’s unrecognized tax benefits and a description of open tax years are summarized in note 4 to the consolidated financial statements starting on page 88.

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Management’s report on internal control over financial reporting

Management, including the company’s chief executive officer and principal accounting officer and principal financial officer, is responsible for establishing and maintaining adequate internal control over the company’s financial reporting. Management conducted an evaluation of the effectiveness of internal control over financial reporting based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on this evaluation, management concluded that Imperial Oil Limited’s internal control over financial reporting was effective as of December 31, 2020.

PricewaterhouseCoopers LLP, an independent registered public accounting firm, audited the effectiveness of the company’s internal control over financial reporting as of December 31, 2020, as stated in their report which is included herein.

/s/ Bradley W. Corson

B.W. Corson

Chairman, president and

chief executive officer

/s/ Daniel E. Lyons

D.E. Lyons

Senior vice-president,

finance and administration, and controller

(Principal accounting officer and principal financial officer)

February 24, 2021

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Report of Independent Registered Public Accounting Firm

To the Board of Directors and Shareholders of Imperial Oil Limited

Opinions on the Financial Statements and Internal Control over Financial Reporting

We have audited the accompanying consolidated balance sheets of Imperial Oil Limited and its subsidiaries (together, the Company) as of December 31, 2020 and 2019, and the related consolidated statements of income, comprehensive income, shareholders’ equity and cash flows for each of the three years in the period ended December 31, 2020, 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, 2020, 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, 2020 and 2019, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2020 in conformity with accounting principles generally accepted in the United States of America. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2020, 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.

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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 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.

Critical Audit Matters

The critical audit matters communicated below are matters arising from the current period audit of the consolidated financial statements that were communicated or required to be communicated to the audit committee and that (i) relate to accounts or disclosures that are material to the consolidated financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.

The impact of proved oil and natural gas reserves on upstream property, plant and equipment, net

As described in Notes 1 and 3 to the consolidated financial statements, the Company’s upstream property, plant and equipment (PP&E), net balance was $28,907 million as of December 31, 2020, and the related depreciation and depletion expense for the year ended December 31, 2020 was $3,084 million. Management uses the successful efforts method to account for its exploration and production activities. Costs incurred to purchase, lease, or otherwise acquire a property (whether unproved or proved) are capitalized when incurred. As disclosed by management, proved oil and natural gas reserve volumes are used as the basis to calculate unit-of-production depreciation rates for most upstream assets. The estimation of proved oil and natural gas reserve volumes is an ongoing process based on technical evaluations, commercial and market assessments, detailed analysis of well information such as flow rates and reservoir pressures, and development and production costs, among other factors. As further disclosed by management, reserves changes are made within a well-established, disciplined process driven by qualified geoscience and engineering professionals, assisted by the reserves management group (together management’s specialists).

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The principal considerations for our determination that performing procedures relating to the impact of proved oil and natural gas reserves on upstream PP&E, net is a critical audit matter are (i) the significant judgment by management, including the use of management’s specialists, when developing the estimates of proved oil and natural gas reserve volumes, which in turn led to (ii) a high degree of auditor judgment, subjectivity, and effort in performing procedures and evaluating the audit evidence related to the data, methods, and assumptions used by management and its specialists in developing the estimates of proved oil and natural gas reserve volumes, and the assumptions related to development and production costs, as applicable.

Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to management’s estimates of proved oil and natural gas reserve volumes. The work of management’s specialists was used in performing the procedures to evaluate the reasonableness of estimates of proved oil and natural gas reserve volumes. As a basis for using this work, management’s specialists’ qualifications were understood and the Company’s relationship with management’s specialists was assessed. The procedures performed also included evaluation of the methods and assumptions used by management’s specialists, tests of the data used by management’s specialists, and an evaluation of management’s specialists’ findings. These procedures also included, among others, testing the completeness and accuracy of the data related to future development and production costs. Additionally, these procedures included evaluating whether the assumptions related to development and production costs were reasonable considering the past performance of the Company and its business and strategic plan, as applicable.

Impairment assessment of certain upstream property, plant and equipment, net

As described in Notes 1 and 3 to the consolidated financial statements, the Company’s upstream property, plant and equipment (PP&E), net balance was $28,907 million as of December 31, 2020. If events or changes in circumstances indicate that the carrying value of an asset may not be recoverable, management estimates the future undiscounted cash flows of the affected properties to judge the recoverability of carrying amounts. In performing this assessment, assets are grouped at the lowest level for which there are identifiable cash flows that are largely independent of cash flows of other groups of assets. These estimates of the future undiscounted cash flows make use of management’s assumptions of future capital allocations, crude oil and natural gas commodity prices including price differentials, upstream production volumes, development and operating costs, foreign currency exchange rates and inflation rates. Management’s estimate of upstream production volumes used for undiscounted cash flows makes use of proved reserve quantities and may include risk-adjusted unproved reserve quantities. As further disclosed by management, estimates of upstream production volumes are made within a well-established, disciplined process driven by qualified geoscience and engineering professionals, assisted by the reserves management group (together management’s specialists). An asset group is impaired if its estimated undiscounted cash flows are less than the asset group’s carrying value. Impairments are measured by the amount by which the carrying value exceeds fair value.

The principal considerations for our determination that performing procedures relating to the impairment assessment of certain upstream PP&E, net is a critical audit matter are (i) the significant judgment by management, including the use of management’s specialists, when developing the estimates of future undiscounted cash flows, which in turn led to (ii) a high degree of auditor judgment, subjectivity, and effort in performing procedures and evaluating management’s significant assumptions related to crude oil and natural gas commodity prices including price differentials, upstream production volumes, and development costs, as applicable.

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Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to management’s upstream PP&E, net impairment assessment over proved properties. These procedures also included, among others (i) testing management’s process for assessing the recoverability of carrying amounts of upstream PP&E, net; (ii) evaluating the appropriateness of the undiscounted cash flow models; (iii) testing the completeness and accuracy of underlying data used in the models; and (iv) evaluating the reasonableness of significant assumptions used by management related to crude oil and natural gas commodity prices including price differentials, upstream production volumes, and development costs. Evaluating the reasonableness of management’s assumptions related to future crude oil and natural gas commodity prices including price differentials involved comparing the assumption against observable market data. Evaluating development costs involved evaluating the reasonableness of the assumptions as compared to the past performance of the Company and its business and strategic plan. The work of management’s specialists was used in performing the procedures to evaluate the reasonableness of upstream production volumes. As a basis for using this work, management’s specialists’ qualifications were understood and the Company’s relationship with management’s specialists was assessed. The procedures performed also included evaluation of the methods and assumptions used by management’s specialists, tests of the data used by management’s specialists, and an evaluation of management’s specialists’ findings.

/s/ PricewaterhouseCoopers LLP

Chartered Professional Accountants

Calgary, Canada

February 24, 2021

We have served as the Company’s auditor since 1934.

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Consolidated statement of income (U.S. GAAP)

millions of Canadian dollars
For the years ended December 31		2020			2019			2018
Revenues and other income
Revenues (a)			22,284			34,002			34,964
Investment and other income (note 9)			104			99			135
Total revenues and other income			22,388			34,101			35,099
Expenses
Exploration (note 16)			13			47			19
Purchases of crude oil and products (b)			13,293			20,946			21,541
Production and manufacturing (c) (note 12)			5,535			6,520			6,121
Selling and general (c)			741			900			908
Federal excise tax and fuel charge			1,736			1,808			1,667
Depreciation and depletion (includes impairments) (note 3, 12)			3,293			1,598			1,555
Non-service pension and postretirement benefit			121			143			107
Financing (d) (note 13)			64			93			108
Total expenses			24,796			32,055			32,026
Income (loss) before income taxes			(2,408	)		2,046			3,073
Income taxes (note 4)			(551	)		(154	)		759
Net income (loss)			(1,857	)		2,200			2,314
Per share information (Canadian dollars)
Net income (loss) per common share - basic (note 11)			(2.53	)		2.88			2.87
Net income (loss) per common share - diluted (note 11)			(2.53	)		2.88			2.86
(a)	Amounts from related parties included in revenues, (note 17).		5,107			8,569			6,383
(b)	Amounts to related parties included in purchases of crude oil and products, (note 17).		2,484			3,305			4,092
(c)	Amounts to related parties included in production and manufacturing, and selling and general expenses, (note 17).		579			628			566
(d)	Amounts to related parties included in financing, (note 17).		61			98			89

The information in the notes to consolidated financial statements is an integral part of these statements.

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Consolidated statement of comprehensive income (U.S. GAAP)

millions of Canadian dollars
For the years ended December 31	2020			2019			2018
Net income (loss)		(1,857	)		2,200			2,314
Other comprehensive income (loss), net of income taxes
Postretirement benefits liability adjustment (excluding amortization)		(212	)		(505	)		158
Amortization of postretirement benefits liability adjustment included in net periodic benefit costs		134			111			140
Total other comprehensive income (loss)		(78	)		(394	)		298
Comprehensive income (loss)		(1,935	)		1,806			2,612

The information in the notes to consolidated financial statements is an integral part of these statements.

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Consolidated balance sheet (U.S. GAAP)

millions of Canadian dollars
At December 31	2020		2019
Assets
Current assets
Cash	771		1,718
Accounts receivable - net (a) (note 2)	1,919		2,699
Inventories of crude oil and products (note 12)	1,161		1,296
Materials, supplies and prepaid expenses	673		616
Total current assets	4,524		6,329
Investments and long-term receivables (b) (note 2)	781		891
Property, plant and equipment,
less accumulated depreciation and depletion	32,034		34,203
Goodwill (note 12)	166		186
Other assets, including intangibles - net	526		578
Total assets	38,031		42,187
Liabilities
Current liabilities
Notes and loans payable (c) (note 13)	227		229
Accounts payable and accrued liabilities (a) (note 12)	3,153		4,260
Income taxes payable	-		106
Total current liabilities	3,380		4,595
Long-term debt (d) (note 15)	4,957		4,961
Other long-term obligations (note 6)	4,100		3,637
Deferred income tax liabilities (note 4)	4,176		4,718
Total liabilities	16,613		17,911
Commitments and contingent liabilities (note 10)
Shareholders’ equity
Common shares at stated value (e) (note 11)	1,357		1,375
Earnings reinvested	22,050		24,812
Accumulated other comprehensive income (loss) (note 18)	(1,989	)	(1,911	)
Total shareholders’ equity	21,418		24,276
Total liabilities and shareholders’ equity	38,031		42,187

(a) Accounts receivable - net included net amounts receivable from related parties of $384 million (2019 – $1,007 million), (note 17).

(b) Investments and long-term receivables included amounts from related parties of $313 million (2019 – $296 million), (note 17).

(c) Notes and loans payable included amounts to related parties of $111 million (2019 – $111 million), (note 17).

(d) Long-term debt included amounts to related parties of $4,447 million (2019 – $4,447 million), (note 17).

(e) Number of common shares authorized and outstanding were 1,100 million and 734 million, respectively (2019 – 1,100 million and 744 million, respectively), (note 11).

The information in the notes to consolidated financial statements is an integral part of these statements.

Approved by the directors.

/s/ Bradley W. Corson   B.W. Corson Chairman, president and chief executive officer /s/ Daniel E. Lyons   D.E. Lyons Senior vice-president, finance and administration, and controller

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Consolidated statement of shareholders’ equity (U.S. GAAP)

millions of Canadian dollars
At December 31	2020		2019		2018
Common shares at stated value (note 11)
At beginning of year	1,375		1,446		1,536
Share purchases at stated value	(18	)	(71	)	(90	)
At end of year	1,357		1,375		1,446
Earnings reinvested
At beginning of year	24,812		24,560		24,714
Net income (loss) for the year	(1,857	)	2,200		2,314
Share purchases in excess of stated value	(256	)	(1,302	)	(1,881	)
Dividends declared	(647	)	(646	)	(587	)
Cumulative effect of accounting change (note 2)	(2	)	-		-
At end of year	22,050		24,812		24,560
Accumulated other comprehensive income (loss) (note 18)
At beginning of year	(1,911	)	(1,517	)	(1,815	)
Other comprehensive income (loss)	(78	)	(394	)	298
At end of year	(1,989	)	(1,911	)	(1,517	)
Shareholders’ equity at end of year	21,418		24,276		24,489

The information in the notes to consolidated financial statements is an integral part of these statements.

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Consolidated statement of cash flows (U.S. GAAP)

millions of Canadian dollars
Inflow (outflow)
For the years ended December 31	2020		2019		2018
Operating activities
Net income (loss)	(1,857	)	2,200		2,314
Adjustments for non-cash items:
Depreciation and depletion (includes impairments) (note 3)	3,273		1,598		1,509
Impairment of intangible assets (note 12)	20		-		46
(Gain) loss on asset sales (note 9)	(35	)	(46	)	(54	)
Deferred income taxes and other	(521	)	(237	)	806
Changes in operating assets and liabilities:
Accounts receivable	780		(170	)	224
Inventories, materials, supplies and prepaid expenses	78		(74	)	(338	)
Income taxes payable	(106	)	41		8
Accounts payable and accrued liabilities	(1,087	)	1,010		(764	)
All other items - net (b)	253		107		171
Cash flows from (used in) operating activities	798		4,429		3,922
Investing activities
Additions to property, plant and equipment	(868	)	(1,636	)	(1,491	)
Proceeds from asset sales (note 9)	82		82		59
Loans to equity companies - net	(16	)	(150	)	(127	)
Cash flows from (used in) investing activities	(802	)	(1,704	)	(1,559	)
Financing activities
Short-term debt - net (note 13)	-		36		-
Reduction in finance lease obligations (note 15)	(20	)	(27	)	(27	)
Dividends paid	(649	)	(631	)	(572	)
Common shares purchased (note 11)	(274	)	(1,373	)	(1,971	)
Cash flows from (used in) financing activities	(943	)	(1,995	)	(2,570	)
Increase (decrease) in cash	(947	)	730		(207	)
Cash at beginning of year	1,718		988		1,195
Cash at end of year (a)	771		1,718		988

(a)  Cash is composed of cash in bank and cash equivalents at cost. Cash equivalents are all highly liquid securities with maturity of three months or less when purchased.

(b)  Included contributions to registered pension plans.	(195	)	(211	)	(203	)
Income taxes (paid) refunded.	(42	)	145		(82	)
Interest (paid), net of capitalization.	(62	)	(91	)	(110	)

Non-cash transactions

In 2019, the company removed $570 million of assets and corresponding liabilities associated with the Government of Ontario’s revocation of its cap and trade legislation. The impact of this removal was not reflected in “Accounts payable and accrued liabilities” and “All other items - net” lines on the Consolidated statement of cash flows as it was not a cash transaction.

The information in the notes to consolidated financial statements is an integral part of these statements.

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Notes to consolidated financial statements

The accompanying consolidated financial statements and the supporting and supplemental material are the responsibility of the management of Imperial Oil Limited.

The company’s principal business is energy, involving the exploration for, and production of, crude oil and natural gas and manufacture, trade, transport and sale of crude oil, natural gas, petroleum products, petrochemicals and a variety of specialty products.

The consolidated financial statements have been prepared in accordance with United States Generally Accepted Accounting Principles (U.S. GAAP), which requires management to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results could differ from these estimates. Prior years’ data has been reclassified in certain cases to conform to the 2020 presentation basis. All amounts are in Canadian dollars unless otherwise indicated.

1. Summary of significant accounting policies

Principles of consolidation

The consolidated financial statements include the accounts of subsidiaries the company controls. Intercompany accounts and transactions are eliminated. Subsidiaries include those companies in which Imperial has both an equity interest and the continuing ability to unilaterally determine strategic, operating, investing and financing policies. Imperial Oil Resources Limited is the only significant subsidiary included in the consolidated financial statements and is wholly owned by Imperial Oil Limited. The consolidated financial statements also include the company’s share of the undivided interest in certain upstream assets, liabilities, revenues and expenses, including its 70.96 percent interest in the Kearl joint venture and its 25 percent interest in the Syncrude joint venture.

Revenues

Imperial generally sells crude oil, natural gas and petroleum and chemical products under short-term agreements at prevailing market prices. In some cases, products may be sold under long-term agreements, with periodic price adjustments to reflect market conditions.

Revenue is recognized at the amount the company expects to receive when the customer has taken control, which is typically when title transfers and the customer has assumed the risks and rewards of ownership. The prices of certain sales are based on price indices that are sometimes not available until the next period. In such cases, estimated realizations are accrued when the sale is recognized, and are finalized when final information is available. Such adjustments to revenue from performance obligations satisfied in previous periods are not significant. Payment for revenue transactions is typically due within 30 days.

Revenues include amounts billed to customers for shipping and handling. Shipping and handling costs incurred up to the point of final storage prior to delivery to a customer are included in “Purchases of crude oil and products” in the Consolidated statement of income. Delivery costs from final storage to customer are recorded as a marketing expense in “Selling and general” expenses. The company does not enter into ongoing arrangements whereby it is required to repurchase its products, nor does the company provide the customer with a right of return.

Future volume delivery obligations that are unsatisfied at the end of the period are expected to be fulfilled through ordinary production or purchases. These performance obligations are based on market prices at the time of the transaction and are fully constrained due to market price volatility.

Purchases and sales of inventory with the same counterparty that are entered into in contemplation of one another are combined and recorded as exchanges measured at the book value of the item sold.

“Revenues” and “Accounts receivable - net” primarily arise from contracts with customers. Long-term receivables are primarily from non-customers. Contract assets are mainly from marketing assistance programs and are not significant. Contract liabilities are mainly customer prepayments, loyalty programs and accruals of expected volume discounts, and are not significant.

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Consumer taxes

Taxes levied on the consumer and collected by the company are excluded from the Consolidated statement of income. These are primarily provincial taxes on motor fuels, the federal goods and services tax and the federal/provincial harmonized sales tax.

Derivative instruments

Imperial may use derivative instruments for trading purposes and to offset exposures associated with commodity prices, currency exchange rates and interest rates that arise from existing assets, liabilities, firm commitments and forecasted transactions. All derivative instruments, except those designated as normal purchase and normal sale, are recorded at fair value. Derivative assets and liabilities with the same counterparty are netted if the right of offset exists and certain other criteria are met. Collateral payables or receivables are netted against derivative assets and derivative liabilities respectively.

Recognition and classification of the gain or loss that results from adjusting a derivative to fair value depends on the purpose for the derivative. The gains and losses resulting from changes in the fair value of derivatives are recorded under “Revenues” or “Purchases of crude oil and products” in the Consolidated statement of income.

Fair value

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. Hierarchy Levels 1, 2 and 3 are terms for the priority of inputs to valuation techniques used to measure fair value. Hierarchy Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Hierarchy Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Hierarchy Level 3 inputs are inputs that are not observable in the market.

Inventories

Inventories are recorded at the lower of current market value or cost. The cost of crude oil and products is determined primarily using the last-in, first-out (LIFO) method. LIFO was selected over the alternative first-in, first-out and average cost methods because it provides a better matching of current costs with the revenues generated in the period.

Inventory costs include expenditures and other charges (including depreciation), directly or indirectly incurred in bringing the inventory to its existing condition and location. Selling and general expenses are reported as period costs and excluded from inventory costs. Inventories of materials and supplies are valued at cost or less.

Investments

The company’s interests in the underlying net assets of affiliates it does not control, but over which it exercises significant influence, are accounted for using the equity method. They are recorded at the original cost of the investment plus Imperial’s share of earnings since the investment was made, less dividends received. Imperial’s share of the after-tax earnings of these investments is included in “Investment and other income” in the Consolidated statement of income. Investments in equity securities, other than consolidated subsidiaries and equity method investments, are measured at fair value, with changes in the fair value recognized in net income. The company uses a modified approach for equity securities that do not have a readily determinable fair value. This modified approach measures investments at cost minus impairment, if any, plus or minus changes resulting from observable price changes in orderly transactions in similar investment of the same issuer. Dividends from these investments are included in “Investment and other income”.

These investments represent interests in non-publicly traded pipeline companies and a rail loading joint venture that facilitate the sale and purchase of liquids in the conduct of company operations. Other parties who also have an equity interest in these investments share in the risks and rewards according to their percentage of ownership. Imperial does not invest in these investments in order to remove liabilities from its balance sheet.

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Property, plant and equipment

Cost basis

Imperial uses the “successful efforts” method to account for its exploration and production activities. Under this method, costs are accumulated on a field-by-field basis. Costs incurred to purchase, lease, or otherwise acquire a property (whether unproved or proved) are capitalized when incurred. Exploratory well costs are carried as an asset when the well has found a sufficient quantity of reserves to justify its completion as a producing well and where the company is making sufficient progress assessing the reserves and the economic and operating viability of the project. Exploratory well costs not meeting these criteria are charged to expense. Other exploratory expenditures, including geophysical costs and annual lease rentals, are expensed as incurred. Development costs, including costs of productive wells and development dry holes, are capitalized.

Maintenance and repair costs, including planned major maintenance, are expensed as incurred. Improvements that increase or prolong the service life or capacity of an asset are capitalized.

Depreciation, depletion and amortization

Depreciation, depletion and amortization are primarily determined under either the unit-of-production method or the straight-line method, which is based on estimated asset service life taking obsolescence into consideration. Depreciation and depletion for assets associated with producing properties begin at the time when production commences on a regular basis. Depreciation for other assets begins when the asset is in place and ready for its intended use. Assets under construction are not depreciated or depleted.

Acquisition costs of proved properties are amortized using a unit-of-production method, computed on the basis of total proved oil and natural gas reserve volumes. Capitalized exploratory drilling and development costs associated with productive depletable extractive properties are amortized using the unit-of-production rates based on the amount of proved developed reserves of oil and gas that are estimated to be recoverable from existing facilities using current operating methods. Under the unit-of-production method, oil and natural gas volumes are considered produced once they have been measured through meters at custody transfer or sales transaction points at the outlet valve on the lease or field storage tank. In the event that the unit-of-production method does not result in an equitable allocation of cost over the economic life of an upstream asset, an alternative method is used. The straight-line method is used in limited situations where the expected life of the asset does not reasonably correlate with that of the underlying reserves. For example, certain assets used in the production of oil and natural gas have a shorter life than the reserves, and as such, the company uses straight-line depreciation to ensure the asset is fully depreciated by the end of its useful life. Investments in mining heavy equipment and certain ore processing plant assets at oil sands mining properties are depreciated on a straight-line basis over a maximum of 15 years and 50 years respectively. Depreciation of other plant and equipment is calculated using the straight-line method, based on the estimated service life of the asset.

To the extent that proved reserves for a property are substantially de-booked and that property continues to produce such that the resulting depreciation charge does not result in an equitable allocation of cost over the expected life, assets will be depreciated using a unit-of-production method based on reserves determined at the most recent SEC price which results in a more meaningful quantity of proved reserves, appropriately adjusted for production and technical changes. This approach was applied in 2017 and 2018, with the corresponding effect on depreciation expense being immaterial when compared to prior periods. This approach will also be applied in 2021 and the effect of this approach is anticipated to be immaterial compared to 2020. For 2019 and 2020, all properties had sufficient reserves at their relevant SEC prices which enabled equitable allocation of cost over the economic lives of the Upstream assets.

Investments in refinery and chemical process manufacturing equipment are generally depreciated on a straight-line basis over a 25-year life. Maintenance and repairs, including planned major maintenance, are expensed as incurred. Major renewals and improvements are capitalized and the assets replaced are retired.

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Impairment assessment

The company tests assets or groups of assets for recoverability on an ongoing basis whenever events or changes in circumstances indicate the carrying amounts may not be recoverable. Among the events or changes in circumstances which could indicate that the carrying value of an asset or asset group may not be recoverable are the following:

● A significant decrease in the market price of a long-lived asset;

● A significant adverse change in the extent or manner in which an asset is being used or in its physical condition including a significant decrease in the company’s current and projected reserve volumes;

● A significant adverse change in legal factors or in the business climate that could affect the value, including a significant adverse action or assessment by a regulator;

● An accumulation of project costs significantly in excess of the amount originally expected;

● A current-period operating loss combined with a history and forecast of operating or cash flow losses; and

● A current expectation that, more likely than not, a long-lived asset will be sold or otherwise disposed of significantly before the end of its previously estimated useful life.

Asset valuation analysis, profitability reviews and other periodic control processes assist Imperial in assessing whether events or changes in circumstances indicate the carrying amounts of any of its assets may not be recoverable.

In general, Imperial does not view temporarily low prices or margins as an indication of impairment. Management believes prices over the long term must be sufficient to generate investments in energy supply to meet global demand. Although prices will occasionally drop significantly, industry prices over the long term will continue to be driven by market supply and demand fundamentals. On the supply side, industry production from mature fields is declining. This is being offset by investments to generate production from new discoveries, field developments and technological and efficiency advancements. OPEC investment activities and production policies also have an impact on world oil supplies. The demand side is largely a function of general economic activities and levels of prosperity. Because the lifespans of the company’s major assets are measured in decades, the value of these assets is predominantly based on long-term views of future commodity prices and development and production costs. During the lifespan of these major assets, the company expects that oil and gas prices will experience significant volatility, and consequently these assets will experience periods of higher earnings and periods of lower earnings, or even losses. In assessing whether events or changes in circumstances indicate the carrying value of an asset may not be recoverable, the company considers recent periods of operating losses in the context of its longer-term view of prices. While near-term prices are subject to wide fluctuations, longer-term price views are more stable and meaningful for purposes of assessing future cash flows.

When the industry experiences a prolonged and deep reduction in commodity prices, the market supply and demand conditions may result in changes to the company’s price or margin assumptions it uses for its capital investment decisions. To the extent those changes result in a significant reduction to its oil prices or natural gas prices or margin ranges, the company may consider that situation, in conjunction with other events or changes in circumstances such as a history of operating losses, as an indicator of potential impairment for certain assets.

In the upstream, the standardized measure of discounted cash flows included in the “Supplemental information on oil and gas exploration and production activities” is required to use prices based on the yearly average of first-day-of-the-month prices. These prices represent discrete points in time and could be higher or lower than the company’s price assumptions which are used for impairment assessments. The company believes the standardized measure does not provide a reliable estimate of the expected future cash flows to be obtained from the development and production of its oil and gas properties or of the value of its oil and gas reserves and therefore does not consider it relevant in determining whether events or changes in circumstances indicate the need for an impairment assessment.

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The company has a robust process to monitor for indicators of potential impairment across its asset groups throughout the year. This process is aligned with the requirements of ASC 360 and ASC 932, and relies on the company’s planning and budgeting cycle. If events or changes in circumstances indicate that the carrying value of an asset may not be recoverable, the company estimates the future undiscounted cash flows of the affected properties to judge the recoverability of carrying amounts. In performing this assessment, assets are grouped at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets. Cash flows used in recoverability assessments are based on the company’s assumptions which are developed in the annual planning and budgeting process, and are consistent with the criteria management uses to evaluate investment opportunities. These evaluations make use of the company’s assumptions of future capital allocations, crude oil and natural gas commodity prices, including price differentials, refining and chemical margins, volumes, development and operating costs, foreign currency exchange rates and inflation rates. Volumes are based on projected field and facility production profiles, throughput, or sales. Management’s estimate of upstream production volumes used for projected cash flows makes use of proved reserve quantities and may include risk-adjusted unproved reserve quantities. Cash flow estimates for impairment testing exclude the effects of derivative instruments.

An asset group is impaired if its estimated future undiscounted cash flows are less than the asset group’s carrying value. Impairments are measured by the amount by which the carrying value exceeds fair value. The assessment of fair value may be based on market prices if an active market exists for the asset group or may require the use of Level 3 inputs and assumptions that are based upon the views of a likely market participant. The principal parameters used to establish fair value can include estimates of acreage values and flowing production metrics from comparable market transactions, market-based estimates of historical cash flow multiples, and discounted cash flows. Inputs and assumptions used in discounted cash flow models include estimates of future production volumes, commodity prices which are consistent with the average of third-party industry experts and government agencies, drilling and development costs, and discount rates.

Significant unproved properties are assessed for impairment individually, and valuation allowances against the capitalized costs would be recorded based on the company’s future development plans, the estimated economic chance of success and the length of time that the company expects to hold the properties. Properties that are not individually significant are aggregated by groups and amortized based on development risk and average holding period.

Gains on sales of proved and unproved properties are only recognized when there is neither uncertainty about the recovery of costs applicable to any interest retained nor any substantial obligation for future performance by the company. Losses on properties sold are recognized when incurred or when the properties are held for sale and the fair value of the properties is less than the carrying value.

Gains or losses on assets sold are included in “Investment and other income” in the Consolidated statement of income.

Interest capitalization

Interest costs incurred to finance expenditures during the construction phase of projects are capitalized as part of property, plant and equipment and are depreciated over the service life of the related assets. The project construction phase commences with the development of the detailed engineering design and ends when the constructed assets are ready for their intended use.

Leases

In situations where assets are leased, right of use assets and lease liabilities are established on the balance sheet for leases with an expected term greater than one year, by discounting the amounts fixed in the lease agreement for the duration of the lease which is reasonably certain, considering the probability of exercising any early termination and extension options. The portion of the fixed payment related to service costs for tankers and finance leases is excluded from the calculation of right of use assets and lease liabilities. Assets leased for nearly all of their useful lives are accounted for as finance leases. In general, leases are capitalized using the company’s incremental borrowing rate. See note 14 to the consolidated financial statements on page 102 for further details.

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Goodwill and other intangible assets

Goodwill is not subject to amortization. Goodwill is tested for impairment annually or more frequently if events or circumstances indicate it might be impaired. Impairment losses are recognized in current period earnings. The evaluation for impairment of goodwill is based on a comparison of the carrying values of goodwill and associated operating assets with the estimated present value of net cash flows from those operating assets.

Intangible assets with determinable useful lives are amortized over the estimated service lives of the assets. Computer software development costs are amortized over a maximum of 15 years and customer lists are amortized over a maximum of 10 years. The amortization is included in “Depreciation and depletion” in the Consolidated statement of income.

Asset retirement obligations and other environmental liabilities

Legal obligations associated with site restoration on the retirement of assets with determinable useful lives are recognized when they are incurred, which is typically at the time the assets are installed. These obligations primarily relate to soil reclamation and remediation, and costs of abandonment and demolition of oil and gas wells and related facilities. The company uses estimates, assumptions and judgments regarding such factors as the existence of a legal obligation for an asset retirement obligation, technical assessments of the assets, estimated amounts and timing of settlements, the credit-adjusted risk-free rate to be used, and inflation rates. The obligations are initially measured at fair value and discounted to present value. A corresponding amount equal to that of the initial obligation is added to the capitalized costs of the related asset. Over time, the discounted asset retirement obligation amount will be accreted for the change in its present value, and the initial capitalized costs will be depreciated over the useful lives of the related assets.

No asset retirement obligations are set up for those manufacturing, distribution, marketing and office facilities with an indeterminate useful life. Asset retirement obligations for these facilities generally become firm at the time the facilities are permanently shut down and dismantled. These obligations may include the costs of asset disposal and additional soil remediation. However, these sites have indeterminate lives based on plans for continued operations, and as such, the fair value of the conditional legal obligations cannot be measured, since it is impossible to estimate the future settlement dates of such obligations. Provision for environmental liabilities of these assets is made when it is probable that obligations have been incurred and the amount can be reasonably estimated. Provisions for environmental liabilities are determined based on engineering estimated costs, taking into account the anticipated method and extent of remediation consistent with legal requirements, current technology and the possible use of the location. These provisions are not reduced by possible recoveries from third parties and projected cash expenditures are not discounted.

Foreign-currency translation

Monetary assets and liabilities in foreign currencies have been translated at the rates of exchange prevailing on December 31. Any exchange gains or losses are recognized in income.

Share-based compensation

The company awards share-based compensation to certain employees in the form of restricted stock units. Compensation expense is measured each reporting period based on the company’s current stock price and is recorded as “Selling and general” expenses in the Consolidated statement of income over the requisite service period of each award. See note 8 to the consolidated financial statements on page 97 for further details.

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2. Accounting changes

Effective January 1, 2020, the company adopted the Financial Accounting Standards Board’s update, Financial Instruments – Credit Losses (Topic 326), as amended. The standard requires a valuation allowance for credit losses be recognized for certain financial assets that reflects the current expected credit loss over the asset’s contractual life. The valuation allowance considers the risk of loss, even if remote, and considers past events, current conditions and reasonable and supportable forecasts. The standard requires this expected loss methodology for trade receivables, certain other financial assets and off-balance-sheet credit exposures. The cumulative effect adjustment related to the adoption of this standard reduced “Earnings reinvested” in Shareholders’ equity by $2 million.

The company is exposed to credit losses primarily through sales of petroleum products, crude oil, natural gas liquids and natural gas, as well as loans to equity companies and joint venture receivables. A counterparty’s ability to pay is assessed through a credit review process that considers payment terms, the counterparty’s established credit rating or the company’s assessment of the counterparty’s credit worthiness, contract terms, and other risks. The company can require prepayment or collateral to mitigate certain credit risks.

The company groups financial assets into portfolios that share similar risk characteristics for purposes of determining the allowance for credit losses and assesses if a significant change in the risk of credit loss has occurred. Among the quantitative and qualitative factors considered are historical financial data, current conditions, industry and country risk, current credit ratings and the quality of third-party guarantees secured from the counterparty. Financial assets are written off in whole, or in part, when practical recovery efforts have been exhausted and no reasonable expectation of recovery exists. Subsequent recoveries of amounts previously written off are recognized in earnings. The company manages receivable portfolios using past due balances as a key credit quality indicator.

The company recognizes a credit allowance for off-balance-sheet credit exposures as a liability on the balance sheet, separate from the allowance for credit losses related to recognized financial assets. These exposures could include unfunded loans to equity companies and financial guarantees that cannot be cancelled unilaterally by the company.

At December 31, 2020, the company’s evaluation of financial assets under Financial Instruments – Credit Losses (Topic 326), as amended, included $1,437 million of accounts receivable, net of allowances of $4 million, and investments and long-term receivables of $323 million. The company has determined that, at this time, no credit allowance is required for investments and long-term receivables, and for off-balance-sheet credit exposures.

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3. Business segments

The company operates its business in Canada. The Upstream, Downstream and Chemical functions best define the operating segments of the business that are reported separately. The factors used to identify these reportable segments are based on the nature of the operations that are undertaken by each segment and the structure of the company’s internal organization. The Upstream segment is organized and operates to explore for and ultimately produce crude oil and its equivalent, and natural gas. The Downstream segment is organized and operates to refine crude oil into petroleum products and to distribute and market these products. The Chemical segment is organized and operates to manufacture and market hydrocarbon-based chemicals and chemical products. The above segmentation has been the long-standing practice of the company and is broadly understood across the petroleum and petrochemical industries.

These functions have been defined as the operating segments of the company because they are the segments (a) that engage in business activities from which revenues are earned and expenses are incurred; (b) whose operating results are regularly reviewed by the company’s chief operating decision maker to make decisions about resources to be allocated to each segment and assess its performance; and (c) for which discrete financial information is available.

Corporate and other includes assets and liabilities that do not specifically relate to business segments – primarily cash, capitalized interest costs, short-term borrowings, long-term debt and liabilities associated with incentive compensation, pension and other postretirement benefit liabilities. Net earnings effects under Corporate and other activities primarily include debt-related financing, corporate governance costs, non-service pension and postretirement benefit costs, share-based incentive compensation expenses and interest income.

Segment accounting policies are the same as those described in the summary of significant accounting policies. Upstream, Downstream and Chemical expenses include amounts allocated from Corporate and other activities. The allocation is based on proportional segment expenses. Transfers of assets between segments are recorded at book amounts. Intersegment sales are made essentially at prevailing market prices. Assets and liabilities that are not identifiable by segment are allocated.

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	Upstream									Downstream									Chemical
millions of Canadian dollars	2020			2019			2018			2020			2019			2018			2020			2019			2018
Revenues and other income
Revenues (a)		6,263			9,479			8,525			15,178			23,591			25,200			843			932			1,239
Intersegment sales		2,527			3,763			2,634			1,480			1,597			1,542			165			229			279
Investment and other income (note 9)		7			17			11			78			47			95			-			-			-
		8,797			13,259			11,170			16,736			25,235			26,837			1,008			1,161			1,518
Expenses
Exploration (note 16)		13			47			19			-			-			-			-			-			-
Purchases of crude oil and products		4,834			6,528			5,833			12,047			19,332			19,326			579			667			831
Production and manufacturing (note 12)		3,852			4,440			4,305			1,468			1,829			1,606			215			251			210
Selling and general		-			-			-			619			774			773			92			86			87
Federal excise tax and fuel charge		-			-			-			1,736			1,808			1,667			-			-			-
Depreciation and depletion (b) (note 12)		3,084			1,374			1,278			166			186			242			19			16			14
Non-service pension and postretirement benefit		-			-			-			-			-			-			-			-			-
Financing (note 13)		3			3			1			-			-			2			-			-			-
Total expenses		11,786			12,392			11,436			16,036			23,929			23,616			905			1,020			1,142
Income (loss) before income taxes		(2,989	)		867			(266	)		700			1,306			3,221			103			141			376
Income tax expense (benefit) (c) (note 4)		(671	)		(481	)		(128	)		147			345			855			25			33			101
Net income (loss)		(2,318	)		1,348			(138	)		553			961			2,366			78			108			275
Cash flows from (used in) operating activities		286			2,423			916			470			1,965			2,749			114			172			354
Capital and exploration expenditures (d)		561			1,248			991			251			484			383			21			34			25
Property, plant and equipment
Cost		47,693			47,050			46,435			6,321			6,123			5,900			975			954			916
Accumulated depreciation and depletion		(18,786	)		(15,889	)		(15,050	)		(3,962	)		(3,830	)		(3,763	)		(699	)		(680	)		(662	)
Net property, plant and equipment (e)		28,907			31,161			31,385			2,359			2,293			2,137			276			274			254
Total assets (f) (g)		31,835			34,554			34,829			4,554			5,179			5,119			408			416			438

	Corporate and other									Eliminations									Consolidated
millions of Canadian dollars	2020			2019			2018			2020			2019			2018			2020			2019			2018
Revenues and other income
Revenues (a)		-			-			-			-			-			-			22,284			34,002			34,964
Intersegment sales		-			-			-			(4,172	)		(5,589	)		(4,455	)		-			-			-
Investment and other income (note 9)		19			35			29			-			-			-			104			99			135
		19			35			29			(4,172	)		(5,589	)		(4,455	)		22,388			34,101			35,099
Expenses
Exploration (note 16)		-			-			-			-			-			-			13			47			19
Purchases of crude oil and products		-			-			-			(4,167	)		(5,581	)		(4,449	)		13,293			20,946			21,541
Production and manufacturing (note 12)		-			-			-			-			-			-			5,535			6,520			6,121
Selling and general		35			48			54			(5	)		(8	)		(6	)		741			900			908
Federal excise tax and fuel charge		-			-			-			-			-			-			1,736			1,808			1,667
Depreciation and depletion (b) (note 12)		24			22			21			-			-			-			3,293			1,598			1,555
Non-service pension and postretirement benefit		121			143			107			-			-			-			121			143			107
Financing (note 13)		61			90			105			-			-			-			64			93			108
Total expenses		241			303			287			(4,172	)		(5,589	)		(4,455	)		24,796			32,055			32,026
Income (loss) before income taxes		(222	)		(268	)		(258	)		-			-			-			(2,408	)		2,046			3,073
Income tax expense (benefit) (c) (note 4)		(52	)		(51	)		(69	)		-			-			-			(551	)		(154	)		759
Net income (loss)		(170	)		(217	)		(189	)		-			-			-			(1,857	)		2,200			2,314
Cash flows from (used in) operating activities		(64	)		(124	)		(116	)		(8	)		(7	)		19			798			4,429			3,922
Capital and exploration expenditures (d)		41			48			28			-			-			-			874			1,814			1,427
Property, plant and equipment
Cost		782			741			693			-			-			-			55,771			54,868			53,944
Accumulated depreciation and depletion		(290	)		(266	)		(244	)		-			-			-			(23,737	)		(20,665	)		(19,719	)
Net property, plant and equipment (e)		492			475			449			-			-			-			32,034			34,203			34,225
Total assets (f) (g)		1,632			2,536			1,548			(398	)		(498	)		(478	)		38,031			42,187			41,456

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(a) Includes export sales to the United States of $4,614 million (2019 - $7,190 million, 2018 - $6,661 million). Export sales to the United States were recorded in all operating segments, with the largest effects in the Upstream segment.

(b) In 2020, the Upstream segment included a non-cash impairment charge of $1,531 million, before-tax, related to the company’s decision not to further develop a significant portion of its unconventional portfolio. In 2018, the Downstream segment included a non-cash impairment charge of $46 million, before-tax, associated with the Government of Ontario’s revocation of its cap and trade legislation.

(c) Segment results in 2019 include a largely non-cash favourable impact of $662 million associated with the Alberta corporate income tax rate decrease, with the largest impact in the Upstream segment.

(d) Capital and exploration expenditures (CAPEX) include exploration expenses, additions to property, plant and equipment, additions to finance leases, additional investments and acquisitions. CAPEX excludes the purchase of carbon emission credits.

(e) Includes property, plant and equipment under construction of $1,874 million (2019 - $2,149 million, 2018 - $1,553 million).

(f) Effective January 1, 2019, Imperial adopted the Financial Accounting Standards Board’s standard, Leases (Topic 842), as amended. As at December 31, 2020, Total assets include operating lease right of use assets of $188 million (2019 - $260 million). An election was made not to restate prior periods. See note 14 for additional details.

(g) In 2019, the company removed $570 million from Total assets and corresponding liabilities in the Downstream segment associated with the Government of Ontario’s revocation of its cap and trade legislation.

4. Income taxes

millions of Canadian dollars	2020		2019		2018
Current income tax expense (benefit) (a)	(27	)	140		(14	)
Deferred income tax expense (benefit) (a)	(524	)	(294	)	773
Total income tax expense (benefit) (a)	(551	)	(154	)	759
Statutory corporate tax rate (percent)	25.0		26.0		26.9
Increase (decrease) resulting from:
Enacted tax rate change (a)	0.1		(31.9	)	-
Other (b)	(2.2	)	(1.6	)	(2.2	)
Effective income tax rate	22.9		(7.5	)	24.7

(a) On June 28, 2019 the Alberta government enacted a 4 percent decrease in the provincial tax rate, from 12 percent to 8 percent by 2022. On December 9, 2020 the Alberta government enacted an accelerated decrease in the province’s general corporate income tax rate from 10 percent to 8 percent, effective July 1, 2020. The cumulative effect of the 2020 legislative tax changes on the company’s financial statements were immaterial.

(b) Other decreases primarily relate to prior year adjustments, re-assessments and disposals.

Deferred income taxes are based on differences between the accounting and tax values of assets and liabilities. These differences in value are re-measured at each year-end using the tax rates and tax laws expected to apply when those differences are realized or settled in the future. Components of deferred income tax liabilities and assets as at December 31 were:

millions of Canadian dollars	2020		2019		2018
Depreciation and amortization	5,319		5,164		5,726
Successful drilling and land acquisitions	363		750		856
Pension and benefits	(534	)	(469	)	(336	)
Asset retirement obligation	(403	)	(336	)	(381	)
Capitalized interest	120		117		121
LIFO inventory valuation	(150	)	(276	)	(107	)
Tax loss carryforwards	(460	)	(141	)	(658	)
Other	(154	)	(161	)	(150	)
Net deferred income tax liabilities	4,101		4,648		5,071

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Unrecognized tax benefits

Unrecognized tax benefits reflect the difference between positions taken or expected to be taken on income tax returns and the amounts recognized in the financial statements.

The following table summarizes the movement in unrecognized tax benefits:

millions of Canadian dollars	2020		2019		2018
Balance as of January 1	35		36		78
Additions based on current year’s tax position	2		-		-
Additions for prior years’ tax positions	-		1		9
Reductions for prior years’ tax positions	-		-		(2	)
Settlements with tax authorities	(1	)	(2	)	(49	)
Balance as of December 31	36		35		36

The unrecognized tax benefit balances shown above are predominately related to tax positions that would reduce the company’s effective tax rate if the positions are favourably resolved. Unfavourable resolution of these tax positions generally would not increase the effective tax rate. The 2020, 2019 and 2018 changes in unrecognized tax benefits did not have a material effect on the company’s net income or cash flow. The company’s tax filings from 2016 to 2020 are subject to examination by the tax authorities. Tax filings from 2007 to 2015 have open objections and therefore are also subject to examination by the tax authorities. The Canada Revenue Agency has made certain adjustments to the company’s filings. Management has evaluated these adjustments and is formally disputing those matters to which the company disagrees. Many of these outstanding matters will not be resolved until after 2021. The impact on unrecognized tax benefits and the company’s effective income tax rate from these matters is not expected to be material.

Resolution of the related tax positions could take many years to complete. It is difficult to predict the timing of resolution for tax positions since such timing is not entirely within the control of the company.

The company classifies interest on income tax related balances as interest expense or interest income and classifies tax related penalties as operating expense.

5. Employee retirement benefits

Retirement benefits, which cover almost all retired employees and their surviving spouses, include pension income and certain health care and life insurance benefits. They are met through funded registered retirement plans and through unfunded supplementary benefits that are paid directly to recipients.

Pension income benefits consist mainly of company-paid defined benefit plans that are based on years of service and final average earnings. The company shares in the cost of health care and life insurance benefits. The company’s benefit obligations are based on the projected benefit method of valuation that includes employee service to date and present compensation levels, as well as a projection of salaries to retirement.

The expense and obligations for both funded and unfunded benefits are determined in accordance with accepted actuarial practices and U.S. GAAP. The process for determining retirement-income expense and related obligations includes making certain long-term assumptions regarding the discount rate, rate of return on plan assets and rate of compensation increases. The obligation and pension expense can vary significantly with changes in the assumptions used to estimate the obligation and the expected return on plan assets.

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The benefit obligations and plan assets associated with the company’s defined benefit plans are measured on December 31.

	Pension benefits			Other postretirement benefits
		2020	2019		2020	2019
Assumptions used to determine benefit obligations at December 31 (percent)
Discount rate		2.50	3.10		2.50	3.10
Long-term rate of compensation increase		4.00	4.50		4.00	4.50

millions of Canadian dollars
Change in projected benefit obligation
Projected benefit obligation at January 1	9,786		8,359		693		582
Current service cost	305		228		24		16
Interest cost	308		324		24		20
Actuarial loss (gain) (a)	811		1,053		152		99
Amendments	-		283		-		-
Benefits paid (b)	(494	)	(461	)	(20	)	(24	)
Projected benefit obligation at December 31	10,716		9,786		873		693
Accumulated benefit obligation at December 31	9,619		8,814

(a) Actuarial loss primarily driven by a decrease in the year-end discount rate from 3.10 percent to 2.50 percent, partially offset by the impact of a reduction in the long-term rate of compensation increase assumption from 4.50 percent to 4.00 percent.

(b) Benefit payments for funded and unfunded plans.

The discount rate for the purpose of calculating year-end postretirement benefits plan liabilities is determined by using the Canadian Institute of Actuaries recommended spot curve for high-quality, long-term Canadian corporate bonds with an average maturity (or duration) approximating that of the liabilities. For the measurement of the accumulated postretirement benefit obligation, the assumed health care cost trend rates start with 5.66 percent in 2021 and gradually decline to 3.57 percent by 2040 and beyond.

	Pension benefits					Other postretirement benefits
millions of Canadian dollars		2020		2019			2020		2019
Change in plan assets
Fair value at January 1		8,599		7,691
Actual return (loss) on plan assets		1,073		1,114
Company contributions		195		211
Benefits paid (a)		(441	)	(417	)
Fair value at December 31		9,426		8,599
Plan assets in excess of (less than) projected benefit obligation at December 31
Funded plans		(641	)	(590	)
Unfunded plans		(649	)	(597	)		(873	)	(693	)
Total (b)		(1,290	)	(1,187	)		(873	)	(693	)

(a) Benefit payments for funded plans only.

(b) Fair value of assets less projected benefit obligation shown above.

Funding of registered retirement plans complies with federal and provincial pension regulations, and the company makes contributions to the plans based on an independent actuarial valuation. In accordance with authoritative guidance relating to the accounting for defined pension and other postretirement benefits plans, the underfunded status of the company’s defined benefit postretirement plans was recorded as a liability in the Consolidated balance sheet, and the changes in that funded status in the year in which the changes occurred was recognized through other comprehensive income.

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	Pension benefits					Other postretirement              benefits
millions of Canadian dollars		2020		2019			2020		2019
Amounts recorded in the Consolidated balance sheet consist of:
Current liabilities		(27	)	(27	)		(31	)	(31	)
Other long-term obligations		(1,263	)	(1,160	)		(842	)	(662	)
Total recorded		(1,290	)	(1,187	)		(873	)	(693	)
Amounts recorded in accumulated other comprehensive income consist of:
Net actuarial loss (gain)		2,232		2,256			272		133
Prior service cost		269		283			-		-
Total recorded in accumulated other comprehensive income, before-tax		2,501		2,539			272		133

The company establishes the long-term expected rate of return on plan assets by developing a forward-looking long-term return assumption for each asset class, taking into account factors such as the expected real return for the specific asset class and inflation. A single, long-term rate of return is then calculated as the weighted average of the target asset allocation percentages and the long-term return assumption for each asset class. The 2020 long-term expected return of 4.5 percent used in the calculations of pension expense compares to an actual rate of return of 8.4 percent and 6.9 percent over the last 10- and 20-year periods respectively, ending December 31, 2020.

	Pension benefits									Other postretirement          benefits
	2020			2019			2018			2020			2019			2018
Assumptions used to determine net periodic benefit cost for years ended December 31 (percent)
Discount rate		3.10			3.90			3.40			3.10			3.90			3.40
Long-term rate of return on funded assets		4.50			4.50			5.00			-			-			-
Long-term rate of compensation increase		4.50			4.50			4.50			4.50			4.50			4.50
millions of Canadian dollars
Components of net periodic benefit cost
Current service cost		305			228			239			24			16			17
Interest cost		308			324			302			24			20			22
Expected return on plan assets		(391	)		(349	)		(402	)		-			-			-
Amortization of prior service cost		14			-			4			-			-			-
Amortization of actuarial loss (gain)		153			149			175			13			(1	)		6
Net periodic benefit cost		389			352			318			61			35			45
Changes in amounts recorded in accumulated other comprehensive income
Net actuarial loss (gain)		129			288			(116	)		152			99			(101	)
Amortization of net actuarial (loss) gain included in net periodic benefit cost		(153	)		(149	)		(175	)		(13	)		1			(6	)
Prior service cost		-			283			-			-			-			-
Amortization of prior service cost included in net periodic benefit cost		(14	)		-			(4	)		-			-			-
Total recorded in other comprehensive income		(38	)		422			(295	)		139			100			(107	)
Total recorded in net periodic benefit cost and other comprehensive income, before-tax		351			774			23			200			135			(62	)

Costs for defined contribution plans, primarily the employee savings plan, were $47 million in 2020 (2019 - $43 million, 2018 - $41 million).

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A summary of the change in accumulated other comprehensive income is shown in the table below:

	Total pension and other postretirement benefits
millions of Canadian dollars	2020			2019			2018
(Charge) credit to other comprehensive income, before-tax		(101	)		(522	)		402
Deferred income tax (charge) credit (note 18)		23			128			(104	)
(Charge) credit to other comprehensive income, after-tax		(78	)		(394	)		298

The company’s investment strategy for pension plan assets reflects a long-term view, a careful assessment of the risks inherent in various asset classes and broad diversification to reduce the risk of the portfolio. Consistent with the long-term nature of the liability, the plan assets are primarily invested in global, market-cap-weighted indexed equity and domestic indexed bond funds to diversify risk while minimizing costs. The balance of the plan assets is largely invested in high-quality corporate and government debt securities. Studies are periodically conducted to establish the preferred target asset allocation. The target asset allocation for equity securities is 30 percent. The target allocation for debt securities is 67 percent. Plan assets for the remaining 3 percent are invested in venture capital partnerships that pursue a strategy of investment in U.S. and international early stage ventures.

The 2020 fair value of the pension plan assets, including the level within the fair value hierarchy, is shown in the table below:

			Fair value measurements at December 31, 2020, using:
millions of Canadian dollars	Total		Level 1		Level 2	Level 3	Net Asset Value
Asset class
Equity securities
Canadian		222						222
Non-Canadian		2,690						2,690
Debt securities - Canadian
Corporate		1,426						1,426
Government		4,825						4,825
Asset backed		-						-
Equities – Venture capital		214						214
Cash		49		41				8
Total plan assets at fair value		9,426		41				9,385

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The 2019 fair value of the pension plan assets, including the level within the fair value hierarchy, is shown in the table below:

			Fair value measurements at December 31, 2019, using:
millions of Canadian dollars	Total		Level 1		Level 2	Level 3	Net Asset Value
Asset class
Equity securities
Canadian		210						210
Non-Canadian		2,449						2,449
Debt securities - Canadian
Corporate		1,379						1,379
Government		4,299						4,299
Asset backed		1						1
Equities – Venture capital		204						204
Cash		57		40				17
Total plan assets at fair value		8,599		40				8,559

A summary of pension plans with accumulated benefit obligation and projected benefit obligation in excess of plan assets is shown in the table below:

	Pension benefits
millions of Canadian dollars	2020		2019
For funded pension plans with accumulated benefit obligation in excess of plan assets: (a)
Accumulated benefit obligation		1,034		942
Fair value of plan assets		954		870
Accumulated benefit obligation less fair value of plan assets		80		72
For funded pension plans with projected benefit obligation in excess of plan assets:
Projected benefit obligation		10,067		9,189
Fair value of plan assets		9,426		8,599
Projected benefit obligation less fair value of plan assets		641		590
For unfunded plans covered by book reserves:
Projected benefit obligation		649		597
Accumulated benefit obligation		565		536

(a) The amounts shown for funded pension plans with accumulated benefit obligation in excess of plan assets represent the company’s proportionate share of a joint venture sponsored pension plan. For the company sponsored funded plan, the fair value of plan assets exceeded the accumulated benefit obligation in both 2020 and 2019.

Cash flows

Benefit payments expected in:

millions of Canadian dollars	Pension benefits		Other postretirement benefits
2021		460		31
2022		460		32
2023		465		32
2024		465		33
2025		465		34
2026 - 2030		2,325		175

In 2021, the company expects to make cash contributions of about $164 million to its pension plans.

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6. Other long-term obligations

millions of Canadian dollars	2020		2019
Employee retirement benefits (a) (note 5)		2,105		1,822
Asset retirement obligations and other environmental liabilities (b) (c)		1,676		1,388
Share-based incentive compensation liabilities (note 8)		45		65
Operating lease liability (note 14)		95		143
Other obligations		179		219
Total other long-term obligations		4,100		3,637

(a) Total recorded employee retirement benefits obligations also included $58 million in current liabilities (2019 – $58 million).

(b) Total asset retirement obligations and other environmental liabilities also included $100 million in current liabilities (2019 – $124 million).

(c) For 2020, the asset retirement obligations were discounted at 6 percent (2019 - 6 percent).

Asset retirement obligations incurred in the current period were Level 3 fair value measurements. The following table summarizes the activity in the liability for asset retirement obligations:

millions of Canadian dollars	2020			2019			2018
Balance as at January 1		1,400			1,417			1,397
Additions (deductions)		265			(23	)		(5	)
Accretion		82			80			85
Settlement		(73	)		(74	)		(60	)
Balance as at December 31		1,674			1,400			1,417

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7. Financial and derivative instruments

Financial instruments

The fair value of the company’s financial instruments is determined by reference to various market data and other appropriate valuation techniques. There are no material differences between the fair value of the company’s financial instruments and the recorded carrying value. At December 31, 2020 and December 31, 2019, the fair value of long-term debt ($4,447 million, excluding finance lease obligations) was primarily a level 2 measurement.

Derivative instruments

The company’s size, strong capital structure and the complementary nature of the Upstream, Downstream and Chemical businesses reduce the company’s enterprise-wide risk from changes in commodity prices and currency exchange rates. In addition, the company uses commodity-based contracts, including derivative instruments to manage commodity price risk. The company does not designate derivative instruments as a hedge for hedge accounting purposes.

Credit risk associated with the company’s derivative position is mitigated by several factors, including the use of derivative clearing exchanges and the quality of and financial limits placed on derivative counterparties. The company maintains a system of controls that includes the authorization, reporting and monitoring of derivative activity.

The net notional long/(short) position of derivative instruments was:

At December 31	2020			2019
Crude (barrels)		(800,000	)		(590,000	)
Products (barrels)		(390,000	)		-

Realized and unrealized gain or (loss) on derivative instruments recognized in the Consolidated statement of income is included in the following lines on a before-tax basis:

millions of Canadian dollars	2020			2019			2018
Revenues		(13	)		(3	)		6
Purchases of crude oil and products		(21	)		(7	)		(24	)
Total		(34	)		(10	)		(18	)

The estimated fair value of derivative instruments, and the related hierarchy level for the fair value measurement is as follows:

millions of Canadian dollars At December 31, 2020
	Fair value								Effect of counterparty netting			Effect of collateral netting			Net carrying value
	Level 1		Level 2		Level 3		Total
Assets
Derivative assets (a)		2		-		-		2		(2	)		-			-
Liabilities
Derivative liabilities (b)		12		-		-		12		(2	)		(10	)		-

(a) Included in the Consolidated balance sheet line: “Materials, supplies and prepaid expenses”.

(b) Included in the Consolidated balance sheet line: “Accounts payable and accrued liabilities”.

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millions of Canadian dollars At December 31, 2019
	Fair value								Effect of		Effect of		Net
									counterparty		collateral		carrying
	Level 1		Level 2		Level 3		Total		netting		netting		value
Assets
Derivative assets (a)		-		-		-		-		-		-		-
Liabilities
Derivative liabilities (b)		2		-		-		2		-		(2)		-

(a) Included in the Consolidated balance sheet line: “Materials, supplies and prepaid expenses”.

(b) Included in the Consolidated balance sheet line: “Accounts payable and accrued liabilities”.

At December 31, 2020, the Company had $5 million of collateral under a master netting arrangement not offset against the derivatives on the Consolidated balance sheet in “Accounts receivable - net”, primarily related to initial margin requirements.

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8. Share-based incentive compensation programs

Share-based incentive compensation programs are designed to retain selected employees, reward them for high performance and promote individual contribution to sustained improvement in the company’s future business performance and shareholder value over the long-term. The nonemployee directors also participate in share-based incentive compensation programs.

Restricted stock units and deferred share units

Under the restricted stock unit plan, each unit entitles the recipient to the conditional right to receive from the company, upon vesting, an amount equal to the value of one common share of the company, based on the five-day average of the closing price of the company’s common shares on the Toronto Stock Exchange on and immediately prior to the vesting dates. For the majority of the units, fifty percent of the units vest on the third anniversary of the grant date, and the remainder vest on the seventh anniversary of the grant date. The company may also issue units to the chairman, president and chief executive officer where 50 percent of the units vest on the fifth anniversary of the grant date and the remainder vest on the tenth anniversary of the grant date, except that for awards granted prior to 2020, the vesting of the tenth anniversary portion is delayed until retirement if later than 10 years.

The deferred share unit plan is made available to nonemployee directors. The nonemployee directors can elect to receive all or part of their eligible directors’ fees in units. The number of units granted is determined at the end of each calendar quarter by dividing the dollar amount of the nonemployee director’s fees for that calendar quarter elected to be received as deferred share units by the average closing price of the company’s shares for the five consecutive trading days (“average closing price”) immediately prior to the last day of the calendar quarter. Additional units are granted to represent dividends on unexercised units, and are calculated by dividing the cash dividend payable on the company’s shares by the average closing price immediately prior to the payment date for that dividend and multiplying the resulting number by the number of deferred share units held by the recipient, as adjusted for any share splits. Deferred share units cannot be exercised until after termination of service as a director, including termination due to death, and must be exercised in their entirety in one election no later than December 31 of the year following the year of termination of service. On the exercise date, the cash value to be received for the units is determined based on the company’s average closing price immediately prior to the date of exercise, as adjusted for any share splits.

All units require settlement by cash payments with the following exceptions. The restricted stock unit program provides that, for units granted to Canadian residents, the recipient may receive one common share of the company per unit or elect to receive the cash payment for the units that vest on the seventh year anniversary of the grant date. For units where 50 percent vest on the fifth anniversary of the grant date and the remainder vest on the tenth anniversary of grant, the recipient may receive one common share of the company per unit or elect to receive cash payment for all that vest.

The company accounts for all units by using the fair-value-based method. The fair value of awards in the form of restricted stock and deferred share units is the market price of the company’s stock. Under this method, compensation expense related to the units of these programs is measured each reporting period based on the company’s current stock price and is recorded in the Consolidated statement of income over the requisite service period of each award.

The following table summarizes information about these units for the year ended December 31, 2020:

	Restricted			Deferred
	stock units			share units
Outstanding at January 1, 2020		4,912,805			170,163
Granted		747,040			34,811
Vested / Exercised		(1,187,630	)		(57,569	)
Forfeited and cancelled		(8,895	)		-
Outstanding at December 31, 2020		4,463,320			147,405

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In 2020, net loss included a favourable impact of $2 million before tax associated with compensation programs (2019 - $34 million expense, 2018 - $32 million expense). Income tax expense associated with compensation programs for the year was $0 million (2019 - $9 million benefit, 2018 - $9 million benefit). Cash payments of $33 million were made for these programs in 2020 (2019 - $50 million, 2018 - $59 million).

As of December 31, 2020, there was $45 million of total before-tax unrecognized compensation expense related to non-vested restricted stock units based on the company’s share price at the end of the current reporting period. The weighted average vesting period of non-vested restricted stock units is 4.1 years. All units under the deferred share programs have vested as of December 31, 2020.

9. Investment and other income

Investment and other income includes gains and losses on asset sales as follows:

millions of Canadian dollars	2020		2019		2018
Proceeds from asset sales		82		82		59
Book value of asset sales		47		36		5
Gain (loss) on asset sales, before-tax		35		46		54
Gain (loss) on asset sales, after-tax		32		42		38

10. Litigation and other contingencies

A variety of claims have been made against Imperial and its subsidiaries in a number of lawsuits. Management has regular litigation reviews, including updates from corporate and outside counsel, to assess the need for accounting recognition or disclosure of these contingencies. The company accrues an undiscounted liability for those contingencies where the incurrence of a loss is probable and the amount can be reasonably estimated. If a range of amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. The company does not record liabilities when the likelihood that the liability has been incurred is probable but the amount cannot be reasonably estimated or when the liability is believed to be only reasonably possible or remote. For contingencies where an unfavourable outcome is reasonably possible and which are significant, the company discloses the nature of the contingency and, where feasible, an estimate of the possible loss. For purposes of the company’s contingency disclosures, “significant” includes material matters, as well as other matters which management believes should be disclosed. Based on a consideration of all relevant facts and circumstances, the company does not believe the ultimate outcome of any currently pending lawsuits against the company will have a material adverse effect on the company’s operations, financial condition, or financial statements taken as a whole.

Additionally, the company has other commitments arising in the normal course of business for operating and capital needs, all of which are expected to be fulfilled with no adverse consequences material to the company’s operations or financial condition. Unconditional purchase obligations, as defined by accounting standards, are those long-term commitments that are non-cancelable or cancelable only under certain conditions and that third parties have used to secure financing for the facilities that will provide the contracted goods and services. The company has not entered into any unconditional purchase obligations.

As a result of the completed sale of Imperial’s remaining company-owned Esso retail sites, the company was contingently liable at December 31, 2020, for guarantees relating to performance under contracts of other third-party obligations totalling $26 million (2019 - $30 million).

At December 31, 2020 the company is contingently liable for up to $62 million, under existing indemnification arrangements, for costs associated with continuing a third-party pipeline project development (2019 - $64 million).

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11. Common shares

thousands of shares At December 31	2020		2019
Authorized		1,100,000		1,100,000
Common shares outstanding		734,077		743,902

The current 12-month limited normal course issuer bid program came into effect on June 29, 2020 and is used primarily to eliminate dilution from shares issued in conjunction with Imperial’s restricted stock unit plan. The program enables the company to purchase up to a maximum of 50,000 common shares, which includes shares purchased under the normal course issuer bid and from Exxon Mobil Corporation concurrent with, but outside of the normal course issuer bid. As in the past, Exxon Mobil Corporation has advised the company that it intends to participate to maintain its ownership percentage at approximately 69.6 percent.

The excess of the purchase cost over the stated value of shares purchased has been recorded as a distribution of earnings reinvested.

The company’s common share activities are summarized below:

	Thousands of			Millions of
	shares			dollars
Balance as at January 1, 2018		831,242			1,536
Issued under employee share-based awards		2			-
Purchases at stated value		(48,679	)		(90	)
Balance as at December 31, 2018		782,565			1,446
Issued under employee share-based awards		1			-
Purchases at stated value		(38,664	)		(71	)
Balance as at December 31, 2019		743,902			1,375
Issued under employee share-based awards		7			-
Purchases at stated value		(9,832	)		(18	)
Balance as at December 31, 2020		734,077			1,357

The following table provides the calculation of basic and diluted earnings per common share and the dividends declared by the company on its outstanding common shares:

	2020			2019		2018
Net income (loss) per common share – basic
Net income (loss) (millions of Canadian dollars)		(1,857	)		2,200		2,314
Weighted average number of common shares outstanding (millions of shares)		735.3			762.7		807.5
Net income (loss) per common share (dollars)		(2.53	)		2.88		2.87
Net income (loss) per common share – diluted
Net income (loss) (millions of Canadian dollars)		(1,857	)		2,200		2,314
Weighted average number of common shares outstanding (millions of shares)		735.3			762.7		807.5
Effect of employee share-based awards (millions of shares) (a)		-			2.3		2.6
Weighted average number of common shares outstanding, assuming dilution (millions of shares)		735.3			765.0		810.1
Net income (loss) per common share (dollars)		(2.53	)		2.88		2.86
Dividends per common share – declared (dollars)		0.88			0.85		0.73

a) For 2020, the Net income (loss) per common share – diluted excludes the effect of 1.9 million employee share-based awards. Share-based awards have the potential to dilute basic earnings per share in the future.

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12. Miscellaneous financial information

In 2020, net loss included an after-tax loss of $19 million (2019 – $22 million loss, 2018 – $16 million gain) attributable to the effect of changes in last-in, first-out (LIFO) inventories. The replacement cost of inventories was estimated to exceed their LIFO carrying values at December 31, 2020 by about $0.8 billion (2019 – $1.2 billion). Inventories of crude oil and products at year-end consisted of the following:

millions of Canadian dollars	2020		2019
Crude oil		630		764
Petroleum products		403		396
Chemical products		55		64
Other		73		72
Total inventories of crude oil and products		1,161		1,296

Research expenditures are mainly spent on developing technologies to improve bitumen recovery, reduce costs and reduce the environmental impact of upstream operations, including technologies to reduce greenhouse gas emissions intensity, supporting environmental and process improvements in the refineries, as well as accessing ExxonMobil’s research worldwide.

The company has scientific research agreements with affiliates of ExxonMobil, which provide for technical and engineering work to be performed by all parties, the exchange of technical information and the assignment and licencing of patents, and patent rights. These agreements provide mutual access to scientific and operating data related to nearly every phase of the petroleum and petrochemical operations of the parties.

Net research and development costs charged to expenses in 2020 were $105 million (2019 – $133 million, 2018 – $110 million). These costs are included in expenses due to the uncertainty of future benefits.

“Accounts payable and accrued liabilities” included accrued taxes other than income taxes of $344 million at December 31, 2020 (2019 – $397 million).

In the second quarter of 2020, the Government of Canada implemented the Canada Emergency Wage Subsidy (CEWS) as part of its COVID-19 Economic Response Plan. The program’s intent is to help sustain employment levels by providing expense relief to companies during the pandemic. The company qualified for these wage subsidies which are recognized throughout the year when received. The relief provided under this program in 2020, about $155  million before tax, including the company’s proportionate share of a joint venture, is recognized as a reduction to expense and is included in the Consolidated statement of income, primarily as part of “Production and manufacturing”.

In the first quarter of 2020, with the change in economic conditions and the reduction in the company’s market capitalization, the company assessed its goodwill balances for impairment and recognized a non-cash goodwill impairment charge of $20 million in the company’s Upstream segment. The goodwill impairment is reflected in “Depreciation and depletion” on the Consolidated statement of income and “Goodwill” on the Consolidated balance sheet. The remaining balance of goodwill is associated with the Downstream segment.

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13. Financing and additional notes and loans payable information

millions of Canadian dollars	2020			2019			2018
Debt-related interest (a)		102			138			133
Capitalized interest		(41	)		(48	)		(28	)
Net interest expense		61			90			105
Other interest		3			3			3
Total financing (b)		64			93			108

(a) Includes related party interest with ExxonMobil.

(b) The weighted average interest rate on short-term borrowings in 2020 was 0.8 percent (2019 – 1.8 percent, 2018 – 1.5 percent). Average effective rate on the long-term borrowings with ExxonMobil in 2020 was 1.4 percent (2019 – 2.2 percent, 2018 – 2.0 percent).

As at December 31, 2020, the company had borrowed $111 million under an arrangement with an affiliated company of ExxonMobil that provides for a non-interest bearing, revolving demand loan from ExxonMobil to the company of up to $150 million. The loan represents ExxonMobil’s share of a working capital facility required to support purchasing, marketing and transportation arrangements for crude oil and diluent products undertaken by Imperial on behalf of ExxonMobil.

In response to market conditions, during the second quarter of 2020, the company entered into a $500 million committed short-term line of credit to May 2021, and a $300 million committed short-term line of credit to June 2021. These facilities were in addition to existing credit facilities of $500 million. The company has not drawn on these facilities.

In November 2020, the company extended the maturity date of one of its existing $250 million committed short-term line of credit to November 2021. The company has not drawn on the facility.

The maturity date of the other existing $250 million credit facility remains unchanged at November 2021. The company has not drawn on the facility.

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14. Leases

The company generally purchases the property, plant and equipment used in operations, but there are situations where assets are leased, primarily storage tanks, rail cars, marine vessels and transportation facilities. Right of use assets and lease liabilities are established on the balance sheet for leases with an expected term greater than one year, by discounting the amounts fixed in the lease agreement for the duration of the lease which is reasonably certain, considering the probability of exercising any early termination and extension options. The portion of the fixed payment related to service costs for tankers and finance leases is excluded from the calculation of right of use assets and lease liabilities. Usually, assets are leased only for a portion of their useful lives and are accounted for as operating leases. In limited situations assets are leased for nearly all of their useful lives and are accounted for as finance leases. In general, leases are capitalized using the company’s incremental borrowing rate.

Variable payments under these lease agreements are not significant. Residual value guarantees, restrictions, or covenants related to leases, and transactions with related parties are also not significant. The company’s activities as a lessor are not material.

The table below summarizes the total lease cost incurred:

	2020				2019
millions of Canadian dollars	Operating leases		Finance leases		Operating leases		Finance leases
Operating lease cost		157				151
Short-term and other (net of sublease rental income)		40				76
Amortization of right of use assets				29				55
Interest on lease liabilities				38				40
Total lease cost		197		67		227		95

The following table summarizes the amounts related to operating leases and finance leases recorded on the Consolidated balance sheet, weighted average remaining lease term and weighted average discount rates applied at December 31:

	2020			2019
millions of Canadian dollars		Operating leases	Finance leases		Operating leases	Finance leases
Right of use assets
Included in Other assets, including intangibles, net		188			260
Included in Property, plant and equipment, net			532			546
Total right of use assets		188	532		260	546
Lease liability due within one year
Included in Accounts payable and accrued liabilities		97	-		115	15
Included in Notes and loans payable			16			18
Long-term lease liability
Included in Other long-term obligations		95	-		143	-
Included in Long-term debt			510			514
Total lease liability		192	526		258	547
Weighted average remaining lease term (years)		4	38		4	40
Weighted average discount rate (percent)		2.5	7.3		2.6	7.5

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The maturity analysis of the company’s lease liabilities as at December 31 are summarized below:

	2020
millions of Canadian dollars, unless noted	Operating leases			Finance leases
Maturity analysis of lease liabilities
2021		96			53
2022		49			52
2023		16			51
2024		12			50
2025		3			47
2026 and beyond		27			1,040
Total lease payments		203			1,293
Discount to present value		(11	)		(767	)
Total lease liability		192			526

In addition to the operating lease liabilities in the table immediately above, at December 31, 2020, additional undiscounted commitments for leases not yet commenced totalled $27 million (2019 - $6 million).

The table below summarizes the cash paid for amounts included in the measurement of lease liabilities and the right of use assets obtained in exchange for new lease liabilities:

	2020				2019
millions of Canadian dollars	Operating leases		Finance leases		Operating leases		Finance leases
Cash paid for amounts included in the measurement of lease liabilities
Cash flows from operating activities		136		15		147		45
Cash flows from financing activities				20				27
Non-cash right of use assets recorded for lease liabilities
For January 1 adoption of Leases (Topic 842)						298
In exchange for lease liabilities during the year		63				104

Disclosures under the previous lease standard – Leases (Topic 840)

Net rental cost incurred under both cancelable and non-cancelable operating leases was $221 million in 2018.

103

15. Long-term debt

millions of Canadian dollars
At December 31	2020	2019
Long-term debt (a)	4,447	4,447
Finance leases (b)	510	514
Total long-term debt	4,957	4,961

(a) Borrowed under an existing agreement with an affiliated company of ExxonMobil that provides for a long-term, variable-rate, Canadian dollar loan from ExxonMobil to the company of up to $7.75 billion at interest equivalent to Canadian market rates. The agreement is effective until June 30, 2025, cancelable if ExxonMobil provides at least 370 days advance written notice.

(b) Finance leases are primarily associated with transportation facilities and services agreements. The average imputed rate was 7.3 percent in 2020 (2019 – 7.5 percent). Total finance lease obligations also include $16 million in current liabilities (2019 - $18 million). Principal payments on finance leases of approximately $15 million on average per year are due in each of the next four years after December 31, 2021.

16. Accounting for suspended exploratory well costs

The company continues capitalization of exploratory well costs when the well has found a sufficient quantity of reserves to justify its completion as a producing well and the company is making sufficient progress assessing the reserves and the economic and operating viability of the project. The term “project” as used in this report can refer to a variety of different activities and does not necessarily have the same meaning as in any government payment transparency reports. At December 31, 2020 the company had no capitalized suspended exploratory well costs (2019 - $0 million, 2018 - $0 million).

Exploration activity often involves drilling multiple wells, over a number of years, to fully evaluate a project. At December 31, 2020 the company had no projects with exploratory wells costs capitalized (2019 - 0, 2018 - 0).

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17. Transactions with related parties

Revenues and expenses of the company also include the results of transactions with affiliated companies of ExxonMobil in the normal course of operations. These were conducted on terms comparable to those which would have been conducted with unrelated parties and primarily consisted of the purchase and sale of crude oil, natural gas, petroleum and chemical products, as well as technical, engineering and research and development costs. Transactions with ExxonMobil also included amounts paid and received in connection with the company’s participation in a number of upstream activities conducted jointly in Canada.

In addition, the company has existing agreements with ExxonMobil:

a)  To provide computer and customer support services to the company and to share common business and operational support services that allow the companies to consolidate duplicate work and systems;

b)  To operate certain western Canada production properties owned by ExxonMobil, as well as provide for the delivery of management, business and technical services to ExxonMobil in Canada. These agreements are designed to provide organizational efficiencies and to reduce costs. No separate legal entities were created from these arrangements. Separate books of account continue to be maintained for the company and ExxonMobil. The company and ExxonMobil retain ownership of their respective assets, and there is no impact on operations or reserves;

c)  To provide for the delivery of management, business and technical services to Syncrude Canada Ltd. by ExxonMobil;

d)  To provide for the option of equal participation in new upstream opportunities; and

e)  To enter into derivative agreements on each other’s behalf.

Certain charges from ExxonMobil have been capitalized; they are not material in the aggregate.

The amounts of purchases and sales by Imperial in 2020, with ExxonMobil, were $2,424 million and $5,101 million respectively (2019 - $3,245 million and $8,552 million respectively).

As at December 31, 2020, the company had outstanding long-term loans of $4,447 million (2019 – $4,447 million) and short-term loans of $111 million (2019 – $111 million) from ExxonMobil (see note 15, Long-term debt, on page 104 and note 13, Financing and additional notes and loans payable information, on page 101 for further details). The amount of financing costs with ExxonMobil were $61 million (2019 - $96 million).

Imperial has other related party transactions not detailed above in note 17, as they are not significant.

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18. Other comprehensive income (loss) information

Changes in accumulated other comprehensive income (loss):

millions of Canadian dollars	2020			2019			2018
Balance at January 1		(1,911	)		(1,517	)		(1,815	)
Postretirement benefits liability adjustment:
Current period change excluding amounts reclassified from accumulated other comprehensive income		(212	)		(505	)		158
Amounts reclassified from accumulated other comprehensive income		134			111			140
Balance at December 31		(1,989	)		(1,911	)		(1,517	)

Amounts reclassified out of accumulated other comprehensive income (loss) - before-tax income (expense):

millions of Canadian dollars	2020			2019			2018
Amortization of postretirement benefits liability adjustment included in net periodic benefit cost (a)		(180	)		(148	)		(185	)

(a) This accumulated other comprehensive income component is included in the computation of net periodic benefit cost (note 5).

Income tax expense (credit) for components of other comprehensive income (loss):

millions of Canadian dollars	2020			2019			2018
Postretirement benefits liability adjustments:
Postretirement benefits liability adjustment (excluding amortization)		(69	)		(165	)		59
Amortization of postretirement benefits liability adjustment included in net periodic benefit cost		46			37			45
Total		(23	)		(128	)		104

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Supplemental information on oil and gas exploration and production activities (unaudited)

The information on pages 107 to 108 excludes items not related to oil and natural gas extraction, such as administrative and general expenses, pipeline operations, gas plant processing fees and gains or losses on asset sales. The company’s 25 percent interest in proved synthetic oil reserves in the Syncrude joint-venture is included as part of the company’s total proved oil and gas reserves and in the calculation of the standardized measure of discounted future cash flows, in accordance with U.S. Securities and Exchange Commission and U.S. Financial Accounting Standards Board rules. Results of operations, costs incurred in property acquisitions, exploration and development activities, and capitalized costs include the company’s share of Kearl, Syncrude and other unproved mineable acreages in the following tables.

Results of operations

millions of Canadian dollars	2020			2019			2018
Sales to customers (a)		2,066			3,927			3,264
Intersegment sales (a) (b)		1,777			2,627			1,964
		3,843			6,554			5,228
Production expenses		3,977			4,467			4,342
Exploration expenses		13			47			19
Depreciation and depletion (includes impairments)		2,857			1,266			1,151
Income taxes		(678	)		(487	)		(92	)
Results of operations		(2,326	)		1,261			(192	)

The amounts reported as costs incurred in property acquisitions, exploration and development activities include both capitalized costs and costs charged to expense during the year. Costs incurred also include new asset retirement obligations established in the current year, as well as increases or decreases to the asset retirement obligation resulting from changes in cost estimates or abandonment date.

Costs incurred in property acquisitions, exploration and development activities

millions of Canadian dollars	2020		2019		2018
Property costs (c)
Proved		-		-		-
Unproved		-		2		-
Exploration costs		13		47		19
Development costs		816		1,176		966
Total costs incurred in property acquisitions, exploration and development activities		829		1,225		985

(a) Sales to customers or intersegment sales do not include the sale of natural gas and natural gas liquids purchased for resale, as well as royalty payments or diluent costs. These items are reported gross in note 3 in “Revenues”, “Intersegment sales” and in “Purchases of crude oil and products”.

(b) Sales of crude oil to consolidated affiliates are at market value, using posted field prices. Sales of natural gas liquids to consolidated affiliates are at prices estimated to be obtainable in a competitive, arm’s-length transaction.

(c) “Property costs” are payments for rights to explore for petroleum and natural gas and for purchased reserves (acquired tangible and intangible assets such as gas plants, production facilities and producing-well costs are included under “producing assets”). “Proved” represents areas where successful drilling has delineated a field capable of production. “Unproved” represents all other areas.

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Capitalized costs

millions of Canadian dollars	2020			2019
Property costs (a)
Proved		2,070			2,236
Unproved		2,462			2,342
Producing assets		39,785			38,975
Incomplete construction		1,518			1,640
Total capitalized cost		45,835			45,193
Accumulated depreciation and depletion		(18,551	)		(15,695	)
Net capitalized costs		27,284			29,498

(a) “Property costs” are payments for rights to explore for petroleum and natural gas and for purchased reserves (acquired tangible and intangible assets such as gas plants, production facilities and producing-well costs are included under “producing assets”). “Proved” represents areas where successful drilling has delineated a field capable of production. “Unproved” represents all other areas.

Standardized measure of discounted future cash flows

As required by the U.S. Financial Accounting Standards Board, the standardized measure of discounted future net cash flows is computed by applying first-day-of-the-month average prices, year-end costs and legislated tax rates and a discount factor of 10 percent to net proved reserves. The standardized measure includes costs for future dismantlement, abandonment and remediation obligations. The company believes the standardized measure does not provide a reliable estimate of the company’s expected future cash flows to be obtained from the development and production of its oil and gas properties or of the value of its proved oil and gas reserves. The standardized measure is prepared on the basis of certain prescribed assumptions, including first-day-of-the-month average prices, which represent discrete points in time and therefore may cause significant variability in cash flows from year to year as prices change.

Standardized measure of discounted future net cash flows related to proved oil and gas reserves

millions of Canadian dollars	2020			2019			2018
Future cash flows		23,911			166,801			174,326
Future production costs		(18,787	)		(127,911	)		(124,316	)
Future development costs		(6,096	)		(24,759	)		(25,507	)
Future income taxes		(155	)		(3,960	)		(5,232	)
Future net cash flows		(1,127	)		10,171			19,271
Annual discount of 10 percent for estimated timing of cash flows		1,065			(4,660	)		(10,537	)
Discounted future cash flows		(62	)		5,511			8,734
Changes in standardized measure of discounted future net cash flows related to proved oil and gas reserves
millions of Canadian dollars	2020			2019			2018
Balance at beginning of year		5,511			8,734			5,136
Changes resulting from:
Sales and transfers of oil and gas produced, net of production costs		(447	)		(2,441	)		(1,117	)
Net changes in prices, development costs and production costs (a)		(8,661	)		(3,117	)		1,395
Extensions, discoveries, additions and improved recovery, less related costs		114			169			259
Development costs incurred during the year		563			1,016			923
Revisions of previous quantity estimates		459			(168	)		2,157
Accretion of discount		623			643			584
Net change in income taxes		1,776			675			(603	)
Net change		(5,573	)		(3,223	)		3,598
Balance at end of year		(62	)		5,511			8,734

(a) SEC rules require the company’s reserves to be calculated on the basis of average first-day-of-the-month oil and natural gas prices during the reporting year. Future net cash flows are determined based on the net proved reserves as outlined in the Net Proved Reserves table.

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Net proved reserves (a)

	Liquids (b)			Natural gas			Synthetic oil			Bitumen			Total oil-equivalent basis (c)
	millions of barrels			billions of cubic feet			millions of barrels			millions of barrels			millions of barrels
Beginning of year 2018		44			641			473			946			1,570
Revisions		4			(66	)		15			2,313			2,321
Improved recovery		-			-			-			-			-
(Sale) purchase of reserves in place		-			-			-			-			-
Discoveries and extensions		16			110			-			-			34
Production		(2	)		(46	)		(22	)		(93	)		(125	)
End of year 2018		62			639			466			3,166			3,800
Revisions		(20	)		(33	)		(27	)		(134	)		(187	)
Improved recovery		-			-			-			-			-
(Sale) purchase of reserves in place		-			(24	)		-			-			(4	)
Discoveries and extensions		4			51			-			-			13
Production		(5	)		(52	)		(24	)		(93	)		(130	)
End of year 2019		41			581			415			2,939			3,492
Revisions		(29	)		(348	)		(79	)		(2,757	)		(2,923	)
Improved recovery		-			-			-			-			-
(Sale) purchase of reserves in place		-			(10	)		-			-			(2	)
Discoveries and extensions		-			-			133			1			134
Production		(5	)		(55	)		(25	)		(102	)		(141	)
End of year 2020		7			168			444			81			560
Net proved developed reserves included above, as of
January 1, 2018		9			282			473			591			1,120
December 31, 2018		24			273			466			2,861			3,396
December 31, 2019		22			291			415			2,609			3,095
December 31, 2020		7			167			311			76			422
Net proved undeveloped reserves included above, as of
January 1, 2018		35			359			-			355			450
December 31, 2018		38			366			-			305			404
December 31, 2019		19			290			-			330			397
December 31, 2020		-			1			133			5			138

(a) Net reserves are the company’s share of reserves after deducting the shares of mineral owners or governments or both. All reported reserves are located in Canada. Reserves of natural gas are calculated at a pressure of 14.73 pounds per square inch at 60°F.

(b) Liquids include crude, condensate and natural gas liquids (NGLs). NGL proved reserves are not material and are therefore included under liquids.

(c) Gas converted to oil-equivalent at six million cubic feet per one thousand barrels.

The information above describes changes during the years and balances of proved oil and gas reserves at year-end 2018, 2019 and 2020. The definitions used are in accordance with the U.S. Securities and Exchange Commission’s Rule 4-10 (a) of Regulation S-X.

Proved oil and natural gas reserves are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible – from a given date forward, from known reservoirs, and under existing economic conditions, operating methods and government regulations – prior to the time at which contracts providing the right to operate expire. In some cases, substantial new investments in additional wells and other facilities will be required to recover these proved reserves.

109

In accordance with SEC rules, the year-end reserves volumes, as well as the reserves change categories shown in the proved reserves tables are required to be calculated on the basis of average prices during the 12-month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period. These reserves quantities were also used in calculating unit-of-production depreciation rates and in calculating the standardized measure of discounted net cash flow.

Revisions can include upward or downward changes in previously estimated volumes of proved reserves for existing fields due to the evaluation or re-evaluation of already available geologic, reservoir or production data; new geologic, reservoir or production data; or changes in the average of first-day-of-the-month oil and natural gas prices and / or costs that are used in the estimation of reserves. Revisions can result from significant changes in either development strategy or production equipment / facility capacity.

At year-end 2016, downward revisions of proved developed and undeveloped bitumen reserves were a result of low prices. The entire 2.5 billion barrels of bitumen at Kearl and approximately 0.2 billion barrels of bitumen at Cold Lake no longer qualified as proved reserves under the U.S. Securities and Exchange Commission definition of proved reserves.

At year-end 2017, an additional 0.3 billion barrels of bitumen at Kearl and Cold Lake qualified as proved reserves resulting from improved prices in the year. Downward revisions of proved developed synthetic oil reserves were a result of higher royalty obligations driven by higher pricing and mine plan updates.

As a result of improved prices in 2018, an additional 2.3 billion barrels of bitumen at Kearl qualified as proved reserves at year-end 2018.

In 2019, downward revisions to proved bitumen reserves were driven by technical and development plan updates at Kearl, resulting in a decrease of 0.2 billion barrels, partially offset by an increase of 0.1 billion barrels at Cold Lake associated with an end of field life change driven by pricing. Downward revisions to proved synthetic oil reserves were a result of higher royalty obligations at Syncrude driven by pricing. Changes to liquids and natural gas proved reserves were the result of updated development plans at the Montney and Duvernay unconventional assets and the divestment of conventional properties.

In 2020, downward revisions of proved bitumen reserves were a result of low prices. The 2.2 billion barrels of bitumen at Kearl and 0.6 billion barrels of bitumen at Cold Lake no longer qualified as proved reserves under the U.S. Securities and Exchange Commission definition of proved reserves. Downward revisions to proved synthetic oil reserves were a result of lower prices, offset by the addition of proved undeveloped reserves associated with future development at Syncrude. Changes to the liquids and natural gas proved reserves were the result of updated development plans at the Montney and Duvernay unconventional assets and the divestment of conventional properties.

Under the terms of certain contractual arrangements or government royalty regimes, lower prices can also increase proved reserves attributable to Imperial. The company does not expect its operations to be affected by the downward revision of reported proved reserves as disclosed under the U.S. Securities and Exchange Commission (SEC) definition.

Net proved reserves are determined by deducting the estimated future share of mineral owners or governments or both. For liquids and natural gas, net proved reserves are based on estimated future royalty rates as of the date the estimate is made incorporating the applicable governments’ oil and gas royalty regimes. For bitumen, net proved reserves are based on the company’s best estimate of average royalty rates over the remaining life of each of the Cold Lake and Kearl fields, and they incorporate the Alberta government’s oil sands royalty regime. For synthetic oil, net proved reserves are based on the company’s best estimate of average royalty rates over the remaining life of the project, and they incorporate the Alberta government’s oil sands royalty regime. In all cases, actual future royalty rates may vary with production, price and costs.

110

Net proved developed reserves are those volumes that are expected to be recovered through existing wells and facilities with existing equipment and operating methods or in which the cost of the required equipment is relatively minor compared to the cost of a new well or facility. Net proved undeveloped reserves are those volumes that are expected to be recovered as a result of future investments to drill new wells, to recomplete existing wells and / or to install facilities to collect and deliver the production from existing and future wells and facilities.

111

Quarterly financial data (a)

	2020												2019
	three months ended												three months ended
	Dec. 31			Sept. 30			June 30			Mar. 31			Dec. 31			Sept. 30			June 30			Mar. 31
Financial data (millions of Canadian dollars)
Total revenues and other income		6,033			5,955			3,710			6,690			8,122			8,736			9,261			7,982
Total expenses		7,496			5,952			4,403			6,945			7,757			8,182			8,532			7,584
Income (loss) before income taxes		(1,463	)		3			(693	)		(255	)		365			554			729			398
Income taxes		(317	)		-			(167	)		(67	)		94			130			(483	)		105
Net income (loss)		(1,146	)		3			(526	)		(188	)		271			424			1,212			293
Net income (loss) (millions of Canadian dollars)
Upstream		(1,192	)		(74	)		(444	)		(608	)		96			209			985			58
Downstream		106			77			(32	)		402			225			221			258			257
Chemical		23			27			7			21			(2	)		38			38			34
Corporate and other		(83	)		(27	)		(57	)		(3	)		(48	)		(44	)		(69	)		(56	)
Net income (loss)		(1,146	)		3			(526	)		(188	)		271			424			1,212			293
Per share information (Canadian dollars)
Net income (loss) per common share - basic (b)		(1.56	)		-			(0.72	)		(0.25	)		0.36			0.56			1.58			0.38
Net income (loss) per common share - diluted (b)		(1.56	)		-			(0.72	)		(0.25	)		0.36			0.56			1.57			0.38
Dividends per common share - declared		0.22			0.22			0.22			0.22			0.22			0.22			0.22			0.19

(a) Quarterly data has not been audited by the company’s independent auditors.

(b) Computed using the average number of shares outstanding during each period. The sum of the four quarters may not add to the full year.

112

Proxy information section

Table of contents	Page
Nominees for director	114
Director nominee tables	114
Majority voting policy	118
Corporate governance disclosure	119
Corporate governance disclosure at a glance	119
Statement of corporate governance practice	120
Composition of our board nominees	120
Tenure of our board nominees	120
Skills and experience of our board members and nominees	121
Independence of our board members and nominees	122
Committee membership of our board	123
Number of meetings	123
Attendance of our board members in 2020	124
Other public company directorships of our board members and nominees	125
Interlocking directorships of our board members	125
Director qualification and selection process	126
Director orientation, education and development	127
Board performance assessment	128
Board and committee structure	128
Director compensation	136
Share ownership guidelines of independent directors and chairman, president and chief executive officer	143
Ethical business conduct	144
Restrictions on insider trading	145
Diversity	145
Shareholder engagement	147
Largest shareholder	148
Transactions with Exxon Mobil Corporation	148
Company executives and executive compensation	150
Named executive officers of the company	150
Other executive officers of the company	151
Letter to shareholders from the executive resources committee on executive compensation	153
Compensation discussion and analysis	156
Overview	157
Compensation program	160
Compensation decision making process and considerations for named executive officers	169
Executive compensation tables and narratives	174
Appendix	181
Appendix A – Board of director and committee charters	181

113

Nominees for director

The director nominee tables on the following pages provide information on the seven nominees proposed for election to the board of directors of the company. All of the nominees, with the exception of M.R. Crocker, are now directors and have been since the dates indicated. D.C. Brownell is a current director and has chosen not to stand for re-election. B.W. Corson was appointed to the board and as president of the company on September 17, 2019 and assumed the additional roles of chairman and chief executive officer on January 1, 2020.

Included in these tables is information relating to the director nominees’ biographies, independence status, expertise, committee memberships, attendance, public board memberships and shareholdings in the company. The information is as of February 16, 2021, the effective date of this circular, unless otherwise indicated.

For more information on our director nominees, please see the Statement of corporate governance practice starting on page 120.

Director nominee tables

	David W. Cornhill Calgary, Alberta, Canada Nonemployee director (independent) Age: 67 Director since: November 29, 2017 Skills and experience: Leadership of large organizations, Operations/technical, Project management, Strategy development, Audit committee financial expert, Financial expertise, Executive compensation, Environment and sustainability, Risk management
	David Cornhill is a director of AltaGas Ltd., and is the chairman of the board of directors of TriSummit Utilities Inc. (formerly AltaGas Canada Inc.), a privately owned corporation. Mr. Cornhill is a founding shareholder of AltaGas (and its predecessors). He was chief executive officer of AltaGas from 1994 to 2016 and served

as interim co-chief executive officer from July to December 2018. Prior to forming AltaGas, Mr. Cornhill served in various capacities with Alberta and Southern Gas Co. Ltd, including vice-president, finance and administration, treasurer and president and chief executive officer. Mr. Cornhill is an experienced leader in the business community and is a strong supporter of communities and community collaboration, investment and enhancement. He is a member of the Ivey Advisory Board at Western University. Mr. Cornhill holds a BSc (Hons.) degree and a MBA degree from Western University, and he was awarded an honorary Doctor of Laws degree by the University in 2015.

Imperial Oil Limited Ownership and Value of Equity (a) (b) (c) (d)
	IMO Common Shares (% of class)	IMO Deferred       Share Units       (DSU)	Total Vested       Equity Holdings       (Common + DSU)	Restricted       Stock Units       (RSU)	Total       Holdings *       (Common + DSU + RSU)
Holdings as at February 16, 2021 (#)	12,500 (<0.01%)	8,184	20,684	11,600	32,284
Total market value as at February 16, 2021 ($)	332,125	217,449	549,574	308,212	857,786
Year over year change (#)	0	4,729	4,729	3,000	7,729

*Meets the necessary share ownership requirements

Board and Committee Membership	Meeting Attendance 2020	Public Company Directorships in the Past Five Years*
Imperial Oil Limited board Audit committee Executive resources committee Public policy and corporate responsibility committee Nominations and corporate governance committee (Chair) Community collaboration and engagement committee	8 of 8 (100%) 4 of 5 (80%) 7 of 7 (100%) 3 of 3 (100%) 4 of 4 (100%) 2 of 2 (100%)	- AltaGas Ltd. (2010 – present) - AltaGas Canada Inc. (2018 – 2020) - Alterra Power Corp. (2008 – 2018) - Painted Pony Energy Ltd. (2015 – 2017)                                             *no public board interlocks

Voting Results of 2020 Annual General Meeting:		Other Positions in the Past Five Years: (position, date office held, and status of employer)
Votes in Favour: 661,610,537 (98.90%)	Votes Withheld: 7,375,061 (1.10%)	- AltaGas Ltd., Chairman of the board (1994 – 2019) - AltaGas Ltd., Interim co-CEO (July to December 2018) - AltaGas Ltd., Chief executive officer (1994 – 2016)

114

	Bradley W. Corson Calgary, Alberta, Canada Non-independent director Age: 59 Director since: September 17, 2019 Skills and experience: Leadership of large organizations, Operations/technical, Project management, Global experience, Strategy development, Financial expertise, Government relations, Executive compensation, Environment and sustainability, Risk management
	Mr. Corson was appointed as president and a director of Imperial Oil Limited on September 17, 2019, and assumed the additional roles of chairman and chief executive officer on January 1, 2020. Mr. Corson has worked for Exxon Mobil Corporation and its predecessor companies since 1983 in various upstream

and downstream assignments, with responsibilities in the United States, Hong Kong and London. In his previous position, Mr. Corson was vice-president of Exxon Mobil Corporation and president of ExxonMobil Upstream Ventures, a division of Exxon Mobil Corporation.

Imperial Oil Limited Ownership and Value of Equity (a) (b) (c) (d)
	IMO Common Shares (% of class)	IMO Deferred       Share Units       (DSU)	Total Vested       Equity Holdings       (Common + DSU)	Restricted       Stock Units       (RSU)	Total       Holdings *       (Common + DSU + RSU)
Holdings as at February 16, 2021 (#)	0	0	0	156,400	156,400
Total market value as at February 16, 2021 ($)	0	0	0	4,155,548	4,155,548
Year over year change (#)	0	0	0	78,200	78,200

*Has three years from appointment as chairman and chief executive officer to meet the necessary share ownership requirements

Board and Committee Membership	Meeting Attendance 2020	Public Company Directorships in the Past Five Years*
Imperial Oil Limited board (Chair) Community collaboration and engagement committee	8 of 8 (100%) 2 of 2 (100%)	None *no public board interlocks

Voting Results of 2020 Annual General Meeting:		Other Positions in the Past Five Years: (position, date office held, and status of employer)
Votes in Favour: 644,504,046 (96.34%)	Votes Withheld: 24,481,552 (3.66%)	- President, Imperial Oil Limited (2019 – present) - President, ExxonMobil Upstream Ventures   (2015 – 2019) (Affiliate)

Matthew R. Crocker Spring, Texas, United States of America Non-independent director Age: 47 Director since: Not currently a member of the board; first nomination for election as director Skills and experience: Leadership of large organizations, Operations/technical, Project management, Global experience, Strategy development, Financial expertise, Government relations, Executive compensation, Environment and sustainability, Risk management

M.R. (Matthew) Crocker is senior vice-president, fuels at ExxonMobil Fuels & Lubricants Company since September, 2020. He is responsible for the downstream global fuels value chain, from crude to customer. Mr. Crocker has also held leadership positions within refining, upstream business development, chemicals

and controllers. Prior to his current position, Mr. Crocker was vice-president, strategy and portfolio management, covering the full scope of ExxonMobil’s upstream business.

Imperial Oil Limited Ownership and Value of Equity (a) (b) (c) (d)
	IMO Common Shares (% of class)	IMO Deferred     Share Units     (DSU)	Total Vested       Equity Holdings       (Common + DSU)	Restricted       Stock Units       (RSU)	Total   Holdings *   (Common + DSU + RSU)
Holdings as at February 16, 2021 (#)	0	0	0	0	0
Total market value as at February 16, 2021 ($)	0	0	0	0	0
Year over year change (#)	0	0	0	0	0

*No share ownership guidelines apply

Board and Committee Membership	Meeting Attendance 2020	Public Company Directorships in the Past Five Years*
Not currently a member of the board or any of its committees	n/a	None                              *no public board interlocks

Voting Results of 2020 Annual General Meeting:		Other Positions in the Past Five Years: (position, date office held, and status of employer)
Votes in Favour: n/a	Votes Withheld: n/a	- Senior vice president, fuels, ExxonMobil Fuels & Lubricants Company   (2020 – Present) (Affiliate) - Vice-president, strategy and portfolio management, ExxonMobil Upstream Business Development Company (2019 – 2020) (Affiliate) - Special assignment, strategy and portfolio management, ExxonMobil Upstream Business Development Company (2019 ) (Affiliate) - Vice-president, intermediates, performance derivatives, ExxonMobil Chemical Company (2017 – 2019) (Affiliate) - Project executive, ExxonMobil Refining & Supply (2016 – 2017) (Affiliate) - Manager, Baytown refinery, Exxon Mobil Corporation (2014 – 2016) (Affiliate)

115

	Krystyna T. Hoeg Toronto, Ontario, Canada Nonemployee director (independent) Age: 71 Director since: May 1, 2008 Skills and experience: Leadership of large organizations, Project management, Global experience, Strategy development, Audit committee financial expert, Financial expertise, Executive compensation, Environment and sustainability, Risk management
	Ms. Hoeg was the president and chief executive officer of Corby Distilleries Limited from 1996 until her retirement in February 2007. She previously held several positions in the finance and controllers functions of Allied Domecq PLC and Hiram Walker & Sons Limited. Prior to that, she spent five years in public practice as a

chartered accountant with the accounting firm Touche Ross. She is currently a director of New Flyer Industries Inc. and is also a director of Samuel, Son & Co. Limited, Revera Inc. and Arterra Wines Canada Inc., privately owned corporations. Ms. Hoeg is a past chair of the board of the Michael Garron Hospital.

Imperial Oil Limited Ownership and Value of Equity (a) (b) (c) (d)
	IMO Common Shares (% of class)	IMO Deferred       Share Units       (DSU)	Total Vested       Equity Holdings       (Common + DSU)	Restricted       Stock Units       (RSU)	Total   Holdings *   (Common + DSU + RSU)
Holdings as at February 16, 2021 (#)	0	46,713	46,713	16,200	62,913
Total market value as at February 16, 2021 ($)	0	1,241,164	1,241,164	430,434	1,671,598
Year over year change (#)	0	7,967	7,967	2,000	9,967

*Meets the necessary share ownership requirements

Board and Committee Membership	Meeting Attendance 2020	Public Company Directorships in the Past Five Years*
Imperial Oil Limited board Audit committee (Chair) Executive resources committee Public policy and corporate responsibility committee Nominations and corporate governance committee Community collaboration and engagement committee	8 of 8 (100%) 5 of 5 (100%) 7 of 7 (100%) 3 of 3 (100%) 4 of 4 (100%) 2 of 2 (100%)	- New Flyer Industries Inc. (2015 – Present) - Sun Life Financial Inc. (2002 – 2016)                                     *no public board interlocks

Voting Results of 2020 Annual General Meeting:		Other Positions in the Past Five Years: (position, date office held, and status of employer)
Votes in Favour: 662,212,058 (98.99%)	Votes Withheld: 6,773,540 (1.01%)	None

	Miranda C. Hubbs Toronto, Ontario, Canada Nonemployee director (independent) Age: 54 Director since: July 26, 2018 Skills and experience: Global experience, Strategy development, Audit committee financial expert, Financial expertise, Information technology/cybersecurity oversight, Executive compensation, Environment and sustainability, Risk management
	Miranda Hubbs is currently an independent director of Nutrien Ltd. and PSP Investments (Public Sector Pension Investment Board). Ms. Hubbs serves as vice-chair of the board of the Canadian Red Cross and is a founding member and national co-chair of the Canadian Red Cross Tiffany Circle—Women Leading Through

Philanthropy. Prior to retirement in 2011, Ms. Hubbs was executive vice president and managing director of McLean Budden. Ms. Hubbs holds a BSc from Western University and an MBA from Schulich School of Business at York University and is a CFA charterholder and a National Association of Corporate Directors Governance Fellow. Ms. Hubbs serves on the ICD Climate Strategy Advisory Board and the Global Risk Institute Sustainable Finance Advisory Committee, holds the Fundamentals of Sustainability Accounting credential from the Sustainability Accounting Standards Board, and has received her CERT Certificate in Cybersecurity Oversight issued by the Software Engineering Institute at Carnegie Mellon University.

Imperial Oil Limited Ownership and Value of Equity (a) (b) (c) (d)
	IMO Common Shares (% of class)	IMO Deferred       Share Units       (DSU)	Total Vested       Equity Holdings       (Common + DSU)	Restricted       Stock Units       (RSU)	Total   Holdings *   (Common + DSU + RSU)
Holdings as at February 16, 2021 (#)	0	10,913	10,913	9,000	19,913
Total market value as at February 16, 2021 ($)	0	289,958	289,958	239,130	529,088
Year over year change (#)	0	6,306	6,306	3,000	9,306

*Meets the necessary share ownership requirements

Board and Committee Membership	Meeting Attendance 2020	Public Company Directorships in the Past Five Years*
Imperial Oil Limited board Audit committee Executive resources committee Public policy and corporate responsibility committee Nominations and corporate governance committee Community collaboration and engagement committee (Chair)	8 of 8 (100%) 5 of 5 (100%) 7 of 7 (100%) 3 of 3 (100%) 4 of 4 (100%) 2 of 2 (100%)	- Nutrien Ltd. (2018 – present) - Agrium Inc. (2016 – 2018) - Spectra Energy Corporation (2015 – 2017) *no public board interlocks

Voting Results of 2020 Annual General Meeting:		Other Positions in the Past Five Years: (position, date office held, and status of employer)
Votes in Favour: 665,197,308 (99.43%)	Votes Withheld: 3,788,290 (0.57%)	None

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	Jack M. Mintz Calgary, Alberta, Canada Nonemployee director (independent) Age: 69 Director since: April 21, 2005 Skills and experience: Global experience, Strategy development, Financial expertise, Government relations, Academic/research, Executive compensation, Environment and sustainability, Risk management
	Dr. Mintz is currently the President’s Fellow at the University of Calgary’s School of Public Policy, a position he has held since July 2015. Dr. Mintz also serves as the national policy advisor for EY (formerly Ernst & Young), Senior Fellow at the C.D. Howe Institute, Distinguished Fellow at the MacDonald-Laurier Institute and board

member of the Canada West Foundation. From 2006 to 2015, Dr. Mintz was the founding Director and Palmer Chair in Public Policy for the University of Calgary, and from 1999 to 2006, he was the president and chief executive officer of the C.D. Howe Institute. Prior to 2007, he also held professor positions at Queen’s University and the Joseph L. Rotman School of Management at the University of Toronto. Dr. Mintz also has published widely in the fields of public economics and fiscal federalism, has been an advisor to governments on fiscal matters, and has frequently published articles in national newspapers and magazines. Dr. Mintz received the Order of Canada in 2015.

Imperial Oil Limited Ownership and Value of Equity (a) (b) (c) (d)
	IMO Common Shares (% of class)	IMO Deferred       Share Units       (DSU)	Total Vested       Equity Holdings       (Common + DSU)	Restricted       Stock Units       (RSU)	Total   Holdings *   (Common + DSU + RSU)
Holdings as at February 16, 2021 (#)	1,000 (<0.01%)	42,205	43,205	16,200	59,405
Total market value as at February 16, 2021 ($)	26,570	1,121,387	1,147,957	430,434	1,578,391
Year over year change (#)	0	7,757	7,757	2,000	9,757

*Meets the necessary share ownership requirements

Board and Committee Membership	Meeting Attendance 2020	Public Company Directorships in the Past Five Years*
Imperial Oil Limited board Audit committee Executive resources committee Public policy and corporate responsibility committee (Chair) Nominations and corporate governance committee Community collaboration and engagement committee	8 of 8 (100%) 5 of 5 (100%) 7 of 7 (100%) 3 of 3 (100%) 4 of 4 (100%) 2 of 2 (100%)	- Morneau Shepell Inc. (2010 – 2020) *no public board interlocks

Voting Results of 2020 Annual General Meeting:		Other Positions in the Past Five Years: (position, date office held, and status of employer)
Votes in Favour: 659,539,737 (98.59%)	Votes Withheld: 9,445,861 (1.41%)	None

David S. Sutherland Scottsdale, Arizona, United States of America Nonemployee director (independent) Age: 71 Director since: April 29, 2010 Skills and experience: Leadership of large organizations, Operations/technical, Global experience, Strategy development, Audit committee financial expert, Financial expertise, Government relations, Executive compensation, Environment and sustainability, Risk management

In July 2007, Mr. Sutherland retired as president and chief executive officer of the former IPSCO, Inc. after spending 30 years with the company and more than five years as president and chief executive officer. Mr. Sutherland is the chairman of the board of United States Steel Corporation and director of GATX Corporation.

Mr. Sutherland is also chairman of Graham Group Ltd., an employee owned corporation and is a director of Steelcraft Inc., a privately owned corporation. Mr. Sutherland is a former chairman of the American Iron and Steel Institute and served as a member of the board of directors of the Steel Manufacturers Association, the International Iron and Steel Institute, the Canadian Steel Producers Association and the National Association of Manufacturers.

Imperial Oil Limited Ownership and Value of Equity (a) (b) (c) (d)
	IMO Common Shares (% of class)	IMO Deferred       Share Units       (DSU)	Total Vested       Equity Holdings       (Common + DSU)	Restricted       Stock Units       (RSU)	Total   Holdings *   (Common + DSU + RSU)
Holdings as at February 16, 2021 (#)	55,000 (<0.01%)	39,388	94,388	16,200	110,588
Total market value as at February 16, 2021 ($)	1,461,350	1,046,539	2,507,889	430,434	2,938,323
Year over year change (#)	0	7,627	7,627	2,000	9,627

*Meets the necessary share ownership requirements

Board and Committee Membership	Meeting Attendance 2020	Public Company Directorships in the Past Five Years*
Imperial Oil Limited board Audit committee Executive resources committee (Chair) Public policy and corporate responsibility committee Nominations and corporate governance committee Community collaboration and engagement committee	8 of 8 (100%) 5 of 5 (100%) 6 of 7 (86%) 3 of 3 (100%) 4 of 4 (100%) 2 of 2 (100%)	- GATX Corporation (2007 – Present) - United States Steel Corporation (2008 – Present) *no public board interlocks

Voting Results of 2020 Annual General Meeting:		Other Positions in the Past Five Years: (position, date office held, and status of employer)
Votes in Favour: 662,963,880 (99.10%)	Votes Withheld: 6,021,718 (0.90%)	None

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Footnotes to director nominee tables on pages 114 through 117:

(a) The information includes the beneficial ownership of common shares of Imperial Oil Limited, which information not being within the knowledge of the company has been provided by the nominees individually.

(b) The company’s plan for restricted stock units for nonemployee directors is described on page 139. The company’s plan for deferred share units for nonemployee directors is described on page 138. The company’s plan for restricted stock units for selected employees is described on page 163.

(c) The numbers for the company’s restricted stock units represent the total of the outstanding restricted stock units received in 2014 through 2020 and deferred share units received since directors’ appointment.

(d) The value for Imperial Oil Limited common shares, deferred share units and restricted stock units is based on the closing price for Imperial Oil Limited common shares on the Toronto Stock Exchange of $26.57 on February 16, 2021.

Director and nominee holdings in Exxon Mobil Corporation (a)

Director	XOM Common Shares (#)	XOM Restricted Stock (#) (b)	Total Common Shares and Restricted Stock (#)	Total Market Value of   Common Shares and   Restricted Stock   ($)   (c)
D.C. Brownell (d)	3,217	77,000	80,217	5,294,927
B.W. Corson	87,758	116,100	203,858	13,456,164
M.R. Crocker	17,915	77,600	95,515	6,304,710
D.S. Sutherland	5,730	-	5,730	378,223

(a) Holdings as at February 16, 2021. The information includes the beneficial ownership of common shares of Exxon Mobil Corporation, which information not being within the knowledge of the company has been provided by the nominees and directors individually. None of these individuals own more than 0.01 percent of the outstanding shares of Exxon Mobil Corporation. D.W. Cornhill, K.T. Hoeg, M.C. Hubbs and J.M. Mintz do not own common shares or hold restricted stock of Exxon Mobil Corporation.

(b) The numbers for Exxon Mobil Corporation restricted stock include outstanding restricted stock and restricted stock units granted under its restricted stock plan which is similar to the company’s restricted stock unit plan.

(c) The value for Exxon Mobil Corporation common shares and restricted stock is based on the closing price for Exxon Mobil Corporation common shares on the New York Stock Exchange of $52.04 U.S., which is converted to Canadian dollars at the daily rate of exchange of $1.2684 provided by the Bank of Canada for February 16, 2021.

(d) D.C. Brownell is a current director and has chosen not to stand for re-election. Mr. Brownell does not hold any Imperial Oil Limited common shares, restricted stock units or deferred share units.

Majority voting policy

In order to better align with the Canadian Coalition for Good Governance’s policy, “Governance Differences of Equity Controlled Corporations”, in 2012, the board of directors of the company passed a resolution adopting a majority voting policy. As of the date of this circular, Exxon Mobil Corporation holds 69.6 percent of the company’s shares. If Exxon Mobil Corporation’s shareholdings were ever to fall below 50 percent, the company’s policy provides that for any non-contested election of directors, any director nominee who receives a greater number of votes “withheld” from his or her election than votes “for” in such election shall tender his or her resignation. Within 90 days after certification of the election results, the board of directors will decide, through a process managed by the nominations and corporate governance committee and excluding the nominee in question, whether to accept the resignation. Absent a compelling reason for the director to remain on the board, the board shall accept the resignation. The board will promptly disclose its decision and, if applicable, the reasons for rejecting the tendered resignation.

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Corporate governance disclosure

Corporate governance at a glance
Controlled company	Yes
Size of board	7
Number of independent directors	5
Women on board	2
Average attendance of directors at board and committee meetings	99%
Independent chair of the executive sessions	Yes
In camera sessions of independent directors at every board meeting	Yes
Independent status of audit committee	100%
Audit committee members financially literate	All
Independent status of executive resources committee	83%
Independent status of nominations and corporate governance committee	83%
Majority of independent directors on all committees	Yes
Individual director elections	Yes
Average tenure of director nominees (approximate)	6.5 years
Average age of director nominees (approximate)	62 years
Mandatory retirement age	72 years
Majority voting policy	Yes
Separate board chair and CEO	No
Number of board interlocks	None
No director serves on more than two boards of another reporting issuer	Yes
Share ownership requirements for independent directors	Yes
Share ownership requirements for chairman and chief executive officer	Yes
Board orientation and education program	Yes
Code of business conduct and ethics	Yes
Board and committee charters	Yes
Position descriptions for the chairman and chief executive officer and the chair of each committee	Yes
Skills matrix for directors	Yes
Annual board evaluation process	Yes
Annual advisory vote on executive compensation	No
Dual-class shares	No
Change of control agreements	No

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Statement of corporate governance practice

This section provides information pertaining to our board, the committees of the board, ethics, diversity and shareholder engagement. The company is committed to high corporate governance standards and best practices. The company’s corporate governance policies and practices comply with and in most cases exceed the requirements of National Instrument 52-110 Audit Committees (NI 52-110), National Policy 58-201 Corporate Governance Guidelines (NP 58-201) and National Instrument 58-101 Disclosure of Corporate Governance Practices (NI 58-101). The company’s common shares trade on the Toronto Stock Exchange and the NYSE American LLC and our corporate governance practices reflect the standards of these exchanges. In accordance with NYSE American LLC requirements for non-U.S. companies, the company is in compliance with NYSE American standards in all significant respects except as described on the company’s website at www.imperialoil.ca.

The company continually reviews its governance practices and monitors regulatory changes.

Composition of our board nominees

More information on diversity, including on the board and among executive officers of the company, can be found at page 145.

Tenure of our board nominees

The board charter provides that incumbent directors will not be re-nominated if they have attained the age of 72, except under exceptional circumstances and at the request of the chairman. The company does not have term limits for independent directors because it values the comprehensive knowledge of the company that long serving directors possess and independent directors are expected to remain qualified to serve for a minimum of five years. The following chart shows the current years of service of the nominees for the board of directors and the year they would normally be expected to retire from the board.

Name of director nominee	Years of service on the board	Year of expected retirement from the board for independent directors
D.W. Cornhill	3 years	2026
B.W. Corson	1 year	-
M.R. Crocker (a)	-	-
K.T. Hoeg	13 years	2022
M.C. Hubbs	2 years	2039
J.M. Mintz	16 years	2023
D.S. Sutherland	11 years	2022

(a) M.R. Crocker is being nominated for election as a director at the annual meeting of shareholders and is not currently a director.

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Skills and experience of our board members and nominees

Our directors bring a wide range of skills, diversity and experience.

The current directors and director nominees collectively have the experience and expertise required to ensure effective oversight, stewardship and governance of the company. The key areas of experience and skills for each of the nominees for election as directors can also be found in each of the nominees tables on pages 114 through 117 of this circular.

The table below sets out the diverse skill set required of the board and identifies the particular experience, qualifications, attributes, and skills of each director and nominee that led the board to conclude that such person should serve as a director of the company.

	D.C. Brownell (a)	D.W. Cornhill	B.W. Corson	M.R. Crocker (b)	K.T. Hoeg	M.C. Hubbs	J.M. Mintz	D.S. Sutherland
Leadership of large organizations	∎	∎	∎	∎	∎			∎
Operations / technical	∎	∎	∎	∎				∎
Project management	∎	∎	∎	∎	∎
Global experience	∎		∎	∎	∎	∎	∎	∎
Strategy development	∎	∎	∎	∎	∎	∎	∎	∎
Environment and sustainability	∎	∎	∎	∎	∎	∎	∎	∎
Audit committee financial expert		∎			∎	∎		∎
Financial expertise	∎	∎	∎	∎	∎	∎	∎	∎
Government relations	∎		∎	∎			∎	∎
Academic / research							∎
Information technology / cybersecurity oversight						∎
Executive compensation	∎	∎	∎	∎	∎	∎	∎	∎
Risk Management	∎	∎	∎	∎	∎	∎	∎	∎

(a) D.C. Brownell is a current director and has chosen not to stand for re-election at the annual meeting of shareholders.

(b) M.R. Crocker is being nominated for election as a director at the annual meeting of shareholders and is not currently a director.

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Independence of our board members and nominees

Five out of seven of the director nominees are independent.

The board is currently composed of seven directors, six of whom will be standing for re-election at the annual meeting of shareholders on May 4, 2021. D.C. Brownell is a current director and has chosen not to stand for re-election. M.R. Crocker is not currently a director and is being nominated for election as a director. The majority of the board and nominees (five out of seven) are independent. The independent directors are not employees of the company.

The board determines independence on the basis of the standards specified by National Instrument 52-110 Audit Committees (NI 52-110), the U.S. Securities and Exchange Commission rules and the listing standards of the NYSE American LLC. The board has reviewed relevant relationships between the company and each nonemployee director and director nominee to determine compliance with these standards.

Based on the directors’ responses to an annual questionnaire, the board determined that none of the independent directors has any interest, business or other relationship that could or could reasonably be perceived to constitute a material relationship with the company. B.W. Corson is a director and chairman, president and chief executive officer of the company and not considered to be independent. The board believes that Mr. Corson’s extensive knowledge of the business of the company and Exxon Mobil Corporation is beneficial to the other directors and his participation enhances the effectiveness of the board.

D.C. Brownell is also a non-independent director as he is an employee of Exxon Mobil Corporation. Mr. Brownell has chosen not to stand for re-election at the annual meeting of shareholders. Director nominee, M.R. Crocker, holds the position of senior vice-president, fuels at ExxonMobil Fuels & Lubricants Company, a division of Exxon Mobil Corporation and if elected will also be a non-independent director. The company believes that Mr. Brownell, and Mr. Crocker, although deemed non-independent under the relevant standards by virtue of their employment, can be viewed as independent of the company’s management and that their ability to reflect the perspective of the company’s shareholders enhances the effectiveness of the board.

Name of director	Management	Independent	Not independent	Reason for non-independent status
D.C. Brownell			∎	D.C. Brownell is an employee of Exxon Mobil Corporation. Mr. Brownell has chosen not to stand for re-election and will cease to be a director on May 4, 2021.
D.W. Cornhill		∎
B.W. Corson	∎		∎	B.W. Corson is a director and chairman, president and chief executive officer of Imperial Oil Limited.
M.R. Crocker			∎	M.R. Crocker is an employee of Exxon Mobil Corporation. Mr. Crocker is a nominee for election as a director at the annual meeting of shareholders.
K.T. Hoeg		∎
M.C. Hubbs		∎
J.M. Mintz		∎
D.S. Sutherland		∎

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Committee membership of our board

Each committee is chaired by a different independent director and

all of the independent directors are members of each committee.

The chart below shows the company’s current committee memberships and the chair of each committee.

Director	Nominations and corporate governance committee	Audit committee (b)	Public policy and corporate responsibility committee	Executive resources committee	Community collaboration and engagement committee
D.C. Brownell (a)	∎	-	∎	∎	∎
D.W. Cornhill (c)	∎ Chair	∎	∎	∎	∎
B.W. Corson (a)	-	-	-	-	∎
K.T. Hoeg (c)	∎	∎ Chair	∎	∎	∎
M.C. Hubbs (c)	∎	∎	∎	∎	∎ Chair
J.M. Mintz	∎	∎	∎ Chair	∎	∎
D.S. Sutherland (c)	∎	∎	∎	∎ Chair	∎

(a) Not independent directors. D.C. Brownell is a current director and has chosen not to stand for re-election.

(b) All members of the audit committee are independent and financially literate within the meaning of National Instrument 52-110 Audit Committees and the listing standards of the NYSE American LLC.

(c) Audit committee financial experts under U.S. regulatory requirements.

Number of meetings

The chart below shows the number of board, committee and annual meetings held in 2020. This includes seven regular meetings and one additional special meeting of the board that was held in relation to COVID-19 and market conditions that arose during 2020. Due to public health recommendations and restrictions related to COVID-19 and for the health and safety of our directors and employees, all meetings from March 2020 onwards were conducted virtually. More information on the board’s activities in relation to COVID-19 and market conditions can be found in the Risk oversight section starting on page 129.

Board or committee	Number of meetings held in 2020
Imperial Oil Limited board	8
Audit committee	5
Executive resources committee	7
Public policy and corporate responsibility committee	3
Nominations and corporate governance committee	4
Community collaboration and engagement committee	2
Annual meeting of shareholders	1

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Attendance of our board members in 2020

99% board and committee meeting attendance from all members.

The following chart provides a summary of the attendance record of each of the directors in 2020. The attendance record of each director nominee is also set out in his or her biographical information on pages 114 through 117. The attendance chart also provides an overall view of the attendance per committee. Senior management directors and other members of management periodically attend committee meetings at the request of the committee chair.

Director	Board	Audit committee	Executive resources committee	Public policy and corporate responsibility committee	Nominations and corporate governance committee	Community collaboration and engagement committee	Annual meeting	Total	Percentage by director
D.C. Brownell	8 of 8	-	7 of 7	3 of 3	4 of 4	2 of 2	1 of 1	25 of 25	100%
D.W. Cornhill	8 of 8	4 of 5	7 of 7	3 of 3	4 of 4 (chair)	2 of 2	1 of 1	29 of 30	97%
B.W. Corson	8 of 8 (chair)	-	-	-	-	2 of 2	-	10 of 10	100%
K.T. Hoeg	8 of 8	5 of 5 (chair)	7 of 7	3 of 3	4 of 4	2 of 2	1 of 1	30 of 30	100%
M.C. Hubbs	8 of 8	5 of 5	7 of 7	3 of 3	4 of 4	2 of 2 (chair)	1 of 1	30 of 30	100%
J.M. Mintz	8 of 8	5 of 5	7 of 7	3 of 3 (chair)	4 of 4	2 of 2	1 of 1	30 of 30	100%
D.S. Sutherland	8 of 8	5 of 5	6 of 7 (chair)	3 of 3	4 of 4	2 of 2	1 of 1	29 of 30	97%
Percentage by committee	100%	96%	98%	100%	100%	100%	100%	183 of 185	Overall attendance 98.9%

124

Other public company directorships of our board members and nominees

No director or nominee serves on more than two boards of another reporting issuer.

The following table shows which directors and nominees serve on the boards of other reporting issuers and the committee memberships in those companies.

Name of     director	Other reporting issuers of which director or nominee is also a director	Type of company	Stock symbol: Exchange	Committee appointments
D.C. Brownell (a)	-	-	-	-
D.W. Cornhill	AltaGas Ltd.	Diversified energy company	ALA:TSX	No committees
B.W. Corson	-	-	-	-
M.R. Crocker (b)	-	-	-	-
K.T. Hoeg	New Flyer Industries Inc.	Manufacturer of heavy duty transit buses	NFI:TSX	Audit committee
M.C. Hubbs	Nutrien Ltd.	Fertilizer manufacturing	NTR:TSX, NYSE	Corporate governance and nominating committee and Safety and sustainability committee (chair)
J.M. Mintz	-	-	-	-
D.S. Sutherland	GATX Corporation	Commercial rail vehicles and aircraft engines – shipping	GMT:NYSE	Compensation committee (chair)
	United States Steel Corporation	Iron and steel	X:NYSE	Chairman of the board

(a) D.C. Brownell is a current director and has chosen not to stand for re-election at the annual meeting of shareholders.

(b) M.R Crocker is not currently a director and is being nominated for election as a director at the annual meeting of shareholders.

Interlocking directorships of our board members

As of the date of this proxy circular, there are no interlocking public company directorships among the directors listed in this circular.

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Director qualification and selection process

The nominations and corporate governance committee is responsible for identifying and recommending new candidates for board nomination. The committee identifies candidates from a number of sources, including executive search firms and referrals from existing directors. The process for selection is described in paragraph 10 (a) of the Board of Directors Charter found in Appendix A of this circular. The committee will consider potential future candidates as required.

In considering the qualifications of potential nominees for election as directors, the nominations and corporate governance committee considers the work experience and other areas of expertise of the potential nominees, with the objective of providing for diversity among the nonemployee directors. The following key criteria are considered to be relevant to the work of the board of directors and its committees:

Work experience

● Experience in leadership of businesses or other large organizations (Leadership of large organizations)

● Operations/technical experience (Operations / technical)

● Project management experience (Project management)

● Experience in working in a global work environment (Global experience)

● Experience in development of business strategy (Strategy development)

● Experience with environmental, health, community relations and/or safety policy, practices and management (Environment and sustainability)

Other expertise

● Audit committee financial expert (also see the financial expert section in the audit committee table starting on page 132)

● Expertise in financial matters (Financial expertise)

● Expertise in managing relations with government (Government relations)

● Experience in academia or in research (Academic / research)

● Expertise in information technology and cybersecurity oversight (Information technology / cybersecurity oversight)

● Expertise in executive compensation policies and practices (Executive compensation)

● Expertise in oversight of risk management policies and practices (Risk management)

The nominations and corporate governance committee may consider the following additional factors in assessing potential nominees:

● possessing expertise in any of the following areas: law, science, marketing, administration, social/political environment or community and civic affairs;

● individual competencies in business and other areas of endeavour in contributing to the collective experience of the directors; and

● providing diversity of age, regional association, gender and other diversity elements (including Aboriginal peoples, persons with disabilities and members of visible minorities).

The nominations and corporate governance committee assesses the work experience and other expertise each existing director possesses and whether the candidate is able to fill any gaps in such experience, expertise and diversity of age, regional association, gender and other diversity elements. Consideration is also given to whether candidates possess the ability to contribute to the broad range of issues with which the board and its committees must deal, are able to devote the necessary amount of time to prepare for and attend board and committee meetings and are free of any potential legal impediment or conflict of interest.

Candidates are expected to remain qualified to serve for a minimum of five years and independent directors are expected to achieve ownership of no less than 15,000 common shares, deferred share units and restricted share units within five years of becoming an independent director.

When the committee is recommending candidates for re-nomination, it assesses such candidates against the criteria for re-nomination as set out in paragraph 10 (b) of the Board of Directors Charter found in Appendix A of this circular. Candidates for re-nomination are expected not to change their principal position, the thrust of their involvement or their regional association in a way that would significantly detract from their value as a director of the corporation. They are also expected to continue to be compatible with the criteria that led to their selection as nominees.

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Director orientation, education and development

The company regularly provides in-depth presentations to the directors on relevant

and emerging issues and encourages continuing education opportunities.

The corporate secretary organizes an orientation program for all new directors. In a series of meetings over several days, new directors are briefed by staff and functional managers on all significant areas of the company’s operations, industry specific topics, risk oversight and regulatory issues. New directors are also briefed on significant company policies, organizational structure, security, information technology management and on critical planning and reserves processes. They also receive key governance and disclosure documents and a comprehensive board manual which contains a record of historical information about the company, by-laws, company policies, the charters of the board and its committees, other relevant company business information, information on directors’ duties and additional board related activities and calendars.

Continuing education is provided to board and committee members through regular presentations by management, which focus on providing more in-depth information about key aspects of the business. Subject to exceptional circumstances, each year the board has an extended meeting that focuses on a particular area of the company’s operations and includes a visit to one or more of the company’s operating sites or a site of relevance. Due to public health recommendations and restrictions related to COVID-19, a site visit was not possible in 2020. However, the board actively engaged with management on pandemic specific topics such as response and mitigation plans and actions, health and safety initiatives, and site-specific issues throughout the pandemic. Further, the board focused on strategic financial and business actions in response to the pandemic and challenging market conditions. It also held refresher reviews of key risk topics in connection with the pandemic, such as crisis communication. More information on the board’s activities in relation to COVID-19 and market conditions can be found in the Risk oversight section starting on page 129.

Although 2020 was an unprecedented year with a number of unique challenges, the board and its committees continued to receive regular presentations and updates that focused on performance, strategy and opportunities for the business. Some of these presentations included an asset impairment review, an investor relations review, numerous environmental, social and governance reviews, climate risk and carbon policy updates, a review of environmental performance, community engagement and investment updates, ongoing reviews of upstream and downstream performance and improvement plans, a review on research and technology, and a competition and anti-corruption review. The board was also provided an information technology and cybersecurity update including strategic cybersecurity priorities, key security initiatives and mitigation efforts and system improvements throughout the year.

Members of ExxonMobil’s management also provide reviews of various aspects of ExxonMobil’s global business. In 2020, the directors received a presentation on ExxonMobil’s information technology and cybersecurity framework and operations, as well as an overview of ExxonMobil’s industry environment, energy outlook update and corresponding strategic objectives.

Members of the board also receive an extensive package of materials prior to each board meeting that provides a comprehensive summary on each agenda item to be discussed. Similarly, the committee members also receive a comprehensive summary on each agenda item to be discussed by that particular committee. Informational communications and other written publications or reports of interest to the directors are also forwarded routinely.

The board members are canvassed as to whether there are any additional topics relevant to the board or to a specific committee that they would like to see addressed, and management schedules presentations covering these areas. In addition, at every meeting the board receives an extensive update from the chairman, president and chief executive officer on business environment trends, relevant geopolitical activities, federal government priorities, key provincial issues and competitor activities, as appropriate.

Directors are encouraged to participate in other continuing education programs and events to ensure their skills and knowledge remain current.

127

Board performance assessment

The board and its committees, as well as the performance of the directors, are assessed on an annual basis. For 2020, the directors engaged in a performance assessment with the chairman, president and chief executive officer, which includes discussion and evaluation of the board and each committee’s effectiveness in various areas. The chairman, president and chief executive officer also meets regularly with directors individually to discuss any outstanding issues. The nominations and corporate governance committee discuss a summary of these assessment outcomes in the first quarter of each year.

Board and committee structure

Leadership structure

The company has chosen to combine the positions of chairman, president and chief executive officer. The board believes the interests of all shareholders are best served at the present time through a leadership model with a combined chairman and chief executive officer position. Through more than 37 years of experience with ExxonMobil and Imperial, the current chief executive officer possesses an in-depth knowledge of the evolving energy industry supply and demand fundamentals and the array of challenges to be faced by the company. The board believes that the extensive experience and other insights put the chief executive officer in the best position to provide broad leadership for the board as it considers strategy and exercises its fiduciary responsibilities. Further, the board has demonstrated its commitment and ability to provide independent oversight of management.

The company does not have a lead director. While the chairman of the board is not an independent director, K.T. Hoeg, chair of the executive sessions of the board, provides leadership for the independent directors. The duties of the chair of the executive sessions include presiding at executive sessions, reviewing and modifying, if necessary, the agenda of the meetings of the board in advance to ensure that the board may successfully carry out its duties, and acting as a liaison with the chairman of the board, including the provision of feedback, as appropriate, from the executive sessions. The position description of the chair of the executive sessions, as well as the purpose of those executive sessions, are fully described in paragraphs 9 (c) and (d) of the Board of Directors Charter attached as Appendix A.

Independent director executive sessions

The executive sessions of the board are in camera meetings of the independent directors and are held in conjunction with every board meeting. These meetings are held in the absence of management. The independent directors held eight executive sessions in 2020. The purposes of the executive sessions of the board include the following:

● raising substantive issues that are more appropriately discussed in the absence of management;

● discussing the need to communicate to the chairman of the board any matter of concern raised by any committee or director;

● addressing issues raised but not resolved at meetings of the board and assessing any follow-up needs with the chairman of the board;

● discussing the quality, quantity, and timeliness of the flow of information from management that is necessary for the independent directors to effectively and responsibly perform their duties, and advising the chairman of the board of any changes required; and

● seeking feedback about board processes.

In camera sessions of the board committees

Various committees also regularly hold in camera sessions without management present. The audit committee regularly holds private sessions of the committee members as well as private meetings of the committee with each of the external auditor, the internal auditor and senior management as part of every regularly scheduled committee meeting.

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Committee structure

The board has created five committees to help carry out its duties. Each committee is chaired by a different independent director and all of the independent directors are members of each committee. D.C. Brownell is also a member of each committee, with the exception of the audit committee, which is composed entirely of independent directors. Mr. Brownell has chosen not to stand for re-election at the annual meeting of shareholders. It is anticipated that if elected, director nominee M.R. Crocker will also be a member of each committee, with the exception of the audit committee. B.W. Corson is also a member of the community collaboration and engagement committee.

Board committees work on key issues in greater detail than would be possible at full board meetings, allowing directors to more effectively discharge their stewardship responsibilities. The independent chairs of the five committees are able to take a leadership role in executing the board’s responsibility with respect to a specific area of the company’s operations falling within the responsibility of the committee he or she chairs. The board and each committee have a written charter that can be found in Appendix A of this circular. The charters are reviewed and approved by the board annually. The charters set out the purpose, structure, position description for the chair, and the responsibility and authority of that committee.

Risk oversight

The company is governed by a comprehensive and well-established risk management system, and the company’s success in managing risk over time has been achieved through emphasis on execution of this disciplined management framework.

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The company’s risk management system includes a process for identifying, prioritizing, measuring, and managing the principal risks across the company, as well as assessing the company’s response to these risks. The system is implemented through various policies, guidelines, processes and systems, including:

● energy outlook scenarios;

● strategic planning;

● risk management guidelines;

● code of ethics and standards of business conduct;

● delegation of authority guidelines;

● credit risk assessment guidelines;

● controls and operations integrity management systems;

● capital project management systems;

● IT risk management (including information technology, systems and cybersecurity);

● guidelines for the management and protection of information; and

● business continuity plans.

For a discussion on the company’s risk management in relation to executive compensation, see the Compensation discussion and analysis section starting on page 156.

The chairman, president and chief executive officer is charged with identifying the company’s principal risks and ensuring appropriate systems are in place to manage these risks. The board of directors is responsible for reviewing the principal risks and overseeing the implementation of the risk management system, with the various committees assisting in risk oversight for issues that fall under their responsibility. For example, the audit committee oversees the company’s system of internal accounting and financial controls, the executive resources committee oversees the compensation programs and practices in relation to risk management, and the public policy and corporate responsibility committee oversees the policies and practices that manage environment, health, safety and security risk, including the risks of climate change. This integrated risk management approach facilitates recognition and oversight of risk.

The board and its committees carry out their risk oversight responsibility through regular reviews and assessments. The board carefully considers these risks in evaluating strategic plans and specific proposals for capital expenditures and budget additions. Topic-specific assessments, such as for compliance programs, controls, stewardship of business performance, regulatory changes, the company’s energy outlook, and climate risk and sustainability are conducted regularly and as necessary. Members of the board ask questions of management to ensure risks are identified, assessed, mitigated, and monitored. Each typical year, the board also visits one or more of the company’s operating sites or locations of importance for the company to better understand issues associated with the company’s business. However, a site visit was not possible in 2020 due to public health recommendations and restrictions related to COVID-19.

COVID-19 and market conditions in 2020

The COVID-19 pandemic and market conditions within the energy industry in 2020 placed a significant emphasis on the board’s role in risk oversight. Throughout the year, the board continuously reviewed and discussed with management the impact of COVID-19 and market conditions on performance, business strategies, employees and the community through scheduled and special meetings and ad-hoc communication. The board also guided the company through prudent business and financial action in response to market conditions. This included significant adjustments to capital and operating expenditures, while maintaining focus on the health and safety of the company’s employees, contract partners, customers and communities and reliably supplying essential products to the company’s customers.

Each committee supported the board by holding reviews and discussions of COVID-19 topics specific to their responsibilities. For example, the audit committee was responsible for maintaining the integrity of the financial statements, as well as ensuring that the quality and effectiveness of internal controls and procedures was not compromised as company adapted to work from home requirements. The public policy and corporate responsibility committee oversaw the activation of pandemic and emergency response plans and safety protocols for mitigating risk and maintaining the company’s focus on the health and safety of employees, contractors and the community. The community collaboration and engagement committee oversaw numerous initiatives to support the community through this challenging period, including a free fuel promotion for healthcare workers, donations of computers for online learning and donations of isopropyl alcohol to be used in disinfectant products.

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The following table provides additional oversight and other information about the board and its five committees:

Board of directors

The board of directors is responsible for the stewardship of the corporation. The stewardship process is carried out by the board directly or through one or more of the committees of the board. The formal mandate of the board can be found within the Board of Directors Charter in Appendix A of this circular.

Directors	● B.W. Corson (chair) ● D.C. Brownell ● D.W. Cornhill ● K.T. Hoeg	● M.C. Hubbs ● J.M. Mintz ● D.S. Sutherland
Number of meetings	Eight meetings of the board of directors were held in 2020, which included one special meeting of the board. The independent directors hold executive sessions of the board in conjunction with every board meeting. These meetings are held in the absence of management. The independent directors held eight executive sessions in 2020.
Board highlights in 2020	● Provided oversight in support of safety, environmental performance and sustainability. ● Regularly discussed industry activity, market updates and company initiatives. ● Regularly discussed operational and project updates. ● Regularly discussed risk management and business controls environment. ● Regularly reviewed information technology, systems and cybersecurity strategies (including trends, risks, preparedness, mitigation, response, system improvements and business continuity strategies) to assess the security and integrity of the company’s information, systems and assets. ● Regularly assessed performance of the Kearl oil sands operations and monitored progress on reliability improvements. ● Discussed comprehensive company strategy for all business lines. ● Reviewed climate change policies, risks and Imperial’s climate strategy. ● Provided oversight of the company’s response to the COVID-19 pandemic. ● Approved prudent business and financial responses to market conditions including significant reductions to capital and operating expenses, and provided oversight over implementation of these actions.
Role in risk oversight	The company’s financial, execution and operational risk rests with management and the company is governed by well-established risk management systems. The board of directors are responsible for reviewing the company’s principal risks and overseeing the implementation of the appropriate systems to manage these risks. The board carefully considers these risks in evaluating the company’s strategic plans and specific proposals for capital expenditures and budget additions. It also approves and monitors compliance with the code of ethics and business conduct, and ensures that executive officers create a culture of integrity throughout the company. The board reviews the company’s information technology, systems and cybersecurity to ensure they adequately protect corporate information and assets. In 2020, the board’s role in risk oversight included the company’s response to the COVID-19 pandemic and market conditions, with a focus on the health and safety of the company’s employees, contract partners, customers and communities.
Disclosure policy	The company is committed to full, true and plain public disclosure of all material information in a timely manner, in order to keep security holders and the investing public informed about the company’s operations. The full details of the corporate disclosure policy can be found on the company’s internet site at www.imperialoil.ca.
Independence	The current board of directors is composed of seven directors, the majority of whom (five of seven) are independent. The five independent directors are not employees of the company.

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Audit committee

The role of the audit committee includes selecting and overseeing the independent auditor, reviewing the scope and results of the audit conducted by the independent auditor, and assisting the board in overseeing the integrity of the company’s financial statements. In addition, the committee’s role includes overseeing the company’s compliance with legal and regulatory requirements and the quality and effectiveness of internal controls, approving any changes in accounting principles and practices, and reviewing the results of monitoring activity under the company’s business ethics compliance program. The formal mandate of the committee can be found within the Audit Committee Charter in Appendix A of this circular.

Committee members	● K.T. Hoeg (chair) ● M.C. Hubbs (vice-chair) ● D.W. Cornhill	● J.M. Mintz ● D.S. Sutherland
Number of meetings	Five meetings of the audit committee were held in 2020. The committee members met in camera without management present and separately with the internal auditor and the external auditor at all regularly scheduled meetings. A pre-audit meeting also occurs prior to every regularly scheduled audit committee meeting with the chair of the audit committee and the chief financial officer and both the internal and external auditors.
Committee highlights in 2020	● Reviewed and recommended for approval the interim and full year financial and operating results. ● Reviewed and assessed the company’s system of internal controls and auditing procedures, and the results of the internal auditor’s audit program. ● Reviewed and assessed the external auditor plan, performance and fees. ● Reviewed evolving regulations and reporting obligations. ● Reviewed the committee’s mandate and completed the committee self-assessment. ● Performed external auditor performance evaluation. ● Ensured the effectiveness of controls and procedures and integrity of financial statements was maintained while responding to the COVID-19 pandemic.
Financial expertise	The company’s board of directors has determined that D.W. Cornhill, K.T. Hoeg, M.C. Hubbs and D.S. Sutherland meet the definition of “audit committee financial expert”. The U.S. Securities and Exchange Commission has indicated that the designation of an audit committee financial expert does not make that person an expert for any purpose, or impose any duties, obligations or liability on that person that are greater than those imposed on members of the audit committee and board of directors in the absence of such designation or identification. All members of the audit committee are financially literate within the meaning of National Instrument 52-110 Audit Committees and the listing standards of the NYSE American LLC.
Role in risk oversight	The audit committee also has an important role in risk oversight. The audit committee oversees risks associated with financial and accounting matters, including compliance with legal and regulatory requirements, and the company’s financial reporting and internal controls systems. In addition, it reviews the scope of PricewaterhouseCoopers’ audit in light of risks associated with the energy industry, the regulatory environment and company-specific financial audit risks. The committee also reviews financial statements and internal and external audit results, and any changes proposed to accounting principles and practices. With respect to the COVID-19 pandemic, the audit committee is also responsible for ensuring the reporting and internal controls are maintained as the company implements various response measures, including work from home arrangements.
Independence	The audit committee is composed entirely of independent directors. All members met board approved independence standards, as that term is defined in National Instrument 52-110 Audit Committees, the U.S. Securities and Exchange Commission rules and the listing standards of the NYSE American LLC.

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Executive resources committee

The executive resources committee is responsible for corporate policy on compensation and for specific decisions on the compensation of the chief executive officer and key senior executives and officers reporting directly to that position. In addition to compensation matters, the committee is also responsible for succession plans and appointments to senior executive and officer positions, including the chief executive officer. The formal mandate of the committee can be found within the Executive Resources Committee Charter in Appendix A of this circular.

Committee members	● D.S. Sutherland (chair) ● D.W. Cornhill (vice-chair) ● D.C. Brownell	● K.T. Hoeg ● M.C. Hubbs ● J.M. Mintz
	None of the members of the executive resources committee currently serves as a chief executive officer of another company.
Number of meetings	Seven meetings of the executive resources committee were held in 2020.
Committee highlights in 2020	●  Reviewed executive compensation program and principles. ● Reviewed strategic work planning and talent strategy plans. ● Reviewed workforce and organizational changes. ● Reviewed harassment policy and process outcomes. ● Continued focus on succession planning for senior management positions. ● Appointed a senior vice-president, treasurer and three vice-president positions as part of normal succession.
Committee members relevant skills and experience	D.W. Cornhill, K.T. Hoeg, M.C. Hubbs and D.S. Sutherland had extensive and lengthy experience in managing and implementing their respective companies’ compensation policies and practices in their past role as chief executive officers or members of senior management. Mr. Cornhill, Ms. Hoeg, Dr. Mintz and Mr. Sutherland serve or have served on compensation committees of one or more public companies. Accordingly, committee members are able to use this experience and knowledge derived from their roles with other companies in judging the suitability of the company’s compensation policies and practices.
Role in risk oversight	The executive resources committee oversees the compensation programs and practices that are designed to encourage appropriate risk assessment and risk management.
Independence	The members of the executive resources committee are independent, with the exception of D.C. Brownell, who is not considered to be independent under the rules of the U.S. Securities and Exchange Commission, Canadian securities rules and the rules of the NYSE American LLC due to his employment with Exxon Mobil Corporation. However, the Canadian Coalition for Good Governance’s policy, “Governance Differences of Equity Controlled Corporations”, views Mr. Brownell as a related director and independent of management and who may participate as a member of the company’s executive resources committee. Mr. Brownell’s participation helps to ensure an objective process for determining compensation of the company’s officers and directors and assists the deliberations of this committee by bringing the views and perspectives of the majority shareholder.

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Public policy and corporate responsibility committee

The role of the public policy and corporate responsibility committee is to review and monitor the company’s policies and practices in matters of the environment, health, safety, security and sustainability. The committee monitors the company’s compliance with legislative, regulatory and corporate standards in these areas, and reviews trends and current and emerging public policy. It also assesses the potential impacts of public policy on corporate performance.

The committee reviews safety and environmental performance, incidents and trends on a regular basis to ensure the company’s focus on the safety of its employees, contractors and stakeholders and on operating in an environmentally responsible manner. It also provides oversight over sustainability and climate risk, including regular reviews and assessment of sustainability performance and initiatives, as well as climate risk within the company’s risk management system and the strategies to address these risks. The formal mandate of the committee can be found within the Public Policy and Corporate Responsibility Committee Charter in Appendix A of this circular.

Committee members	● J.M. Mintz (chair) ● D.S. Sutherland (vice-chair) ● D.C. Brownell	● D.W. Cornhill ● K.T. Hoeg ● M.C. Hubbs
Number of meetings	Three meetings of the public policy and corporate responsibility committee were held in 2020.
Committee highlights in 2020	● Personnel and process safety systems, performance and incident review ● Environmental performance review ● COVID-19 pandemic response and economic recovery review (policy and regulations) ● Updates on Canadian policy, regulatory change, and industry advocacy (clean fuel standard, plastics, UN Declaration on the Rights of Indigenous Peoples) ● Review of climate change policies, risks, and Imperial’s climate strategy ● Review of Imperial’s Sustainability Report and related environmental, social and corporate governance disclosures, including disclosure of greenhouse gas emissions
Role in risk oversight	The public policy and corporate responsibility committee reviews and monitors the company’s policies and practices in matters of environment, health, personnel and process safety and security, which policies and practices are intended to mitigate and manage risk in these areas. This includes specific reviews with respect to climate risk and the company’s strategies to address these risks. It also includes pandemic and emergency response and continuity planning, which is a significant focus of reviews and discussions in relation to the COVID-19 pandemic. The committee receives regular reports from management on these matters.
Independence	The members of the public policy and corporate responsibility committee are independent, with the exception of D.C. Brownell.

Nominations and corporate governance committee

The role of the nominations and corporate governance committee is to oversee issues of corporate governance as they apply to the company, including the overall performance of the board, review potential nominees for directorship and review the charters of the board and any of its committees. The formal mandate of the committee can be found within the Nominations and Corporate Governance Committee Charter in Appendix A of this circular.

Committee members	● D.W. Cornhill (chair) ● J.M. Mintz (vice-chair) ● D.C. Brownell	● K.T. Hoeg ● M.C. Hubbs ● D.S. Sutherland
Number of meetings	Four meetings of the nominations and corporate governance committee were held in 2020.

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Committee highlights in 2020	● Approval of the statement of corporate governance practices. ● Engagement in board and committee self-assessment. ● Recommendation of director compensation. ● Recommendation to amend the board charter to add Environment and sustainability and Risk management to the directors’ skills matrix.
Role in risk oversight	The nominations and corporate governance committee oversees risk by implementing an effective program for corporate governance, including board composition and succession planning.
Independence	The members of the nominations and corporate governance committee are independent, with the exception of D.C. Brownell, who is not considered to be independent under the rules of the U.S. Securities and Exchange Commission, Canadian securities rules and the rules of the NYSE American LLC due to his employment with Exxon Mobil Corporation. However, the Canadian Coalition for Good Governance’s policy, “Governance Differences of Equity Controlled Corporations”, views Mr. Brownell as a related director and independent of management and who may participate as a member of the company’s nominations and corporate governance committee. Mr. Brownell’s participation helps to ensure an objective nominations process and assists the deliberations of this committee by bringing the views and perspectives of the majority shareholder.

Community collaboration and engagement committee

The role of the community collaboration and engagement committee is to oversee all of the company’s community investment activities, including charitable donations. The formal mandate of the committee can be found within the Community Collaboration and Engagement Committee Charter in Appendix A of this circular.

Committee members	● M.C. Hubbs (chair) ● K.T. Hoeg (vice-chair) ● D.C. Brownell ● D.W. Cornhill	● B.W. Corson ● J.M. Mintz ● D.S. Sutherland
Number of meetings	Two meetings of the community collaboration and engagement committee were held in 2020.
Committee highlights in 2020	● Imperial invested more than $15M in Canadian communities in 2019 as reported using the London Benchmark Group Model – a global standard for measuring and reporting community investment ● In 2019, Imperial paid more than $16.7M through community benefit agreements to Indigenous communities and successfully signed two additional agreements for Cold Lake ● Responded to community needs during the COVID-19 pandemic ¡  Launched 2:1 employee donation matching, resulting in $500K in donations to more than 470 organizations across Canada ¡  Recognized healthcare heroes across Canada with a $2M campaign and provided free fuel vouchers to 80,000 front-line workers ¡  As part of Imperial’s 140th anniversary, donated $140,000 to mental health organizations in 14 operating areas across Canada ¡  Provided in-kind donations including 60 tonnes of isopropyl alcohol (IPA) to the Government of Canada to use in disinfectant products and 500 laptops to support student access to technology ● Received Canadian Centre for Diversity and Inclusion’s western Canada “Employer Initiative of the Year” recognizing the company’s approach to Indigenous business development
Independence	The majority of the members of the community collaboration and engagement committee are independent (five out of seven) with the exception of B.W. Corson and D.C. Brownell.

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Director compensation

Director compensation discussion and analysis

Directors’ compensation is intended to align the long-term

financial interests of the directors with those of the shareholders.

Nonemployee director compensation levels are reviewed by the nominations and corporate governance committee each year, and resulting recommendations are presented to the full board for approval. The nominations and corporate governance committee decided not to use an external research firm to assemble the comparator data to determine compensation for the July 1, 2020 - June 30, 2021 period. The committee relied instead on an internally-led assessment to provide competitive compensation and market data for directors’ compensation, which assisted the committee in making a compensation recommendation for the company’s directors. The internally-led assessment included a review of industry survey data, with a limited amount of this survey data being provided by an independent external consultant. The internal assessment maintained the compensation design philosophy, objectives and principles, and was consistent with previous methodology used in this analysis.

Employees of the company or Exxon Mobil Corporation receive no extra pay for serving as directors. Nonemployee directors receive compensation consisting of cash and restricted stock units. Since 1999, the nonemployee directors have been able to receive all or part of their cash directors’ fees in the form of deferred share units. The purpose of the deferred share unit plan for nonemployee directors is to provide them with additional motivation to promote sustained improvement in the company’s business performance and shareholder value by allowing them to have all or part of their directors’ fees tied to the future growth in value of the company’s common shares. The deferred share unit plan is described in more detail on page 138.

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Compensation decision making process and considerations

The nominations and corporate governance committee relies on market comparisons with a group of major Canadian companies with national and international scope and complexity. The company draws its nonemployee directors from a wide variety of industrial sectors and, as such, a broad sample is appropriate for this purpose. The nominations and corporate governance committee does not target any specific percentile among comparator companies at which to align compensation for this group.

The comparator companies included in the benchmark sample are as follows:

Energy	Non-Energy
Canadian Natural Resources Limited	Air Canada
Cenovus Energy Inc.	Bank of Nova Scotia
Enbridge Inc.	BCE Inc.
Husky Energy Inc.	Canadian National Railway Company
Ovintiv Inc.	Nutrien Ltd.
Parkland Fuel Corporation	Royal Bank of Canada
Suncor Energy Inc.	Sun Life Financial Inc.
TC Energy Corporation	Teck Resources Limited
	TELUS Corporation
	Thomson Reuters Corporation
	The Toronto-Dominion Bank

Hedging policy

Company policy prohibits all employees, including executives, and directors, from being a party to derivative or similar financial instruments, including puts, calls, or other options, future or forward contracts, or equity swaps or collars, with respect to the company or Exxon Mobil Corporation stock.

For a discussion on the process by which the compensation of the company’s executive officers is determined, see the Compensation discussion and analysis section starting on page 156.

Compensation details

Board retainer

The compensation of the nonemployee directors is assessed annually.

In 2018, the board approved a change to the compensation paid to the nonemployee directors. Effective July 1, 2018, the nonemployee directors received an annual retainer for board membership of $110,000 per year. The retainer for each committee chaired was eliminated, and the grant of restricted stock units was increased from 2,600 to 3,000.

The nominations and corporate governance committee has reviewed the compensation paid to the nonemployee directors in each subsequent year, and has recommended no changes to the compensation. The board subsequently approved each of these recommendations.

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The following table summarizes the compensation terms for the nonemployee directors in 2020:

Director compensation
Annual retainer terms: (a)
Cash retainer:
Board membership	$110,000 annually
Committee chair	None
Equity based compensation:
Restricted stock units	3,000 units (which vest on the 5th and 10th anniversary of date of grant)

(a) The nonemployee directors may elect to take all or a portion of the cash retainer in the form of deferred share units. Nonemployee directors who are appointed to the board during any given year receive the full restricted stock unit grant and a prorated cash retainer based on the date of appointment.

Equity based compensation

Deferred share units

In 1999, an additional form of long-term incentive compensation (“deferred share units”) was made available to nonemployee directors. Nonemployee directors may elect to receive all or a portion of their cash compensation in the form of deferred share units.

The following table shows the portion of the retainer each nonemployee director elected to receive in cash and deferred share units in 2020.

Director	Election for 2020 director’s fees in cash (%)	Election for 2020 director’s fees in     deferred share units     (%)
D.W. Cornhill	25	75
K.T. Hoeg	0	100
M.C. Hubbs	0	100
J.M. Mintz	0	100
D.S. Sutherland	0	100

The number of deferred share units granted to a nonemployee director is determined at the end of each calendar quarter for that year, according to the following calculation:

(i) the dollar amount of the nonemployee director’s fees for that calendar quarter that the director elected to receive as deferred share units;

divided by

(ii) the average of the closing price of the company’s shares on the Toronto Stock Exchange for the five consecutive trading days (“average closing price”) immediately prior to the last day of that calendar quarter.

Those deferred share units are granted effective the last day of that calendar quarter.

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A nonemployee director is also granted additional deferred share units to represent dividends on unexercised deferred share units. These additional units are granted on the dividend payment dates for the company’s common shares, according to the following calculation:

(i) the cash dividend payable for a common share of the company divided by the average closing price immediately prior to the payment date for that dividend;

multiplied by

(ii) the number of unexercised deferred share units held by the nonemployee directors on the dividend record date.

A nonemployee director may only exercise deferred share units by the end of the calendar year following the year of termination of service as a director of the company, including termination of service due to death. No deferred share units may be exercised unless all of the deferred share units are exercised on the same date. On the exercise date, the cash value to be received for the units is determined based on the company’s average closing price immediately prior to the date of exercise.

Restricted stock units

In addition to the cash fees described above, the company pays a significant portion of director compensation in restricted stock units to align director compensation with the long-term interests of shareholders. The restricted stock unit plan is described in more detail beginning on page 163.

Up until 2015, an award of 2,000 restricted stock units was granted annually with 50 percent vesting on the third anniversary of the grant date and the remaining 50 percent vesting on the seventh anniversary of the grant date. On the third anniversary, directors receive a cash payment for the units to be vested. On the seventh anniversary, directors may elect to receive one common share for each unit or a cash payment for the units.

In 2016, in order to better align the long-term financial interests of the directors with those of the shareholders, the vesting period of the restricted stock units was increased such that 50 percent vests on the fifth anniversary of the grant date and the remaining 50 percent vests on the tenth anniversary of the grant date. For all the units to be vested, directors may elect to receive one common share for each unit or a cash payment for the units. The vesting periods are not accelerated upon separation or retirement from the board, except in the event of death. In addition, in 2016, the number of restricted stock units granted annually was increased to 2,600 units. In 2018, the number of restricted stock units granted annually was increased to 3,000 units.

In contrast to the forfeiture provisions for restricted stock units held by employees of the company, the restricted stock units awarded to nonemployee directors are not subject to risk of forfeiture at the time a director leaves the company’s board. This provision is designed to reinforce the independence of these board members. However, while on the board and for a 24-month period after leaving the company’s board, restricted stock units may be forfeited if the nonemployee director engages in direct competition with the company or otherwise engages in any activity detrimental to the company. The board agreed that the word “detrimental” shall not include any actions taken by a nonemployee director or former nonemployee director who acted in good faith and in the best interest of the company.

Prior to vesting of the restricted stock units, the nonemployee directors receive amounts equivalent to the cash dividends paid to holders of common shares. The amount is determined for each cash dividend payment date by the following calculation:

(i) the cash dividend payable for a common share divided by the average closing price immediately prior to the payment date for that dividend;

multiplied by

(ii) the number of unvested restricted stock units held by the nonemployee directors on the dividend record date.

Other reimbursement

Nonemployee directors are also reimbursed for travel and other expenses incurred for attendance at board and committee meetings.

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Components of director compensation

The following table sets out the details of compensation paid to the nonemployee directors in 2020.

Director (a)	Annual retainer for board membership ($)	Restricted stock units (RSU) (#)	Total fees paid in cash ($) (b)	Total value of deferred share units (DSU) ($) (c)	Total value of restricted stock units (RSU) ($) (d)	All other compen- sation ($) (e)	Total     compensation     ($)
D.W. Cornhill	110,000	3,000	27,500	82,500	72,780	11,664	194,444
K.T. Hoeg	110,000	3,000	0	110,000	72,780	49,043	231,823
M.C. Hubbs	110,000	3,000	0	110,000	72,780	10,962	193,742
J.M. Mintz	110,000	3,000	0	110,000	72,780	45,185	227,965
D.S. Sutherland	110,000	3,000	0	110,000	72,780	42,773	225,553

(a) As directors employed by the company or Exxon Mobil Corporation in 2020, B.W. Corson and D.C. Brownell did not receive compensation for acting as directors.

(b) “Total fees paid in cash” is the portion of the “Annual retainer for board membership” that the director elected to receive as cash. This amount is reported as “Fees earned” in the Director compensation table on page 141.

(c) “Total value of deferred share units” is the portion of the “Annual retainer for board membership” that the director elected to receive as deferred share units, as set out in the previous table on page 138. This amount plus the “Total value of restricted stock units” amount is shown as “Share-based awards” in the Director compensation table on page 141.

(d) The values of the restricted stock units shown are the number of units multiplied by the closing price of the company’s shares on the date of grant, which was $24.26.

(e) Amounts under “All other compensation” consist of dividend equivalent payments on unvested restricted stock units and the value of additional deferred share units granted in lieu of dividends on unvested deferred share units. In 2020, D.W. Cornhill received $6,908 in dividend equivalent payments on restricted stock units and additional deferred share units valued at $4,756 in lieu of dividends on deferred share units. K.T. Hoeg received $12,056 in dividend equivalent payments on restricted stock units and additional deferred share units valued at $36,987 in lieu of dividends on deferred share units. M.C. Hubbs received $4,620 in dividend equivalent payments on restricted stock units and additional deferred share units valued at $6,342 in lieu of dividends on deferred share units. J.M. Mintz received $12,056 in dividend equivalent payments on restricted stock units and additional deferred share units valued at $33,129 in lieu of dividends on deferred share units. D.S. Sutherland received $12,056 in dividend equivalent payments on restricted stock units and additional deferred share units valued at $30,717 in lieu of dividends on deferred share units.

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Director compensation table

The following table summarizes the compensation paid, payable, awarded or granted for 2020 to each of the nonemployee directors of the company.

Name (a)	Fees earned ($)(b)	Share- based awards ($) (c)	Option- based awards ($)	Non-equity incentive plan compensation ($)	Pension value ($)	All other compensation ($) (d)	Total   ($)
D.W. Cornhill	27,500	155,280	-	-	-	11,664	194,444
K.T. Hoeg	0	182,780	-	-	-	49,043	231,823
M.C. Hubbs	0	182,780	-	-	-	10,962	193,742
J.M. Mintz	0	182,780	-	-	-	45,185	227,965
D.S. Sutherland	0	182,780	-	-	-	42,773	225,553

(a) As directors employed by the company or Exxon Mobil Corporation in 2020, B.W. Corson and D.C. Brownell did not receive compensation for acting as directors.

(b) Represents all fees awarded, earned, paid or payable in cash for services as a director. The nonemployee directors are able to receive all or part of their directors’ fees in the form of deferred share units.

(c) Represents the value of the restricted stock units (calculated by multiplying the number of units by the closing price of the company’s shares on the date of grant), plus the value of deferred share units (calculated by the portion of the “Annual retainer for board membership” that the director elected to receive as deferred share units as noted on page 138).

(d) Amounts under “All other compensation” consist of dividend equivalent payments on unvested restricted stock units and the value of additional deferred share units granted in lieu of dividends on unvested deferred share units. In 2020, D.W. Cornhill received $6,908 in dividend equivalent payments on restricted stock units and additional deferred share units valued at $4,756 in lieu of dividends on deferred share units. K.T. Hoeg received $12,056 in dividend equivalent payments on restricted stock units and additional deferred share units valued at $36,987 in lieu of dividends on deferred share units. M.C. Hubbs received $4,620 in dividend equivalent payments on restricted stock units and additional deferred share units valued at $6,342 in lieu of dividends on deferred share units. J.M. Mintz received $12,056 in dividend equivalent payments on restricted stock units and additional deferred share units valued at $33,129 in lieu of dividends on deferred share units. D.S. Sutherland received $12,056 in dividend equivalent payments on restricted stock units and additional deferred share units valued at $30,717 in lieu of dividends on deferred share units.

Five-year look back at total compensation paid to nonemployee directors
Year	Amount                     ($)
2016	1,342,664
2017	1,351,454
2018	1,500,739
2019	1,251,395
2020	1,073,527

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Outstanding share-based awards and option-based awards for directors

The following table sets forth all outstanding awards held by nonemployee directors of the company as at December 31, 2020 and does not include common shares owned by the director.

	Option-based awards				Share-based awards
Name (a)	Number of securities underlying unexercised options (#)	Option exercise price ($)	Option expiration date	Value of unexercised in-the- money options ($)	Number of shares or units of shares that have not vested (#) (b)	Market or payout value of share-based awards that have not vested ($) (c)
D.W. Cornhill	-	-	-	-	19,784	477,981
K.T. Hoeg	-	-	-	-	62,913	1,519,978
M.C. Hubbs	-	-	-	-	19,913	481,098
J.M. Mintz	-	-	-	-	58,405	1,411,065
D.S. Sutherland	-	-	-	-	55,588	1,343,006

(a) As directors employed by the company or Exxon Mobil Corporation in 2020, B.W. Corson and D.C. Brownell did not receive compensation for acting as directors.

(b) Represents restricted stock units and deferred share units held as of December 31, 2020.

(c) Value is based on the closing price of the company’s shares on December 31, 2020 ($24.16).

Incentive plan awards for directors – Value vested or earned during the year

The following table sets forth the value of the awards that vested or were earned by each nonemployee director of the company in 2020.

Name (a)	Option-based awards – Value vested during the year ($)	Share-based awards – Value vested during the year ($) (b)	Non-equity incentive plan compensation – Value earned during the year ($)
D.W. Cornhill	-	-	-
K.T. Hoeg	-	23,118	-
M.C. Hubbs	-	-	-
J.M. Mintz	-	23,118	-
D.S. Sutherland	-	23,118	-

(a) As directors employed by the company or Exxon Mobil Corporation in 2020, B.W. Corson and D.C. Brownell did not receive compensation for acting as directors.

(b) Represents restricted stock units granted in 2013 and 2017, which vested in 2020. Value is based on the average of the weighted average price (as determined by the Toronto Stock Exchange) of common shares of the company on the vesting date and the four consecutive trading days immediately prior to the vesting date.

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Share ownership guidelines of independent directors and chairman, president and chief executive officer

Independent directors are required to hold the equivalent of at least 15,000 shares of Imperial Oil Limited, including common shares, deferred share units and restricted stock units. Independent directors are expected to reach this level within five years from the date of appointment to the board. The chairman, president and chief executive officer has separate share ownership requirements and must, within three years of his appointment, acquire shares of the company, including common shares and restricted stock units, of a value of no less than five times his base salary.

The board of directors believes that these share ownership guidelines will result in an alignment of the interests of board members with the interests of all other shareholders. As of the date of this circular, the independent directors currently have holdings of 285,103 shares which is more than three times the required guideline.

	Minimum share ownership requirement	Time to fulfill
Chairman, president and chief executive officer	5 x base salary	Within 3 years of appointment
Independent directors	15,000 shares	Within 5 years of initial appointment

The chart below shows the shareholdings of the independent directors and the chairman, president and chief executive officer of the company as of February 16, 2021, the record date of the management proxy circular.

Director	Director since	Amount acquired since last report (February 13, 2020 to February 16, 2021) (#)	Total holdings (includes common shares, deferred share units and restricted stock units) (#)	Market value of total holdings (a) ($)	Minimum shareholding requirement	Minimum requirement met
D.W. Cornhill	November 29, 2017	7,729	32,284	857,786	15,000	Yes
B.W. Corson (b)	September 17, 2019	78,200	156,400	4,155,548	Five times base salary	No (b)
K.T. Hoeg	May 1, 2008	9,967	62,913	1,671,598	15,000	Yes
M.C. Hubbs	July 26, 2018	9,306	19,913	529,088	15,000	Yes
J.M. Mintz	April 21, 2005	9,757	59,405	1,578,391	15,000	Yes
D.S. Sutherland	April 29, 2010	9,627	110,588	2,938,323	15,000	Yes
Total accumulated holdings (#) and value of directors’ holdings ($)			441,503	$11,730,734

(a) The amount shown in the column “Market value of total holdings” is equal to the “Total holdings” multiplied by the closing price of the company’s shares on the proxy circular record date February 16, 2021 ($26.57).

(b) B.W. Corson was appointed to the board and as president of the company on September 17, 2019, and assumed the additional roles of chairman and chief executive officer on January 1, 2020. Mr. Corson is expected to meet the share ownership guidelines of five times base salary within three years of appointment as chairman and chief executive officer.

For information relating to compensation of the company’s named executive officers, see the Compensation discussion and analysis section starting on page 156.

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Ethical business conduct

The company is committed to high ethical standards through its policies and practices.

The company’s directors, officers and employees are responsible for developing, approving and implementing plans and actions designed to achieve corporate objectives. In doing so, they are expected to observe the highest standards of integrity in the conduct of the company’s business, with the methods employed to attain results being as important as the results themselves.

The board has adopted a written code of ethics and business conduct (the “Code”) which can be found on the company’s website at www.imperialoil.ca/en-CA/Investors/Investor-relations, including any applicable amendments. The Code applies to each of the company’s directors, officers and employees, and consists of the ethics policy, the conflicts of interest policy, the corporate assets policy, the directorships policy and the procedures and open door communication. No person in the company has the authority to make exceptions or grant waivers with respect to its foundational policies. There have been no material change reports filed in the past 12 months pertaining to conduct of a director or executive officer that constitute a departure from the Code. In addition, the directors of the company must comply with the conflict of interest provisions of the Canada Business Corporations Act, as well as the relevant securities regulatory instruments, in order to ensure that the directors exercise independent judgment in considering transactions and agreements in respect of which such director has a material interest.

Under the company’s procedures and open door communication, employees are encouraged and expected to refer suspected violations of the law, company policy or internal controls and procedures by various means, including to their supervisors or the company’s ethics advisor, controller or general auditor. Imperial also has an ethics “hotline” that is operated by a third-party service provider and offers confidential, anonymous reporting 24 hours a day, seven days a week. Suspected violations involving a director or executive officer, as well as any concern regarding questionable accounting or auditing matters are to be referred directly to the internal auditor. The audit committee initially reviews all issues involving directors or executive officers, and then refers all issues to the board of directors. In the alternative, employees may also address concerns to individual nonemployee directors or to nonemployee directors as a group. No action may be taken or threatened against employees for asking questions, voicing concerns, or making complaints or suggestions in good faith.

Management provides the board of directors with a review of corporate ethics and conflicts of interest on an annual basis. The company’s internal auditors audit each business line’s compliance with the program and report to the audit committee. Directors, officers and employees review the company’s standards of business conduct (which includes the Code) on an annual basis, with independent directors and all employees being required to sign a declaration card confirming that they have read and are familiar with the standards of business conduct. In addition, every four years a business practices review is conducted in which managers review the standards of business conduct with all employees in their respective work units.

The board, through its audit committee, examines the effectiveness of the company’s internal control processes and management information systems. The board consults with the external auditor, the internal auditor and the management of the company to ensure the integrity of the systems.

There are a number of structures and processes in place to facilitate the functioning of the board independently of management. The board has a majority of independent directors. Each committee is chaired by a different independent director and all of the independent directors are members of each committee. The audit committee is composed entirely of independent directors. Each other committee (except the community collaboration and engagement committee) is composed entirely of the independent directors and D.C. Brownell, who is an employee of Exxon Mobil Corporation and although deemed non-independent under the relevant standards by virtue of his employment, is viewed as independent of the company’s management. The agendas of each of the board and its committees are not set by management alone, but by the board as a whole and by each committee. A significant number of agenda items are mandatory and recurring. Board meetings are scheduled at least one full year in advance. Any director may call a meeting of the board or a meeting of a committee of which the director is a member. There is a board-prescribed flow of financial, operating and other corporate information to all directors.

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The independent directors conduct executive sessions in the absence of members of management. These meetings are chaired by K.T. Hoeg, the independent director designated by the independent directors to chair and lead these discussions. Eight executive sessions were held in 2020.

The company’s delegation of authority guide provides that certain matters of the company are reviewed by functional contacts within ExxonMobil. The company’s employees are regularly reminded that they are expected to act in the best interests of the company, and are reminded of their obligation to identify any instances where the company’s general interest may not be consistent with ExxonMobil’s priorities. If such situations ever occurred, employees are expected to escalate such issues with successive levels of the company’s management. Final resolution of any such issues is made by the company’s chairman, president and chief executive officer.

Restrictions on insider trading

Commitment to stringent safeguards with trading restrictions and reporting for company insiders.

Structures and processes are in place to caution, track and monitor reporting insiders, nonemployee directors and key employees with access to sensitive information with respect to personal trading in the company’s shares. The company has guidelines regarding insider trading prohibitions and trading bans that are applicable to all directors, officers and employees.

Nonemployee directors are required to pre-clear any trades in the company’s shares. Reporting insiders are required to give advance notice to the company of any sale of the company’s shares and advise the company within five days of any purchase of the company’s shares. Reporting insiders are required, under securities regulations, to publically disclose all transactions in the company’s shares on the System for Electronic Disclosure by Insiders (SEDI).

From time to time, the company advises its directors and officers, and those of Exxon Mobil Corporation, and employees in certain positions not to trade in the company’s shares. Trading bans occur in connection with the directors’ pending consideration of the financial statements of the company, including the unaudited financial statements for each quarter, and in connection with undisclosed pending events that constitute material information about the business affairs of the company.

Diversity

The company has a long history of valuing diversity on the board and in its executive management.

Board diversity

The company has a longstanding commitment to diversity amongst its directors, and has had at least one woman on its board continuously since 1977.

The company does not have a formal written policy relating to the identification and nomination of directors who are women, Aboriginal peoples, persons with disabilities or members of visible minorities (the “designated groups”, as defined under the Canada Business Corporations Regulations, 2001), and has not adopted a target regarding members of the designated groups on its board. With the objective of fostering a diversity of expertise, viewpoint and competencies, the board charter provides that the nominations and corporate governance committee may consider a number of factors, including membership in a designated group, in assessing potential nominees. The nominations and corporate governance committee assesses the work experience, other expertise, individual competencies and diversity of age, regional association and the designated groups that each existing director possesses and whether each nominee is able to fill any gaps amongst the existing directors. Additionally, the committee may consider any other factors that it believes to be relevant. The company does not believe that any one of these dimensions should be considered in isolation and without due regard to all of the other factors, in determining the ability of potential directors to contribute to the work of the board of directors.

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As of the date of this proxy circular, the number and percentage of directors and nominees who are members of the designated groups are:

Designated group (a)	Number	Percent (%)
Women	2 of 7 (board) 2 of 7 (nominees) 2 of 5 (independent directors)	29 29 40
Aboriginal peoples	0 of 7	0
Persons with disabilities	0 of 7	0
Members of visible minorities	0 of 7	0

(a) Defined under the Employment Equity Act (Canada)

The above diversity disclosure relies on voluntary self-identification by directors and nominees, and therefore only represents the information of individuals who have chosen to self-identify. The information has not been independently verified by the company. The board nominee composition charts on page 120 show the diversity of our board nominees with respect to gender, experience and regional association, but do not reflect membership in other designated groups.

Executive officer diversity

The company believes inclusion and diversity are key competitive strengths that are critical to maintaining the company’s position as an industry leader. To ensure commitment at all levels of the company, inclusion and diversity, anti-harassment and equal employment opportunity performance is stewarded annually to the company’s senior management. There is an in-depth succession planning process, which includes the consideration of various aspects of diversity as well as plans to address gaps, if any, for key positions.

The company’s internal training programs emphasize the value of collaboration, appreciating differences and sustaining an inclusive work environment, keeping inclusion and diversity top-of-mind with all employees. Imperial also values external perspective and expertise, and collaborates with leading diversity organizations to help shape our future inclusion and diversity plans. The company supports educational development and recruiting practices that facilitate the employment of Indigenous peoples, and was recognized in 2020 by the Canadian Centre for Diversity and Inclusion as western Canada’s “employer initiative of the year” with respect to work done in the Indigenous community space. Imperial maintains a supportive work environment though a range of development and networking programs, including employee-led diversity networks that are focused on common interests. These programs continued in a virtual format in 2020 as a result of the COVID-19 pandemic.

In considering potential nominees for executive officer appointments, the executive resources committee considers diversity of gender and the other designated groups, work experience, other expertise, individual competencies and other dimensions of diversity in addition to the other factors described on page 160. The company has not adopted a target regarding members of the designated groups in executive officer positions. The company does not believe that any one of these dimensions should be considered, without due regard to all of these other factors, in determining the ability of potential nominees to fill executive officers positions.

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As of the date of this proxy circular, the number and percentage of executive officers of the company and its major subsidiaries who are members of the designated groups are:

Designated group (a)	Number	Percent (%)
Women	14 of 26	54
Aboriginal peoples	0 of 26	0
Persons with disabilities	0 of 26	0
Members of visible minorities	0 of 26	0

(a) Defined under the Employment Equity Act (Canada)

The above diversity disclosure relies on voluntary self-identification by executive officers, and therefore only represents the information of individuals who have chosen to self-identify. The information has not been independently verified by the company.

Shareholder engagement

    Shareholder engagement strategy focuses on wide-ranging dialogue between shareholders and management.

The company’s senior management regularly meet with institutional investors and shareholders through industry conferences, roadshows and company hosted investor events. In response to COVID-19 and to ensure the health and safety of our employees, investors and shareholders, these meetings were held exclusively in a virtual format for the balance of 2020. Materials from these conferences and hosted events are available on the company’s website.

Also in response to COVID-19 and to ensure the health and safety of its shareholders, directors, officers and stakeholders, the company took a number of steps to ensure active engagement through the annual meeting that was held in a virtual only format. Shareholders were given the opportunity to register a proxyholder to attend and ask questions in real time, and the company encouraged engagement from shareholders prior to the event. This format also allowed shareholders who may not otherwise have been able to attend in person to log in as a guest and follow the meeting. The webcast is available on the company website along with speeches and presentations from the annual general meeting and the outcome of the voting on each resolution.

The company also hosts regular quarterly earnings calls in connection with earnings releases, and archives of these calls (including transcripts) are available on Imperial’s website for one year after each call. These calls allow the company to provide more insight and context regarding the company’s performance, as well as directly address questions from the investment community.

The company annually solicits questions and comments from shareholders through the annual meeting of shareholders. The comments received are reviewed by senior management providing them with an indication of areas of interest to our shareholders, and those requiring a response are answered individually. In addition, the company’s Investor Relations team proactively reaches out to shareholders to obtain their views on matters identified broadly by shareholders, including with respect to environment, social and governance topics and to solicit feedback on the company’s approach to executive compensation. The Investor Relations team is available to respond to shareholder and investor queries throughout the year.

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Largest shareholder

    Exxon Mobil Corporation is the majority shareholder of the company, holding 69.6% of the company’s shares.

To the knowledge of the directors and executive officers of the company, the only shareholder who, as of February 16, 2021, owned beneficially, or exercised control or direction over, directly or indirectly, more than five percent of the outstanding common shares of the company is Exxon Mobil Corporation, 5959 Las Colinas Boulevard, Irving, Texas 75039-2298, which owns beneficially 510,916,893 common shares, representing approximately 69.6 percent of the outstanding voting shares of the company. As a consequence, the company is a “controlled company” for purposes of the listing standards of the NYSE American LLC and a “majority controlled company” for purposes of the TSX Company Manual.

Transactions with Exxon Mobil Corporation

The company has written procedures and controls that require any transactions between the company and ExxonMobil and its subsidiaries to be reviewed by controllers, tax, treasurers and legal to ensure that each agreement meets the company’s policies and procedures, is fair, and complies with legal and tax requirements. These agreements may also be subject to review by the chairman, president, and chief executive officer. Annual training is provided for key individuals to ensure awareness of the requirements for identifying related party transactions, and procedures are in place to ensure reporting of these transactions is complete and accurate. Related party transactions with ExxonMobil and its subsidiaries are analyzed and reviewed by management on a quarterly basis to understand any significant variances from period to period, and reviewed with the board of directors on an annual basis.

On June 27, 2019, the company implemented a 12-month “normal course” share purchase program. Between June 27, 2019 and June 26, 2020, the company purchased 8,724,518 common shares on the open market and a corresponding 19,972,996 common shares from ExxonMobil concurrent with, but outside of the program to maintain its shareholding at approximately 69.6 percent. In response to market conditions, the company announced the suspension of purchases under this program on April 1, 2020. On June 29, 2020, a further 12-month normal course share purchase program was implemented, primarily to eliminate dilution from shares issued in conjunction with Imperial’s restricted stock unit plan. Under the current program, the company may purchase up to 50,000 common shares. As of February 16, 2021, under the current program, the company has purchased 6,975 common shares on the open market and none from Exxon Mobil Corporation outside of this program.

The amounts of purchases and sales by the company and its subsidiaries for other transactions in 2020 with ExxonMobil and its affiliates were $2,424 million and $5,101 million, respectively. These transactions were conducted on terms as favourable as they would have been with unrelated parties, and primarily consisted of the purchase and sale of crude oil, natural gas, petroleum and chemical products, as well as technical, engineering and research and development costs. Transactions with ExxonMobil also included amounts paid and received in connection with the company’s participation in a number of upstream activities conducted jointly in Canada. In addition, the company has existing agreements with affiliates of ExxonMobil to provide information technology and customer support services to the company and to share common business and operational support services to allow the companies to consolidate duplicate work and systems. The company has a contractual agreement with an affiliate of ExxonMobil in Canada to operate certain western Canada production properties owned by ExxonMobil. There are no asset ownership changes.

The company and that affiliate also have a contractual agreement to provide for equal participation in new upstream opportunities. During 2007, the company entered into agreements with ExxonMobil and one of its affiliated companies that provide for the delivery of management, business and technical services to Syncrude Canada Ltd. by ExxonMobil.

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As at December 31, 2020, the company had an outstanding loan of $4,447 million under an existing agreement with an affiliated company of ExxonMobil that provides for a long term, variable rate loan from ExxonMobil to the company of up to $7.75 billion (Canadian) at market interest rates. The agreement is effective until June 30, 2025, cancellable if ExxonMobil provides at least 370 days advance written notice. Additionally, the company had an outstanding short-term loan of $111 million from an affiliated company of ExxonMobil. This loan is borrowed under an arrangement with ExxonMobil that provides for a non-interest bearing, revolving demand loan from ExxonMobil to the company of up to $150 million and represents ExxonMobil’s share of a working capital facility required to support purchasing, marketing, transportation and derivative arrangements for crude oil and diluent products undertaken by the company on behalf of ExxonMobil.

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Company executives and executive compensation

Named executive officers of the company

The named executive officers of the company at year end 2020 are listed below. B.W. Corson was appointed to the board and as president of the company on September 17, 2019 and assumed the additional roles of chairman and chief executive officer on January 1, 2020. T.B. Redburn retired from the company on January 1, 2021. All other named executive officers remain in their positions as of February 16, 2021.

Bradley W. Corson, 59
Calgary, Alberta, Canada
	Position held at the end of 2020 (date office held): Chairman, president and chief executive officer (2020 – Present)
	Other positions in the past five years (position, date office held and status of employer):
	President (2019 – Present)
	President, ExxonMobil Upstream Ventures (2015 – 2019) (Affiliate)
Daniel E. Lyons, 58
Calgary, Alberta, Canada
	Position held at the end of 2020 (date office held): Senior vice-president, finance and administration, and controller (2018 – Present)
	Other positions in the past five years (position, date office held and status of employer):
	Vice-president, downstream business services and downstream treasurer, Exxon Mobil Corporation (2015 – 2018) (Affiliate)
Theresa B. Redburn, 59
Calgary, Alberta, Canada
	Position held at the end of 2020 (date office held):
	Senior vice-president, commercial and corporate development (2017 – 2020)
	Other positions in the past five years (position, date office held and status of employer):
	Vice-president, upstream commercial (2014 – 2016)
Simon P. Younger, 45
Calgary, Alberta, Canada	Position held at the end of 2020 (date office held):
	Senior vice-president, upstream (2020 – Present)
	Other positions in the past five years (position, date office held and status of employer):
	Vice-president, production, upstream (2019 – 2020)
	Senior planning advisor, corporate strategic planning, upstream, Exxon Mobil Corporation (2017 – 2019) (Affiliate)
	Vice-president, production and joint interest manager, ExxonMobil Qatar Limited (2015 – 2017) (Affiliate)

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Bruce A. Jolly, 53
Calgary, Alberta, Canada
	Position held at the end of 2020 (date office held):
	Assistant controller (2019 – Present)
	Other positions in the past five years (position, date office held and status of employer):
	Upstream controller (2018 – 2019)
	Controller, United States upstream production, Exxon Mobil Corporation (2016 – 2018) (Affiliate)
	Manager, global downstream financial coordination, Exxon Mobil Corporation (2013 – 2016) (Affiliate)

Other executive officers of the company

In addition to the named executive officers listed above and on the previous page (with the exception of T.B. Redburn), the following individuals are executive officers of the company as of February 16, 2021.

Jonathan R. Wetmore, 48
Calgary, Alberta, Canada
	Position held (date office held):
	Vice-president, downstream and Western Canada fuels manager (2018 – Present)
	Other positions in the past five years (position, date office held and status of employer):
	Manager, supply and manufacturing (June 2017 – December 2017)
	Refinery manager, Fawley UK, UK Esso Petroleum Company Ltd (2013 – 2017) (Affiliate)
Sherri L. Evers, 44
Calgary, Alberta, Canada
	Position held (date office held):
	Vice-president, commercial and corporate development (2021 – Present)
	Other positions in the past five years (position, date office held and status of employer):
	Fuels manager, Central and Eastern Canada, fuels and lubricants (2018 – 2020)
	Product exchange and analysis manager, refining and supply, Exxon Mobil Corporation (2016 – 2018) (Affiliate)
	Midwest and northeast integrated business team lead, refining and supply, Exxon Mobil Corporation (2014 – 2016) (Affiliate)

Kitty Lee, 44
Calgary, Alberta, Canada	Position held (date office held):
	Treasurer
	(2020 – Present)
	Other positions in the past five years (position, date office held and status of employer):
	Financial advisor, treasurer’s, Exxon Mobil Corporation
	(2019 – 2020) (Affiliate)
	Benefits finance manager, treasurer’s, Exxon Mobil Corporation
	(2018 – 2019) (Affiliate)
	Global coordination manager, controller’s, Exxon Mobil Corporation
	(2016 – 2018) (Affiliate)
	Financial advisor, treasurer’s, Exxon Mobil Corporation
	(2015 – 2016) (Affiliate)

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Kristi L. Desjardins, 47
Calgary, Alberta, Canada	Position held (date office held):
	Vice-president, human resources
	(2020 – Present)
	Other positions in the past five years (position, date office held and status of employer):
	Human resources services manager, global human resources operations, Exxon Mobil Corporation
	(2018 – 2020) (Affiliate)
	Manager, human resources services
	(2017 – 2018)
	Manager, human resources services, operations
	(2014 – 2017)
Constance D. Gemmell, 54
Calgary, Alberta, Canada
	Position held (date office held): Director, corporate tax (2018 – Present)
	Other positions in the past five years (position, date office held and status of employer):
	Manager, income tax planning and advice (2013 – 2018)
Kimberly J. Haas, 47
Sarnia, Ontario, Canada	Position held (date office held):
	Vice-president, chemicals and Sarnia chemical plant manager
	(2020 – Present)
	Other positions in the past five years (position, date office held and status of employer):
	Project executive, chemicals, global operations, Exxon Mobil Chemical Company
	(2020) (Affiliate)
	Process manager, Baytown olefins plant, Exxon Mobil Chemical Company,
	(2016 – 2020) (Affiliate)
	Plant manager, Pensacola specialty elastomers plant, Exxon Mobil Chemical Company
	(2014 – 2016) (Affiliate)
Ian R. Laing, 47
Calgary, Alberta, Canada	Position held (date office held):
	Vice-president, general counsel and corporate secretary
	(2020 – Present)
	Other positions in the past five years (position, date office held and status of employer):
	Assistant general counsel, downstream and corporate departments and corporate secretary
	(2019 – 2020)
	Assistant general counsel, upstream
	(2017 – 2018)
	Assistant general counsel, downstream
	(2014 – 2016)

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Letter to shareholders from the executive resources committee on executive compensation

Dear fellow shareholders:

The executive resources committee (“committee”) would like to outline for you the role of the committee in ensuring good governance in the management of executive compensation within the company.

Compensation governance

The committee is responsible for corporate policy on compensation and for specific decisions on the compensation of the chief executive officer, key senior executives and officers of the company. In exercising this responsibility, the committee views long-term orientation and the management of risk as integral elements of the compensation policies and practices of the company. These policies and practices are designed to keep management, including named executive officers, focused on the strategic objectives of the company over the long term and to effectively assess and mitigate risk in the execution of these objectives. The committee exercises oversight of a compensation program that supports the company’s objective to attract, develop and retain key talent needed to achieve its strategic objectives.

The compensation discussion and analysis (“CD&A”) section that follows describes the compensation program for the company’s named executive officers and how the program supports the business goals of the company. The company’s compensation program is designed to:

● align the interests of its executives with long-term shareholder interests;

● encourage executives to manage risk and take a long-term view when making investments and managing the assets of the business;

● reinforce the company’s philosophy that the experience, skill and motivation of the company’s executives are significant determinants of future business success; and

● promote career orientation and strong individual performance.

The compensation program design is aligned with the core elements of the majority shareholder’s compensation program, including linkage to short and medium term aspects of incentive pay, long vesting periods, risk of forfeiture and alignment with the shareholder experience.

We execute our oversight responsibilities in this regard by ensuring the company’s program is built on sound principles of compensation design, including an annual assessment of comparator companies, appropriate risk assessment and risk management practices, sound governance principles, and support of the company’s business model. In exercising our oversight and decision making roles, the committee balances many factors each year in terms of impact on compensation decisions relative to the company’s performance.

2020 business performance results

The committee considers both business results and individual performance in its decisions. 2020 presented the company and the broader industry with extreme challenges. On the demand side, the COVID-19 pandemic resulted in significantly reduced demand for our products. Just as the pandemic took hold, we also saw announcements of increased production in certain key oil-producing countries leading to sharp declines in oil prices. In this difficult environment, the company took rapid action to weather the storm, while remaining focused on delivering long-term shareholder value and positioning itself well for a recovery in demand and prices. Key 2020 business results include:

● Protected our work force in the face of the pandemic and delivered strong safety performance and effective management of enterprise risk

● Responded to market conditions resulting from the COVID-19 pandemic and decreases in commodity prices

¡ Effective April 1, the company suspended the share buyback program to preserve cash

¡ Took decisive action to reduce capital and operating expenditures - committed to reducing capital expenditures by $0.5 billion compared to initial guidance of $1.6 to $1.7 billion, and expense reduction of $0.5 billion compared to the same period of 2019. Significantly exceeded both commitments:

◾ Capital expenditures for the full year of about $0.9 billion, down by nearly half versus initial guidance

◾ Production and manufacturing expenses for the full year are $5.5 billion, approximately $1.0 billion or 15 percent below 2019

¡ Adjusted planned asset maintenance scopes and schedules to reduce on-site staffing levels, lower costs and to opportunistically complete maintenance during periods of lower demand

¡ Supported the national COVID-19 response, including:

◾ Donating 60 tonnes of isopropyl alcohol to be used in disinfectant products

◾ Providing $2 million in free fuel vouchers to frontline workers

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● $1.9 billion net loss, reflecting the extremely challenging business environment and including non-cash impairment charge of $1.2 billion related to the company’s decision to not further develop a significant portion of its unconventional portfolio

● Generated positive cash flow from operating activities of $0.8 billion with substantial expense reductions helping to offset the difficult market conditions

● Maintained quarterly dividend level of $0.22 per share and increased the annual dividend paid for the 26th consecutive year while maintaining stable debt levels

● Over $0.9 billion returned to shareholders through dividends and share purchases

● Strong operational performance in the upstream

¡ 398,000 gross oil-equivalent barrels per day of full-year upstream production

¡ Successfully completed full startup of Kearl supplemental crushing facilities driving record annual production at Kearl

¡ Achieved the highest upstream quarterly production in 30 years in the fourth quarter

● Adaptability drove positive earnings in the Downstream and Chemical businesses

¡ Economically optimized utilization, feedstock and product slates in line with pandemic impacts

¡ Leveraged new facilities at Strathcona refinery to produce and sell record volumes of asphalt

¡ Used spare capacity to produce record levels of diluent amidst favorable market conditions in the fourth quarter

¡ Commenced operations of Strathcona refinery’s co-generation project

● Continued commitment to industry leadership in technology, innovation and sustainability

¡ Invested $140 million in research and development activities

¡ Published Imperial’s Corporate Sustainability Report

● Received Canadian Centre for Diversity and Inclusion’s western Canada “Employer Initiative of the Year” recognizing the company’s approach to Indigenous business development

● Recognized as one of Canada’s top 100 employers by Mediacorp Canada Inc.

Collectively, the above factors had an impact on 2020 compensation decisions for the named executive officers.

2020 Compensation program highlights
Base salary	●   Salary increases included in this disclosure reflect market analysis and competitiveness at the time of the decision in 2019. ●   For 2021, the executive resources committee elected to hold base salaries at 2020 levels, reflective of the current market conditions.
Annual bonus	●   The 2020 annual bonus program (cash bonus and earnings bonus units) was suspended, reflective of the current business environment and the resulting company earnings. ●   This resulted in no executives receiving an annual bonus in 2020, compared to 65 executives who received an annual bonus in 2019 (program cost $3.2 million).
Restricted stock units	●   After a review of the competitive orientation of the company’s restricted stock unit program, it was determined that current levels of restricted stock units were appropriate and that the program continues to align with the design of the majority shareholder’s program. ●   In 2020, 456 recipients, including 63 executives, were granted 747,040 restricted stock units.

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The committee’s assessment is that the company’s compensation program is working as intended, particularly in the current business environment, and has been effectively integrated over the long term with the company’s business model. A substantial portion of executive total direct compensation is variable pay at risk, which exposes their compensation to the full impact of the commodity price cycle. Further, the suspension of the annual bonus program and the nature of our restricted stock units program being issued on a share denominated basis have directly impacted the overall compensation levels for our executives. The results of the executive compensation program has demonstrated the intent with which it was designed, and consequently has resulted in lower levels of compensation in 2020 for our chief executive officer, key senior executives and officers of the company.

The committee has recommended to the board that the CD&A be included in the company’s management proxy circular for the 2021 annual meeting of shareholders. We encourage you to read the comprehensive disclosure in the CD&A that follows. The committee is committed to overseeing all aspects of the executive compensation program in the best interests of the company and all shareholders.

Submitted on behalf of the executive resources committee,

Original signed by

D.S. Sutherland,

Chair, executive resources committee

D.W. Cornhill, Vice-chair

D.C. Brownell

K.T. Hoeg

M.C. Hubbs

J.M. Mintz

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Compensation discussion and analysis
Table of contents
Overview	157
Canadian business environment	157
Business model	157
Key business strategies	157
Key elements of the compensation program	157
Management of risk	158
Other supporting compensation and staffing practices	159
Hedging policy	159
Business performance and basis for compensation	159
Succession planning	160
Compensation program	160
Career orientation	160
Base salary	161
Annual bonus	162
Restricted stock units	163
Vesting of restricted stock units	164
Amendments to the restricted stock unit plan	164
Forfeiture and claw-back risk	166
Retirement benefits	167
Pension plan benefits	167
Savings plan benefits	168
Compensation considerations	169
Benchmarking	169
Comparator companies	169
Analytical tools – Compensation summary sheets	170
2020 named executive officer compensation assessment	170
2020 chief executive officer compensation assessment	172
Pay awarded to other named executive officers	172
Independent consultant	172
Performance graph	173
Frequently used terms	173
Executive compensation tables and narratives	174
Summary compensation table	174
Outstanding share-based awards and option-based awards for named executive officers	176
Incentive plan awards for named executive officers – Value vested during the year	177
Equity compensation plan information	178
Restricted stock units as a percentage of outstanding shares	178
Annual burn rate	179
Status of prior long-term incentive compensation plans	179
Pension plan benefits	179

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Overview

The company takes a long-term view to managing its business.

Providing energy to help meet the demands of both Canada and the rest of North America is a complex business. The company meets this challenge by taking a long-term view in managing its business rather than reacting to short-term business cycles. The company’s strategies provide the framework to deliver on its commitments, create shareholder value throughout the commodity price cycle, and address the dual challenge of meeting growing energy demand while reducing environmental impacts. As such, the compensation program design aligns with the long-term sustainability of the business and supports key business strategies as outlined below:

Canadian business environment

· Large, accessible upstream resources

· Mature, competitive downstream markets

· Evolving environmental, fiscal and energy policies impacting global competitiveness

· Market access limitations, uncertainties

Business model

· Long-life, competitively advantaged assets

· Disciplined investment and cost management

· Value-chain integration and synergies

· High-impact technologies and innovation

· Operational excellence and responsible growth

Key business strategies

· Personnel safety and operational excellence

· Grow profitable production and sales volumes

· Disciplined and long-term focus on improving the productivity of the company’s asset mix

· Best-in-class cost structure to support industry-leading returns on capital and superior cash flow

These key business strategies are the primary focus and support long-term growth in shareholder value.

Key elements of the compensation program

The key elements of the company’s compensation program that align with the business model and support key business strategies are:

	Element	Features
	Restricted Stock Units	·   Approximately 50 percent or more of total direct compensation for named executive officers (a) ·   Aligns level of executive compensation with returns of long-term shareholders ·   Encourages long-term view through commodity price cycle ·   Places significant portion of executive pay at risk of forfeiture
	Annual bonus (b)	·   Approximately 10 to 20 percent of total direct compensation for named executive officers (a) ·   Link pay to annual company earnings performance ·   Actual award determined by company earnings performance, individual performance and pay grade ·   50 percent of award paid in cash at grant; 50 percent subject to delayed payout feature that is based on future earnings performance ·   Delayed feature provides medium-term performance metric and puts 50 percent of bonus at risk of forfeiture
	Base Salary	·   Provides a base level of competitive income, determined by performance, experience and pay grade ·   Ties directly to retirement benefits
	Retirement Benefits	·   Pension and savings plans ·   Provide for financial security after employment

(a) Total direct compensation includes salary, the annual bonus grant (cash and earnings bonus units awards), and the grant date fair value of the restricted stock unit award which is equal to the price of the company’s common shares on the date of grant.

(b) The annual bonus program was suspended for 2020. See page 162 for further details about the program.

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Management of risk

The company is governed by a comprehensive and well-established risk management system, and the company’s success in managing risk over time has been achieved through emphasis on execution of this disciplined management framework. The company operates in an industry in which effective risk management is critical. The company’s risk management framework includes a process for identifying, prioritizing, measuring, and managing the principal risks across the company, as well as assessing the company’s response to these risks. This framework establishes common expectations for addressing risks inherent in our business and takes priority over other business and financial objectives. For further discussion on the company’s risk management system and oversight, see “Risk oversight” within the “Statement of corporate governance practice” on page 129.

The company’s long-term orientation and compensation program design encourage the highest performance standards and discourage inappropriate risk taking. The compensation program components described below are designed to incent effective management of all operating and financial risks associated with the company’s business, including risks related to climate change, in order to:

· protect the safety and security of our employees, the communities and the environment in which we operate;

· manage risk and operate the business with effective business controls;

· create sustainable value for company shareholders by increasing shareholder return, net income, return on average capital employed*; and

· advance the long-term strategic direction of the company.

Due to the long vesting periods of restricted stock units and the linkage of compensation to overall company performance, including all aspects of risk management, executive compensation is inherently designed to support the sustainability of our operations and management of risk.

* For a definition of return on average capital employed, see the “Frequently used terms” section on page 173.

Compensation components

To manage risk, a substantial portion of total compensation (excluding compensatory pension value) to senior executives is in the form of an annual bonus and restricted stock units. In the judgment of the committee, the mix of short, medium and long-term incentives strikes an appropriate balance in aligning the interests of the senior executives with the business priorities and the long-term sustainable growth of the company to create value for the shareholder. Ongoing reviews of our compensation program, including incentives, ensure continued relevance of this mix and applicability for the company.

The table below outlines the risk management elements of our compensation programs:

Compensation Components	Risk Management
Common programs	·  All executives employed by the company, including the named executive officers, participate in common programs (the same salary, incentive and retirement programs). Similar compensation design features and allocation of awards within the programs discourage inappropriate risk taking. The compensation of executives is differentiated based on individual performance assessment, level of responsibility and individual experience. ·  All executives on assignment from an affiliate of the company, including the named executive officers on assignment from Exxon Mobil Corporation and Esso Australia Pty Ltd., also participate in common programs that are administered by Exxon Mobil Corporation or such affiliates. The named executive officers on assignment receive the company’s restricted stock units. ·  The executive resources committee reviews and approves compensation recommendations for each named executive officer prior to implementation.
Annual bonus	·  Delayed payout – Payout of 50 percent of the annual bonus is delayed. The timing of the delayed payout is determined by earnings performance. This is a unique feature of the company’s program relative to many comparator companies. ·  Recoupment (“claw-back”) and forfeiture – The entire annual bonus is subject to claw-back and the delayed portion of the annual bonus is subject to forfeiture in the event of material negative restatement of the company’s reported financial or operating results. This reinforces the importance of the company’s financial controls and compliance programs. Claw-back and forfeiture provisions also apply if an executive resigns or engages in detrimental activity.

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Restricted stock units

·  Long holding periods – To further reinforce the importance of risk management and a long-term investment orientation, senior executives are required to hold a substantial portion of their equity incentive award for periods that far exceed the typical holding periods of comparator stock programs. The lengthy holding periods are tailored to the company’s business model. ·  Risk of forfeiture – During these long holding periods, the restricted stock units are at risk of forfeiture for resignation or detrimental activity. The long vesting periods on restricted stock units and the risk of forfeiture together support an appropriate risk/reward profile that reinforces the long-term orientation expected of senior executives.

Pension

·  The company’s defined benefit pension plan and supplemental pension arrangements are highly dependent on executives remaining with the company for a career and performing at the highest levels until retirement. This dimension of total compensation encourages executives to take a long-term view when making business decisions and to focus on achieving sustainable growth for shareholders.

For more details about the aforementioned compensation components, see the “Compensation program” section.

Other supporting compensation and staffing practices

· A long established program of management development and succession planning is in place to reinforce a career orientation and ensure continuity of leadership.

· The use of perquisites at the company is very limited, and mainly composed of financial planning for senior executives and the selective use of club memberships which are largely tied to building business relationships.

· Tax assistance is provided for employees on expatriate assignment. This assistance consists primarily of a tax equalization component designed to maintain the employees’ overall income tax burden at approximately the same level it would have otherwise been, had they remained in their home country. The expatriate relocation program is broad-based and applies to all executive, management, professional and technical transferred employees.

Hedging policy

Company policy prohibits all employees, including executives, and directors, from being a party to derivative or similar financial instruments, including puts, calls, or other options, future or forward contracts, or equity swaps or collars, with respect to the company or Exxon Mobil Corporation stock.

Business performance and basis for compensation

The assessment of employee performance is conducted through the company’s performance assessment program. Conducted annually, the process assesses performance against relevant business performance measures and objectives, including the means by which performance is achieved. These business performance measures may include:

· safety, health and environmental performance;

· risk management;

· total shareholder return;

· net income;

· return on average capital employed*;

· cash flow from operations and asset sales*;

· operating performance of the upstream, downstream and chemical segments; and

· progress on advancing government relations and long-term strategic interests.

* For a definition of return on average capital employed and cash flow from operations and asset sales, see the “Frequently used terms” section on page 173.

The performance assessment program includes a comparative assessment of employee performance using a standard approach throughout the organization and at all levels. It is integrated with the compensation program, which results in significant pay differentiation between higher and lower performers. The performance assessment program is also integrated with the executive development process. Both have been in place for many years and are the basis for planning individual development and succession for management positions. Decision-making with respect to compensation requires judgment, taking into account business and individual performance and responsibility. Quantitative targets or formulae are not used to assess individual performance or determine the amount of compensation.

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Succession planning

The succession planning process fosters the company’s approach to a career orientation and promotion from within. This approach strengthens continuity of leadership and supports ongoing alignment with our long-term business model. This process helps to assess the competence and readiness of individuals for senior executive positions. The executive resources committee is responsible for approving specific succession plans for the position of chairman, president and chief executive officer and key senior executive positions, including all officers of the company.

The executive resources committee regularly reviews the company’s succession plans for key senior executive positions. It considers candidates for these positions from within the company and certain candidates from Exxon Mobil Corporation and its affiliates. This is an in-depth review of succession plans, which includes the consideration of various aspects of diversity as well as plans to address gaps, if any, for key executives. The company has a long-standing practice to regularly review with senior management the progress of women, Indigenous people, persons with disabilities and visible minorities including topics such as recruitment, attrition, training and development. For more information regarding executive officer diversity see page 145.

The chairman, president and chief executive officer also discusses the strengths, progress and development needs of key succession candidates regularly. This provides the board an opportunity to confirm a pipeline of key and diverse talent exists to enable achievement of long-term strategic objectives. The executive resources committee makes recommendations to the board of directors for selection of all officers of the company, as well as other key senior executive positions reporting to the chairman, president and chief executive officer.

Compensation program

The company’s compensation program is designed to reward performance,

promote retention, and encourage long-term business decisions.

Career orientation

The company’s objective is to attract, develop and retain over a career the best talent available. It takes a long period of time and significant investment to develop the experienced executive talent necessary to succeed in the company’s business. Senior executives must have experience with all phases of the business cycle to be effective leaders. The company’s compensation program elements are designed to encourage a career orientation among employees at all levels of the company. Career orientation among a dedicated and highly skilled workforce, combined with the highest performance standards, contributes to the company’s leadership in the industry and serves the interests of shareholders in the long term. Company service of the named executive officers ranges from approximately 30 to 36 years and reflects this on-going career orientation strategy.

The compensation program emphasizes individual experience and performance; executives holding similar positions may receive substantially different levels of compensation. Consistent with the company’s long-term career orientation, high-performing executives typically earn substantially higher levels of compensation in the later years of their careers. This pay practice reinforces the importance of a long-term focus on making decisions that are key to business success.

The company’s executive compensation program is composed of base salaries, as well as short-term cash bonus and medium-term and long-term incentive compensation. The company does not have written employment contracts or any other agreement with its named executive officers providing for payments on change of control or termination of employment. The following chart provides an overview of the combined elements of the compensation program for executives, including the ‘pay at risk’ horizon for the executives.

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Base salary

Salaries provide executives with a base level of income. Individual salary increases may vary based on each executive’s performance assessment and other factors such as the executive’s responsibility, career development and experience. Salary decisions also directly affect the level of retirement benefits since salary is included in the retirement benefits calculation. Thus, the level of retirement benefits is also performance-based, like other elements of compensation.

2020 Decisions

· Given that executive salaries are determined prior to the start of each year, the salary increases included in this disclosure reflect market analysis and competitiveness at the time of the decision in 2019.

· For 2021, the executive resources committee elected to hold base salaries at 2020 levels, reflective of the current market conditions.

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Annual bonus

The bonus program is established annually by the executive resources committee based on earnings, and can be highly variable depending on these results.

In establishing the annual bonus program, the executive resources committee:

· considers input from the chairman, president and chief executive officer on performance of the company and from the company’s internal compensation advisors regarding compensation trends as obtained from external consultants;

· considers the linkage to the majority shareholder’s bonus program given the company’s working interest is included in Exxon Mobil Corporation earnings;

· considers annual net income of the company; and

· uses judgment to manage the overall size of the annual bonus program taking into consideration the cyclical nature and long-term orientation of the business.

The annual bonus program incorporates unique elements to further reinforce retention and recognize performance. Awards under this program are generally delivered as:

· The annual bonus includes the combined value of the cash bonus and delayed earnings bonus unit portion, and is intended to be competitive with other major comparator companies.

· The cash component is intended to be a short-term incentive, while the earnings bonus unit is intended to be a medium-term incentive. Earnings bonus units are generally equal to and granted in tandem with cash bonuses. Individual bonus awards vary depending on each executive’s performance assessment.

· Earnings bonus units are cash awards that are tied to future cumulative earnings per share. This is a unique feature of the company’s program relative to many comparator companies.

· Earnings bonus units pay out when a specified level of cumulative earnings per share (or trigger) is achieved or in three years at a reduced level. The trigger is intentionally set at a level that is expected to be achieved within the three-year period and reinforces the company’s principle of sustained improvement in the company’s business performance and aligns the interests of executives with those of long-term shareholders.

· If cumulative earnings per share do not reach the trigger within three years, the payment with respect to the earnings bonus units will be reduced to an amount equal to the number of units multiplied by the actual cumulative earnings per share over the three-year period. The amount of the award, once vested, will never exceed the original grant value. The delayed payout of the earnings bonus units puts part of the annual bonus at risk of forfeiture and thus reinforces the performance basis of the annual bonus grant.

2020 Decisions

· The 2020 annual bonus program (cash bonus and earnings bonus units) was suspended, reflective of the current business environment and the resulting company earnings.

· This resulted in no executives receiving an annual bonus in 2020, compared to 65 executives who received an annual bonus in 2019 (program cost $3.2 million).

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Restricted stock units

The vesting periods of the company’s long-term incentive program are greater

than those in use by comparator companies.

The company’s only long-term incentive compensation plan is a restricted stock unit plan, in place since December 2002. Restricted stock units are granted to select employees of the company, select employees of a designated affiliate and nonemployee directors of the company. The current plan’s vesting periods for employees are as follows:

·   for the chairman, president and chief executive officer

·   for all other employees

Granting compensation in the form of restricted stock units with long vesting periods is aligned with the long-term nature of the company’s business. This stock program design helps keep executives focused on the key premise that decisions made today affect the performance of the organization and company stock for many years to come. This practice supports a risk/reward model that reinforces a long-term view, which is critical to the company’s sustainable business success, and discourages inappropriate risk taking.

The basis for the grant includes an annual assessment of individual performance including a review of business performance results as noted on page 170. The amount granted is intended to provide an incentive to promote individual contribution to the company’s performance and to retain employees. The restricted stock unit program awards the same number of shares for individuals with the same level of individual performance and pay grade or level of responsibility. Grants may be adjusted periodically based on an assessment of the program’s competitive orientation. An individual’s grant amount may be reduced at time of grant, if recent performance is deemed to have changed significantly at that time. As a matter of principle, the company does not offset losses on prior grants with higher share awards in subsequent grants, nor does the company re-price restricted stock units. Restricted stock units are not included in pension calculations.

The vesting periods, which are typically greater than those in use by other companies, reinforce the company’s focus on growing shareholder value over the long term by linking a large percentage of executive compensation and the shareholding net worth of executives to the value of the company’s stock. The long vesting periods ensure that a substantial portion of the compensation received by the chairman, president and chief executive officer, as well as other key senior executives, will be received after retirement. The value of this compensation is at risk in the event that their decisions prior to retirement negatively impact share market value after retirement. The objective of these aforementioned vesting periods is to hold senior executives accountable for many years into the future, and even into retirement, for investment and operating decisions made today. This type of compensation design removes employee discretion in the timing of exercising restricted stock units, reinforces retention objectives, and supports alignment with the long-term interests of shareholders.

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2020 Decisions

· After a review of the competitive orientation of the company’s restricted stock unit program, it was determined that current levels of restricted stock units were appropriate and that the program continues to align with the design of the majority shareholder’s program.

· In 2020, 456 recipients, including 63 executives, were granted 747,040 restricted stock units.

Vesting of restricted stock units

Restricted stock units vest pursuant to the vesting provisions described in the previous section. Restricted stock units cannot be assigned. The vesting period for restricted stock unit awards is not subject to acceleration, except in the case of death.

Upon vesting, each restricted stock unit entitles the recipient the right to receive an amount equal to the value of one common share of the company, based on the five day average closing price of the company’s shares on the vesting date and the four preceding trading days. For units granted to senior executives other than the chairman, president and chief executive officer, 50 percent of the units vest as a cash payment on the third and seventh anniversary of the grant date, with the following exception: for units granted to Canadian residents, the recipient may receive one common share of the company per unit or elect to receive a cash payment for the units that vest on the seventh anniversary. For all units granted to the chairman, president and chief executive officer, upon vesting, the recipient may receive one common share of the company per unit or elect to receive a cash payment for the units. During the restricted period, the recipient will also receive cash payments equivalent to the cash dividends paid to holders of regular common stock.

The company’s directors and officers as a group hold approximately 11 percent of the unvested restricted stock units that give the recipient the right to receive common shares that represent about 0.03 percent of the company’s outstanding common shares. Currently, the maximum number of common shares that any one person may receive from the vesting of restricted stock units is 690,500 common shares, which is about 0.09 percent of the outstanding common shares. In the case of any subdivision, consolidation, or reclassification of the shares of the company or other relevant change in the capitalization of the company, the company, in its discretion, may make appropriate adjustments in the number of common shares to be issued and the calculation of the cash amount payable per restricted stock unit.

Exxon Mobil Corporation has a plan similar to the company’s restricted stock unit plan, under which grantees may receive restricted stock or restricted stock units, both of which are referred to herein as Exxon Mobil Corporation restricted stock. B.W. Corson holds Exxon Mobil Corporation restricted stock granted in 2018 and previous years, as well as the company’s restricted stock units granted since 2019. D.E. Lyons holds Exxon Mobil Corporation restricted stock granted in 2017 and previous years, as well as the company’s restricted stock units granted since 2018. S.P. Younger holds Exxon Mobil Corporation restricted stock granted in 2019 and previous years, as well as the company’s restricted stock units granted in 2020.

Amendments to the restricted stock unit plan

In 2008, the company’s restricted stock unit plan was amended to provide that the number of common shares of the company issuable under the plan to any insiders (as defined by the Toronto Stock Exchange) cannot exceed 10 percent of the issued and outstanding common shares, whether at any time or as issued in any one year. The Toronto Stock Exchange advised that this amendment did not require shareholder approval. Additionally, shareholders approved the following changes to the restricted stock unit plan:

· In addition to the existing three and seven year vesting provisions, include an additional vesting period option for 50 percent of restricted stock units to vest on the fifth anniversary of the date of grant, with the remaining 50 percent of the grant to vest on the later of the tenth anniversary of the date of grant or the date of retirement of the grantee. The recipient of such restricted stock units may receive one common share of the company per unit or elect to receive the cash payment for all units to be vested. The choice of which vesting period provision to use will be at the discretion of the company.

· Set a vesting price based on the weighted average price of the company’s shares on the vesting date and the four consecutive trading days immediately prior to the vesting date.

· Set out which amendments in the future will require shareholder approval, and which amendments will only require board of directors approval. The board of directors may amend the plan without shareholder approval for RSUs previously issued or to be issued in the future, unless the amendment is with respect to:

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· increasing the shares served for issuance;

· increasing the vesting price;

· extending eligibility to participate in the plan to persons not included in the plan;

· extending the right of a grantee to transfer or assign RSUs; or

· adjusting the vesting date for any RSUs previously granted.

In 2011, the restricted stock unit plan was amended to include language confirming the long-standing practice of not forfeiting any restricted stock units in the event that the grantee’s continued employment terminates on or after the date the grantee reaches the age of 65 in circumstances where the grantee becomes entitled to an annuity under the company’s retirement plan.

In 2016, the restricted stock unit plan was amended to update provisions regarding forfeiture of restricted stock units in the event of detrimental activity and to provide a new vesting option in addition to the existing vesting options previously described, such that the second 50 percent of the restricted stock units may vest on the tenth anniversary following the grant date.

In 2020, the restricted stock unit plan was amended to update provisions regarding the vesting periods for the units granted in 2020 and onwards to the chairman, president and chief executive officer, such that 50 percent of restricted stock units vest on the fifth anniversary and remaining 50 percent on the tenth anniversary. For awards granted prior to 2020, the vesting of the tenth anniversary portion of the award is delayed until retirement if later than 10 years.

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Forfeiture and claw-back risk

The company’s incentive plans include forfeiture and claw-back provisions that discourage

employees from taking inappropriate risks and engaging in detrimental activities.

The annual bonus is subject to forfeiture and claw-back if:

· An executive retires or employment with the company terminates (for any reason, whether at initiative of employee, the company or otherwise).

· The company has indicated its intention not to forfeit outstanding awards of employees who retire at age 65. In other circumstances, where a recipient retires or terminates employment, the company may determine that awards shall not be forfeited.

· Risk of forfeiture and claw-back continues to exist for detrimental activity.

· An executive, without the consent of the company, engages in any activity, during employment or after retirement or the termination of employment, which is detrimental to the company, including working for a competitor.

· In 2016, the plan was amended to extend the forfeiture period for detrimental activity from two years to the life of the award.

· There is a material negative restatement of the company’s reported financial or operating results. For executive officers of the company, some or all of any unvested earnings bonus units granted in the three years prior to the restatement are subject to forfeiture. In addition, any cash amounts received from bonus or earnings bonus units that were paid out up to five years prior to the restatement are subject to claw-back.

Restricted stock units are subject to forfeiture and claw-back if:

· A recipient retires or employment with the company terminates (for any reason, whether at initiative of employee, the company or otherwise).

· The company has indicated its intention not to forfeit restricted stock units of employees who retire at age 65. In other circumstances, where a recipient retires or terminates employment, the company may determine that restricted stock units shall not be forfeited.

· Risk of forfeiture and claw-back continues to exist for detrimental activity.

· A recipient, without the consent of the company, engages in any activity, during employment or after retirement or termination of employment, which is detrimental to the company, including working for a competitor.

· With respect to executives, at any time prior to vesting of the outstanding awards.

· With respect to all other employees, for a period of up to three years after retirement or the termination of employment.

· In 2016, the plan was amended to extend the forfeiture period for detrimental activity from two years to the periods noted.

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Retirement benefits

Named executive officers participate in the same pension plan, including supplemental pension arrangements outside the registered plan, as other employees, except for B.W. Corson, D.E. Lyons and S.P. Younger who participate in Exxon Mobil Corporation or respective affiliates’ pension plans.

Pension plan benefits

The company has provided defined benefit pension plans to its employees since 1919. The current pension plan provides a 1.5 percent accrual formula to all employees hired on and after September 1, 2015. All plan participants employed prior to the date of the change will continue to accrue pension benefits based on accrual formulae in place prior to September 1, 2015. A portion of the pension plan provides for pension benefits accrual only until December 1st in the year the employee reaches the age of 71. The company’s non-registered supplemental pension arrangements address any portions of the defined benefit that cannot be paid from the registered plan due to income tax regulations that impose limits on the amounts that can be paid from a registered plan.

Any pension amounts paid to an eligible employee are subject to the employee meeting the terms of the registered pension plan, and if applicable, the criteria of the supplemental pension arrangements. No supplemental pension amounts are payable if an employee resigns before reaching retirement eligibility.

For executive officers who receive an annual bonus, the company’s supplemental pension arrangements can also provide an annual benefit of either 1.5 percent or 1.6 percent of final average bonus earnings multiplied by years of service depending on the plan which they participate in. Final average bonus earnings include the average annual bonus for the three highest grants of the last five awarded prior to retirement for eligible executives, but do not include restricted stock units. Limiting the final average bonus earnings to the five awards granted prior to retirement provides a strong incentive for executives to continue to perform at a high level. Annual bonus includes the cash amounts that are paid at grant and the maximum settlement value of any earnings bonus units received, as described starting on page 162. The value of the earnings bonus units are expected to pay out, subject to forfeiture provisions, and are therefore included for supplemental pension arrangement purposes in the year of grant rather than the year of payment.

The estimated benefits that would be payable upon retirement to each named executive officer under the company’s pension plan and the supplemental pension arrangements can be found in the pension plan benefits table starting on page 179. The company does not grant additional pension service credit.

T.B. Redburn and B.A. Jolly participate in the historic 1.6 percent provision of the company’s plan that was closed to new participants at the end of 1997. Key features of this historic plan include:

· An annual benefit equal to 1.6 percent multiplied by final average earnings multiplied by years of service, with a partial offset for applicable government pension benefits. Final average earnings consists of base salary over the highest 36 consecutive months in the 10 years of service prior to retirement.

· An option to forego a portion of the company’s matching contributions to the savings plan in order to receive an additional 0.4 percent of final average earnings.

B.W. Corson, D.E. Lyons and S.P. Younger are not participants in the company’s pension plan, but are participants in the Exxon Mobil Corporation or respective affiliates’ pension plans:

· Mr. Corson and Mr. Lyons participate in the Exxon Mobil Corporation defined benefit plan. Under this plan, the pension is payable in U.S. dollars and is calculated based on final average base salary over the highest 36 consecutive months in the 10 years of service prior to retirement, and the average annual bonus for the three highest grants of the last five awarded prior to retirement, but do not include restricted stock units.

· Mr. Younger participates in the Esso Australia Pty Ltd. Defined benefit plan. Under this plan, the pension is payable in Australian dollars and is calculated based on final average base salary over the highest 12 consecutive months in the 10 years of service prior to retirement.

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Savings plan benefits

The company maintains a savings plan into which career employees with more than one year of service may contribute between 1 and 30 percent of normal earnings. The company provides contributions which vary depending on the amount of employee contributions and in which defined benefit pension arrangement the employee participates. All named executive officers are eligible to receive a company matching contribution of up to 6 percent, except for B.W. Corson, D.E. Lyons, and S.P. Younger, who participate in their respective affiliates’ savings plan, where applicable.

Employee and company contributions can be allocated in any combination to a non-registered (tax-paid) account, or a registered (tax-deferred) group retirement savings plan (RRSP). Employee contributions can be redirected from the tax-paid account to a tax-free savings account (TFSA). Both the RRSP and TFSA accounts are subject to contribution limits under the Income Tax Act.

Available investment options include cash savings, a money market mutual fund, a suite of four index-based equity or bond mutual funds and company shares. Assets in the RRSP account and company contributions to the tax-paid account may only be withdrawn upon retirement or termination of employment, reinforcing the company’s long-term approach to total compensation. Income tax regulations require RRSPs to be converted into an eligible form of retirement income by the end of the calendar year in which the individual reaches age 71.

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Compensation decision making process and considerations for named executive officers

Benchmarking

In addition to the assessment of business performance, individual performance and level of responsibility, the executive resources committee relies on market comparisons to a group of major Canadian companies.

Comparator companies

The following criteria are used to select comparator companies:

· Canadian companies or Canadian affiliates;

· large operating scope and complexity;

· capital intensive; and

· proven sustainability.

Energy	Non-Energy
Canadian Natural Resources Limited	BCE Inc.
Cenovus Energy Inc.	Canadian Pacific Railway Limited
Chevron Canada Ltd.	Canadian Tire Corporation, Limited
China National Offshore Oil Corporation	General Electric Canada
ConocoPhillips Canada	IBM Canada Ltd.
Devon Canada Corporation	Proctor & Gamble Inc.
Enbridge Inc.	Royal Bank of Canada
Husky Energy Inc.
Irving Oil Ltd.
NOVA Chemicals Corporation
Nutrien Ltd.
Ovintiv Inc.
Repsol Oil & Gas Canada Inc.
Shell Canada Limited
Suncor Energy Inc.
TC Energy Corporation
Valero Energy

The company is a national employer drawing from a wide range of disciplines. It is important to understand its competitive orientation relative to a variety of energy and non-energy employers. Compensation trends across industries, based on survey data, are prepared annually by an independent external consultant with additional analysis and recommendation provided by the company’s internal compensation advisors. Consistent with the executive resources committee’s practice of using well-informed judgment rather than formulae to determine executive compensation, the committee does not target any specific percentile among comparator companies to align compensation. The focus is on a broader and more flexible orientation, generally a range around the median of the comparator energy companies’ compensation. This approach applies to salaries and the annual incentive program that includes annual bonus and restricted stock units.

As a secondary source of data, the executive resources committee also considers a comparison with the majority shareholder when it determines the annual bonus program. For the restricted stock unit program, the executive resources committee may review a summary of comparator company data provided by the same external consultant in order to assist in assessing total value of long-term compensation grants. As a result, grant level guidelines may be adjusted periodically to maintain the program’s competitive orientation. As a matter of principle, the company does not offset losses on prior grants with higher share awards in subsequent grants, nor does the company re-price restricted stock units.

This overall approach provides the company with the ability to:

· better respond to changing business conditions;

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· manage salaries based on a career orientation;

· minimize potential for automatic increasing of salaries, which could occur with an inflexible and narrow target among benchmarked companies; and

· differentiate salaries based on performance and experience levels among executives.

Details of the compensation assessment for the named executive officers are outlined on pages 170 and 172.

Analytical tools – Compensation summary sheets

The compensation summary sheet is a matrix used by the executive resources committee that shows the individual elements and total compensation for each senior executive. The summary sheet is used to understand how decisions on each individual element of compensation affect total compensation for each senior executive. The committee considers both current compensation recommendations and prior compensation results in its final determination.

The elements of Exxon Mobil Corporation and respective affiliates’ compensation programs for B.W. Corson, D.E. Lyons and S.P. Younger, including salary, annual bonus and restricted stock units (long-term) compensation considerations, are generally similar to those of the company. The data used for long-term compensation determination for Mr. Corson, Mr. Lyons, and Mr. Younger is as described previously, as they received the company’s restricted stock units in 2020. The executive resources committee reviews and approves recommendations for each named executive officer prior to implementation. Mr. Corson’s compensation determination is described in more detail on page 172.

2020 named executive officer compensation assessment

When determining the annual compensation for the named executive officers, the executive resources committee has reflected on the following business performance result indicators in its determination of 2020 salary and incentive compensation.

Business performance results for consideration

The operating and financial performance results listed below and the company’s continued maintenance of sound business controls and a strong corporate governance environment formed the basis for the salary and incentive award decisions made by the executive resources committee in 2020. The executive resources committee considered the results over multiple years, relative to the company’s proven business model and strategies, to deliver long-term shareholder value.

· Protected our work force in the face of the pandemic and delivered strong safety performance and effective management of enterprise risk

· Responded to market conditions resulting from the COVID-19 pandemic and decreases in commodity prices

o Effective April 1, the company suspended the share buyback program to preserve cash

o Took decisive action to reduce capital and operating expenditures - committed to reducing capital expenditures by $0.5 billion compared to initial guidance of $1.6 to $1.7 billion, and expense reduction of $0.5 billion compared to the same period of 2019. Significantly exceeded both commitments:

◾ Capital expenditures for the full year of about $0.9 billion, down by nearly half versus initial guidance

◾ Production and manufacturing expenses for the full year are $5.5 billion, approximately $1.0 billion or 15 percent below 2019

o Adjusted planned asset maintenance scopes and schedules to reduce on-site staffing levels, lower costs and to opportunistically complete maintenance during periods of lower demand

o Supported the national COVID-19 response, including:

◾ Donating 60 tonnes of isopropyl alcohol to be used in disinfectant products

◾ Providing $2 million in free fuel vouchers to frontline workers

· $1.9 billion net loss, reflecting the extremely challenging business environment and including non-cash impairment charge of $1.2 billion related to the company’s decision to not further develop a significant portion of its unconventional portfolio

· Generated positive cash flow from operating activities of $0.8 billion with substantial expense reductions helping to offset the difficult market conditions

· Maintained quarterly dividend level of $0.22 per share and increased the annual dividend paid for the 26th consecutive year while maintaining stable debt levels

· Over $0.9 billion returned to shareholders through dividends and share purchases

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· Strong operational performance in the upstream

o 398,000 gross oil-equivalent barrels per day of full-year upstream production

o Successfully completed full startup of Kearl supplemental crushing facilities driving record annual production at Kearl

o Achieved the highest upstream quarterly production in 30 years in the fourth quarter

· Adaptability drove positive earnings in the Downstream and Chemical businesses

o Economically optimized utilization, feedstock and product slates in line with pandemic impacts

o Leveraged new facilities at Strathcona refinery to produce and sell record volumes of asphalt

o Used spare capacity to produce record levels of diluent amidst favorable market conditions in the fourth quarter

o Commenced operations of Strathcona refinery’s co-generation project

· Continued commitment to industry leadership in technology, innovation and sustainability

o Invested $140 million in research and development activities

o Published Imperial’s Corporate Sustainability Report

· Received Canadian Centre for Diversity and Inclusion’s western Canada “Employer Initiative of the Year” recognizing the company’s approach to Indigenous business development

· Recognized as one of Canada’s top 100 employers by Mediacorp Canada Inc.

Performance assessment considerations

The preceding results form the context in which the committee assesses the individual performance of each senior executive, taking into account experience and level of responsibility. Annually, the chairman, president and chief executive officer reviews the performance of the senior executives in achieving business results and individual development needs.

The same long-term key business strategies noted on page 157 and the company’s business performance results are key elements in the assessment of the chairman, president and chief executive officer’s performance by the executive resources committee.

The performance of all named executive officers is also assessed by the board of directors throughout the year during specific business reviews and board committee meetings that provide information on strategy development, operating and financial results, safety, health, and environmental results, business controls, and other areas pertinent to the general performance of the company.

The executive resources committee does not use quantitative targets or formulae to assess individual executive performance or determine compensation. The executive resources committee does not assign weights to the factors considered. Formula-based performance assessments and compensation typically require emphasis on two or three business metrics. For the company to be an industry leader and effectively manage the technical complexity and integrated scope of its operations, most senior executives must advance multiple strategies and objectives in parallel, versus emphasizing one or two at the expense of others that require equal attention.

Senior executives and officers are expected to perform at the highest level or they are replaced. If it is determined that another executive is ready and would make a stronger contribution than one of the current incumbents, a replacement plan is implemented.

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2020 chief executive officer compensation assessment

B.W. Corson was appointed to the board and as president of the company on September 17, 2019 and assumed the additional roles of chairman and chief executive officer on January 1, 2020. Mr. Corson worked for Exxon Mobil Corporation and its predecessor companies since 1983. His level of salary in 2020 was determined by the executive resources committee based on his individual performance and to align with that of his peers in ExxonMobil. It was also the objective of the executive resources committee to ensure appropriate internal alignment with senior management in the company. For 2021, the executive resources committee elected to hold Mr. Corson’s base salary at the 2020 level reflective of the current market conditions.

Consistent with all other executives, Mr. Corson’s 2020 annual bonus was suspended to reflect the current business environment and resulting company earnings. His long-term incentive award was granted in the form of company restricted stock units, not Exxon Mobil Corporation restricted stock, to reinforce alignment of his interests with that of the company’s shareholders. His company restricted stock units are subject to vesting periods longer than those applied by most companies conducting business in Canada. 50 percent of the restricted stock units awarded vest in five years and the other 50 percent vest on ten years from the date of grant. The purpose of these long vesting periods is to reinforce the long investment lead times in the business and to link a substantial portion of Mr. Corson’s shareholding net worth to the performance of the company. As such, the payout value of the long-term incentive grants may differ from the amounts shown in the summary compensation table, depending on how the company actually performs at time of future vesting. During these vesting periods, the awards are subject to risk of forfeiture based on detrimental activity even after retirement.

The executive resources committee has determined that the total compensation of Mr. Corson was appropriate based on the company’s financial and operating performance, and its assessment of his effectiveness in leading the organization relative to the business performance measures outlined on page 159. Taking all factors into consideration, the committee’s decisions on compensation of the chief executive officer reflect judgment, rather than the application of formulae or targets.

Pay awarded to other named executive officers

Within the context of the compensation program structure and performance assessment processes previously described, the value of 2020 incentive awards and salary adjustments align with:

· performance of the company;

· individual performance;

· long-term strategic plan of the business; and

· annual compensation of comparator companies.

Taking all factors into consideration, the executive resources committee’s decisions on pay awarded to other named executive officers reflect judgment, rather than the application of formulae or targets. The executive resources committee approved the individual elements of compensation and the total compensation as shown in the summary compensation table on page 174.

Independent consultant

In fulfilling its responsibilities during 2020, the executive resources committee did not retain an independent consultant or advisor in determining compensation for any of the company’s officers or any other senior executives. The company’s management retained an independent consultant to provide an assessment of competitive compensation and market data for all salaried levels of employees of the company. While providing this data, they did not provide individual compensation recommendations or advice for the compensation of the chairman, president and chief executive officer or other senior executives.

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Performance graph

The following graph shows changes over the past 10 years in the value of $100 invested in (i) Imperial Oil Limited common shares, (ii) the S&P/TSX Composite Index, and (iii) the S&P/TSX Composite Energy Index. The S&P/TSX Composite Energy Index is currently made up of share performance data for 23 oil and gas companies including integrated oil companies, oil and gas producers and oil and gas service companies.

The year-end values in the graph represent appreciation in share price and the value of dividends paid and reinvested. The calculations exclude trading commissions and taxes. Total shareholder returns from each investment, whether measured in dollars or percent, can be calculated from the year-end investment values shown beneath the graph.

During the past 10 years, the company’s cumulative total shareholder return was negative 30 percent, for an average annual return of negative 3 percent. Over the past five years, the cumulative total shareholder return was negative 40 percent. Total direct compensation for named executive officers generally reflects the trend in total shareholder returns as the largest single component of executive compensation is awarded in the form of restricted stock units with long holding periods. This design reinforces the long-term linkage between executive compensation and the shareholding net worth of executives to the return on the company’s stock realized by shareholders. Total direct compensation includes salary, the annual bonus grant (cash and earnings bonus unit awards), and the grant date fair value of the restricted stock unit award which is equal to the price of the company’s common shares on the date of grant.

Frequently used terms

Return on average capital employed is a measure of capital productivity, and equals net income excluding the after-tax cost of financing divided by total average capital employed. Capital employed is property, plant and equipment, and other assets, less liabilities, excluding both short-term and long-term debt, plus the company’s share of equity company debt.

Cash flow from operating activities and asset sales is the sum of the net cash provided by operating activities and proceeds from asset sales reported in the consolidated statement of cash flows.

For additional information and reconciliation with respect to the terms, see the “Frequently used terms” section of the company’s most recent Annual Report on Form 10-K.

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Executive compensation tables and narratives

Summary compensation table

The following table shows the compensation for the chairman and chief executive officer; the senior vice-president, finance and administration, and controller; and the three other most highly compensated executive officers of the company who were serving as of the end of 2020. B.W. Corson was appointed to the board and as president of the company on September 17, 2019 and assumed the additional roles of chairman and chief executive officer on January 1, 2020. T.B. Redburn retired from the company on January 1, 2021 after 35 years of service.

The information in the Summary compensation table includes the Canadian dollar value of base salaries, cash bonus awards and earnings bonus unit payments, long-term incentive compensation and certain other compensation. Amounts in the table pertain to the named executive officers’ respective periods of assignment with the company.

Name and principal     position at the end of                   2020	Year	Salary ($) (d)		Share- based awards ($) (e)		Option- based awards ($) (f)		Non-equity incentive plan compensation ($)				Pension value ($) (i)		All other compensation ($) (j)		Total compensation ($) (k)
								Annual incentive plans (g)		Long-term incentive plans (h)
B.W. Corson (b) Chairman, president and chief executive officer (since September 17, 2019)	2020		996,734		1,897,132		-		-		0		(340,046)		1,945,980		4,499,800
	2019 (a)		187,070		2,532,116		-		376,176		317,791		(63,715)		151,909		3,501,347
D.E. Lyons (b) Senior vice-president, finance and administration, and controller (since May 1, 2018)	2020		689,307		553,128		-		-		0		(207,474)		1,516,702		2,551,663
	2019		665,551		621,696		-		135,344		135,341		(150,729)		545,109		1,952,312
	2018 (a)		419,807		737,088		-		165,202		94,588		(102,873)		573,059		1,886,871
T.B. Redburn Senior vice-president, commercial and corporate development	2020		531,600		533,720		-		-		0		(36,600)		127,184		1,155,904
	2019		501,600		712,360		-		101,800		156,548		(181,500)		82,308		1,373,116
	2018		471,600		844,580		-		123,700		82,411		442,200		66,967		2,031,458
S.P. Younger (b) Senior vice-president, upstream (since July 1, 2019)	2020		527,126		393,012		-		-		0		(299,441)		555,097		1,175,794
	2019 (a)		249,870		674,962		-		79,747		81,927		64,157		385,445		1,536,108
B.A. Jolly Assistant Controller (since April 1, 2018)	2020		444,500		393,012		-		-		0		23,300		76,767		937,579
	2019		413,333		427,416		-		63,300		75,954		(118,700)		70,093		931,396
	2018 (c)		296,250		506,748		-		77,200		46,270		733,400		43,880		1,703,748

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Footnotes to the Summary compensation table for named executive officers

(a) The compensation for B.W. Corson, D.E. Lyons, and S.P. Younger for the first year of their assignment has been prorated based on the start of their assignment. Mr. Corson was appointed as president of the company effective September 17, 2019. Mr. Corson’s expatriate assignment from Exxon Mobil Corporation, an affiliate in the U.S., formally started November 1, 2019 reflecting a transition period from his previous role. The company incurred costs related to Mr. Corson’s compensation from November 1, 2019 onwards, and a portion of his compensation between his appointment on September 17 and formal assignment on November 1, for service he provided to the company during this period. Mr. Lyons has been on expatriate assignment from Exxon Mobil Corporation, an affiliate in the U.S., since May 1, 2018. Mr. Younger has been on expatriate assignment from Esso Australia Pty Ltd., an affiliate in Australia, since July 1, 2019.

(b) The compensation for B.W. Corson, D.E. Lyons, and S.P. Younger is paid directly by Exxon Mobil Corporation and respective affiliates, with the exception of the compensation related to the vesting of the company’s restricted stock units and dividend equivalents on outstanding restricted stock units. They also receive employee benefits under their respective affiliates’ employee benefit plans, and not under the company’s employee benefit plans. The company reimburses the respective affiliates for applicable compensation paid and employee benefits provided to them. The company does not reimburse Exxon Mobil Corporation for the cost of incentive awards granted by Exxon Mobil Corporation.

(c) B.A. Jolly is an employee of the company who was on expatriate assignment with Exxon Mobil Corporation and returned to the company on April 1, 2018. Mr. Jolly’s compensation has been prorated in 2018 based on his date of return to the company.

(d) The amounts listed in the “Salary” column for each named executive officer on expatriate assignment (B.W. Corson, D.E. Lyons and S.P. Younger) are paid in their local currency, but disclosed in Canadian dollars. Mr. Corson’s and Mr. Lyons’ salaries are paid in U.S. dollars and were converted to Canadian dollars at the average 2020 exchange rate of 1.3415. In 2019 and 2018 the average exchange rate was 1.3269 and 1.2957 respectively. Mr. Younger’s salary is paid in Australian dollars and was converted to Canadian dollars at the average 2020 exchange rate 0.9247. In 2019 the average exchange rate was 0.9228.

(e) The grant date fair value equals the number of restricted stock units multiplied by the closing price of the company’s shares on the date of grant. The closing price of the company’s shares on the grant date in 2020 was $24.26, which is the same as the accounting fair value for the restricted stock units on the date of grant. The closing price of the company’s shares on the grant date in 2019 was $32.38 and in 2018 was $38.39, which is the same as the accounting fair value for the restricted stock units on the date of grant. The company chose this method of valuation as it believes it results in the most accurate representation of fair value.

(f) The company has not granted stock options since 2002. The stock option plan expired in 2012.

(g) The amounts listed in the “Annual incentive plans” column for each named executive officer represent their cash bonus in the current year. In 2020, the company suspended the annual cash bonus program, and therefore no cash payment was made. B.W. Corson, D.E. Lyons, and S.P. Younger participate in Exxon Mobil Corporation’s annual cash bonus program, which is similar to the company’s plan, and is paid in U.S. dollars, but disclosed in Canadian dollars. In 2020, Exxon Mobil Corporation’s annual bonus program was also suspended. For amounts paid in 2019 and 2018 in U.S. dollars, they were converted to Canadian dollars at the average exchange rate of 1.3269 and 1.2957 respectively.

(h) The amounts listed in the “Long-term incentive plans” column represent earnings bonus units related to prior year grants that paid out in 2020. In 2020, the maximum settlement value (trigger) or cumulative earnings per share was not achieved, therefore no payments were made. Also in 2020, the company suspended the annual bonus program, and therefore no earnings bonus units were granted. The earnings bonus unit program is described starting on page 162. B.W. Corson, D.E. Lyons and S.P. Younger participate in Exxon Mobil Corporation’s earnings bonus unit program, which is similar to the company’s plan, and is paid in U.S. dollars, but disclosed in Canadian dollars. Under the Exxon Mobil Corporation’s plan the maximum settlement value (trigger) or cumulative earnings per share was not achieved, therefore no payments were made. For amounts paid in 2019 and 2018 in U.S. dollars, they were converted to Canadian dollars at the average exchange rate of 1.3269 and 1.2957 respectively.

(i) “Pension value” is the “Compensatory change” in pensions as of December 31, 2020 as set out in the “Pension plan benefits” table on page 179.

(j) The amounts listed in the “All other compensation” column include dividend equivalent payments on restricted stock units granted, savings plans contributions, expatriate assignment costs, parking and the cost of perquisites including financial planning and business club memberships, as well as security costs and costs associated with participation in Exxon Mobil Corporation’s executive life insurance benefit plan, as applicable. For B.W. Corson and D.E. Lyons, Exxon Mobil Corporation suspended its company contributions to saving plans effective October 1, 2020.

· For each named executive officer, the aggregate value of perquisites received in 2020 was not greater than $50,000 or 10 percent of the named executive officer’s base salary.

· It is noted that in 2020, the actual dividend equivalent payments on the company restricted stock units were $51,612 for B.W. Corson, $29,568 for D.E. Lyons, $84,722 for T.B. Redburn and $48,510 B.A. Jolly. The dividend equivalent payments on Exxon Mobil Corporation restricted stock granted in previous years were $673,186 for Mr. Corson, $139,352 for Mr. Lyons and $144,721 for Mr. Younger; these amounts were paid in U.S. dollars and converted to Canadian dollars at the average 2020 exchange rate of 1.3415.

· For the named executive officers on expatriate assignment (B.W. Corson, D.E. Lyons and S.P. Younger), “All other compensation” also includes expatriate assignment costs which consist of expatriate allowances and the net effect of tax equalization costs in the year. Tax equalization costs include the net effect of taxes paid by the companies to local taxing authorities on behalf of the named executive officer offset by a withholding from their income that approximates the amount of tax they would pay if they had not gone on expatriate assignment. Tax equalization is an integral part of the expatriate relocation program and is designed to maintain an individual’s overall tax burden at approximately the same level it would have otherwise been, had they remained in their home country. Tax equalization amounts vary from one year to the next and the net impact may be positive or negative in the year.

(k) “Total compensation” consists of the total dollar value of “Salary”, “Share-based awards”, “Option-based awards”, “Non-equity incentive plan compensation”, “Pension value” and “All other compensation”.

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Outstanding share-based awards and option-based awards for named executive officers

The following table sets forth all share-based and option-based awards outstanding for each named executive officer of the company as at December 31, 2020.

	Option-based awards				Share-based awards
Name	Number of securities underlying unexercised options (#)	Option exercise price ($)	Option expiration date	Value of unexercised in-the- money options ($)	Number of shares or units of shares that have not vested (#) (d)	Market or payout value of share- based awards that have not vested ($) (d)	Market or payout value of vested share- based awards   not paid out or   distributed ($)
B.W. Corson (a)	-	-	-	-	156,400	3,778,624	-
D.E. Lyons (b)	-	-	-	-	61,200	1,478,592	-
T.B. Redburn	-	-	-	-	101,500	2,452,240	-
S.P. Younger (c)	-	-	-	-	16,200	391,392	-
B.A. Jolly	-	-	-	-	63,150	1,525,704	-

(a) B.W. Corson was granted restricted stock units in 2019 and 2020 under the company’s plan. With respect to previous years, Mr. Corson participated in Exxon Mobil Corporation’s restricted stock plan, which is similar to the company’s restricted stock unit plan. Under that plan, Mr. Corson held 116,100 Exxon Mobil Corporation restricted stock whose value on December 31, 2020 was $6,093,079 based on a closing price for Exxon Mobil Corporation shares on December 31, 2020 of $41.22 U.S., which was converted to Canadian dollars at the December 31, 2020 close rate of 1.2732 provided by the Bank of Canada.

(b) D.E. Lyons was granted restricted stock units from 2018 to 2020 under the company’s plan. With respect to previous years, Mr. Lyons participated in Exxon Mobil Corporation’s restricted stock plan, which is similar to the company’s restricted stock unit plan. Under that plan, Mr. Lyons held 19,550 Exxon Mobil Corporation restricted stock whose value on December 31, 2020 was $1,026,009 based on a closing price for Exxon Mobil Corporation shares on December 31, 2020 of $41.22 U.S., which was converted to Canadian dollars at the December 31, 2020 close rate of 1.2732 provided by the Bank of Canada.

(c) S.P. Younger was granted restricted stock units in 2020 under the company’s plan. With respect to previous years, Mr. Younger participated in Exxon Mobil Corporation’s restricted stock plan, which is similar to the company’s restricted stock unit plan. Under that plan, Mr. Younger held 25,800 Exxon Mobil Corporation restricted stock whose value on December 31, 2020 was $1,354,018 based on a closing price for Exxon Mobil Corporation shares on December 31, 2020 of $41.22 U.S., which was converted to Canadian dollars at the December 31, 2020 close rate of 1.2732 provided by the Bank of Canada.

(d) Represents the total of the outstanding restricted stock units received from the company plan in 2014 through 2020. The value is based on the closing price of the company’s shares on December 31, 2020 of $24.16.

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Incentive plan awards for named executive officers – Value vested or earned during the year

The following table sets forth the value of the incentive plan awards that vested in the year for each named executive officer of the company.

Name	Option-based awards – Value vested during the year ($)	Share-based awards – Value vested during the year ($) (d)	Non-equity incentive plan   compensation – Value earned   during the year ($) (e)
B.W. Corson (a)	-	-	-
D.E. Lyons (b)	-	-	-
T.B. Redburn	-	428,839	0
S.P. Younger (c)	-	-	-
B.A. Jolly	-	220,199	0

(a) Although B.W. Corson received restricted stock units under the company’s plan in 2019 and 2020, these restricted stock units have not vested. In previous years, Mr. Corson participated in Exxon Mobil Corporation’s restricted stock plan, which is similar to the company’s restricted stock unit plan. In 2020, restrictions were removed on 28,100 Exxon Mobil Corporation restricted stock having a value as at December 31, 2020 of $1,474,725 based on the closing price of Exxon Mobil Corporation common shares of $41.22 U.S., which was converted to Canadian dollars at the December 31, 2020 close rate of 1.2732 provided by the Bank of Canada. In 2020, Exxon Mobil Corporation suspended its annual bonus program, and therefore Mr. Corson did not receive an annual cash payment. Mr. Corson participates in Exxon Mobil Corporation’s earnings bonus unit plan, which is similar to the company’s earnings bonus unit plan. In 2020, the maximum settlement value (trigger) or cumulative earnings per share was not achieved, and therefore no payments were made.

(b) Although D.E. Lyons received restricted stock units under the company’s plan from 2018 to 2020, these restricted stock units have not vested. In previous years, Mr. Lyons participated in Exxon Mobil Corporation’s restricted stock plan, which is similar to the company’s restricted stock unit plan. In 2020, restrictions were removed on 10,300 Exxon Mobil Corporation restricted stock having a value as at December 31, 2020 of $540,557 based on the closing price of Exxon Mobil Corporation common shares of $41.22 U.S., which was converted to Canadian dollars at the December 31, 2020 close rate of 1.2732 provided by the Bank of Canada. In 2020, Exxon Mobil Corporation suspended its annual bonus program, and therefore Mr. Lyons did not receive an annual cash payment. Mr. Lyons participates in Exxon Mobil Corporation’s earnings bonus unit plan, which is similar to the company’s earnings bonus unit plan. In 2020, the maximum settlement value (trigger) or cumulative earnings per share was not achieved, and therefore no payments were made.

(c) Although S.P. Younger received restricted stock units under the company’s plan in 2020, these restricted stock units have not vested. In previous years, Mr. Younger participated in Exxon Mobil Corporation’s restricted stock plan, which is similar to the company’s restricted stock unit plan. In 2020, restrictions were removed on 5,200 Exxon Mobil Corporation restricted stock having a value as at December 31, 2020 of $ 272,903 based on the closing price of Exxon Mobil Corporation common shares of $41.22 U.S., which was converted to Canadian dollars at the December 31, 2020 close rate of 1.2732 provided by the Bank of Canada. In 2020, Exxon Mobil Corporation suspended its annual bonus program, and therefore Mr. Younger did not receive an annual cash payment. Mr. Younger participates in Exxon Mobil Corporation’s earnings bonus unit plan, which is similar to the company’s earnings bonus unit plan. In 2020, the maximum settlement value (trigger) or cumulative earnings per share was not achieved, and therefore no payments were made.

(d) These values show restricted stock units granted by the company that vested in 2020. The value is based on the five day average closing price of the company’s shares, which includes the vesting date and the four preceding trading days. For T.B. Redburn and B.A. Jolly the values represent restricted stock units granted in 2013 and 2017, which vested in 2020.

(e) This column represents amounts paid by the company with respect to the annual cash bonus and earnings bonus units granted in prior years that paid out in the current year. In 2020, the company suspended its annual bonus program, and therefore no annual cash payment was made. In 2020, the maximum settlement value (trigger) or cumulative earnings per share was not achieved, and therefore no earnings bonus unit payments were made.

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Equity compensation plan information

The following table provides information on the common shares of the company that may be issued as of the end of 2020 pursuant to compensation plans of the company.

Plan category	Number of securities to be issued upon exercise of outstanding options, warrants and rights (#) (c)	Weighted average exercise price of outstanding options, warrants and rights ($)	Number of securities remaining   available for future issuance under equity compensation plans (excluding securities reflected in the first column) (#) (c)
Equity compensation plans approved by security holders (a)	-	-	-
Equity compensation plans not approved by security holders (b)	2,217,145	-	8,257,617
Total	2,217,145		8,257,617

(a) The company’s stock option plan expired in 2012.

(b) This is a restricted stock unit plan, which is described starting on page 163.

(c) The Number of securities to be issued represents the total number of restricted stock units issued since 2011 and still outstanding (4,463,320) minus the outstanding restricted stock units that are only eligible for cash (and not common shares) upon vesting (2,246,175). The Number of securities remaining available for future issuance represents the restricted stock units not yet granted (6,011,442) plus the number of outstanding restricted stock units that are only eligible for cash (and not common shares) upon vesting (2,246,175).

Restricted stock units as a percentage of outstanding shares

The following table provides information on the restricted stock unit plan, expressed as a number and as a percentage of the common shares of the company as of the end of 2020.

	Maximum number of restricted stock units issuable under the plan (#) (b)	Total number of restricted stock units awarded and outstanding (#)	Total number of restricted     stock units available for grant     (#)
Number	10,474,762	4,463,320	6,011,442
Percent of outstanding common shares (a)	1.43%	0.61%	0.82%

(a) As of December 31, 2020, the number of common shares outstanding was 734,076,755.

(b) The Maximum number of restricted stock units issuable under the company plan is the number as of December 31, 2019 (10,481,737) minus the common shares issued in 2020 pursuant to the vesting of restricted stock units under the plan (6,975 common shares).

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Annual burn rate

The following table provides the annual burn rate associated with the restricted stock unit plan for each of the company’s three most recent fiscal years. The annual burn rate is the number of restricted stock units granted as a percentage of the weighted average number of outstanding shares of the company, which provides a measure of how quickly a company is using its available shares for incentive purposes.

	Number of restricted stock units granted under the plan (#) (a)	Weighted average number of securities outstanding (#) (b)	Annual burn rate             (%) (c)
2020	747,040	735,285,422	0.10%
2019	854,800	762,680,114	0.11%
2018	739,870	807,517,306	0.09%

(a) The Number of restricted stock units granted under the plan in the applicable fiscal year.

(b) The Weighted average number of securities outstanding during the period is the number of securities outstanding at the beginning of the period, adjusted by the number of securities bought back or issued during the period multiplied by a time-weighting factor.

(c) The Annual burn rate percent is calculated as the Number of restricted stock units granted under the plan divided by the Weighted average number of securities outstanding.

Status of prior long-term incentive compensation plans

The company’s only long-term incentive compensation plan is the restricted stock unit plan described starting on page 163. There are no units outstanding for any historical plan.

Pension plan benefits

The following table provides information for each named executive officer of the company participating in a defined benefit pension plan. Information for named executive officers on assignment from affiliates of the company who participate in a plan provided by such affiliates is disclosed in the footnotes.

Name	Number of years credited service (as of December 31, 2020) (#) (a)	Annual benefits   payable ($)		Opening present value of defined benefit   obligation   ($) (d)	Compensatory   change ($) (e)	Non-   compensatory   change ($) (f)	Closing present value of defined benefit   obligation   ($) (d)
		At year- end (b)	At age 65 (c)
B.W. Corson	-	-	-	-	-	-	-
D.E. Lyons	-	-	-	-	-	-	-
T.B. Redburn	35.6	116,500	110,000	7,978,400	(36,600)	2,347,400	10,289,200
S.P. Younger (g)	-	-	-	-	-	-	-
B.A. Jolly	29.5	249,100	350,800	4,890,300	23,300	633,300	5,546,900

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(a) B.W. Corson and D.E. Lyons participate in the Exxon Mobil Corporation defined benefit pension plan including tax-qualified and non-qualified plans. Benefits under this plan are payable in U.S. dollars and have been converted to Canadian dollars at the average 2020 exchange rate of 1.3415. Under this plan, Mr. Corson had 37.5 years of credited service and Mr. Lyons had 30.5 years of credited service. S.P. Younger participates in the Esso Australia Pty Ltd. defined benefit and defined contribution pension plans. Benefits under these plans are payable in Australian dollars and have been converted to Canadian dollars at the average 2020 exchange rate of 0.9247. Under these plans, Mr. Younger had 23.8 years of credited service.

(b) For members of the company’s pension plan, the annual benefits include the amount of the accrued annual lifetime pension from the company’s registered pension plan and supplemental pension arrangement. Benefits under the supplemental pension arrangement can be paid as a lump-sum equivalent upon retirement. For T.B. Redburn this value does not include the supplemental pension arrangement amount, which she elected to receive as a lump-sum upon retirement on January 1, 2021. For members of the Exxon Mobil Corporation’s pension plan, the annual benefits include the accrued annual lifetime pension from the tax-qualified and the annual amount calculated under the non-qualified plans. For B.W. Corson this value was $990,511. For D.E. Lyons this value was $457,161. Non-qualified plan benefits are payable only as a lump-sum equivalent upon retirement. For members of the Esso Australia Pty Ltd. defined benefit plan, benefits are payable as lump-sum equivalent or annual lifetime pension upon retirement for participants age 55 and older. For S.P. Younger, this is not applicable as his age is under 55 years, and therefore he is not currently entitled to pension if leaving service.

(c) For members of the company’s pension plan, the annual benefits include the amount of the accrued annual lifetime pension from the company’s registered pension plan and supplemental pension arrangement that would be earned to age 65 assuming final average earnings as at December 31, 2020. Benefits under the supplemental pension arrangement can be paid as a lump-sum equivalent upon retirement. For T.B. Redburn this value does not include the supplemental pension arrangement amount, which she elected to receive as a lump-sum upon retirement on January 1, 2021. For members of the Exxon Mobil Corporation’s pension plan, the annual benefits include the annual lifetime pension from the tax-qualified and the annual amount calculated under the non-qualified plans that would be earned to age 65 assuming final average earnings as at December 31, 2020. For B.W. Corson this value was $1,147,260. For D.E. Lyons this value was $560,639. Non-qualified plan benefits are payable only as a lump-sum equivalent upon retirement. For members of the Esso Australia Pty. Ltd. defined benefit plan, benefits are payable as an annual lifetime pension or a lump-sum equivalent upon retirement or a combination of both, as elected by the participant upon leaving service. For S.P. Younger the lump-sum value that would be earned to age 65 assuming final average earnings as of December 31, 2020 was $347,706.

(d) For members of the company’s pension plan, the opening and closing defined benefit obligation is defined under U.S. Generally Accepted Accounting Principles (GAAP) and values are calculated on a basis that is consistent with the valuation that was performed for accounting purposes for the company’s plans. The value is calculated based on estimated earnings eligible for pension as described previously and Yearly Maximum Pensionable Earnings (YMPE) as defined by the Canada Revenue Agency, projected to retirement and pro-rated on service to the date of valuation. The calculations assume that the Canada Pension Plan offset is based on the annual maximum benefit at retirement and the Old Age Security (OAS) offset is based on the OAS benefit at the date of valuation, projected to retirement. For members of the Exxon Mobil Corporation and Esso Australia Pty Ltd. pension plan respectively, the opening and closing defined benefit obligation is defined under GAAP and values are consistent with the valuation performed for accounting purposes for the applicable affiliate plan. The values are calculated based on estimated earnings eligible for pension as described previously. For B.W. Corson, the opening value was $13,197,216 and the closing value was $13,704,884. For D.E. Lyons the opening value was $6,170,553 the closing value was $6,412,007. For S.P. Younger, the opening value was $3,184,827 and the closing value was $3,171,837.

(e) The value for “Compensatory change” includes service cost for 2020 and the impact of change in earnings on the projected benefit obligation. For members of the company’s plan, these values are calculated using the individual’s additional pensionable service in 2020 and the actual salary and bonus received in 2020. For members of the Exxon Mobil Corporation and Esso Australia Pty Ltd. pension plans, these values are calculated using the individual’s additional pensionable service in 2020 and earnings as described previously. For B.W. Corson this value was ($340,046). For D.E. Lyons this value was ($207,474). For S.P. Younger this value was ($299,621).

(f) The value for “Non-compensatory change” includes the impact of experience not related to earnings, benefit payments and change in measurement assumptions. With respect to the company’s pension plan, the discount rate used to determine the closing present value of defined benefit obligation at the end of 2020 decreased to 2.5 percent, from 3.1 percent at the end of 2019, which had a positive impact on the non-compensatory change element. For members of the Exxon Mobil Corporation and Esso Australia Pty Ltd., the value for “Non-compensatory change” includes the impact of experience not related to earnings or service. For the Exxon Mobil Corporation’s plan this includes the effect of interest based on a discount rate of 2.8 percent at the end of 2020, down from 3.5 percent at the end of 2019. For the Esso Australia Pty Ltd. Plan, this includes the effect of interest based on a discount rate of 2.1 percent at the end of 2020, down from 2.9 percent at the end of 2019. For B.W. Corson this value was $847,714. For D.E. Lyons this value was $448,928. For S.P. Younger this value was $286,631.

(g) S.P. Younger participates in the Esso Australia Pty Ltd. defined contribution plan. Contribution limits under this plan have been reached. The “Accumulated value at start of year” was $40,046, the “Compensatory value” was $180 reflecting affiliate contribution and investment earnings, and the “Accumulated value at year-end” was $40,226.

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Appendix A – Board of director and committee charters

Board of Directors Charter

The structure, process and responsibilities of the board of directors of the corporation shall include the following items and matters:

1. Responsibility

The directors shall be responsible for the stewardship of the corporation.

2. Duty of care

The directors, in exercising their powers and discharging their duties, shall:

(a) act honestly and in good faith with a view to the best interests of the corporation; and

(b) exercise the care, diligence and skill that a reasonably prudent person would exercise in comparable circumstances.

3. Stewardship process

In order to carry out their responsibility for stewardship within their duty of care, the directors shall, directly or through one or more committees of directors,

(a) contribute to the formulation of and approve strategic plans on at least an annual basis;

(b) identify the principal risks of the corporation’s business where identifiable and oversee the implementation of appropriate systems to manage such risks;

(c) oversee succession planning for senior management, including the appointing, training and monitoring thereof;

(d) approve the corporate disclosure guidelines and monitor the external communications of the corporation;

(e) monitor the integrity of the corporation’s internal control and management information systems;

(f) monitor the integrity of the corporation’s information technology and systems to ensure the security and integrity of the corporation’s electronic information, systems and assets;

(g) consider management’s recommendations regarding major corporation decisions and actions, which have significant societal implications;

(h) monitor compliance with major corporate policies;

(i) charge the chief executive officer of the corporation with the general management and direction of the business and affairs of the corporation;

(j) monitor the performance of the chief executive officer;

(k) satisfy itself as to the integrity of the chief executive officer and other executive officers and ensure that the chief executive officer and the other executive officers create a culture of integrity throughout the company;

(l) annually review and approve the corporation’s code of ethics and business conduct;

(m) monitor compliance with the code of ethics and business conduct, provided that any waivers from the code that are granted for the benefit of the issuer’s directors or executive officers should be granted by the board only;

(n) determine appropriate measures are in place for receiving feedback from stakeholders;

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(o) by appropriate charter resolutions, establish the audit, executive resources, nominations and corporate governance, public policy and corporate responsibility and community collaboration and engagement committees of the board with specific duties defined and the corporation provide each board committee with sufficient funds to discharge its responsibilities in accordance with its charter;

(p) determine membership of each committee, including its chair and vice-chair, after receiving the recommendation of the nominations and corporate governance committee;

(q) direct the distribution to the board by management of information that will enhance their familiarity with the corporation’s activities and the environment in which it operates, as set out in section 5;

(r) review the corporation’s process in respect of employee conflicts of interest and directorships in non-affiliated commercial, financial and industrial organizations and the disclosures thereof;

(s) review the mandates of the board and of the committees and their effectiveness at least annually; and

(t) undertake such additional activities within the scope of its responsibilities as it may deem appropriate.

4. Range of items to be considered by the board

The following categories and specific items shall be referred to the board for information or decision on a regularly scheduled basis, to the extent appropriate:

Organization/legal

● fixing of the number of directors

● director appointments to fill interim vacancies

● director slate for election by the shareholders

● officer appointments

● board governance processes

● by-laws and administrative resolutions

● changes in fundamental structure of the corporation

● shareholder meeting notice and materials

● non-employee director compensation

● policies adopted by the board

● investigations and litigation of a material nature

Financial

● equity or debt financing

● dividend declarations

● financial statements and the related management discussion and analysis, annual and quarterly

● status of the corporation’s retirement plan and employee savings plan

Strategic/investment/operating plans/performance

● near-term and long-range outlooks

● capital, lease, loan and contributions budgets annually

● budget additions over $250 million individually

● quarterly updates of actual and projected capital expenditures

● capital expenditures or dispositions in excess of $250 million individually

● entering into any venture that is outside of the corporation’s existing businesses

● financial and operating results quarterly

● Canadian and world economic outlooks

● regional socio-economic reviews

● corporate reputation reviews

● risk management reviews

● environment and sustainability reviews

● personnel and process safety systems and performance reviews

● information technology, systems and cybersecurity

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In addition to the items which are specific to the categories identified above, the chief executive officer shall refer to the board for information or decision all other items of corporate significance; and any member of the board may request a review of any such item. Items to be referred to the committees of the board are specified in their respective charters.

5. Information to be received by the board

Material shall be distributed to directors through the office of the corporate secretary. Corporate policies, board calendars, contact information and other company processes, are updated on the board portal site and accessible to all directors.

Material under the following general headings, including the specific items listed below and only other similar items, shall be distributed to directors on a regular basis:

Organization/legal

● articles of incorporation, by-laws and administrative resolutions

● corporate policies

● corporate data

● board and management processes

● financial and operating report

● organization outline

Social/political/economic environment

● public issues updates

● economic outlook

● external communications packages

● information technology, systems and cybersecurity updates

Major announcements

● press releases

● speeches by management

● organization changes

Communications to shareholders

Other significant submissions, studies and reports

6. Meetings of the board

(a) The board normally holds seven (7) regular meetings per year. Additional meetings may be scheduled as required to consider the range of items charged for consideration by the board.

(b) An agenda for each board meeting and briefing materials will, to the extent practicable in light of the timing of matters that require board attention, be distributed to each director approximately five to seven days prior to each meeting. The chairman, in consultation with the chair of the executive sessions will normally set the agenda for board meetings. Any director may request the inclusion of specific items.

(c) It is expected that each director will make every effort to attend each board meeting and each meeting of any committee on which he or she serves. Attendance in person is preferred but attendance by teleconference is permitted if necessary.

(d) Each director should be familiar with the agenda for each meeting, have carefully reviewed all other materials distributed in advance of the meeting, and be prepared to participate meaningfully in the meeting, and to discuss all scheduled items of business.

(e) The proceedings and deliberations of the board and its committees are confidential. Each director will maintain the confidentiality of information received in connection with his or her service as a director, and the chief executive officer, or those whom he or she has designated, will speak for the corporation.

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7. Independent directors

(a) The board shall be composed of a majority of independent directors. The board may also include one or more directors who are not independent, but who, as officers of the majority shareholder, may be viewed as independent of the company’s management.

(b) In respect of each director to be appointed to fill a vacancy and each director to be nominated for election or re-election by the shareholders, the board shall make an express determination as to whether he or she is an independent director and, for a director who may become a member of the audit committee, whether he or she is an audit committee financial expert or financially literate.

(c) The term “independent”, shall have the meaning as set out in applicable law, including on the basis of the standards specified by National Instrument 52-110 Audit Committees, the US. Securities and Exchange Commission rules and the listing standards of the NYSE American LLC.

(d) Independent directors will have full access to senior management of the corporation and other employees on request to discuss the business and affairs of the corporation. The board expects that there will be regular opportunities for directors to meet with the chief executive officer, and other members of management in board and committee meetings and in other formal or informal settings.

(e) Compensation for independent directors will be determined by the board on the recommendation of the nominations and corporate governance committee and will be reviewed annually. Non-employee director compensation will be set at a level that is consistent with market practice, taking into account the size and scope of the corporation’s business and the responsibilities of its directors. A substantial portion of the compensation paid to independent directors for service on the board will be paid in restricted stock units of the corporation.

8. Independent legal or other advice

It is normally expected that information regarding the corporation’s business and affairs will be provided to the board by the corporation’s management and staff and by its independent auditors. However, the board and, with the approval of the board, any director, may engage independent counsel and other advisors at the expense of the corporation. The fees and expenses of any such advisor will be paid by the corporation.

9. Meetings of the independent directors in the absence of members of management

(a) Meetings of the independent directors (“executive sessions of the board”) shall be held in conjunction with all board meetings including unscheduled telephonic board meetings. Additional executive sessions may be convened by the chair or the executive sessions at his or her discretion and will be convened if requested by any other director. Any independent director may raise issues for discussion at an executive session.

(b) The chair of the executive sessions of the board shall be chosen by the independent directors.

(c) The chair of the executive sessions of the board, or in the chair’s absence an independent director chosen by the independent directors, shall

(i) preside at executive sessions of the board;

(ii) ensure that meetings of the independent directors are held in accordance with this charter;

(iii) review, and modify if necessary the agenda of the meetings of the board in advance to ensure that the board may successfully carry out its duties; and

(iv) act as a liaison with the chairman, including providing feedback from the executive sessions to the chairman, provided that each director will also be afforded direct and complete access to the chairman at any time as such director deems necessary or appropriate.

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(d) The purposes of the executive sessions of the board shall include the following:

(i) to raise substantive issues that are more appropriately discussed in the absence of management;

(ii) to discuss the need to communicate to the chairman of the board any matter of concern raised by any committee or any director;

(iii) to address issues raised but not resolved at meetings of the board and assess any follow-up needs with the chairman of the board;

(iv) to discuss the quality, quantity, and timeliness of the flow of information from management that is necessary for the independent directors to effectively and responsibly perform their duties, and advise the chairman of the board of any changes required; and

(v) to seek feedback about board processes.

10. Selection and tenure of directors

The nominations and corporate governance committee shall recommend to the board a slate of director candidates for election at each annual meeting of shareholders and shall recommend to the board directors to fill vacancies, including vacancies created as a result of any increase of the size of the board.

The guidelines for selection and tenure of directors shall be as follows:

(a) Selection

In considering the qualifications of potential nominees for election as directors, the nominations and corporate governance committee considers the work experience and other areas of expertise of the potential nominees with the objective of providing for diversity among non-employee directors. The following key criteria are considered to be relevant to the work of the board of directors and its committees:

Work Experience

● Experience in leadership of businesses or other large organizations (Leadership of large organizations)

● Operations/technical experience (Operations / technical)

● Project management experience (Project management)

● Experience in working in a global work environment (Global experience)

● Experience in development of business strategy (Strategy development)

● Experience with environmental, health, community relations and/or safety policy, practices and management (Environment and sustainability)

Other Expertise

● Audit committee financial expert

● Expertise in financial matters (Financial expertise)

● Expertise in managing relations with government (Government relations)

● Experience in academia or in research (Academic / research)

● Expertise in information technology and cybersecurity oversight (Information technology / Cybersecurity oversight)

● Expertise in executive compensation policies and practices (Executive compensation)

● Expertise in oversight of risk management policies and practices (Risk management)

In addition, the nominations and corporate governance committee may consider the following additional factors:

● possessing expertise in any of the following areas: law, science, marketing, administration, social/political environment or community and civic affairs;

● individual competencies in business and other areas of endeavour in contributing to the collective experience of the directors; and

● providing diversity in age, regional association, gender and other diversity elements (including Aboriginal peoples, persons with disabilities and members of visible minorities).

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The nominations and corporate governance committee shall then assess what work experience and other expertise each existing director possesses. The nominations and corporate governance committee shall identify individuals qualified to become new board members and recommend to the board the new director nominees. In making its recommendations, the nominations and corporate governance committee shall consider the work experience and other expertise that the board considers each existing director to possess and which each new nominee will bring. The nominations and corporate governance committee may also consider the additional factors noted above and any other factors which it believes to be relevant.

A candidate may be nominated for directorship after consideration has been given as to his or her degree of compatibility with the following criteria, i.e., as to whether he or she:

● will not adversely affect the requirements with respect to citizenship and residency for the directors imposed by the Canada Business Corporations Act;

● will not adversely affect the corporation’s status as a foreign private issuer under U.S. securities legislation;

● possesses the ability to contribute to the broad range of issues with which the directors and any one or all of the committees of directors must deal;

● will serve on the boards of other public companies only to the extent that such services do not detract from the director’s ability to devote the necessary time and attention as a director;

● is able to devote the necessary amount of time to prepare for and attend all meetings of the directors and committees of directors, and to keep abreast of significant corporate developments;

● is free of any present or apparent potential legal impediment or conflict of interest, such as:

o serving as an employee or principal of any organization presently providing a significant level of service to the corporation or which might so provide to the corporation, for example, institutions engaged in commercial banking, underwriting, law, management consulting, insurance, or trust companies; or of any substantial customer or supplier of the corporation;

o serving as an employee or director of a competitor of the corporation, such as petroleum or chemical businesses, or of a significant competitor of corporations represented by a director of this corporation;

o serving as the chief executive officer or a top administrator of an organization that has the chief executive officer or a top administrator of this corporation serving as director;

● is expected to remain qualified to serve for a minimum of five years;

● will not, at the time that he or she stands for election or appointment, have attained the age of 72;

● if an independent director, is, or will become within a period of five years of becoming a director, the beneficial owner, directly or indirectly, of not less than 15,000 common shares, deferred share units or restricted stock units of the corporation.

(b)     Tenure

(i) Re-nomination

An incumbent director shall be supported for re-nomination as long as he or she:

● does not suffer from any disability that would prevent the effective discharge of his or her responsibilities as a director;

● makes a positive contribution to the effective performance of the directors;

● regularly attends directors’ and committee meetings;

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• has not made a change with respect to principal position or thrust of involvement or regional association that would significantly detract from his or her value as a director of the corporation;

• is not otherwise, to a significant degree, incompatible with the criteria established for use in the selection process;

• in a situation where it is known that a director will become incompatible with the criteria established for use in the selection process within a three-month period of election, such as retirement from principal position at age 65, this information would be included in the management proxy circular, and where possible, information regarding the proposed replacement would also be included;

• will not, at the time that he or she stands for re-election, have attained the age of 72; however, under exceptional circumstances, at the request of the chairman, the nominations and corporate governance committee may continue to support the nomination.

(ii)     Resignation

An incumbent director will resign in the event that he or she:

• experiences a change in circumstances such as a change in his or her principal occupation, including an officer of the corporation ceasing to hold that position, but not merely a change in geographic location;

• displays a change in the exercise of his or her powers and in the discharge of duties that, in the opinion of at least 75 percent of the directors, is incompatible with the duty of care of a director as defined in the Canada Business Corporations Act;

• has made a change in citizenship or residency that will adversely affect the requirements for directors with respect to those areas imposed by the Canada Business Corporations Act;

• has made a change in citizenship or residency that adversely affects the corporation’s status as a foreign private issuer under U.S. securities legislation;

• develops a conflict of interest, such as

¡ assuming a position as an employee or principal with any organization providing a significant level of service to the corporation, for example, institutions engaged in commercial banking, underwriting, law, management consulting, insurance, or trust companies; or with any substantial customer or supplier of the corporation;

¡ assuming a position as an employee or director of any competitor of the corporation, such as petroleum or chemical businesses, or of a competitor of corporations represented by a director of this corporation;

¡ assuming the position of chief executive officer or a top administrator of an organization that has the chief executive officer or a top administrator of this corporation serving as a director;

¡ becomes unable to devote the necessary amount of time to prepare for and regularly attend meetings of the directors and committees of directors, and to keep abreast of significant corporate developments,

and the nominations and corporate governance committee will make a recommendation to the board as to whether to accept or reject such resignation.

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11. Election of Directors

All directors will stand for election at the annual meeting of shareholders. If the majority shareholder’s holdings were ever to fall below 50% for any non-contested elections of directors, any director nominee who receives a greater number of votes “withheld” from his or her election than votes “for” in such election shall tender his or her resignation. Within 90 days after certification of the election results, the board will decide, through a process managed by the nominations and corporate governance committee and excluding the nominee in question, whether to accept the resignation. Absent a compelling reason for the director to remain on the board, the board shall accept the resignation. The board will promptly disclose and, if applicable, the reasons for rejecting the tendered resignation.

12. Director Orientation and Continuing Education

(a)    Orientation

New non-employee directors will receive a comprehensive orientation from appropriate executives regarding the corporation’s business and affairs.

(b)    Continuing Education

Reviews of aspects of the corporation’s operations will be presented by appropriate employees from time to time as part of the agenda of regular board meetings. The board will also normally conduct an on-site visit to a location other than the corporation’s headquarters in conjunction with one or more regular board meetings every year.

13. Chairman and chief executive officer

The board currently believes that it is appropriate and efficient for the corporation’s chief executive officer to also act as chairman of the board. However, the board retains the authority to separate those functions if it deems such action appropriate in the future.

(a)    Position description

The chairman and chief executive officer shall:

● plan and organize all activities of the board of directors;

● ensure that the board receives sufficient, timely information on all material aspects of the corporation’s operations and financial affairs;

● chair annual and special meetings of the shareholders;

● conduct the general management and direction of the business and affairs of the corporation;

● recommend to the board of directors a strategic plan for the corporation’s business and, when approved by the board of directors, implement this strategic plan and report to the board of directors on the implementation of this strategic plan;

● develop and implement operational policies to guide the corporation within the limits prescribed by the corporation’s by-laws and the directions adopted by the board of directors;

● identify, for review with the board of directors, the principal risks of the corporation’s business, where identifiable, and develop appropriate systems to manage such risks;

● under the oversight of the board of directors, develop plans for succession planning for senior management, including the appointing, training and monitoring thereof, and implement those plans;

● ensure compliance with the corporation’s code of ethics and business conduct so as to foster a culture of integrity throughout the company; and

● ensure effective internal controls and management information systems are in place.

(b)    Minimum shareholding requirements

The chairman and chief executive officer shall hold, or shall, within three years after his appointment as chairman and chief executive officer, acquire shares of the corporation, including common shares and restricted stock units, of a value no less than five times his base salary.

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Audit Committee Charter

1. Purpose of the Committee

The primary purpose of the audit committee (the “committee”) is oversight. The committee shall assist the board of directors (the “board”) in fulfilling its responsibility to oversee:

● management’s conduct of the corporation’s financial reporting process,

● the integrity of the financial statements and other financial information provided by the corporation to Canadian securities regulators, the United States Securities and Exchange Commission (the “SEC”) and the public,

● the corporation’s system of internal accounting and financial controls,

● the corporation’s compliance with legal and regulatory requirements,

● the performance of the corporation’s internal audit function,

● the independent auditors’ qualifications, performance, and independence, and

● the annual independent audit of the corporation’s financial statements.

The corporation’s management is responsible for preparing the corporation’s financial statements. The independent auditors are responsible for auditing those financial statements. Management, including the internal audit function, and the independent auditors, have more time, knowledge, and detailed information about the corporation than do committee members. Consequently, in carrying out its oversight responsibilities, the committee is not providing any expert or special assurance as to the corporation’s financial statements, or any professional certification as to the independent auditors’ work, including with respect to auditor independence. Each member of the committee shall be entitled to rely on the integrity of people and organizations from whom the committee receives information and the accuracy of such information, including representations by management and the independent auditors regarding non-audit services provided by the independent auditors.

2. Committee Membership

The committee shall consist of no fewer than three members. Committee members shall be appointed by the board from among its independent members who shall serve at the pleasure of the board, but only so long as he or she continues to be a director of the corporation and is independent. Each member of the committee must satisfy such criteria of independence as the board may establish and such additional regulatory or listing requirements as the board may determine to be applicable or appropriate. Each member of the committee shall serve only so long as he or she continues to be a director of the corporation and is independent. The actual number of members shall be determined from time to time by resolution of the board.

Accordingly, each member of the committee shall be financially literate within a reasonable period of time after appointment to the committee; must be “independent” as defined in the board charter; and may not serve on more than two other public company audit committees unless the board determines that such simultaneous service would not impair the ability of the member to serve effectively on the committee. In addition, at least one member of the committee shall be an “audit committee financial expert” as defined by applicable laws.

3. Committee Structure and Operation

The chair and vice-chair of the committee shall be designated by the board from among the members of the committee. The committee shall fix its own rules of procedure and shall meet where and as provided by such rules or by resolution of the committee. In addition to the regular meeting schedule established by the committee, the chair of the committee may call a special meeting at any time.

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The chair, or in that person’s absence, the vice-chair or in the vice-chair’s absence, an alternate designated by the committee, shall:

(a) preside at committee meetings;

(b) ensure that meetings of the committee are held in accordance with this charter; and

(c) review, and modify if necessary the agenda of the meetings of this committee in advance to ensure that the committee may effectively carry out its duties.

A majority of the members of the committee shall constitute a quorum thereof. Every question shall be decided by a majority of the votes cast on the question and in the case of an equality of votes, the chair of the meeting shall be entitled to a second or casting vote.

The committee shall designate its secretary.

Meetings of the committee may be called by any member or by the external auditors of the corporation, and notice of every meeting shall be given to the external auditors.

The external auditors and the internal auditor of the corporation shall report directly to the audit committee.

The committee shall act only on the affirmative vote of a majority of the members at a meeting or by unanimous written consent.

The committee may establish sub-committees to carry out such duties as the committee may assign.

4. Committee Activities

The following shall be the common recurring activities of the committee in carrying out its purposes. These activities are set forth as a guide with the understanding that the committee may diverge from this guide as appropriate given the circumstances.

The committee shall:

(a) recommend the external auditors to be appointed by the shareholders, review and recommend their remuneration to the board, approve advances on such remuneration, which shall be paid by the corporation, and oversee their work, including the resolution of disagreements between management and the external auditor regarding financial reporting.

(b) approve the proposed current year audit program of the external auditors and assess the results of the program after the end of the program period.

(c) approve in advance any non-audit services that are permitted by applicable law to be performed by the external auditors after considering the effect of such services on their independence.

(d) receive from the external auditors a formal written statement delineating all relationships between the external auditor and the corporation consistent with Independence Standards Board Standard 1, and shall actively engage in a dialogue with the external auditor with respect to any disclosed relationships or services that may impact the objectivity and independence of the external auditor and shall recommend that the board take any appropriate action to oversee the independence of the external auditor.

(e) maintain hiring policies for employees and former employees of the independent auditors.

(f) establish procedures for the receipt, retention and treatment of complaints received by the corporation regarding accounting, internal accounting controls, or auditing matters and the confidential, anonymous submission by employees of the corporation of concerns regarding questionable accounting or auditing matters.

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(g) approve the proposed current year audit program of the internal auditors and assess the results of the program after the end of each quarter.

(h) review the adequacy of the corporation’s system of internal controls and auditing procedures.

(i) review the accounting and financial reporting processes of the corporation.

(j) approve changes proposed by management in accounting principles and practices, and review changes proposed by the accounting profession or other regulatory bodies which impact directly on such principles and practices.

(k) review the quarterly news release of financial and operating results, the annual and quarterly financial statements of the corporation, any accounting items affecting the statements and the overall format and content of the statements, and the related management discussion and analysis, prior to approval of such news release and financial statements by the board of directors.

(l) review the results of the corporation’s business ethics compliance program.

(m) review annually a summary of senior management expense accounts.

(n) evaluate, along with the other members of the board, management, the controller, and the general auditor, the qualifications, performance and independence of the independent auditors, including the performance of the lead audit partner.

(o) require attendances at its meetings by members of management, as the committee may direct.

(p) undertake such additional activities within the scope of its responsibilities as it may deem appropriate.

5. Committee Evaluation

The committee will annually complete a self-evaluation of the committee’s own performance and effectiveness and will consider whether any changes to the committee’s charter are appropriate.

6. Resources and Authority of the Committee

The committee has exclusive authority with respect to the retention of the independent auditors described in section 4 of this charter. In discharging its oversight role, the committee is empowered to investigate any matter brought to its attention with full access to all books, records, facilities, and personnel of the corporation. The committee also has the authority to retain outside advisors, including legal counsel, auditors, or other experts, as it deems appropriate; to approve the fees and expenses of such advisors; and to incur such other ordinary administrative expenses as are necessary or appropriate in carrying out its duties.

Public Policy and Corporate Responsibility Committee Charter

1. Purpose of the Committee

The primary purpose of the public policy and corporate responsibility committee (the ‘committee’) is to review and provide advice, as the committee deems appropriate, regarding the corporation’s policies, programs and practices on public issues of significance including their effects on safety, security, health and the environment. This includes environmental, health, personnel and process safety, security and sustainability risks and performance, including the risks associated with climate change. It also includes compliance with legislation and the assessment of long term impacts of public policy, climate change and sustainable business practices on corporate performance.

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2. Committee Membership

The committee shall consist of no fewer than three members, to be appointed by the board of directors from among (a) the independent directors; and (b) the non-independent directors who are not members of the corporation’s management, who shall serve at the pleasure of the board, but only so long as he or she continues to be a director of the corporation. The actual number of members shall be determined from time to time by resolution of the board. Members of the committee should be suitably knowledgeable in matters pertaining to public issues.

3. Committee Structure and Operation

The chair and vice-chair of the committee shall be designated by the board from among the members of the committee. The committee shall fix its own rules of procedure and shall meet where and as provided by such

rules or by resolution of the committee.

The chair, or in that person’s absence, the vice-chair or in the vice-chair’s absence, an alternate designated by the committee, shall:

(a) preside at committee meetings;

(b) ensure that meetings of the committee are held in accordance with this charter; and

(c) review, and modify if necessary the agenda of the meetings of this committee in advance to ensure that the committee may effectively carry out its duties.

A majority of the members of the committee shall constitute a quorum thereof. Every question shall be decided by a majority of the votes cast on the question and in the case of an equality of votes, the chair of the meeting shall be entitled to a second or casting vote.

The committee shall designate its secretary.

Meetings of the committee may be called by any member.

The committee shall act only on the affirmative vote of a majority of the members at a meeting or by unanimous written consent.

The committee may establish subcommittees consisting of one or more members to carry out such duties as the committee may delegate.

4. Committee Activities

The following shall be the common recurring activities of the committee in carrying out its purpose. These activities are set forth as a guide with the understanding that the committee may diverge from this guide as appropriate given the circumstances.

The committee shall:

(a) review and monitor the effectiveness of the corporation’s policies, programs and practices on environment, health, safety, security and sustainability, including the impact, risks and disclosure associated with climate change and greenhouse gas emissions, and make such recommendations to the board with respect thereto as it may deem advisable.

(b) monitor the corporation’s compliance with legislative, regulatory and corporation standards for environmental, health, safety, security and sustainability practices and matters, including the impact, risks and disclosure associated with climate change and greenhouse gas emissions, and advise the directors on the results and adequacy thereof.

(c) monitor trends and review current and emerging public policy issues relating to matters of significance to the corporation, including environment, health, safety, security and sustainability issues and the impact, risks and disclosure associated with climate change and greenhouse gas emissions, as they may impact the corporation’s operations.

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(d) review the impact of proposed legislation relating to matters of significance to the corporation, including the impact of the environment, health, safety and security on the operations of the corporation and to advise the directors and management as to the appropriate response of the corporation thereto.

(e) recommend to the directors and management desirable policies and actions arising from its review and monitoring activity.

(f) require attendances at its meetings by members of management, as the committee may direct.

(g) undertake such additional activities within the scope of its responsibilities as it may deem appropriate.

5. Committee Evaluation

The committee will annually complete a self-evaluation of the committee’s own performance and effectiveness and will consider whether any changes to the committee’s charter are appropriate.

6. Resources and Authority of the Committee

The committee has the authority to retain such outside advisors, including legal counsel or other experts, as it deems appropriate, and to approve the fees and expenses of such advisors.

Executive Resources Committee Charter

1. Purpose of the Committee

The primary purpose of the executive resources committee (the “committee”) is to discharge the board of directors’ (the “board”) responsibilities relating to the evaluation and compensation of the corporation’s chief executive officer (the “CEO”) and certain other key senior executive management positions reporting directly to the CEO, including all officers of the corporation, and to discharge the responsibilities of the committee under applicable rules and regulations. The committee also makes recommendations to the board regarding succession planning and development for senior executives and positions as needed.

2. Committee Membership

The committee shall consist of no fewer than three members, to be appointed by the board of directors from among (a) the independent directors; and (b) the non-independent directors who are not members of the corporation’s management, who shall serve at the pleasure of the board, but only so long as he or she continues to be a director of the corporation. The actual number of members shall be determined from time to time by resolution of the board. Members of the committee should be suitably knowledgeable in matters pertaining to executive compensation.

3. Committee Structure and Operation

The chair and vice-chair of the committee shall be designated by the board from among the members of the committee. The committee shall fix its own rules of procedure and shall meet where and as provided by such rules or by resolution of the committee.

The chair, or in that person’s absence, the vice-chair or in the vice-chair’s absence, an alternate designated by the committee, shall:

(a) preside at committee meetings;

(b) ensure that meetings of the committee are held in accordance with this charter; and

(c) review, and modify if necessary the agenda of the meetings of this committee in advance to ensure that the committee may effectively carry out its duties.

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A majority of the members of the committee shall constitute a quorum thereof. Every question shall be decided by a majority of the votes cast on the question and in the case of an equality of votes, the chair of the meeting shall be entitled to a second or casting vote.

The committee shall designate its secretary.

Meetings of the committee may be called by any member.

The committee shall act only on the affirmative vote of a majority of the members at a meeting or by unanimous written consent.

The committee may establish subcommittees consisting of one or more members to carry out such duties as the committee may delegate.

4. Committee Activities

The following shall be the common recurring activities of the committee in carrying out its purposes. These activities are set forth as a guide with the understanding that the committee may diverge from this guide as appropriate given the circumstances.

The committee shall:

(a) review and approve the corporate goals and objectives relevant to the compensation of the CEO.

(b) review data on competitive compensation practices and review and evaluate policies and programs through which the corporation compensates its employees.

(c) at least annually evaluate the CEO’s performance as measured against the goals and objectives outlined above.

(d) approve salaries and other compensation (including supplemental compensation such as cash bonuses and incentive bonus units, long-term incentive compensation such as restricted stock units, and any other payments for service), for the CEO and other key senior executive management positions reporting directly to the CEO, including all officers of the corporation.

(e) at least annually review succession planning and development strategies for the CEO and key senior executive management positions reporting directly to the CEO, including all officers of the corporation.

(f) review the executive development system to ensure that it foresees the corporation’s senior management requirements and provides for early identification and development of key resources.

(g) review and approve an annual report on compensation for inclusion in the corporation’s management proxy circular in accordance with applicable legal requirements.

(h) make recommendations to the board with respect to incentive compensation plans and equity-based plans.

(i) review proposed terms of any new incentive program and any major amendment of an existing program, and make such recommendations to the board with respect thereto as it may deem advisable.

(j) review and report on risks arising from the corporation’s compensation policies and practices for employees as required by Canadian securities regulators and stock exchanges on which the corporation’s stock trades.

(k) consider factors that could affect the independence or represent a conflict of interest on the part of any compensation consultant, independent legal counsel, or other adviser the committee may retain and report thereon as required by Canadian securities regulators and stock exchanges on which the corporation’s stock trades.

(l) require attendances at its meetings by members of management, as the committee may direct.

(m) undertake such additional activities within the scope of its responsibilities as it may deem appropriate.

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5. Committee Evaluation

The committee will annually complete a self-evaluation of the committee’s own performance and effectiveness and will consider whether any changes to the committee’s charter are appropriate.

6. Resources and Authority of the Committee

The committee and, with the approval of the committee, any member, may engage independent counsel, compensation consultants or other advisors at the expense of the corporation. The committee shall be directly responsible for the appointment, compensation and oversight of the work of any independent legal counsel, compensation consultant or other advisor retained by the committee. The committee may select outside legal counsel, a compensation consultant or other advisor (an “Advisor”) to the committee only after taking into consideration all factors relevant to the Advisor’s independence from management, including the following:

● the provision of other services to the corporation by the person that employs the Advisor;

● the amount of fees received from the corporation by the person that employs the Advisor as a percentage of such that person’s total revenue;

● the policies and procedures of the person that employs the Advisor that are designed to prevent conflicts of interest;

● any business or personal relationship of the Advisor with a member of the committee;

● any stock of the corporation owned by the Advisor; and

● any business or personal relationship of the Advisor or the person employing the Advisor with an executive officer of the corporation.

Nominations and Corporate Governance Committee Charter

1. Purpose of the Committee

The primary purpose of the nominations and corporate governance committee (the ‘committee’) is to monitor compliance with good corporate governance standards; to identify individuals qualified to become board members; to recommend to the board director nominees for election at the annual meeting of shareholders or for election by the board to fill open seats between annual meetings; to recommend to the board committee appointments for directors, including appointments as chair and vice chair of such committees; to review and make recommendations to the board regarding non-employee director compensation; and to develop and recommend to the board corporate governance guidelines applicable to the corporation.

2. Committee Membership

The committee shall consist of no fewer than three members, to be appointed by the board of directors from among (a) the independent directors; and (b) the non-independent directors who are not members of the corporation’s management, who shall serve at the pleasure of the board, but only so long as he or she continues to be a director of the corporation. The actual number of members shall be determined from time to time by resolution of the board. Members of the committee should be suitably knowledgeable in matters pertaining to corporate governance.

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3. Committee Structure and Operation

The chair and vice-chair of the committee shall be designated by the board from among the members of the committee. The committee shall fix its own rules of procedure and shall meet where and as provided by such rules or by resolution of the committee.

The chair, or in that person’s absence, the vice-chair or in the vice-chair’s absence, an alternate designated by the committee, shall:

(a) preside at committee meetings;

(b) ensure that meetings of the committee are held in accordance with this charter; and

(c) review, and modify if necessary the agenda of the meetings of this committee in advance to ensure that the committee may effectively carry out its duties.

A majority of the members of the committee shall constitute a quorum thereof. Every question shall be decided by a majority of the votes cast on the question and in the case of an equality of votes, the chair of the meeting shall be entitled to a second or casting vote.

The committee shall designate its secretary.

Meetings of the committee may be called by any member.

The committee shall act only on the affirmative vote of a majority of the members at a meeting or by unanimous written consent.

The committee may establish subcommittees consisting of one or more members to carry out such duties as the committee may delegate.

4. Committee Activities

The following shall be the common recurring activities of the committee in carrying out its purpose. These activities are set forth as a guide with the understanding that the committee may diverge from this guide as appropriate given the circumstances.

The committee shall:

(a) oversee issues of corporate governance as they apply to the corporation, including the effectiveness of the system of corporate governance, and the board’s relationship with management, and report to the board on such matters.

(b) oversee the annual assessment of the effectiveness and contribution of the board, its committees and each individual director.

(c) make recommendations to the board as to the appropriate size of the board with a view to facilitating effective decision-making.

(d) review and recommend to the board of directors any modifications to the charters of the board or any of its committees.

(e) review qualifications of existing directors and individuals suggested as potential candidates for director of the corporation, including candidates suggested by shareholders, and consider for nomination any of such individuals who are deemed qualified pursuant to the provisions of the board charter.

(f) recommend to the board the nominees to be proposed by the board for election as directors of the corporation at the annual meeting of shareholders.

(g) recommend to the board candidates for election as directors of the corporation to fill open seats on the board between annual meetings, including vacancies created by an increase in the authorized number of directors.

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(h) consider resignations tendered by directors in the event of:

(i) the majority shareholder’s holdings falling below 50%, for any non-contested election of directors in the event a nominee standing for election by shareholders in a non-contested election receives a greater number of votes withheld from his or her election than votes for such election and, in any such case, refer the matter to the board with the committee’s recommendation whether such resignation should be accepted, or

(ii) a change of circumstance as described in section 10(b)(ii) of the board charter.

(i) review the remuneration of independent directors and make such recommendations to the board with respect thereto as it may deem advisable.

(j) review present plans, programs or arrangements, and any proposed terms of any new plans, programs or arrangements, for the benefit of independent directors, and make such recommendations to the board with respect thereto as it may deem advisable.

(k) review and recommend to the board guidelines to be adopted relating to tenure of independent directors.

(l) provide recommendations to the board concerning committee structure of the board, committee operations, committee member qualifications, and committee member appointment.

(m) review any allegation that an executive officer or director may have violated the corporation’s Standards of Business Conduct and report its findings to the board and the general auditor.

(n) require attendances at its meetings by members of management, as the committee may direct.

(o) undertake such additional activities within the scope of its responsibilities as it may deem appropriate.

5. Committee Evaluation

The committee will annually complete a self-evaluation of the committee’s own performance and effectiveness and will consider whether any changes to the committee’s charter are appropriate.

6. Resources and Authority of the Committee

The committee has the authority to retain such outside advisors, including legal counsel or other experts, as it deems appropriate, and to approve the fees and expenses of such advisors. Without limiting the foregoing, the committee will have sole authority to retain and terminate any search firm to be used by the committee to identify director candidates and any consultant used by the committee to evaluate non-employee director compensation.

Community Collaboration and Engagement Committee Charter

1. Purpose of the Committee

The primary purpose of the community collaboration and engagement committee (the ‘committee’) is to review and provide advice on the corporation’s guidelines, procedures and performance supporting public awareness and consultation efforts, government, community and Indigenous relations, and community partnership and investment programs.

2. Committee Membership

The committee shall consist of no fewer than three members to be appointed by the board from among its members who shall serve at the pleasure of the board, but only so long as he or she continues to be a director of the corporation. The actual number of members shall be determined from time to time by resolution of the board. Members of the committee should be suitably knowledgeable in matters pertaining to issues relating to corporate contributions and community investment.

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3. Committee Structure and Operation

The chair and vice-chair of the committee shall be designated by the board from among the members of the committee. The committee shall fix its own rules of procedure and shall meet where and as provided by such rules or by resolution of the committee. In addition to the regular meeting schedule established by the committee, the chair of the committee may call a special meeting at any time.

The chair, or in that person’s absence, the vice-chair or in the vice-chair’s absence, an alternate designated by the committee, shall:

(a) preside at committee meetings;

(b) ensure that meetings of the committee are held in accordance with this charter; and

(c) review, and modify if necessary the agenda of the meetings of this committee in advance to ensure that the committee may effectively carry out its duties.

A majority of the members of the committee shall constitute a quorum thereof. Every question shall be decided by a majority of the votes cast on the question and in the case of an equality of votes, the chair of the meeting shall be entitled to a second or casting vote.

The committee shall designate its secretary.

Meetings of the committee may be called by any member.

The committee shall act only on the affirmative vote of a majority of the members at a meeting or by unanimous written consent.

The committee may establish subcommittees consisting of one or more members to carry out such duties as the committee may delegate.

4. Committee Activities

The following shall be the common recurring activities of the committee in carrying out its purpose. These activities are set forth as a guide with the understanding that the committee may diverge from this guide as appropriate given the circumstances.

The committee shall:

(a) review and monitor the effectiveness of the corporation’s programs and practices supporting public awareness and consultation activities.

(b) monitor trends and review current and emerging issues related to government, stakeholder and Indigenous relations.

(c) review and provide advice on the corporation’s overall community investment strategies and programs, which consists of:

(i) charitable contributions;

(ii) local community contributions by business units on community-serving projects that also benefit the corporation, which are charitable in nature;

(iii) funding for public policy groups;

(iv) university research awards;

(v) sponsorships whose primary purpose is to promote community support and corporate recognition; and

(vi) expenditures required under socio-economic agreements to support the development of mutually-beneficial long-term relationships.

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(d) approve all grants or contributions for charitable contributions and local community contributions; as described in section 4(c)(i) above, in excess of $300,000.

(e) require attendances at its meetings by members of management, as the committee may direct.

(f) undertake such additional activities within the scope of its responsibilities as it may deem appropriate.

5. Committee Evaluation

The committee will annually complete a self-evaluation of the committee’s own performance and effectiveness and will consider whether any changes to the committee’s charter are appropriate.

6. Resources and Authority of the Committee

The committee has the authority to retain such outside advisors, including legal counsel or other experts, as it deems appropriate, and to approve the fees and expenses of such advisors.

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EX-10.III.A.6

2020 RESTRICTED STOCK UNIT PLAN (for residents of Canada)

Residents of Canada

1. Plan Purpose:

The purpose of the 2016 Restricted Stock Unit Plan (the “Plan”) is to provide an incentive to selected employees and nonemployee directors to promote optimum individual contribution to sustained improvement in the Company’s business performance and shareholder value, and to motivate them to remain with the Company, its wholly owned subsidiaries or a Designated Employer, and to promote continued loyalty to the Company and avoidance of conflict of interest during the period following termination of Continued Employment.

2. Description of Units:

This incentive is provided by the grant of Restricted Stock Units (“RSU”) which give the Plan participant the right, subject to the terms and conditions herein:

(a) on the first Vesting Date, if the Grantee has received RSUs vesting the first 50% on the third anniversary of the Grant Date, to receive from the Company, upon vesting, an amount in respect of each RSU, which is equal to the Vesting Price; and

(b) on the first Vesting Date, if the Grantee has received RSUs vesting the first 50% on the fifth anniversary of the Grant Date, and on the last Vesting Date, to receive from the Company, upon vesting, Common Shares, or to elect to receive a cash amount in respect of each RSU, which is equal to the Vesting Price.

3. Eligibility and Awards:

RSUs will be granted only to selected employees and to nonemployee directors of the Company or to selected employees of a Designated Employer. Frequency and level of awards to individual participants will be determined by the administrative authority. Individual awards under this Plan will not necessarily be granted annually. The entitlement to receive amounts and Common Shares pursuant to clause 2 and clause 6 arises from past services rendered from the Grant Date to the date of vesting of the RSU.

4. Definitions:

In this Plan document, except where the context otherwise indicates, the following definitions apply:

(a) “Administrative authority” means the Board of Directors of the Company and those committees and persons designated as the administrative authority pursuant to clause 13(e).

(b) “Affiliate” means a legal entity which controls, or which is controlled by, or which is controlled by an entity which controls, the Company.

(c) “Common Share” means a common share in the capital of the Company.

(d) “Company” means Imperial Oil Limited.

(e) “Continued Employment” means continued employment after the RSU Grant Date with any one or more of the Company, its wholly owned subsidiaries or a Designated Employer, and for nonemployee directors means the period of time while serving as a director of Imperial Oil Limited.

(f) “Control” means the power to direct or cause the direction of the management and policies of another person or entity whether through the ownership of shares or partnership interest, a contract, trust arrangement or any other means, either directly or indirectly, that results in control in fact and without restricting the generality of the foregoing includes, with respect to the control of or by a corporation or a partnership, the ownership of shares or partnership interest carrying not less than 50% of the voting rights regardless of whether such ownership occurs directly or indirectly, as contemplated above. “Controls” and “Controlled by” and other derivatives shall be construed accordingly.

(g) “Designated Employer” means an employer which is an affiliate of the Company and which is designated as such for the purposes of this Plan by the Company.

(h) “Detrimental activity” of a Grantee means, with respect to the Grantee’s retention of outstanding awards under this Plan, activity at any time that is determined in individual cases by the administrative authority to be (a) a material violation of applicable standards, policies, or procedures of the Company or an affiliate; or (b) a material breach of legal or other duties owed by the Grantee to the Company or an affiliate; or (c) a material breach of any contract between the Grantee and the Company or an affiliate; or (d) acceptance by the Grantee of duties to a third party under circumstances that create a material conflict of interest, or the appearance of a material conflict of interest. Detrimental activity includes, without limitation, activity that would be a basis for termination of employment for cause under applicable law in Canada. With respect to material conflict of interest or the appearance of material conflict of interest, such conflict or appearance might occur when, for example and without limitation, a Grantee holding an outstanding award becomes employed or otherwise engaged by an entity that regulates, deals with, or competes with the Company or an affiliate.

(i) With respect to Executive Employees of the Company or a Designated Employer, detrimental activity, or the activity otherwise described in clause 7(f)(ii), may occur at any time prior to vesting of the employee’s outstanding awards.

(ii) With respect to Managerial, Professional and Technical (MPT) Employees of the Company or a Designated Employer, detrimental activity, or the activity otherwise described in clause 7(f)(ii), may occur at any time prior to, or within 36 months of, termination of Continued Employment of such Managerial, Professional and Technical Employee.

(iii) With respect to nonemployee directors of the Company, detrimental activity, or the activity otherwise described in clause 7(f)(ii), may occur at any time prior to, or within 24 months of, termination of Continued Employment of the nonemployee director. Notwithstanding any other provision of this clause, with respect to a nonemployee director, any actions taken by a nonemployee director or former nonemployee director who acted in good faith and in the best interests of the Company shall not constitute detrimental activity.

(i) “Dividend Equivalents” means cash payments pursuant to clause 6 corresponding in amount and timing to the cash dividend that is paid by the Company on a Common Share of the Company.

(j) “Grant Date” means the date specified in the Grant Instrument that an RSU is granted under the Plan.

(k) “Grant Instrument” means the document given by the Company to an employee and nonemployee director governing a grant of Restricted Stock Units.

(l) “Grantee” means the recipient of a Grant Instrument.

(m) “Legal Representatives” means a Grantee’s executors or administrators.

(n) “Normal retirement time” means for each employee, the first day of the month immediately following the normal retirement date, as determined in the Imperial Oil Limited Retirement Plan (or the provision in any plan or plans of the Company substituted therefore).

(o) “Terminate” means cease to be an employee for any reason, whether at the initiative of the employee, the employer, or otherwise. That reason could include, without limitation, resignation or retirement by the employee; discharge of the employee by the employer, with or without cause; death; transfer of employment to an entity that is a not an affiliate; or a sale, divestiture, or other transaction as a result of which an employer ceases to be an affiliate. A change of employment from the Company or one affiliate to another affiliate, or to the Company, is not a termination. The time or date of termination is not necessarily the employee’s last day on the payroll.

(p) “Vesting Date” means, in respect of an RSU being vested pursuant to clause 5, the dates on which the RSU is vested, the date of death of a Grantee or the date of deferral of vesting, as applicable.

(q) “Vesting Price” for a particular RSU means the average of the weighted average price (as determined by the Toronto Stock Exchange) of Common Shares of the Company on the Toronto Stock Exchange on the Vesting Date and the four consecutive trading days immediately prior to the Vesting Date, or if there is no weighted average price on any such day or days, the weighted average price on the Toronto Stock Exchange on the day or days immediately preceding the fourth trading day prior to the Vesting Date shall be included in computing such average.

5. Vesting of Units:

Subject to the restrictions in clause 7 or the deferral of vesting in clause 8, the total number of RSUs granted under a particular Grant Instrument shall vest in accordance with the following schedule:

(a) 50% of the RSUs will vest on either:

(i) the third anniversary following the Grant Date, or

(ii) the fifth anniversary following the Grant Date,

the choice of which will be at the discretion of the administrative authority and which will be set out in the Grant Instrument; and

(b) the remaining 50% of the RSUs will vest on either:

(i) the seventh anniversary following the Grant Date, or

(ii) the tenth anniversary following the Grant Date,

the choice of which will be at the discretion of the administrative authority and which will be set out in the Grant Instrument.

6. Dividend Equivalents:

The Company will pay the Grantee cash with respect to each outstanding RSU granted to the Grantee corresponding in amount and timing to the cash dividend that is paid by the Company on a Common Share of the Company.

7. Restrictions on RSUs:

(a) No RSU will be vested other than in accordance with the provisions of clauses 5, 7 and 8.

(b) Except as provided hereinafter, an RSU will be vested only during Continued Employment. Notwithstanding the foregoing but subject to the provisions of clause 7(f)(ii), an RSU may continue to be vested by a nonemployee director subsequent to his or her Continued Employment in accordance with the provisions of clauses 5, 7 and 8.

(c) In case the Grantee becomes entitled on or after the Grant Date to payment of extended disability benefits under the Company’s extended disability benefit plan, the RSUs or the balance remaining will be vested in accordance with the provisions of clause 5.

(d) In case of death of the Grantee, the outstanding RSUs will vest as of the date of death and be paid to the Grantee’s Legal Representatives.

(e) In case the Grantee’s Continued Employment terminates before normal retirement time, and on or before the seventh anniversary of the Grant Date, where the last Vesting Date has been determined pursuant to clause 5(b)(i), or the tenth anniversary of the Grant Date, where the last Vesting Date has been determined pursuant to clause 5(b)(ii), and the Grantee becomes entitled to an annuity under the Imperial Oil Limited Retirement Plan (or the provision in any plan or plans of the Company substituted therefore), the administrative authority shall determine, at its discretion, whether the Grantee’s RSUs will not be forfeited.

(i) Notwithstanding section 7(e), the Company’s practice is not to forfeit any RSUs upon termination in the event that Grantee’s Continued Employment terminates on or after the date Grantee reaches normal retirement time in circumstances where Grantee becomes entitled to an annuity under the Imperial Oil Limited Retirement Plan (or the provision in any plan or plans of the Company substituted therefore).

(f) Notwithstanding anything to the contrary in this Plan, the administrative authority, at its discretion, may determine that the Grantee’s RSUs, or the balance remaining, are forfeited as a consequence of any of the following situations:

(i) the administrative authority believes that the Grantee intends to terminate Continued Employment and clauses 7(b), 7(c), 7(d) and 7(e) would not be applicable,

(ii) the Grantee, without the written consent of the administrative authority, directly or indirectly is employed in, or as principal, agent, partner or otherwise engages in any business that is in competition with the Company, as determined by the administrative authority, or otherwise engages in detrimental activity, as determined by the administrative authority during Continued Employment or during the period of time described in clause 4(h)(i), (ii) or (iii), as the case may be, with respect to such Grantee, or

(iii) the administrative authority determines that Grantee has committed a fraudulent act during Grantee’s Continued Employment.

(g) Except as provided in clauses 7(b), 7(c), 7(d), and 7(e), the RSUs, or the balance remaining, if not forfeited earlier, will be forfeited after the last day of Continued Employment.

(h) Notwithstanding any other provision of this clause 7, the administrative authority may determine that a Grantee’s RSUs will not be forfeited in whole or in part after the cessation of Continued Employment.

(i) For purposes of this Program, the administrative authority may determine that the time or date an employee resigns or otherwise terminates is the time or date the employee gives notice of resignation, accepts employment with another employer, otherwise indicates an intent to resign, or is discharged. The time or date of termination for this purpose is not necessarily the employee’s last day on the payroll.

8. Method and Deferral of Vesting:

The RSUs will vest in accordance with clauses 5 and 7, provided however, the administrative authority may, at its discretion, defer the vesting of any RSUs to a later date in the event that a ban on trading, imposed by the Company or applicable law, in Common Shares of the Company by a director of the Company or an employee of the Company, its wholly owned subsidiaries or a Designated Employer is in effect on the Vesting Dates described in clauses 5 and 7.

9. Issue of Common Shares:

(a) One Common Share will be issued by the Company for each RSU that is vested on:

(i) the first Vesting Date, if the Grantee has received RSUs vesting the first 50% on the fifth anniversary of the Grant Date, or

(ii) the last Vesting Date,

unless the Grantee notifies the Company, in such manner and within such period of time as may be determined by the Company from time-to-time, that the Grantee elects to receive a cash payment for the RSUs equal to the Vesting Price for each RSU vested.

(b) The aggregate number of Common Shares that may be issued pursuant to the vesting of RSUs shall not exceed 10.5 million Common Shares, provided that

(i) the number of Common Shares issuable to insiders (as defined by the Toronto Stock Exchange), at any time, under all security based compensation arrangements, cannot exceed 10% of the issued and outstanding Common Shares; and

(ii) the number of Common Shares issued to insiders (as defined by the Toronto Stock Exchange), within any one year period, under all security based compensation arrangements, cannot exceed 10% of the issued and outstanding Common Shares.

10. Method of Payment:

(a) The issue of share certificates or the cash payment of the benefit arising on the vesting of an RSU will normally be made as soon as practicable after the Vesting Date.

(b) Cash payment of the Dividend Equivalents described in clause 6 will be made as soon as practicable after the Company pays a dividend on the Common Shares of the Company.

(c) Payments will be reduced by any amount required to be withheld by any government authority.

11. Repayments:

Notwithstanding the vesting of an RSU by the Grantee, in the event any of the situations described in clause 7(f)(ii) are applicable to the Grantee, the administrative authority, at its discretion, may require the Grantee to pay to the Company a cash amount equal to the Vesting Price for each RSU vested during a period up to 180 days prior to termination of the Grantee’s Continued Employment.

12. Significant Changes:

In the case of any subdivision, consolidation, or reclassification of the shares of the Company or other relevant change in the capitalization of the Company, the administrative authority, in its discretion, may make appropriate adjustments in the number of Common Shares to be issued and the calculation of the cash amount payable per RSU, and an adjustment by the Company shall be conclusive as to the amount payable per RSU and shall be final and binding upon all persons.

13. Other:

(a) An RSU award does not carry any benefits associated with the Company’s benefit plans.

(b) No right created by the granting of an RSU can be pledged in any circumstance, nor can it be assigned. Any attempt to pledge or assign may, in the discretion of the administrative authority, result in forfeiture of the rights created herein.

(c) A Restricted Stock Unit means a unit equivalent in value to a Common Share of the Company, credited by means of a book entry on the Company’s books.

(d) Under no circumstances shall the RSUs be considered Common Shares or other securities of the Company, nor shall they entitle any Grantee to exercise voting rights or any other rights attaching to the ownership of the Common Shares or other securities of the Company, nor shall any Grantee be considered the owner of the Common Shares by virtue of the award of the RSUs.

(e) The Company’s Board of Directors is the ultimate administrative authority for this Plan, with the power to interpret and administer its provisions. The Board of Directors may delegate its authority to a committee which, except in the case of the Executive Resources Committee, need not be a committee of the Board. Subject to the authority of the Board or an authorized committee, the Chairman of the Board and his delegates will serve as the administrative authority for purposes of establishing requirements and procedures for the operation of this Plan; making final determinations and interpretations with respect to outstanding awards; and exercising other powers assigned to the administrative authority under this Plan.

(f) The Company’s obligation to issue Common Shares in accordance with the Plan is subject to compliance with applicable securities laws and the rules and regulations of applicable securities regulatory authorities and stock exchanges regarding the issuance and distribution of such Common Shares and to the listing of such additional Common Shares on any stock exchange on which the Common Shares are then listed.

(g) This Plan is conclusively deemed to be an agreement made under the laws of the Province of Ontario and, for all purposes and in respect of any claim or dispute arising hereunder or in connection herewith, shall be constituted and construed in accordance with the laws of the Province of Ontario, without regard to principles of conflict of law.

14. Amendments to the Plan:

The Board of Directors of the Company may without the approval of the shareholders or the Grantees (i) amend the Plan with respect to RSUs previously issued and (ii) amend the Plan with respect to RSUs to be issued in the future without the approval of shareholders, provided that no amendment that:

(a) increases the number of Common Shares reserved for issuance under the Plan;

(b) increases the Vesting Price, expressed as either a cash amount or the number of Common Shares with respect to RSUs previously granted or to be granted, provided that in the case of any subdivision, consolidation, or reclassification of the Common Shares of the company or other relevant change in the capitalization of the Company, the Company in its discretion, may make appropriate adjustments in the number of Common Shares to be issued and in the calculation of the amount payable per unit;

(c) extends eligibility to participate in the Plan to any persons not contemplated by clause 3, provided that the company may at any time designate affiliates of the Company as Designated Employers, the employees of which may be eligible to receive units;

(d) extends the right of the Grantee to transfer or assign RSUs; or

(e) adjusts the Vesting Date of any RSUs previously granted,

shall be made without securing approval by the shareholders of the Company.

15. Consent of Grantees not Required for Amendments to the Plan:

For greater certainty, clause 14 gives the Board of Directors of the Company the right and power to amend or change the Plan at any time and from time to time in any respect without requiring the consent or approval of any of the Grantees and without any fresh or further consideration, including in order to (i) amend the Plan with respect to RSUs previously issued and (ii) amend the Plan with respect to RSUs to be issued in the future.

Imperial Oil Limited November 2020

2020 RESTRICTED STOCK UNIT PLAN (for non-residents of Canada)

Non-Residents of Canada

1. Plan Purpose:

The purpose of the 2016 Restricted Stock Unit Plan (the “Plan”) is to provide an incentive to selected employees and nonemployee directors to promote optimum individual contribution to sustained improvement in the Company’s business performance and shareholder value, and to motivate them to remain with the Company, its wholly owned subsidiaries or a Designated Employer, and to promote continued loyalty to the Company and avoidance of conflict of interest during the period following termination of Continued Employment.

2. Description of Units:

This incentive is provided by the grant of Restricted Stock Units (“RSU”) which give the Plan participant the right, subject to the terms and conditions herein, on each Vesting Date, to receive from the Company an amount in respect of each RSU which is equal to the Vesting Price.

3. Eligibility and Awards:

RSUs will be granted only to selected employees and to nonemployee directors of the Company or to selected employees of a Designated Employer. Frequency and level of awards to individual participants will be determined by the administrative authority. Individual awards under this Plan will not necessarily be granted annually. The entitlement to receive amounts and Common Shares pursuant to clause 2 and clause 6 arises from past services rendered from the Grant Date to the date of vesting of the RSU.

4. Definitions:

In this Plan document, except where the context otherwise indicates, the following definitions apply:

(a) “Administrative authority” means the Board of Directors of the Company and those committees and persons designated as the administrative authority pursuant to clause 12(e).

(b) “Affiliate” means a legal entity which controls, or which is controlled by, or which is controlled by an entity which controls, the Company.

(c) “Common Share” means a common share in the capital of the Company.

(d) “Company” means Imperial Oil Limited.

(e) “Continued Employment” means continued employment after the RSU Grant Date with any one or more of the Company, its wholly owned subsidiaries or a Designated Employer, and for nonemployee directors means the period of time while serving as a director of Imperial Oil Limited.

(f) “Control” means the power to direct or cause the direction of the management and policies of another person or entity whether through the ownership of shares or partnership interest, a contract, trust arrangement or any other means, either directly or indirectly, that results in control in fact and without restricting the generality of the foregoing includes, with respect to the control of or by a corporation or a partnership, the ownership of shares or partnership interest carrying not less than 50% of the voting rights regardless of whether such ownership occurs directly or indirectly, as contemplated above. “Controls” and “Controlled by” and other derivatives shall be construed accordingly.

(g) “Designated Employer” means an employer which is an affiliate of the Company and which is designated as such for the purposes of this Plan by the Company.

(h) “Detrimental activity” of a Grantee means, with respect to the Grantee’s retention of outstanding awards under this Plan, activity at any time that is determined in individual cases by the administrative authority to be (a) a material violation of applicable standards, policies, or procedures of the Company or an affiliate; or (b) a material breach of legal or other duties owed by the Grantee to the Company or an affiliate; or (c) a material breach of any contract between the Grantee and the Company or an affiliate; or (d) acceptance by the Grantee of duties to a third party under circumstances that create a material conflict of interest, or the appearance of a material conflict of interest. Detrimental activity includes, without limitation, activity that would be a basis for termination of employment for cause under applicable law in Canada. With respect to material conflict of interest or the appearance of material conflict of interest, such conflict or appearance might occur when, for example and without limitation, a Grantee holding an outstanding award becomes employed or otherwise engaged by an entity that regulates, deals with, or competes with the Company or an affiliate.

(i) With respect to Executive Employees of the Company or a Designated Employer, detrimental activity, or the activity otherwise described in clause 7(f)(ii), may occur at any time prior to vesting of the employee’s outstanding awards.

(ii) With respect to Managerial, Professional and Technical (MPT) Employees of the Company or a Designated Employer, detrimental activity, or the activity otherwise described in clause 7(f)(ii), may occur at any time prior to, or within 36 months of, termination of Continued Employment of such Managerial, Professional and Technical Employee.

(iii) With respect to nonemployee directors of the Company, detrimental activity, or the activity otherwise described in clause 7(f)(ii), may occur at any time prior to, or within 24 months of, termination of Continued Employment of the nonemployee director. Notwithstanding any other provision of this clause, with respect to a nonemployee director, any actions taken by a nonemployee director or former nonemployee director who acted in good faith and in the best interests of the Company shall not constitute detrimental activity.

(i) “Dividend Equivalents” means cash payments pursuant to clause 6 corresponding in amount and timing to the cash dividend that is paid by the Company on a Common Share of the Company.

(j) “Grant Date” means the date specified in the Grant Instrument that an RSU is granted under the Plan.

(k) “Grant Instrument” means the document given by the Company to an employee and nonemployee director governing a grant of Restricted Stock Units.

(l) “Grantee” means the recipient of a Grant Instrument.

(m) “Legal Representatives” means a Grantee’s executors or administrators.

(n) “Normal retirement time” means for each employee, the first day of the month immediately following the normal retirement date, as determined in the Imperial Oil Limited Retirement Plan (or the provision in any plan or plans of the Company substituted therefore).

(o) “Terminate” means cease to be an employee for any reason, whether at the initiative of the employee, the employer, or otherwise. That reason could include, without limitation, resignation or retirement by the employee; discharge of the employee by the employer, with or without cause; death; transfer of employment to an entity that is a not an affiliate; or a sale, divestiture, or other transaction as a result of which an employer ceases to be an affiliate. A change of employment from the Company or one affiliate to another affiliate, or to the Company, is not a termination. The time or date of termination is not necessarily the employee’s last day on the payroll.

(p) “Vesting Date” means, in respect of an RSU being vested pursuant to clause 5, the dates on which the RSU is vested, the date of death of a Grantee or the date of deferral of vesting, as applicable.

(q) “Vesting Price” for a particular RSU means the average of the weighted average price (as determined by the Toronto Stock Exchange) of Common Shares of the Company on the Toronto Stock Exchange on the Vesting Date and the four consecutive trading days immediately prior to the Vesting Date, or if there is no weighted average price on any such day or days, the weighted average price on the Toronto Stock Exchange on the day or days immediately preceding the fourth trading day prior to the Vesting Date shall be included in computing such average.

5. Vesting of Units:

Subject to the restrictions in clause 7 or the deferral of vesting in clause 8, the total number of RSUs granted under a particular Grant Instrument shall vest in accordance with the following schedule:

(a) 50% of the RSUs will vest on either:

(i) the third anniversary following the Grant Date, or

(ii) the fifth anniversary following the Grant Date,

the choice of which will be at the discretion of the administrative authority and which will be set out in the Grant Instrument; and

(b) the remaining 50% of the RSUs will vest on either:

(i) the seventh anniversary following the Grant Date, or

(ii) the tenth anniversary following the Grant Date,

the choice of which will be at the discretion of the administrative authority and which will be set out in the Grant Instrument.

6. Dividend Equivalents:

The Company will pay the Grantee cash with respect to each outstanding RSU granted to the Grantee corresponding in amount and timing to the cash dividend that is paid by the Company on a Common Share of the Company.

7. Restrictions on RSUs:

(a) No RSU will be vested other than in accordance with the provisions of clauses 5, 7 and 8.

(b) Except as provided hereinafter, an RSU will be vested only during Continued Employment. Notwithstanding the foregoing but subject to the provisions of clause 7(f)(ii), an RSU may continue to be vested by a nonemployee director subsequent to his or her Continued Employment in accordance with the provisions of clauses 5, 7 and 8.

(c) In case the Grantee becomes entitled on or after the Grant Date to payment of extended disability benefits under the Company’s extended disability benefit plan, the RSUs or the balance remaining will be vested in accordance with the provisions of clause 5.

(d) In case of death of the Grantee, the outstanding RSUs will vest as of the date of death and be paid to the Grantee’s Legal Representatives.

(e) In case the Grantee’s Continued Employment terminates before normal retirement time, and on or before the seventh anniversary of the Grant Date, where the last Vesting Date has been determined pursuant to clause 5(b)(i), or the tenth anniversary of the Grant Date, where the last Vesting Date has been determined pursuant to clause 5(b)(ii), and the Grantee becomes entitled to an annuity under the Imperial Oil Limited Retirement Plan (or the provision in any plan or plans of the Company substituted therefore), the administrative authority shall determine, at its discretion, whether the Grantee’s RSUs will not be forfeited.

(i) Notwithstanding section 7(e), the Company’s practice is not to forfeit any RSUs upon termination in the event that Grantee’s Continued Employment terminates on or after the date Grantee reaches normal retirement time in circumstances where Grantee becomes entitled to an annuity under the Imperial Oil Limited Retirement Plan (or the provision in any plan or plans of the Company substituted therefore).

(f) Notwithstanding anything to the contrary in this Plan, the administrative authority, at its discretion, may determine that the Grantee’s RSUs, or the balance remaining, are forfeited as a consequence of any of the following situations:

(i) the administrative authority believes that the Grantee intends to terminate Continued Employment and clauses 7(b), 7(c), 7(d) and 7(e) would not be applicable,

(ii) the Grantee, without the written consent of the administrative authority, directly or indirectly is employed in, or as principal, agent, partner or otherwise engages in any business that is in competition with the Company, as determined by the administrative authority, or otherwise engages in detrimental activity, as determined by the administrative authority during the period of time described in clause 4(h)(i), (ii) or (iii), as the case may be, with respect to such Grantee, or

(iii) the administrative authority determines that Grantee has committed a fraudulent act during Grantee’s Continued Employment.

(g) Except as provided in clauses 7(b), 7(c), 7(d), and 7(e), the RSUs, or the balance remaining, if not forfeited earlier, will be forfeited after the last day of Continued Employment.

(h) Notwithstanding any other provision of this clause 7, the administrative authority may determine that a Grantee’s RSUs will not be forfeited in whole or in part after the cessation of Continued Employment.

(i) For purposes of this Program, the administrative authority may determine that the time or date an employee resigns or otherwise terminates is the time or date the employee gives notice of resignation, accepts employment with another employer, otherwise indicates an intent to resign, or is discharged. The time or date of termination for this purpose is not necessarily the employee’s last day on the payroll.

8. Method and Deferral of Vesting:

The RSUs will vest in accordance with clauses 5 and 7, provided however, the administrative authority may, at its discretion, defer the vesting of any RSUs to a later date in the event that a ban on trading, imposed by the Company or applicable law, in Common Shares of the Company by a director of the Company or an employee of the Company, its wholly owned subsidiaries or a Designated Employer is in effect on the Vesting Dates described in clauses 5 and 7.

9. Method of Payment:

(a) Cash payment of the benefit arising on the vesting of an RSU will normally be made as soon as practicable after the Vesting Date.

(b) Cash payment of the Dividend Equivalents described in clause 6 will be made as soon as practicable after the Company pays a dividend on the Common Shares of the Company.

(c) Payments will be reduced by any amount required to be withheld by any government authority.

10. Repayments:

Notwithstanding the vesting of an RSU by the Grantee, in the event any of the situations described in clause 7(f)(ii) are applicable to the Grantee, the administrative authority, at its discretion, may require the Grantee to pay to the Company a cash amount equal to the Vesting Price for each RSU vested during a period up to 180 days prior to termination of the Grantee’s Continued Employment.

11. Significant Changes:

In the case of any subdivision, consolidation, or reclassification of the shares of the Company or other relevant change in the capitalization of the Company, the administrative authority, in its discretion, may make appropriate adjustments in the cash amount payable per RSU, and an adjustment by the Company shall be conclusive as to the amount payable per RSU and shall be final and binding upon all persons.

12. Other:

(a) An RSU award does not carry any benefits associated with the Company’s benefit plans.

(b) No right created by the granting of an RSU can be pledged in any circumstance, nor can it be assigned. Any attempt to pledge or assign may, in the discretion of the administrative authority, result in forfeiture of the rights created herein.

(c) A Restricted Stock Unit means a unit equivalent in value to a Common Share of the Company, credited by means of a book entry on the Company’s books.

(d) Under no circumstances shall the RSUs be considered Common Shares or other securities of the Company, nor shall they entitle any Grantee to exercise voting rights or any other rights attaching to the ownership of the Common Shares or other securities of the Company, nor shall any Grantee be considered the owner of the Common Shares by virtue of the award of the RSUs.

(e) The Company’s Board of Directors is the ultimate administrative authority for this Plan, with the power to interpret and administer its provisions. The Board of Directors may delegate its authority to a committee which, except in the case of the Executive Resources Committee, need not be a committee of the Board. Subject to the authority of the Board or an authorized committee, the Chairman of the Board and his delegates will serve as the administrative authority for purposes of establishing requirements and procedures for the operation of this Plan; making final determinations and interpretations with respect to outstanding awards; and exercising other powers assigned to the administrative authority under this Plan.

(f) This Plan is conclusively deemed to be an agreement made under the laws of the Province of Ontario and, for all purposes and in respect of any claim or dispute arising hereunder or in connection herewith, shall be constituted and construed in accordance with the laws of the Province of Ontario, without regard to principles of conflict of law.

13. Amendments to the Plan:

The Board of Directors of the Company may without the approval of the shareholders or the Grantees (i) amend the Plan with respect to RSUs previously issued and (ii) amend the Plan with respect to RSUs to be issued in the future without the approval of shareholders, provided that no amendment that:

(a) increases the number of Common Shares reserved for issuance under the Plan;

(b) increases the Vesting Price, expressed as either a cash amount or the number of Common Shares with respect to RSUs previously granted or to be granted, provided that in the case of any subdivision, consolidation, or reclassification of the Common Shares of the company or other relevant change in the capitalization of the Company, the Company in its discretion, may make appropriate adjustments in the number of Common Shares to be issued and in the calculation of the amount payable per unit;

(c) extends eligibility to participate in the Plan to any persons not contemplated by clause 3, provided that the company may at any time designate affiliates of the Company as Designated Employers, the employees of which may be eligible to receive units;

(d) extends the right of the Grantee to transfer or assign RSUs; or

(e) adjusts the Vesting Date of any RSUs previously granted, shall be made without securing approval by the shareholders of the Company.

14. Consent of Grantees not Required for Amendments to the Plan:

For greater certainty, clause 13 gives the Board of Directors of the Company the right and power to amend or change the Plan at any time and from time to time in any respect without requiring the consent or approval of any of the Grantees and without any fresh or further consideration, including in order to (i) amend the Plan with respect to RSUs previously issued and (ii) amend the Plan with respect to RSUs to be issued in the future.

Imperial Oil Limited November 2020

EX-31.1

Exhibit (31.1)

Certification

Pursuant to Securities Exchange Act Rule 13a-14(a)

I, Bradley W. Corson, certify that:

1. I have reviewed this annual report on Form 10-K of Imperial Oil Limited;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, 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;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:     February 24, 2021

/s/ Bradley W. Corson

Bradley W. Corson

Chairman, president and

chief executive officer

(Principal executive officer)

EX-31.2

Exhibit (31.2)

Certification

Pursuant to Securities Exchange Act Rule 13a-14(a)

I, Daniel E. Lyons, certify that:

1. I have reviewed this annual report on Form 10-K of Imperial Oil Limited;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, 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;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:     February 24, 2021

/s/ Daniel E. Lyons

Daniel E. Lyons

Senior vice-president, finance and

administration, and controller

(Principal financial officer)

EX-32.1

Exhibit (32.1)

Certification of Periodic Financial Report

Pursuant to 18 U.S.C. Section 1350

For purposes of 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, the undersigned, Bradley W. Corson, the chief executive officer of Imperial Oil Limited (the “company”), hereby certifies that, to his knowledge:

(i) the Annual Report on Form 10-K of the company for the year ended December 31, 2020 as filed with the Securities and Exchange Commission (the “Report”), fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(ii) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the company.

Date:     February 24, 2021

/s/ Bradley W. Corson

Bradley W. Corson

Chairman, president and

chief executive officer

(Principal executive officer)

EX-32.2

Exhibit (32.2)

Certification of Periodic Financial Report

Pursuant to 18 U.S.C. Section 1350

For purposes of 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, the undersigned, Daniel E. Lyons, the chief financial officer of Imperial Oil Limited (the “company”), hereby certifies that, to his knowledge:

(i) the Annual Report on Form 10-K of the company for the year ended December 31, 2020 as filed with the Securities and Exchange Commission (the “Report”), fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(ii) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the company.

Date:     February 24, 2021

/s/ Daniel E. Lyons

Daniel E. Lyons

Senior vice-president, finance and

administration, and controller

(Chief financial officer)

XML

Cover Page - CAD ($)	12 Months Ended
	Dec. 31, 2020	Feb. 16, 2021	Jun. 30, 2020
Cover [Abstract]
Document Type	10-K
Document Period End Date	Dec. 31, 2020
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	FY
Document Transition Report	false
Entity Central Index Key	0000049938
Current Fiscal Year End Date	--12-31
Document Annual Report	true
Entity Registrant Name	IMPERIAL OIL LIMITED
Amendment Flag	false
Entity Filer Category	Large Accelerated Filer
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Shell Company	false
Entity File Number	0-12014
Entity Small Business	false
Entity Incorporation, State or Country Code	CA
Entity Emerging Growth Company	false
Entity Address, Address Line One	505 QUARRY PARK BOULEVARD S.E.
Entity Tax Identification Number	98-0017682
Entity Address, City or Town	CALGARY
Entity Address, State or Province	AB
Entity Address, Country	CA
Entity Address, Postal Zip Code	T2C 5N1
City Area Code	800
Local Phone Number	567-3776
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
ICFR Auditor Attestation Flag	true
Entity Common Stock, Shares Outstanding		734,076,755
Entity Public Float			$ 4,873,811,386

XML

Consolidated statement of income - CAD ($) $ in Millions		12 Months Ended
		Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Revenues and other income
Revenues	[1],[2]	$ 22,284	$ 34,002	$ 34,964
Investment and other income (note 9)		104	99	135
Total revenues and other income		22,388	34,101	35,099
Expenses
Exploration (note 16)		13	47	19
Purchases of crude oil and products	[3]	13,293	20,946	21,541
Production and manufacturing (note 12)	[4]	5,535	6,520	6,121
Selling and general	[4]	741	900	908
Federal excise tax and fuel charge		1,736	1,808	1,667
Depreciation and depletion (includes impairments) (note 3, 12)	[5]	3,293	1,598	1,555
Non-service pension and postretirement benefit		121	143	107
Financing (note 13)	[6],[7]	64	93	108
Total expenses		24,796	32,055	32,026
Income (loss) before income taxes		(2,408)	2,046	3,073
Income taxes (note 4)	[8],[9]	(551)	(154)	759
Net income (loss)		$ (1,857)	$ 2,200	$ 2,314
Per share information (Canadian dollars)
Net income (loss) per common share - basic (note 11)		$ (2.53)	$ 2.88	$ 2.87
Net income (loss) per common share - diluted (note 11)		$ (2.53)	$ 2.88	$ 2.86

[1] Amounts from related parties included in revenues, (note 17). 5,107 8,569 6,383

[2] Includes export sales to the United States of $4,614 million (2019 - $7,190 million, 2018 - $6,661 million). Export sales to the United States were recorded in all operating segments, with the largest effects in the Upstream segment.

[3] Amounts to related parties included in purchases of crude oil and products, (note 17). 2,484 3,305 4,092

[4] Amounts to related parties included in production and manufacturing, and selling and general expenses, (note 17). 579 628 566

[5] In 2020, the Upstream segment included a non-cash impairment charge of $1,531 million, before-tax, related to the company’s decision not to further develop a significant portion of its unconventional portfolio. In 2018, the Downstream segment included a non-cash impairment charge of $46 million, before-tax, associated with the Government of Ontario’s revocation of its cap and trade legislation.

[6] Amounts to related parties included in financing, (note 17). 61 98 89

[7] The weighted average interest rate on short-term borrowings in 2020 was 0.8 percent (2019 – 1.8 percent, 2018 – 1.5 percent). Average effective rate on the long-term borrowings with ExxonMobil in 2020 was 1.4 percent (2019 – 2.2 percent, 2018 – 2.0 percent).

[8] On June 28, 2019 the Alberta government enacted a 4 percent decrease in the provincial tax rate, from 12 percent to 8 percent by 2022. On December 9, 2020 the Alberta government enacted an accelerated decrease in the province’s general corporate income tax rate from 10 percent to 8 percent, effective July 1, 2020. The cumulative effect of the 2020 legislative tax changes on the company’s financial statements were immaterial.

[9] Segment results in 2019 include a largely non-cash favourable impact of $662 million associated with the Alberta corporate income tax rate decrease, with the largest impact in the Upstream segment.

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Consolidated statement of income (Parenthetical) - CAD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Amounts from related parties included in revenues, (note 17).	$ 5,107	$ 8,569	$ 6,383
Amounts to related parties included in purchases of crude oil and products, (note 17).	2,484	3,305	4,092
Amounts to related parties included in production and manufacturing, and selling and general expenses, (note 17).	579	628	566
Amounts to related parties included in financing, (note 17).	$ 61	$ 98	$ 89

XML

Consolidated statement of comprehensive income - CAD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Net income (loss)	$ (1,857)	$ 2,200	$ 2,314
Other comprehensive income (loss), net of income taxes
Postretirement benefits liability adjustment (excluding amortization)	(212)	(505)	158
Amortization of postretirement benefits liability adjustment included in net periodic benefit costs	134	111	140
Total other comprehensive income (loss)	(78)	(394)	298
Comprehensive income (loss)	$ (1,935)	$ 1,806	$ 2,612

XML

Consolidated balance sheet - CAD ($) $ in Millions		Dec. 31, 2020	Dec. 31, 2019
Current assets
Cash	[1]	$ 771	$ 1,718
Accounts receivable - net (note 2)	[2]	1,919	2,699
Inventories of crude oil and products (note 12)		1,161	1,296
Materials, supplies and prepaid expenses		673	616
Total current assets		4,524	6,329
Investments and long-term receivables (note 2)	[3]	781	891
Property, plant and equipment, less accumulated depreciation and depletion	[4]	32,034	34,203
Goodwill (note 12)		166	186
Other assets, including intangibles, net		526	578
Total assets	[5],[6]	38,031	42,187
Current liabilities
Notes and loans payable (note 13)	[7]	227	229
Accounts payable and accrued liabilities (note 12)		3,153	4,260
Income taxes payable		0	106
Total current liabilities		3,380	4,595
Long-term debt (note 15)	[8]	4,957	4,961
Other long-term obligations (note 6)		4,100	3,637
Deferred income tax liabilities (note 4)		4,176	4,718
Total liabilities		16,613	17,911
Commitments and contingent liabilities (note 10)
Shareholders' equity
Common shares at stated value (note 11)	[9]	1,357	1,375
Earnings reinvested		22,050	24,812
Accumulated other comprehensive income (loss) (note 18)		(1,989)	(1,911)
Total shareholders' equity		21,418	24,276
Total liabilities and shareholders' equity		$ 38,031	$ 42,187

[1] Cash is composed of cash in bank and cash equivalents at cost. Cash equivalents are all highly liquid securities with maturity of three months or less when purchased.

[2] Accounts receivable - net included net amounts receivable from related parties of $384 million (2019 – $1,007 million), (note 17).

[3] Investments and long-term receivables included amounts from related parties of $313 million (2019 – $296 million), (note 17).

[4] Includes property, plant and equipment under construction of $1,874 million (2019 - $2,149 million, 2018 - $1,553 million).

[5] Effective January 1, 2019, Imperial adopted the Financial Accounting Standards Board’s standard, Leases (Topic 842), as amended. As at December 31, 2020, Total assets include operating lease right of use assets of $188 million (2019 - $260 million). An election was made not to restate prior periods. See note 14 for additional details.

[6] In 2019, the company removed $570 million from Total assets and corresponding liabilities in the Downstream segment associated with the Government of Ontario’s revocation of its cap and trade legislation.

[7] Notes and loans payable included amounts to related parties of $111 million (2019 – $111 million), (note 17).

[8] Long-term debt included amounts to related parties of $4,447 million (2019 – $4,447 million), (note 17).

[9] Number of common shares authorized and outstanding were 1,100 million and 734 million, respectively (2019 – 1,100 million and 744 million, respectively), (note 11).

XML

Consolidated balance sheet (Parenthetical) - CAD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Amounts receivable (payable) from (to) related parties	$ 384	$ 1,007
Common shares authorized	1,100,000,000	1,100,000,000
Common shares outstanding	734,000,000	744,000,000
Investments and Long Term Receivables
Due from related parties	$ 313	$ 296
Long-term debt
Due to related parties	4,447	4,447
Notes and loans payable
Due to related parties, current	$ 111	$ 111

XML

Consolidated statement of shareholders' equity - CAD ($) $ in Millions	Total	Common shares at stated value (note 11)	Earnings reinvested	Earnings reinvested Cumulative effect, period of adoption, adjustment	Accumulated other comprehensive income (loss) (note 18)
At beginning of period at Dec. 31, 2017		$ 1,536	$ 24,714		$ (1,815)
Net income (loss) for the year	$ 2,314		2,314
Share purchases at stated value		(90)
Share purchases in excess of stated value			(1,881)
Dividends declared			(587)
Cumulative effect of accounting change (note 2) at Dec. 31, 2018				$ 0
Other comprehensive income (loss)	298				298
At end of period at Dec. 31, 2018	24,489	1,446	24,560		(1,517)
Net income (loss) for the year	2,200		2,200
Share purchases at stated value		(71)
Share purchases in excess of stated value			(1,302)
Dividends declared			(646)
Cumulative effect of accounting change (note 2) at Dec. 31, 2019	24,812			0
Other comprehensive income (loss)	(394)				(394)
At end of period at Dec. 31, 2019	24,276	1,375	24,812		(1,911)
Net income (loss) for the year	(1,857)		(1,857)
Share purchases at stated value		(18)
Share purchases in excess of stated value			(256)
Dividends declared			(647)
Cumulative effect of accounting change (note 2) at Dec. 31, 2020	22,050			$ (2)
Other comprehensive income (loss)	(78)				(78)
At end of period at Dec. 31, 2020	$ 21,418	$ 1,357	$ 22,050		$ (1,989)

XML

Consolidated statement of cash flows - CAD ($) $ in Millions		12 Months Ended
		Dec. 31, 2020		Dec. 31, 2019		Dec. 31, 2018
Operating activities
Net income (loss)		$ (1,857)		$ 2,200		$ 2,314
Adjustments for non-cash items:
Depreciation and depletion (includes impairments) (note 3)		3,273		1,598		1,509
Impairment of intangible assets (note 12)		20		0		46
(Gain) loss on asset sales (note 9)		(35)		(46)		(54)
Deferred income taxes and other		(521)		(237)		806
Changes in operating assets and liabilities:
Accounts receivable		780		(170)		224
Inventories, materials, supplies and prepaid expenses		78		(74)		(338)
Income taxes payable		(106)		41		8
Accounts payable and accrued liabilities		(1,087)		1,010		(764)
All other items - net	[1]	253		107		171
Cash flows from (used in) operating activities		798		4,429		3,922
Investing activities
Additions to property, plant and equipment		(868)		(1,636)		(1,491)
Proceeds from asset sales (note 9)		82		82		59
Loans to equity companies - net		(16)		(150)		(127)
Cash flows from (used in) investing activities		(802)		(1,704)		(1,559)
Financing activities
Short-term debt - net (note 13)		0		36		0
Reduction in finance lease obligations (note 15)		(20)		(27)		(27)
Dividends paid		(649)		(631)		(572)
Common shares purchased (note 11)		(274)		(1,373)		(1,971)
Cash flows from (used in) financing activities		(943)		(1,995)		(2,570)
Increase (decrease) in cash		(947)		730		(207)
Cash at beginning of year		1,718	[2]	988	[2]	1,195
Cash at end of year	[2]	$ 771		$ 1,718		$ 988

[1] Included contributions to registered pension plans. (195) (211) (203) Income taxes (paid) refunded. (42) 145 (82) Interest (paid), net of capitalization. (62) (91) (110)

[2] Cash is composed of cash in bank and cash equivalents at cost. Cash equivalents are all highly liquid securities with maturity of three months or less when purchased.

XML

Consolidated statement of cash flows (Parenthetical) - CAD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Included contributions to registered pension plans	$ (195)	$ (211)	$ (203)
Income taxes (paid) refunded	(42)	145	(82)
Interest (paid), net of capitalization	$ (62)	(91)	$ (110)
Accounts payable and accrued liabilities
Non-cash adjustments to accrued liabilities and all other items		$ 570

XML

Summary of significant accounting policies

12 Months Ended

Dec. 31, 2020

Summary of significant accounting policies

1. Summary of significant accounting policies

Principles of consolidation

The consolidated financial statements include the accounts of subsidiaries the company controls. Intercompany accounts and transactions are eliminated. Subsidiaries include those companies in which Imperial has both an equity interest and the continuing ability to unilaterally determine strategic, operating, investing and financing policies. Imperial Oil Resources Limited is the only significant subsidiary included in the consolidated financial statements and is wholly owned by Imperial Oil Limited. The consolidated financial statements also include the company’s share of the undivided interest in certain upstream assets, liabilities, revenues and expenses, including its 70.96 percent interest in the Kearl joint venture and its 25 percent interest in the Syncrude joint venture.

Revenues

Imperial generally sells crude oil, natural gas and petroleum and chemical products under short-term agreements at prevailing market prices. In some cases, products may be sold under long-term agreements, with periodic price adjustments to reflect market conditions.

Revenue is recognized at the amount the company expects to receive when the customer has taken control, which is typically when title transfers and the customer has assumed the risks and rewards of ownership. The prices of certain sales are based on price indices that are sometimes not available until the next period. In such cases, estimated realizations are accrued when the sale is recognized, and are finalized when final information is available. Such adjustments to revenue from performance obligations satisfied in previous periods are not significant. Payment for revenue transactions is typically due within 30 days.

Revenues include amounts billed to customers for shipping and handling. Shipping and handling costs incurred up to the point of final storage prior to delivery to a customer are included in “Purchases of crude oil and products” in the Consolidated statement of income. Delivery costs from final storage to customer are recorded as a marketing expense in “Selling and general” expenses. The company does not enter into ongoing arrangements whereby it is required to repurchase its products, nor does the company provide the customer with a right of return.

Future volume delivery obligations that are unsatisfied at the end of the period are expected to be fulfilled through ordinary production or purchases. These performance obligations are based on market prices at the time of the transaction and are fully constrained due to market price volatility.

Purchases and sales of inventory with the same counterparty that are entered into in contemplation of one another are combined and recorded as exchanges measured at the book value of the item sold.

“Revenues” and “Accounts receivable - net” primarily arise from contracts with customers. Long-term receivables are primarily from non-customers. Contract assets are mainly from marketing assistance programs and are not significant. Contract liabilities are mainly customer prepayments, loyalty programs and accruals of expected volume discounts, and are not significant.

Consumer taxes

Taxes levied on the consumer and collected by the company are excluded from the Consolidated statement of income. These are primarily provincial taxes on motor fuels, the federal goods and services tax and the federal/provincial harmonized sales tax.

Derivative instruments

Imperial may use derivative instruments for trading purposes and to offset exposures associated with commodity prices, currency exchange rates and interest rates that arise from existing assets, liabilities, firm commitments and forecasted transactions. All derivative instruments, except those designated as normal purchase and normal sale, are recorded at fair value. Derivative assets and liabilities with the same counterparty are netted if the right of offset exists and certain other criteria are met. Collateral payables or receivables are netted against derivative assets and derivative liabilities respectively.

Recognition and classification of the gain or loss that results from adjusting a derivative to fair value depends on the purpose for the derivative. The gains and losses resulting from changes in the fair value of derivatives are recorded under “Revenues” or “Purchases of crude oil and products” in the Consolidated statement of income.

Fair value

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. Hierarchy Levels 1, 2 and 3 are terms for the priority of inputs to valuation techniques used to measure fair value. Hierarchy Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Hierarchy Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Hierarchy Level 3 inputs are inputs that are not observable in the market.

Inventories

Inventories are recorded at the lower of current market value or cost. The cost of crude oil and products is determined primarily using the last-in, first-out (LIFO) method. LIFO was selected over the alternative first-in, first-out and average cost methods because it provides a better matching of current costs with the revenues generated in the period.

Inventory costs include expenditures and other charges (including depreciation), directly or indirectly incurred in bringing the inventory to its existing condition and location. Selling and general expenses are reported as period costs and excluded from inventory costs. Inventories of materials and supplies are valued at cost or less.

Investments

The company’s interests in the underlying net assets of affiliates it does not control, but over which it exercises significant influence, are accounted for using the equity method. They are recorded at the original cost of the investment plus Imperial’s share of earnings since the investment was made, less dividends received. Imperial’s share of the after-tax earnings of these investments is included in “Investment and other income” in the Consolidated statement of income. Investments in equity securities, other than consolidated subsidiaries and equity method investments, are measured at fair value, with changes in the fair value recognized in net income. The company uses a modified approach for equity securities that do not have a readily determinable fair value. This modified approach measures investments at cost minus impairment, if any, plus or minus changes resulting from observable price changes in orderly transactions in similar investment of the same issuer. Dividends from these investments are included in “Investment and other income”.

These investments represent interests in non-publicly traded pipeline companies and a rail loading joint venture that facilitate the sale and purchase of liquids in the conduct of company operations. Other parties who also have an equity interest in these investments share in the risks and rewards according to their percentage of ownership. Imperial does not invest in these investments in order to remove liabilities from its balance sheet.

Property, plant and equipment

Cost basis

Imperial uses the “successful efforts” method to account for its exploration and production activities. Under this method, costs are accumulated on a field-by-field basis. Costs incurred to purchase, lease, or otherwise acquire a property (whether unproved or proved) are capitalized when incurred. Exploratory well costs are carried as an asset when the well has found a sufficient quantity of reserves to justify its completion as a producing well and where the company is making sufficient progress assessing the reserves and the economic and operating viability of the project. Exploratory well costs not meeting these criteria are charged to expense. Other exploratory expenditures, including geophysical costs and annual lease rentals, are expensed as incurred. Development costs, including costs of productive wells and development dry holes, are capitalized.

Maintenance and repair costs, including planned major maintenance, are expensed as incurred. Improvements that increase or prolong the service life or capacity of an asset are capitalized.

Depreciation, depletion and amortization

Depreciation, depletion and amortization are primarily determined under either the unit-of-production method or the straight-line method, which is based on estimated asset service life taking obsolescence into consideration. Depreciation and depletion for assets associated with producing properties begin at the time when production commences on a regular basis. Depreciation for other assets begins when the asset is in place and ready for its intended use. Assets under construction are not depreciated or depleted.

Acquisition costs of proved properties are amortized using a unit-of-production method, computed on the basis of total proved oil and natural gas reserve volumes. Capitalized exploratory drilling and development costs associated with productive depletable extractive properties are amortized using the unit-of-production rates based on the amount of proved developed reserves of oil and gas that are estimated to be recoverable from existing facilities using current operating methods. Under the unit-of-production method, oil and natural gas volumes are considered produced once they have been measured through meters at custody transfer or sales transaction points at the outlet valve on the lease or field storage tank. In the event that the unit-of-production method does not result in an equitable allocation of cost over the economic life of an upstream asset, an alternative method is used. The straight-line method is used in limited situations where the expected life of the asset does not reasonably correlate with that of the underlying reserves. For example, certain assets used in the production of oil and natural gas have a shorter life than the reserves, and as such, the company uses straight-line depreciation to ensure the asset is fully depreciated by the end of its useful life. Investments in mining heavy equipment and certain ore processing plant assets at oil sands mining properties are depreciated on a straight-line basis over a maximum of 15 years and 50 years respectively. Depreciation of other plant and equipment is calculated using the straight-line method, based on the estimated service life of the asset.

To the extent that proved reserves for a property are substantially de-booked and that property continues to produce such that the resulting depreciation charge does not result in an equitable allocation of cost over the expected life, assets will be depreciated using a unit-of-production method based on reserves determined at the most recent SEC price which results in a more meaningful quantity of proved reserves, appropriately adjusted for production and technical changes. This approach was applied in 2017 and 2018, with the corresponding effect on depreciation expense being immaterial when compared to prior periods. This approach will also be applied in 2021 and the effect of this approach is anticipated to be immaterial compared to 2020. For 2019 and 2020, all properties had sufficient reserves at their relevant SEC prices which enabled equitable allocation of cost over the economic lives of the Upstream assets.

Investments in refinery and chemical process manufacturing equipment are generally depreciated on a straight-line basis over a 25-year life. Maintenance and repairs, including planned major maintenance, are expensed as incurred. Major renewals and improvements are capitalized and the assets replaced are retired.

Impairment assessment

The company tests assets or groups of assets for recoverability on an ongoing basis whenever events or changes in circumstances indicate the carrying amounts may not be recoverable. Among the events or changes in circumstances which could indicate that the carrying value of an asset or asset group may not be recoverable are the following:

● A significant decrease in the market price of a long-lived asset;

● A significant adverse change in the extent or manner in which an asset is being used or in its physical condition including a significant decrease in the company’s current and projected reserve volumes;

● A significant adverse change in legal factors or in the business climate that could affect the value, including a significant adverse action or assessment by a regulator;

● An accumulation of project costs significantly in excess of the amount originally expected;

● A current-period operating loss combined with a history and forecast of operating or cash flow losses; and

● A current expectation that, more likely than not, a long-lived asset will be sold or otherwise disposed of significantly before the end of its previously estimated useful life.

Asset valuation analysis, profitability reviews and other periodic control processes assist Imperial in assessing whether events or changes in circumstances indicate the carrying amounts of any of its assets may not be recoverable.

In general, Imperial does not view temporarily low prices or margins as an indication of impairment. Management believes prices over the long term must be sufficient to generate investments in energy supply to meet global demand. Although prices will occasionally drop significantly, industry prices over the long term will continue to be driven by market supply and demand fundamentals. On the supply side, industry production from mature fields is declining. This is being offset by investments to generate production from new discoveries, field developments and technological and efficiency advancements. OPEC investment activities and production policies also have an impact on world oil supplies. The demand side is largely a function of general economic activities and levels of prosperity. Because the lifespans of the company’s major assets are measured in decades, the value of these assets is predominantly based on long-term views of future commodity prices and development and production costs. During the lifespan of these major assets, the company expects that oil and gas prices will experience significant volatility, and consequently these assets will experience periods of higher earnings and periods of lower earnings, or even losses. In assessing whether events or changes in circumstances indicate the carrying value of an asset may not be recoverable, the company considers recent periods of operating losses in the context of its longer-term view of prices. While near-term prices are subject to wide fluctuations, longer-term price views are more stable and meaningful for purposes of assessing future cash flows.

When the industry experiences a prolonged and deep reduction in commodity prices, the market supply and demand conditions may result in changes to the company’s price or margin assumptions it uses for its capital investment decisions. To the extent those changes result in a significant reduction to its oil prices or natural gas prices or margin ranges, the company may consider that situation, in conjunction with other events or changes in circumstances such as a history of operating losses, as an indicator of potential impairment for certain assets.

In the upstream, the standardized measure of discounted cash flows included in the “Supplemental information on oil and gas exploration and production activities” is required to use prices based on the yearly average of first-day-of-the-month prices. These prices represent discrete points in time and could be higher or lower than the company’s price assumptions which are used for impairment assessments. The company believes the standardized measure does not provide a reliable estimate of the expected future cash flows to be obtained from the development and production of its oil and gas properties or of the value of its oil and gas reserves and therefore does not consider it relevant in determining whether events or changes in circumstances indicate the need for an impairment assessment.

The company has a robust process to monitor for indicators of potential impairment across its asset groups throughout the year. This process is aligned with the requirements of ASC 360 and ASC 932, and relies on the company’s planning and budgeting cycle. If events or changes in circumstances indicate that the carrying value of an asset may not be recoverable, the company estimates the future undiscounted cash flows of the affected properties to judge the recoverability of carrying amounts. In performing this assessment, assets are grouped at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets. Cash flows used in recoverability assessments are based on the company’s assumptions which are developed in the annual planning and budgeting process, and are consistent with the criteria management uses to evaluate investment opportunities. These evaluations make use of the company’s assumptions of future capital allocations, crude oil and natural gas commodity prices, including price differentials, refining and chemical margins, volumes, development and operating costs, foreign currency exchange rates and inflation rates. Volumes are based on projected field and facility production profiles, throughput, or sales. Management’s estimate of upstream production volumes used for projected cash flows makes use of proved reserve quantities and may include risk-adjusted unproved reserve quantities. Cash flow estimates for impairment testing exclude the effects of derivative instruments.

An asset group is impaired if its estimated future undiscounted cash flows are less than the asset group’s carrying value. Impairments are measured by the amount by which the carrying value exceeds fair value. The assessment of fair value may be based on market prices if an active market exists for the asset group or may require the use of Level 3 inputs and assumptions that are based upon the views of a likely market participant. The principal parameters used to establish fair value can include estimates of acreage values and flowing production metrics from comparable market transactions, market-based estimates of historical cash flow multiples, and discounted cash flows. Inputs and assumptions used in discounted cash flow models include estimates of future production volumes, commodity prices which are consistent with the average of third-party industry experts and government agencies, drilling and development costs, and discount rates.

Significant unproved properties are assessed for impairment individually, and valuation allowances against the capitalized costs would be recorded based on the company’s future development plans, the estimated economic chance of success and the length of time that the company expects to hold the properties. Properties that are not individually significant are aggregated by groups and amortized based on development risk and average holding period.

Gains on sales of proved and unproved properties are only recognized when there is neither uncertainty about the recovery of costs applicable to any interest retained nor any substantial obligation for future performance by the company. Losses on properties sold are recognized when incurred or when the properties are held for sale and the fair value of the properties is less than the carrying value.

Gains or losses on assets sold are included in “Investment and other income” in the Consolidated statement of income.

Interest capitalization

Interest costs incurred to finance expenditures during the construction phase of projects are capitalized as part of property, plant and equipment and are depreciated over the service life of the related assets. The project construction phase commences with the development of the detailed engineering design and ends when the constructed assets are ready for their intended use.

Leases

In situations where assets are leased, right of use assets and lease liabilities are established on the balance sheet for leases with an expected term greater than one year, by discounting the amounts fixed in the lease agreement for the duration of the lease which is reasonably certain, considering the probability of exercising any early termination and extension options. The portion of the fixed payment related to service costs for tankers and finance leases is excluded from the calculation of right of use assets and lease liabilities. Assets leased for nearly all of their useful lives are accounted for as finance leases. In general, leases are capitalized using the company’s incremental borrowing rate. See note 14 to the consolidated financial statements on page 102 for further details.

Goodwill and other intangible assets

Goodwill is not subject to amortization. Goodwill is tested for impairment annually or more frequently if events or circumstances indicate it might be impaired. Impairment losses are recognized in current period earnings. The evaluation for impairment of goodwill is based on a comparison of the carrying values of goodwill and associated operating assets with the estimated present value of net cash flows from those operating assets.

Intangible assets with determinable useful lives are amortized over the estimated service lives of the assets. Computer software development costs are amortized over a maximum of 15 years and customer lists are amortized over a maximum of 10 years. The amortization is included in “Depreciation and depletion” in the Consolidated statement of income.

Asset retirement obligations and other environmental liabilities

Legal obligations associated with site restoration on the retirement of assets with determinable useful lives are recognized when they are incurred, which is typically at the time the assets are installed. These obligations primarily relate to soil reclamation and remediation, and costs of abandonment and demolition of oil and gas wells and related facilities. The company uses estimates, assumptions and judgments regarding such factors as the existence of a legal obligation for an asset retirement obligation, technical assessments of the assets, estimated amounts and timing of settlements, the credit-adjusted risk-free rate to be used, and inflation rates. The obligations are initially measured at fair value and discounted to present value. A corresponding amount equal to that of the initial obligation is added to the capitalized costs of the related asset. Over time, the discounted asset retirement obligation amount will be accreted for the change in its present value, and the initial capitalized costs will be depreciated over the useful lives of the related assets.

No asset retirement obligations are set up for those manufacturing, distribution, marketing and office facilities with an indeterminate useful life. Asset retirement obligations for these facilities generally become firm at the time the facilities are permanently shut down and dismantled. These obligations may include the costs of asset disposal and additional soil remediation. However, these sites have indeterminate lives based on plans for continued operations, and as such, the fair value of the conditional legal obligations cannot be measured, since it is impossible to estimate the future settlement dates of such obligations. Provision for environmental liabilities of these assets is made when it is probable that obligations have been incurred and the amount can be reasonably estimated. Provisions for environmental liabilities are determined based on engineering estimated costs, taking into account the anticipated method and extent of remediation consistent with legal requirements, current technology and the possible use of the location. These provisions are not reduced by possible recoveries from third parties and projected cash expenditures are not discounted.

Foreign-currency translation

Monetary assets and liabilities in foreign currencies have been translated at the rates of exchange prevailing on December 31. Any exchange gains or losses are recognized in income.

Share-based compensation

The company awards share-based compensation to certain employees in the form of restricted stock units. Compensation expense is measured each reporting period based on the company’s current stock price and is recorded as “Selling and general” expenses in the Consolidated statement of income over the requisite service period of each award. See note 8 to the consolidated financial statements on page 97 for further details.

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Accounting changes

12 Months Ended

Dec. 31, 2020

Accounting changes

2. Accounting changes

Effective January 1, 2020, the company adopted the Financial Accounting Standards Board’s update, Financial Instruments – Credit Losses (Topic 326), as amended. The standard requires a valuation allowance for credit losses be recognized for certain financial assets that reflects the current expected credit loss over the asset’s contractual life. The valuation allowance considers the risk of loss, even if remote, and considers past events, current conditions and reasonable and supportable forecasts. The standard requires this expected loss methodology for trade receivables, certain other financial assets and off-balance-sheet credit exposures. The cumulative effect adjustment related to the adoption of this standard reduced “Earnings reinvested” in Shareholders’ equity by $2 million.

The company is exposed to credit losses primarily through sales of petroleum products, crude oil, natural gas liquids and natural gas, as well as loans to equity companies and joint venture receivables. A counterparty’s ability to pay is assessed through a credit review process that considers payment terms, the counterparty’s established credit rating or the company’s assessment of the counterparty’s credit worthiness, contract terms, and other risks. The company can require prepayment or collateral to mitigate certain credit risks.

The company groups financial assets into portfolios that share similar risk characteristics for purposes of determining the allowance for credit losses and assesses if a significant change in the risk of credit loss has occurred. Among the quantitative and qualitative factors considered are historical financial data, current conditions, industry and country risk, current credit ratings and the quality of third-party guarantees secured from the counterparty. Financial assets are written off in whole, or in part, when practical recovery efforts have been exhausted and no reasonable expectation of recovery exists. Subsequent recoveries of amounts previously written off are recognized in earnings. The company manages receivable portfolios using past due balances as a key credit quality indicator.

The company recognizes a credit allowance for off-balance-sheet credit exposures as a liability on the balance sheet, separate from the allowance for credit losses related to recognized financial assets. These exposures could include unfunded loans to equity companies and financial guarantees that cannot be cancelled unilaterally by the company.

At December 31, 2020, the company’s evaluation of financial assets under Financial Instruments – Credit Losses (Topic 326), as amended, included $1,437 million of accounts receivable, net of allowances of $4 million, and investments and long-term receivables of $323 million. The company has determined that, at this time, no credit allowance is required for investments and long-term receivables, and for off-balance-sheet credit exposures.

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Business segments

12 Months Ended

Dec. 31, 2020

Business segments

3. Business segments

The company operates its business in Canada. The Upstream, Downstream and Chemical functions best define the operating segments of the business that are reported separately. The factors used to identify these reportable segments are based on the nature of the operations that are undertaken by each segment and the structure of the company’s internal organization. The Upstream segment is organized and operates to explore for and ultimately produce crude oil and its equivalent, and natural gas. The Downstream segment is organized and operates to refine crude oil into petroleum products and to distribute and market these products. The Chemical segment is organized and operates to manufacture and market hydrocarbon-based chemicals and chemical products. The above segmentation has been the long-standing practice of the company and is broadly understood across the petroleum and petrochemical industries.

These functions have been defined as the operating segments of the company because they are the segments (a) that engage in business activities from which revenues are earned and expenses are incurred; (b) whose operating results are regularly reviewed by the company’s chief operating decision maker to make decisions about resources to be allocated to each segment and assess its performance; and (c) for which discrete financial information is available.

Corporate and other includes assets and liabilities that do not specifically relate to business segments – primarily cash, capitalized interest costs, short-term borrowings, long-term debt and liabilities associated with incentive compensation, pension and other postretirement benefit liabilities. Net earnings effects under Corporate and other activities primarily include debt-related financing, corporate governance costs, non-service pension and postretirement benefit costs, share-based incentive compensation expenses and interest income.

Segment accounting policies are the same as those described in the summary of significant accounting policies. Upstream, Downstream and Chemical expenses include amounts allocated from Corporate and other activities. The allocation is based on proportional segment expenses. Transfers of assets between segments are recorded at book amounts. Intersegment sales are made essentially at prevailing market prices. Assets and liabilities that are not identifiable by segment are allocated.

	Upstream									Downstream									Chemical
millions of Canadian dollars	2020			2019			2018			2020			2019			2018			2020			2019			2018
Revenues and other income
Revenues (a)		6,263			9,479			8,525			15,178			23,591			25,200			843			932			1,239
Intersegment sales		2,527			3,763			2,634			1,480			1,597			1,542			165			229			279
Investment and other income (note 9)		7			17			11			78			47			95			-			-			-
		8,797			13,259			11,170			16,736			25,235			26,837			1,008			1,161			1,518
Expenses
Exploration (note 16)		13			47			19			-			-			-			-			-			-
Purchases of crude oil and products		4,834			6,528			5,833			12,047			19,332			19,326			579			667			831
Production and manufacturing (note 12)		3,852			4,440			4,305			1,468			1,829			1,606			215			251			210
Selling and general		-			-			-			619			774			773			92			86			87
Federal excise tax and fuel charge		-			-			-			1,736			1,808			1,667			-			-			-
Depreciation and depletion (b) (note 12)		3,084			1,374			1,278			166			186			242			19			16			14
Non-service pension and postretirement benefit		-			-			-			-			-			-			-			-			-
Financing (note 13)		3			3			1			-			-			2			-			-			-
Total expenses		11,786			12,392			11,436			16,036			23,929			23,616			905			1,020			1,142
Income (loss) before income taxes		(2,989	)		867			(266	)		700			1,306			3,221			103			141			376
Income tax expense (benefit) (c) (note 4)		(671	)		(481	)		(128	)		147			345			855			25			33			101
Net income (loss)		(2,318	)		1,348			(138	)		553			961			2,366			78			108			275
Cash flows from (used in) operating activities		286			2,423			916			470			1,965			2,749			114			172			354
Capital and exploration expenditures (d)		561			1,248			991			251			484			383			21			34			25
Property, plant and equipment
Cost		47,693			47,050			46,435			6,321			6,123			5,900			975			954			916
Accumulated depreciation and depletion		(18,786	)		(15,889	)		(15,050	)		(3,962	)		(3,830	)		(3,763	)		(699	)		(680	)		(662	)
Net property, plant and equipment (e)		28,907			31,161			31,385			2,359			2,293			2,137			276			274			254
Total assets (f) (g)		31,835			34,554			34,829			4,554			5,179			5,119			408			416			438

	Corporate and other									Eliminations									Consolidated
millions of Canadian dollars	2020			2019			2018			2020			2019			2018			2020			2019			2018
Revenues and other income
Revenues (a)		-			-			-			-			-			-			22,284			34,002			34,964
Intersegment sales		-			-			-			(4,172	)		(5,589	)		(4,455	)		-			-			-
Investment and other income (note 9)		19			35			29			-			-			-			104			99			135
		19			35			29			(4,172	)		(5,589	)		(4,455	)		22,388			34,101			35,099
Expenses
Exploration (note 16)		-			-			-			-			-			-			13			47			19
Purchases of crude oil and products		-			-			-			(4,167	)		(5,581	)		(4,449	)		13,293			20,946			21,541
Production and manufacturing (note 12)		-			-			-			-			-			-			5,535			6,520			6,121
Selling and general		35			48			54			(5	)		(8	)		(6	)		741			900			908
Federal excise tax and fuel charge		-			-			-			-			-			-			1,736			1,808			1,667
Depreciation and depletion (b) (note 12)		24			22			21			-			-			-			3,293			1,598			1,555
Non-service pension and postretirement benefit		121			143			107			-			-			-			121			143			107
Financing (note 13)		61			90			105			-			-			-			64			93			108
Total expenses		241			303			287			(4,172	)		(5,589	)		(4,455	)		24,796			32,055			32,026
Income (loss) before income taxes		(222	)		(268	)		(258	)		-			-			-			(2,408	)		2,046			3,073
Income tax expense (benefit) (c) (note 4)		(52	)		(51	)		(69	)		-			-			-			(551	)		(154	)		759
Net income (loss)		(170	)		(217	)		(189	)		-			-			-			(1,857	)		2,200			2,314
Cash flows from (used in) operating activities		(64	)		(124	)		(116	)		(8	)		(7	)		19			798			4,429			3,922
Capital and exploration expenditures (d)		41			48			28			-			-			-			874			1,814			1,427
Property, plant and equipment
Cost		782			741			693			-			-			-			55,771			54,868			53,944
Accumulated depreciation and depletion		(290	)		(266	)		(244	)		-			-			-			(23,737	)		(20,665	)		(19,719	)
Net property, plant and equipment (e)		492			475			449			-			-			-			32,034			34,203			34,225
Total assets (f) (g)		1,632			2,536			1,548			(398	)		(498	)		(478	)		38,031			42,187			41,456

(a) Includes export sales to the United States of $4,614 million (2019 - $7,190 million, 2018 - $6,661 million). Export sales to the United States were recorded in all operating segments, with the largest effects in the Upstream segment.

(b) In 2020, the Upstream segment included a non-cash impairment charge of $1,531 million, before-tax, related to the company’s decision not to further develop a significant portion of its unconventional portfolio. In 2018, the Downstream segment included a non-cash impairment charge of $46 million, before-tax, associated with the Government of Ontario’s revocation of its cap and trade legislation.

(c) Segment results in 2019 include a largely non-cash favourable impact of $662 million associated with the Alberta corporate income tax rate decrease, with the largest impact in the Upstream segment.

(d) Capital and exploration expenditures (CAPEX) include exploration expenses, additions to property, plant and equipment, additions to finance leases, additional investments and acquisitions. CAPEX excludes the purchase of carbon emission credits.

(e) Includes property, plant and equipment under construction of $1,874 million (2019 - $2,149 million, 2018 - $1,553 million).

(f) Effective January 1, 2019, Imperial adopted the Financial Accounting Standards Board’s standard, Leases (Topic 842), as amended. As at December 31, 2020, Total assets include operating lease right of use assets of $188 million (2019 - $260 million). An election was made not to restate prior periods. See note 14 for additional details.

(g) In 2019, the company removed $570 million from Total assets and corresponding liabilities in the Downstream segment associated with the Government of Ontario’s revocation of its cap and trade legislation.

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Income taxes

12 Months Ended

Dec. 31, 2020

Income taxes

4. Income taxes

millions of Canadian dollars	2020		2019		2018
Current income tax expense (benefit) (a)	(27	)	140		(14	)
Deferred income tax expense (benefit) (a)	(524	)	(294	)	773
Total income tax expense (benefit) (a)	(551	)	(154	)	759
Statutory corporate tax rate (percent)	25.0		26.0		26.9
Increase (decrease) resulting from:
Enacted tax rate change (a)	0.1		(31.9	)	-
Other (b)	(2.2	)	(1.6	)	(2.2	)
Effective income tax rate	22.9		(7.5	)	24.7

(a) On June 28, 2019 the Alberta government enacted a 4 percent decrease in the provincial tax rate, from 12 percent to 8 percent by 2022. On December 9, 2020 the Alberta government enacted an accelerated decrease in the province’s general corporate income tax rate from 10 percent to 8 percent, effective July 1, 2020. The cumulative effect of the 2020 legislative tax changes on the company’s financial statements were immaterial.

(b) Other decreases primarily relate to prior year adjustments, re-assessments and disposals.

Deferred income taxes are based on differences between the accounting and tax values of assets and liabilities. These differences in value are re-measured at each year-end using the tax rates and tax laws expected to apply when those differences are realized or settled in the future. Components of deferred income tax liabilities and assets as at December 31 were:

millions of Canadian dollars	2020		2019		2018
Depreciation and amortization	5,319		5,164		5,726
Successful drilling and land acquisitions	363		750		856
Pension and benefits	(534	)	(469	)	(336	)
Asset retirement obligation	(403	)	(336	)	(381	)
Capitalized interest	120		117		121
LIFO inventory valuation	(150	)	(276	)	(107	)
Tax loss carryforwards	(460	)	(141	)	(658	)
Other	(154	)	(161	)	(150	)
Net deferred income tax liabilities	4,101		4,648		5,071

Unrecognized tax benefits

Unrecognized tax benefits reflect the difference between positions taken or expected to be taken on income tax returns and the amounts recognized in the financial statements.

The following table summarizes the movement in unrecognized tax benefits:

millions of Canadian dollars	2020		2019		2018
Balance as of January 1	35		36		78
Additions based on current year’s tax position	2		-		-
Additions for prior years’ tax positions	-		1		9
Reductions for prior years’ tax positions	-		-		(2	)
Settlements with tax authorities	(1	)	(2	)	(49	)
Balance as of December 31	36		35		36

The unrecognized tax benefit balances shown above are predominately related to tax positions that would reduce the company’s effective tax rate if the positions are favourably resolved. Unfavourable resolution of these tax positions generally would not increase the effective tax rate. The 2020, 2019 and 2018 changes in unrecognized tax benefits did not have a material effect on the company’s net income or cash flow. The company’s tax filings from 2016 to 2020 are subject to examination by the tax authorities. Tax filings from 2007 to 2015 have open objections and therefore are also subject to examination by the tax authorities. The Canada Revenue Agency has made certain adjustments to the company’s filings. Management has evaluated these adjustments and is formally disputing those matters to which the company disagrees. Many of these outstanding matters will not be resolved until after 2021. The impact on unrecognized tax benefits and the company’s effective income tax rate from these matters is not expected to be material.

Resolution of the related tax positions could take many years to complete. It is difficult to predict the timing of resolution for tax positions since such timing is not entirely within the control of the company.

The company classifies interest on income tax related balances as interest expense or interest income and classifies tax related penalties as operating expense.

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Employee retirement benefits

12 Months Ended

Dec. 31, 2020

Employee retirement benefits

5. Employee retirement benefits

Retirement benefits, which cover almost all retired employees and their surviving spouses, include pension income and certain health care and life insurance benefits. They are met through funded registered retirement plans and through unfunded supplementary benefits that are paid directly to recipients.

Pension income benefits consist mainly of company-paid defined benefit plans that are based on years of service and final average earnings. The company shares in the cost of health care and life insurance benefits. The company’s benefit obligations are based on the projected benefit method of valuation that includes employee service to date and present compensation levels, as well as a projection of salaries to retirement.

The expense and obligations for both funded and unfunded benefits are determined in accordance with accepted actuarial practices and U.S. GAAP. The process for determining retirement-income expense and related obligations includes making certain long-term assumptions regarding the discount rate, rate of return on plan assets and rate of compensation increases. The obligation and pension expense can vary significantly with changes in the assumptions used to estimate the obligation and the expected return on plan assets.

The benefit obligations and plan assets associated with the company’s defined benefit plans are measured on December 31.

	Pension benefits			Other postretirement benefits
		2020	2019		2020	2019
Assumptions used to determine benefit obligations at December 31 (percent)
Discount rate		2.50	3.10		2.50	3.10
Long-term rate of compensation increase		4.00	4.50		4.00	4.50

millions of Canadian dollars
Change in projected benefit obligation
Projected benefit obligation at January 1	9,786		8,359		693		582
Current service cost	305		228		24		16
Interest cost	308		324		24		20
Actuarial loss (gain) (a)	811		1,053		152		99
Amendments	-		283		-		-
Benefits paid (b)	(494	)	(461	)	(20	)	(24	)
Projected benefit obligation at December 31	10,716		9,786		873		693
Accumulated benefit obligation at December 31	9,619		8,814

(a) Actuarial loss primarily driven by a decrease in the year-end discount rate from 3.10 percent to 2.50 percent, partially offset by the impact of a reduction in the long-term rate of compensation increase assumption from 4.50 percent to 4.00 percent.

(b) Benefit payments for funded and unfunded plans.

The discount rate for the purpose of calculating year-end postretirement benefits plan liabilities is determined by using the Canadian Institute of Actuaries recommended spot curve for high-quality, long-term Canadian corporate bonds with an average maturity (or duration) approximating that of the liabilities. For the measurement of the accumulated postretirement benefit obligation, the assumed health care cost trend rates start with 5.66 percent in 2021 and gradually decline to 3.57 percent by 2040 and beyond.

	Pension benefits					Other postretirement benefits
millions of Canadian dollars		2020		2019			2020		2019
Change in plan assets
Fair value at January 1		8,599		7,691
Actual return (loss) on plan assets		1,073		1,114
Company contributions		195		211
Benefits paid (a)		(441	)	(417	)
Fair value at December 31		9,426		8,599
Plan assets in excess of (less than) projected benefit obligation at December 31
Funded plans		(641	)	(590	)
Unfunded plans		(649	)	(597	)		(873	)	(693	)
Total (b)		(1,290	)	(1,187	)		(873	)	(693	)

(a) Benefit payments for funded plans only.

(b) Fair value of assets less projected benefit obligation shown above.

Funding of registered retirement plans complies with federal and provincial pension regulations, and the company makes contributions to the plans based on an independent actuarial valuation. In accordance with authoritative guidance relating to the accounting for defined pension and other postretirement benefits plans, the underfunded status of the company’s defined benefit postretirement plans was recorded as a liability in the Consolidated balance sheet, and the changes in that funded status in the year in which the changes occurred was recognized through other comprehensive income.

	Pension benefits					Other postretirement              benefits
millions of Canadian dollars		2020		2019			2020		2019
Amounts recorded in the Consolidated balance sheet consist of:
Current liabilities		(27	)	(27	)		(31	)	(31	)
Other long-term obligations		(1,263	)	(1,160	)		(842	)	(662	)
Total recorded		(1,290	)	(1,187	)		(873	)	(693	)
Amounts recorded in accumulated other comprehensive income consist of:
Net actuarial loss (gain)		2,232		2,256			272		133
Prior service cost		269		283			-		-
Total recorded in accumulated other comprehensive income, before-tax		2,501		2,539			272		133

The company establishes the long-term expected rate of return on plan assets by developing a forward-looking long-term return assumption for each asset class, taking into account factors such as the expected real return for the specific asset class and inflation. A single, long-term rate of return is then calculated as the weighted average of the target asset allocation percentages and the long-term return assumption for each asset class. The 2020 long-term expected return of 4.5 percent used in the calculations of pension expense compares to an actual rate of return of 8.4 percent and 6.9 percent over the last 10- and 20-year periods respectively, ending December 31, 2020.

	Pension benefits									Other postretirement          benefits
	2020			2019			2018			2020			2019			2018
Assumptions used to determine net periodic benefit cost for years ended December 31 (percent)
Discount rate		3.10			3.90			3.40			3.10			3.90			3.40
Long-term rate of return on funded assets		4.50			4.50			5.00			-			-			-
Long-term rate of compensation increase		4.50			4.50			4.50			4.50			4.50			4.50
millions of Canadian dollars
Components of net periodic benefit cost
Current service cost		305			228			239			24			16			17
Interest cost		308			324			302			24			20			22
Expected return on plan assets		(391	)		(349	)		(402	)		-			-			-
Amortization of prior service cost		14			-			4			-			-			-
Amortization of actuarial loss (gain)		153			149			175			13			(1	)		6
Net periodic benefit cost		389			352			318			61			35			45
Changes in amounts recorded in accumulated other comprehensive income
Net actuarial loss (gain)		129			288			(116	)		152			99			(101	)
Amortization of net actuarial (loss) gain included in net periodic benefit cost		(153	)		(149	)		(175	)		(13	)		1			(6	)
Prior service cost		-			283			-			-			-			-
Amortization of prior service cost included in net periodic benefit cost		(14	)		-			(4	)		-			-			-
Total recorded in other comprehensive income		(38	)		422			(295	)		139			100			(107	)
Total recorded in net periodic benefit cost and other comprehensive income, before-tax		351			774			23			200			135			(62	)

Costs for defined contribution plans, primarily the employee savings plan, were $47 million in 2020 (2019 - $43 million, 2018 - $41 million).

A summary of the change in accumulated other comprehensive income is shown in the table below:

	Total pension and other postretirement benefits
millions of Canadian dollars	2020			2019			2018
(Charge) credit to other comprehensive income, before-tax		(101	)		(522	)		402
Deferred income tax (charge) credit (note 18)		23			128			(104	)
(Charge) credit to other comprehensive income, after-tax		(78	)		(394	)		298

The company’s investment strategy for pension plan assets reflects a long-term view, a careful assessment of the risks inherent in various asset classes and broad diversification to reduce the risk of the portfolio. Consistent with the long-term nature of the liability, the plan assets are primarily invested in global, market-cap-weighted indexed equity and domestic indexed bond funds to diversify risk while minimizing costs. The balance of the plan assets is largely invested in high-quality corporate and government debt securities. Studies are periodically conducted to establish the preferred target asset allocation. The target asset allocation for equity securities is 30 percent. The target allocation for debt securities is 67 percent. Plan assets for the remaining 3 percent are invested in venture capital partnerships that pursue a strategy of investment in U.S. and international early stage ventures.

The 2020 fair value of the pension plan assets, including the level within the fair value hierarchy, is shown in the table below:

			Fair value measurements at December 31, 2020, using:
millions of Canadian dollars	Total		Level 1		Level 2	Level 3	Net Asset Value
Asset class
Equity securities
Canadian		222						222
Non-Canadian		2,690						2,690
Debt securities - Canadian
Corporate		1,426						1,426
Government		4,825						4,825
Asset backed		-						-
Equities – Venture capital		214						214
Cash		49		41				8
Total plan assets at fair value		9,426		41				9,385

The 2019 fair value of the pension plan assets, including the level within the fair value hierarchy, is shown in the table below:

			Fair value measurements at December 31, 2019, using:
millions of Canadian dollars	Total		Level 1		Level 2	Level 3	Net Asset Value
Asset class
Equity securities
Canadian		210						210
Non-Canadian		2,449						2,449
Debt securities - Canadian
Corporate		1,379						1,379
Government		4,299						4,299
Asset backed		1						1
Equities – Venture capital		204						204
Cash		57		40				17
Total plan assets at fair value		8,599		40				8,559

A summary of pension plans with accumulated benefit obligation and projected benefit obligation in excess of plan assets is shown in the table below:

	Pension benefits
millions of Canadian dollars	2020		2019
For funded pension plans with accumulated benefit obligation in excess of plan assets: (a)
Accumulated benefit obligation		1,034		942
Fair value of plan assets		954		870
Accumulated benefit obligation less fair value of plan assets		80		72
For funded pension plans with projected benefit obligation in excess of plan assets:
Projected benefit obligation		10,067		9,189
Fair value of plan assets		9,426		8,599
Projected benefit obligation less fair value of plan assets		641		590
For unfunded plans covered by book reserves:
Projected benefit obligation		649		597
Accumulated benefit obligation		565		536

(a) The amounts shown for funded pension plans with accumulated benefit obligation in excess of plan assets represent the company’s proportionate share of a joint venture sponsored pension plan. For the company sponsored funded plan, the fair value of plan assets exceeded the accumulated benefit obligation in both 2020 and 2019.

Cash flows

Benefit payments expected in:

millions of Canadian dollars	Pension benefits		Other postretirement benefits
2021		460		31
2022		460		32
2023		465		32
2024		465		33
2025		465		34
2026 - 2030		2,325		175

In 2021, the company expects to make cash contributions of about $164 million to its pension plans.

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Other long-term obligations

12 Months Ended

Dec. 31, 2020

Other long-term obligations

6. Other long-term obligations

millions of Canadian dollars	2020		2019
Employee retirement benefits (a) (note 5)		2,105		1,822
Asset retirement obligations and other environmental liabilities (b) (c)		1,676		1,388
Share-based incentive compensation liabilities (note 8)		45		65
Operating lease liability (note 14)		95		143
Other obligations		179		219
Total other long-term obligations		4,100		3,637

(a) Total recorded employee retirement benefits obligations also included $58 million in current liabilities (2019 – $58 million).

(b) Total asset retirement obligations and other environmental liabilities also included $100 million in current liabilities (2019 – $124 million).

(c) For 2020, the asset retirement obligations were discounted at 6 percent (2019 - 6 percent).

Asset retirement obligations incurred in the current period were Level 3 fair value measurements. The following table summarizes the activity in the liability for asset retirement obligations:

millions of Canadian dollars	2020			2019			2018
Balance as at January 1		1,400			1,417			1,397
Additions (deductions)		265			(23	)		(5	)
Accretion		82			80			85
Settlement		(73	)		(74	)		(60	)
Balance as at December 31		1,674			1,400			1,417

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Financial and derivative instruments

12 Months Ended

Dec. 31, 2020

Financial and derivative instruments

7. Financial and derivative instruments

Financial instruments

The fair value of the company’s financial instruments is determined by reference to various market data and other appropriate valuation techniques. There are no material differences between the fair value of the company’s financial instruments and the recorded carrying value. At December 31, 2020 and December 31, 2019, the fair value of long-term debt ($4,447 million, excluding finance lease obligations) was primarily a level 2 measurement.

Derivative instruments

The company’s size, strong capital structure and the complementary nature of the Upstream, Downstream and Chemical businesses reduce the company’s enterprise-wide risk from changes in commodity prices and currency exchange rates. In addition, the company uses commodity-based contracts, including derivative instruments to manage commodity price risk. The company does not designate derivative instruments as a hedge for hedge accounting purposes.

Credit risk associated with the company’s derivative position is mitigated by several factors, including the use of derivative clearing exchanges and the quality of and financial limits placed on derivative counterparties. The company maintains a system of controls that includes the authorization, reporting and monitoring of derivative activity.

The net notional long/(short) position of derivative instruments was:

At December 31	2020			2019
Crude (barrels)		(800,000	)		(590,000	)
Products (barrels)		(390,000	)		-

Realized and unrealized gain or (loss) on derivative instruments recognized in the Consolidated statement of income is included in the following lines on a before-tax basis:

millions of Canadian dollars	2020			2019			2018
Revenues		(13	)		(3	)		6
Purchases of crude oil and products		(21	)		(7	)		(24	)
Total		(34	)		(10	)		(18	)

The estimated fair value of derivative instruments, and the related hierarchy level for the fair value measurement is as follows:

millions of Canadian dollars At December 31, 2020
	Fair value								Effect of counterparty netting			Effect of collateral netting			Net carrying value
	Level 1		Level 2		Level 3		Total
Assets
Derivative assets (a)		2		-		-		2		(2	)		-			-
Liabilities
Derivative liabilities (b)		12		-		-		12		(2	)		(10	)		-

(a) Included in the Consolidated balance sheet line: “Materials, supplies and prepaid expenses”.

(b) Included in the Consolidated balance sheet line: “Accounts payable and accrued liabilities”.

millions of Canadian dollars At December 31, 2019
	Fair value								Effect of		Effect of		Net
									counterparty		collateral		carrying
	Level 1		Level 2		Level 3		Total		netting		netting		value
Assets
Derivative assets (a)		-		-		-		-		-		-		-
Liabilities
Derivative liabilities (b)		2		-		-		2		-		(2)		-

(a) Included in the Consolidated balance sheet line: “Materials, supplies and prepaid expenses”.

(b) Included in the Consolidated balance sheet line: “Accounts payable and accrued liabilities”.

At December 31, 2020, the Company had $5 million of collateral under a master netting arrangement not offset against the derivatives on the Consolidated balance sheet in “Accounts receivable - net”, primarily related to initial margin requirements.

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Share-based incentive compensation programs

12 Months Ended

Dec. 31, 2020

Share-based incentive compensation programs

8. Share-based incentive compensation programs

Share-based incentive compensation programs are designed to retain selected employees, reward them for high performance and promote individual contribution to sustained improvement in the company’s future business performance and shareholder value over the long-term. The nonemployee directors also participate in share-based incentive compensation programs.

Restricted stock units and deferred share units

Under the restricted stock unit plan, each unit entitles the recipient to the conditional right to receive from the company, upon vesting, an amount equal to the value of one common share of the company, based on the five-day average of the closing price of the company’s common shares on the Toronto Stock Exchange on and immediately prior to the vesting dates. For the majority of the units, fifty percent of the units vest on the third anniversary of the grant date, and the remainder vest on the seventh anniversary of the grant date. The company may also issue units to the chairman, president and chief executive officer where 50 percent of the units vest on the fifth anniversary of the grant date and the remainder vest on the tenth anniversary of the grant date, except that for awards granted prior to 2020, the vesting of the tenth anniversary portion is delayed until retirement if later than 10 years.

The deferred share unit plan is made available to nonemployee directors. The nonemployee directors can elect to receive all or part of their eligible directors’ fees in units. The number of units granted is determined at the end of each calendar quarter by dividing the dollar amount of the nonemployee director’s fees for that calendar quarter elected to be received as deferred share units by the average closing price of the company’s shares for the five consecutive trading days (“average closing price”) immediately prior to the last day of the calendar quarter. Additional units are granted to represent dividends on unexercised units, and are calculated by dividing the cash dividend payable on the company’s shares by the average closing price immediately prior to the payment date for that dividend and multiplying the resulting number by the number of deferred share units held by the recipient, as adjusted for any share splits. Deferred share units cannot be exercised until after termination of service as a director, including termination due to death, and must be exercised in their entirety in one election no later than December 31 of the year following the year of termination of service. On the exercise date, the cash value to be received for the units is determined based on the company’s average closing price immediately prior to the date of exercise, as adjusted for any share splits.

All units require settlement by cash payments with the following exceptions. The restricted stock unit program provides that, for units granted to Canadian residents, the recipient may receive one common share of the company per unit or elect to receive the cash payment for the units that vest on the seventh year anniversary of the grant date. For units where 50 percent vest on the fifth anniversary of the grant date and the remainder vest on the tenth anniversary of grant, the recipient may receive one common share of the company per unit or elect to receive cash payment for all that vest.

The company accounts for all units by using the fair-value-based method. The fair value of awards in the form of restricted stock and deferred share units is the market price of the company’s stock. Under this method, compensation expense related to the units of these programs is measured each reporting period based on the company’s current stock price and is recorded in the Consolidated statement of income over the requisite service period of each award.

The following table summarizes information about these units for the year ended December 31, 2020:

	Restricted			Deferred
	stock units			share units
Outstanding at January 1, 2020		4,912,805			170,163
Granted		747,040			34,811
Vested / Exercised		(1,187,630	)		(57,569	)
Forfeited and cancelled		(8,895	)		-
Outstanding at December 31, 2020		4,463,320			147,405

In 2020, net loss included a favourable impact of $2 million before tax associated with compensation programs (2019 - $34 million expense, 2018 - $32 million expense). Income tax expense associated with compensation programs for the year was $0 million (2019 - $9 million benefit, 2018 - $9 million benefit). Cash payments of $33 million were made for these programs in 2020 (2019 - $50 million, 2018 - $59 million).

As of December 31, 2020, there was $45 million of total before-tax unrecognized compensation expense related to non-vested restricted stock units based on the company’s share price at the end of the current reporting period. The weighted average vesting period of non-vested restricted stock units is 4.1 years. All units under the deferred share programs have vested as of December 31, 2020.

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Investment and other income

12 Months Ended

Dec. 31, 2020

Investment and other income

9. Investment and other income

Investment and other income includes gains and losses on asset sales as follows:

millions of Canadian dollars	2020		2019		2018
Proceeds from asset sales		82		82		59
Book value of asset sales		47		36		5
Gain (loss) on asset sales, before-tax		35		46		54
Gain (loss) on asset sales, after-tax		32		42		38

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Litigation and other contingencies

12 Months Ended

Dec. 31, 2020

Commitments and Contingencies Disclosure [Text Block]

10. Litigation and other contingencies

A variety of claims have been made against Imperial and its subsidiaries in a number of lawsuits. Management has regular litigation reviews, including updates from corporate and outside counsel, to assess the need for accounting recognition or disclosure of these contingencies. The company accrues an undiscounted liability for those contingencies where the incurrence of a loss is probable and the amount can be reasonably estimated. If a range of amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. The company does not record liabilities when the likelihood that the liability has been incurred is probable but the amount cannot be reasonably estimated or when the liability is believed to be only reasonably possible or remote. For contingencies where an unfavourable outcome is reasonably possible and which are significant, the company discloses the nature of the contingency and, where feasible, an estimate of the possible loss. For purposes of the company’s contingency disclosures, “significant” includes material matters, as well as other matters which management believes should be disclosed. Based on a consideration of all relevant facts and circumstances, the company does not believe the ultimate outcome of any currently pending lawsuits against the company will have a material adverse effect on the company’s operations, financial condition, or financial statements taken as a whole.

Additionally, the company has other commitments arising in the normal course of business for operating and capital needs, all of which are expected to be fulfilled with no adverse consequences material to the company’s operations or financial condition. Unconditional purchase obligations, as defined by accounting standards, are those long-term commitments that are non-cancelable or cancelable only under certain conditions and that third parties have used to secure financing for the facilities that will provide the contracted goods and services. The company has not entered into any unconditional purchase obligations.

As a result of the completed sale of Imperial’s remaining company-owned Esso retail sites, the company was contingently liable at December 31, 2020, for guarantees relating to performance under contracts of other third-party obligations totalling $26 million (2019 - $30 million).

At December 31, 2020 the company is contingently liable for up to $62 million, under existing indemnification arrangements, for costs associated with continuing a third-party pipeline project development (2019 - $64 million).

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Common shares

12 Months Ended

Dec. 31, 2020

Common shares

11. Common shares

thousands of shares At December 31	2020		2019
Authorized		1,100,000		1,100,000
Common shares outstanding		734,077		743,902

The current 12-month limited normal course issuer bid program came into effect on June 29, 2020 and is used primarily to eliminate dilution from shares issued in conjunction with Imperial’s restricted stock unit plan. The program enables the company to purchase up to a maximum of 50,000 common shares, which includes shares purchased under the normal course issuer bid and from Exxon Mobil Corporation concurrent with, but outside of the normal course issuer bid. As in the past, Exxon Mobil Corporation has advised the company that it intends to participate to maintain its ownership percentage at approximately 69.6 percent.

The excess of the purchase cost over the stated value of shares purchased has been recorded as a distribution of earnings reinvested.

The company’s common share activities are summarized below:

	Thousands of			Millions of
	shares			dollars
Balance as at January 1, 2018		831,242			1,536
Issued under employee share-based awards		2			-
Purchases at stated value		(48,679	)		(90	)
Balance as at December 31, 2018		782,565			1,446
Issued under employee share-based awards		1			-
Purchases at stated value		(38,664	)		(71	)
Balance as at December 31, 2019		743,902			1,375
Issued under employee share-based awards		7			-
Purchases at stated value		(9,832	)		(18	)
Balance as at December 31, 2020		734,077			1,357

The following table provides the calculation of basic and diluted earnings per common share and the dividends declared by the company on its outstanding common shares:

	2020			2019		2018
Net income (loss) per common share – basic
Net income (loss) (millions of Canadian dollars)		(1,857	)		2,200		2,314
Weighted average number of common shares outstanding (millions of shares)		735.3			762.7		807.5
Net income (loss) per common share (dollars)		(2.53	)		2.88		2.87
Net income (loss) per common share – diluted
Net income (loss) (millions of Canadian dollars)		(1,857	)		2,200		2,314
Weighted average number of common shares outstanding (millions of shares)		735.3			762.7		807.5
Effect of employee share-based awards (millions of shares) (a)		-			2.3		2.6
Weighted average number of common shares outstanding, assuming dilution (millions of shares)		735.3			765.0		810.1
Net income (loss) per common share (dollars)		(2.53	)		2.88		2.86
Dividends per common share – declared (dollars)		0.88			0.85		0.73

a) For 2020, the Net income (loss) per common share – diluted excludes the effect of 1.9 million employee share-based awards. Share-based awards have the potential to dilute basic earnings per share in the future.

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Miscellaneous financial information

12 Months Ended

Dec. 31, 2020

Miscellaneous financial information

12. Miscellaneous financial information

In 2020, net loss included an after-tax loss of $19 million (2019 – $22 million loss, 2018 – $16 million gain) attributable to the effect of changes in last-in, first-out (LIFO) inventories. The replacement cost of inventories was estimated to exceed their LIFO carrying values at December 31, 2020 by about $0.8 billion (2019 – $1.2 billion). Inventories of crude oil and products at year-end consisted of the following:

millions of Canadian dollars	2020		2019
Crude oil		630		764
Petroleum products		403		396
Chemical products		55		64
Other		73		72
Total inventories of crude oil and products		1,161		1,296

Research expenditures are mainly spent on developing technologies to improve bitumen recovery, reduce costs and reduce the environmental impact of upstream operations, including technologies to reduce greenhouse gas emissions intensity, supporting environmental and process improvements in the refineries, as well as accessing ExxonMobil’s research worldwide.

The company has scientific research agreements with affiliates of ExxonMobil, which provide for technical and engineering work to be performed by all parties, the exchange of technical information and the assignment and licencing of patents, and patent rights. These agreements provide mutual access to scientific and operating data related to nearly every phase of the petroleum and petrochemical operations of the parties.

Net research and development costs charged to expenses in 2020 were $105 million (2019 – $133 million, 2018 – $110 million). These costs are included in expenses due to the uncertainty of future benefits.

“Accounts payable and accrued liabilities” included accrued taxes other than income taxes of $344 million at December 31, 2020 (2019 – $397 million).

In the second quarter of 2020, the Government of Canada implemented the Canada Emergency Wage Subsidy (CEWS) as part of its COVID-19 Economic Response Plan. The program’s intent is to help sustain employment levels by providing expense relief to companies during the pandemic. The company qualified for these wage subsidies which are recognized throughout the year when received. The relief provided under this program in 2020, about $155  million before tax, including the company’s proportionate share of a joint venture, is recognized as a reduction to expense and is included in the Consolidated statement of income, primarily as part of “Production and manufacturing”.

In the first quarter of 2020, with the change in economic conditions and the reduction in the company’s market capitalization, the company assessed its goodwill balances for impairment and recognized a non-cash goodwill impairment charge of $20 million in the company’s Upstream segment. The goodwill impairment is reflected in “Depreciation and depletion” on the Consolidated statement of income and “Goodwill” on the Consolidated balance sheet. The remaining balance of goodwill is associated with the Downstream segment.

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Financing and additional notes and loans payable information

12 Months Ended

Dec. 31, 2020

Financing and additional notes and loans payable information

13. Financing and additional notes and loans payable information

millions of Canadian dollars	2020			2019			2018
Debt-related interest (a)		102			138			133
Capitalized interest		(41	)		(48	)		(28	)
Net interest expense		61			90			105
Other interest		3			3			3
Total financing (b)		64			93			108

(a) Includes related party interest with ExxonMobil.

(b) The weighted average interest rate on short-term borrowings in 2020 was 0.8 percent (2019 – 1.8 percent, 2018 – 1.5 percent). Average effective rate on the long-term borrowings with ExxonMobil in 2020 was 1.4 percent (2019 – 2.2 percent, 2018 – 2.0 percent).

As at December 31, 2020, the company had borrowed $111 million under an arrangement with an affiliated company of ExxonMobil that provides for a non-interest bearing, revolving demand loan from ExxonMobil to the company of up to $150 million. The loan represents ExxonMobil’s share of a working capital facility required to support purchasing, marketing and transportation arrangements for crude oil and diluent products undertaken by Imperial on behalf of ExxonMobil.

In response to market conditions, during the second quarter of 2020, the company entered into a $500 million committed short-term line of credit to May 2021, and a $300 million committed short-term line of credit to June 2021. These facilities were in addition to existing credit facilities of $500 million. The company has not drawn on these facilities.

In November 2020, the company extended the maturity date of one of its existing $250 million committed short-term line of credit to November 2021. The company has not drawn on the facility.

The maturity date of the other existing $250 million credit facility remains unchanged at November 2021. The company has not drawn on the facility.

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Leases

12 Months Ended

Dec. 31, 2020

Leases

14. Leases

The company generally purchases the property, plant and equipment used in operations, but there are situations where assets are leased, primarily storage tanks, rail cars, marine vessels and transportation facilities. Right of use assets and lease liabilities are established on the balance sheet for leases with an expected term greater than one year, by discounting the amounts fixed in the lease agreement for the duration of the lease which is reasonably certain, considering the probability of exercising any early termination and extension options. The portion of the fixed payment related to service costs for tankers and finance leases is excluded from the calculation of right of use assets and lease liabilities. Usually, assets are leased only for a portion of their useful lives and are accounted for as operating leases. In limited situations assets are leased for nearly all of their useful lives and are accounted for as finance leases. In general, leases are capitalized using the company’s incremental borrowing rate.

Variable payments under these lease agreements are not significant. Residual value guarantees, restrictions, or covenants related to leases, and transactions with related parties are also not significant. The company’s activities as a lessor are not material.

The table below summarizes the total lease cost incurred:

	2020				2019
millions of Canadian dollars	Operating leases		Finance leases		Operating leases		Finance leases
Operating lease cost		157				151
Short-term and other (net of sublease rental income)		40				76
Amortization of right of use assets				29				55
Interest on lease liabilities				38				40
Total lease cost		197		67		227		95

The following table summarizes the amounts related to operating leases and finance leases recorded on the Consolidated balance sheet, weighted average remaining lease term and weighted average discount rates applied at December 31:

	2020			2019
millions of Canadian dollars		Operating leases	Finance leases		Operating leases	Finance leases
Right of use assets
Included in Other assets, including intangibles, net		188			260
Included in Property, plant and equipment, net			532			546
Total right of use assets		188	532		260	546
Lease liability due within one year
Included in Accounts payable and accrued liabilities		97	-		115	15
Included in Notes and loans payable			16			18
Long-term lease liability
Included in Other long-term obligations		95	-		143	-
Included in Long-term debt			510			514
Total lease liability		192	526		258	547
Weighted average remaining lease term (years)		4	38		4	40
Weighted average discount rate (percent)		2.5	7.3		2.6	7.5

The maturity analysis of the company’s lease liabilities as at December 31 are summarized below:

	2020
millions of Canadian dollars, unless noted	Operating leases			Finance leases
Maturity analysis of lease liabilities
2021		96			53
2022		49			52
2023		16			51
2024		12			50
2025		3			47
2026 and beyond		27			1,040
Total lease payments		203			1,293
Discount to present value		(11	)		(767	)
Total lease liability		192			526

In addition to the operating lease liabilities in the table immediately above, at December 31, 2020, additional undiscounted commitments for leases not yet commenced totalled $27 million (2019 - $6 million).

The table below summarizes the cash paid for amounts included in the measurement of lease liabilities and the right of use assets obtained in exchange for new lease liabilities:

	2020				2019
millions of Canadian dollars	Operating leases		Finance leases		Operating leases		Finance leases
Cash paid for amounts included in the measurement of lease liabilities
Cash flows from operating activities		136		15		147		45
Cash flows from financing activities				20				27
Non-cash right of use assets recorded for lease liabilities
For January 1 adoption of Leases (Topic 842)						298
In exchange for lease liabilities during the year		63				104

Disclosures under the previous lease standard – Leases (Topic 840)

Net rental cost incurred under both cancelable and non-cancelable operating leases was $221 million in 2018.

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Long-term debt

12 Months Ended

Dec. 31, 2020

Long-term debt

15. Long-term debt

millions of Canadian dollars
At December 31	2020	2019
Long-term debt (a)	4,447	4,447
Finance leases (b)	510	514
Total long-term debt	4,957	4,961

(a) Borrowed under an existing agreement with an affiliated company of ExxonMobil that provides for a long-term, variable-rate, Canadian dollar loan from ExxonMobil to the company of up to $7.75 billion at interest equivalent to Canadian market rates. The agreement is effective until June 30, 2025, cancelable if ExxonMobil provides at least 370 days advance written notice.

(b) Finance leases are primarily associated with transportation facilities and services agreements. The average imputed rate was 7.3 percent in 2020 (2019 – 7.5 percent). Total finance lease obligations also include $16 million in current liabilities (2019 - $18 million). Principal payments on finance leases of approximately $15 million on average per year are due in each of the next four years after December 31, 2021.

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Accounting for suspended exploratory well costs

12 Months Ended

Dec. 31, 2020

Accounting for suspended exploratory well costs

16. Accounting for suspended exploratory well costs

The company continues capitalization of exploratory well costs when the well has found a sufficient quantity of reserves to justify its completion as a producing well and the company is making sufficient progress assessing the reserves and the economic and operating viability of the project. The term “project” as used in this report can refer to a variety of different activities and does not necessarily have the same meaning as in any government payment transparency reports. At December 31, 2020 the company had no capitalized suspended exploratory well costs (2019 - $0 million, 2018 - $0 million).

Exploration activity often involves drilling multiple wells, over a number of years, to fully evaluate a project. At December 31, 2020 the company had no projects with exploratory wells costs capitalized (2019 - 0, 2018 - 0).

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Transactions with related parties

12 Months Ended

Dec. 31, 2020

Transactions with related parties

17. Transactions with related parties

Revenues and expenses of the company also include the results of transactions with affiliated companies of ExxonMobil in the normal course of operations. These were conducted on terms comparable to those which would have been conducted with unrelated parties and primarily consisted of the purchase and sale of crude oil, natural gas, petroleum and chemical products, as well as technical, engineering and research and development costs. Transactions with ExxonMobil also included amounts paid and received in connection with the company’s participation in a number of upstream activities conducted jointly in Canada.

In addition, the company has existing agreements with ExxonMobil:

a)  To provide computer and customer support services to the company and to share common business and operational support services that allow the companies to consolidate duplicate work and systems;

b)  To operate certain western Canada production properties owned by ExxonMobil, as well as provide for the delivery of management, business and technical services to ExxonMobil in Canada. These agreements are designed to provide organizational efficiencies and to reduce costs. No separate legal entities were created from these arrangements. Separate books of account continue to be maintained for the company and ExxonMobil. The company and ExxonMobil retain ownership of their respective assets, and there is no impact on operations or reserves;

c)  To provide for the delivery of management, business and technical services to Syncrude Canada Ltd. by ExxonMobil;

d)  To provide for the option of equal participation in new upstream opportunities; and

e)  To enter into derivative agreements on each other’s behalf.

Certain charges from ExxonMobil have been capitalized; they are not material in the aggregate.

The amounts of purchases and sales by Imperial in 2020, with ExxonMobil, were $2,424 million and $5,101 million respectively (2019 - $3,245 million and $8,552 million respectively).

As at December 31, 2020, the company had outstanding long-term loans of $4,447 million (2019 – $4,447 million) and short-term loans of $111 million (2019 – $111 million) from ExxonMobil (see note 15, Long-term debt, on page 104 and note 13, Financing and additional notes and loans payable information, on page 101 for further details). The amount of financing costs with ExxonMobil were $61 million (2019 - $96 million).

Imperial has other related party transactions not detailed above in note 17, as they are not significant.

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Other comprehensive income (loss) information

12 Months Ended

Dec. 31, 2020

Other comprehensive income (loss) information

18. Other comprehensive income (loss) information

Changes in accumulated other comprehensive income (loss):

millions of Canadian dollars	2020			2019			2018
Balance at January 1		(1,911	)		(1,517	)		(1,815	)
Postretirement benefits liability adjustment:
Current period change excluding amounts reclassified from accumulated other comprehensive income		(212	)		(505	)		158
Amounts reclassified from accumulated other comprehensive income		134			111			140
Balance at December 31		(1,989	)		(1,911	)		(1,517	)

Amounts reclassified out of accumulated other comprehensive income (loss) - before-tax income (expense):

millions of Canadian dollars	2020			2019			2018
Amortization of postretirement benefits liability adjustment included in net periodic benefit cost (a)		(180	)		(148	)		(185	)

(a) This accumulated other comprehensive income component is included in the computation of net periodic benefit cost (note 5).

Income tax expense (credit) for components of other comprehensive income (loss):

millions of Canadian dollars	2020			2019			2018
Postretirement benefits liability adjustments:
Postretirement benefits liability adjustment (excluding amortization)		(69	)		(165	)		59
Amortization of postretirement benefits liability adjustment included in net periodic benefit cost		46			37			45
Total		(23	)		(128	)		104

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Summary of significant accounting policies (Policies)

12 Months Ended

Dec. 31, 2020

Principles of consolidation

Principles of consolidation

The consolidated financial statements include the accounts of subsidiaries the company controls. Intercompany accounts and transactions are eliminated. Subsidiaries include those companies in which Imperial has both an equity interest and the continuing ability to unilaterally determine strategic, operating, investing and financing policies. Imperial Oil Resources Limited is the only significant subsidiary included in the consolidated financial statements and is wholly owned by Imperial Oil Limited. The consolidated financial statements also include the company’s share of the undivided interest in certain upstream assets, liabilities, revenues and expenses, including its 70.96 percent interest in the Kearl joint venture and its 25 percent interest in the Syncrude joint venture.

Revenues

Revenues

Imperial generally sells crude oil, natural gas and petroleum and chemical products under short-term agreements at prevailing market prices. In some cases, products may be sold under long-term agreements, with periodic price adjustments to reflect market conditions.

Revenue is recognized at the amount the company expects to receive when the customer has taken control, which is typically when title transfers and the customer has assumed the risks and rewards of ownership. The prices of certain sales are based on price indices that are sometimes not available until the next period. In such cases, estimated realizations are accrued when the sale is recognized, and are finalized when final information is available. Such adjustments to revenue from performance obligations satisfied in previous periods are not significant. Payment for revenue transactions is typically due within 30 days.

Revenues include amounts billed to customers for shipping and handling. Shipping and handling costs incurred up to the point of final storage prior to delivery to a customer are included in “Purchases of crude oil and products” in the Consolidated statement of income. Delivery costs from final storage to customer are recorded as a marketing expense in “Selling and general” expenses. The company does not enter into ongoing arrangements whereby it is required to repurchase its products, nor does the company provide the customer with a right of return.

Future volume delivery obligations that are unsatisfied at the end of the period are expected to be fulfilled through ordinary production or purchases. These performance obligations are based on market prices at the time of the transaction and are fully constrained due to market price volatility.

Purchases and sales of inventory with the same counterparty that are entered into in contemplation of one another are combined and recorded as exchanges measured at the book value of the item sold.

“Revenues” and “Accounts receivable - net” primarily arise from contracts with customers. Long-term receivables are primarily from non-customers. Contract assets are mainly from marketing assistance programs and are not significant. Contract liabilities are mainly customer prepayments, loyalty programs and accruals of expected volume discounts, and are not significant.

Consumer taxes

Consumer taxes

Taxes levied on the consumer and collected by the company are excluded from the Consolidated statement of income. These are primarily provincial taxes on motor fuels, the federal goods and services tax and the federal/provincial harmonized sales tax.

Derivative instruments

Derivative instruments

Imperial may use derivative instruments for trading purposes and to offset exposures associated with commodity prices, currency exchange rates and interest rates that arise from existing assets, liabilities, firm commitments and forecasted transactions. All derivative instruments, except those designated as normal purchase and normal sale, are recorded at fair value. Derivative assets and liabilities with the same counterparty are netted if the right of offset exists and certain other criteria are met. Collateral payables or receivables are netted against derivative assets and derivative liabilities respectively.

Recognition and classification of the gain or loss that results from adjusting a derivative to fair value depends on the purpose for the derivative. The gains and losses resulting from changes in the fair value of derivatives are recorded under “Revenues” or “Purchases of crude oil and products” in the Consolidated statement of income.

Fair value

Fair value

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. Hierarchy Levels 1, 2 and 3 are terms for the priority of inputs to valuation techniques used to measure fair value. Hierarchy Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Hierarchy Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Hierarchy Level 3 inputs are inputs that are not observable in the market.

Inventories

Inventories

Inventories are recorded at the lower of current market value or cost. The cost of crude oil and products is determined primarily using the last-in, first-out (LIFO) method. LIFO was selected over the alternative first-in, first-out and average cost methods because it provides a better matching of current costs with the revenues generated in the period.

Inventory costs include expenditures and other charges (including depreciation), directly or indirectly incurred in bringing the inventory to its existing condition and location. Selling and general expenses are reported as period costs and excluded from inventory costs. Inventories of materials and supplies are valued at cost or less.

Investments

Investments

The company’s interests in the underlying net assets of affiliates it does not control, but over which it exercises significant influence, are accounted for using the equity method. They are recorded at the original cost of the investment plus Imperial’s share of earnings since the investment was made, less dividends received. Imperial’s share of the after-tax earnings of these investments is included in “Investment and other income” in the Consolidated statement of income. Investments in equity securities, other than consolidated subsidiaries and equity method investments, are measured at fair value, with changes in the fair value recognized in net income. The company uses a modified approach for equity securities that do not have a readily determinable fair value. This modified approach measures investments at cost minus impairment, if any, plus or minus changes resulting from observable price changes in orderly transactions in similar investment of the same issuer. Dividends from these investments are included in “Investment and other income”.

These investments represent interests in non-publicly traded pipeline companies and a rail loading joint venture that facilitate the sale and purchase of liquids in the conduct of company operations. Other parties who also have an equity interest in these investments share in the risks and rewards according to their percentage of ownership. Imperial does not invest in these investments in order to remove liabilities from its balance sheet.

Property, plant and equipment

Property, plant and equipment

Cost basis

Imperial uses the “successful efforts” method to account for its exploration and production activities. Under this method, costs are accumulated on a field-by-field basis. Costs incurred to purchase, lease, or otherwise acquire a property (whether unproved or proved) are capitalized when incurred. Exploratory well costs are carried as an asset when the well has found a sufficient quantity of reserves to justify its completion as a producing well and where the company is making sufficient progress assessing the reserves and the economic and operating viability of the project. Exploratory well costs not meeting these criteria are charged to expense. Other exploratory expenditures, including geophysical costs and annual lease rentals, are expensed as incurred. Development costs, including costs of productive wells and development dry holes, are capitalized.

Maintenance and repair costs, including planned major maintenance, are expensed as incurred. Improvements that increase or prolong the service life or capacity of an asset are capitalized.

Depreciation, depletion and amortization

Depreciation, depletion and amortization are primarily determined under either the unit-of-production method or the straight-line method, which is based on estimated asset service life taking obsolescence into consideration. Depreciation and depletion for assets associated with producing properties begin at the time when production commences on a regular basis. Depreciation for other assets begins when the asset is in place and ready for its intended use. Assets under construction are not depreciated or depleted.

Acquisition costs of proved properties are amortized using a unit-of-production method, computed on the basis of total proved oil and natural gas reserve volumes. Capitalized exploratory drilling and development costs associated with productive depletable extractive properties are amortized using the unit-of-production rates based on the amount of proved developed reserves of oil and gas that are estimated to be recoverable from existing facilities using current operating methods. Under the unit-of-production method, oil and natural gas volumes are considered produced once they have been measured through meters at custody transfer or sales transaction points at the outlet valve on the lease or field storage tank. In the event that the unit-of-production method does not result in an equitable allocation of cost over the economic life of an upstream asset, an alternative method is used. The straight-line method is used in limited situations where the expected life of the asset does not reasonably correlate with that of the underlying reserves. For example, certain assets used in the production of oil and natural gas have a shorter life than the reserves, and as such, the company uses straight-line depreciation to ensure the asset is fully depreciated by the end of its useful life. Investments in mining heavy equipment and certain ore processing plant assets at oil sands mining properties are depreciated on a straight-line basis over a maximum of 15 years and 50 years respectively. Depreciation of other plant and equipment is calculated using the straight-line method, based on the estimated service life of the asset.

To the extent that proved reserves for a property are substantially de-booked and that property continues to produce such that the resulting depreciation charge does not result in an equitable allocation of cost over the expected life, assets will be depreciated using a unit-of-production method based on reserves determined at the most recent SEC price which results in a more meaningful quantity of proved reserves, appropriately adjusted for production and technical changes. This approach was applied in 2017 and 2018, with the corresponding effect on depreciation expense being immaterial when compared to prior periods. This approach will also be applied in 2021 and the effect of this approach is anticipated to be immaterial compared to 2020. For 2019 and 2020, all properties had sufficient reserves at their relevant SEC prices which enabled equitable allocation of cost over the economic lives of the Upstream assets.

Investments in refinery and chemical process manufacturing equipment are generally depreciated on a straight-line basis over a 25-year life. Maintenance and repairs, including planned major maintenance, are expensed as incurred. Major renewals and improvements are capitalized and the assets replaced are retired.

Impairment assessment

The company tests assets or groups of assets for recoverability on an ongoing basis whenever events or changes in circumstances indicate the carrying amounts may not be recoverable. Among the events or changes in circumstances which could indicate that the carrying value of an asset or asset group may not be recoverable are the following:

● A significant decrease in the market price of a long-lived asset;

● A significant adverse change in the extent or manner in which an asset is being used or in its physical condition including a significant decrease in the company’s current and projected reserve volumes;

● A significant adverse change in legal factors or in the business climate that could affect the value, including a significant adverse action or assessment by a regulator;

● An accumulation of project costs significantly in excess of the amount originally expected;

● A current-period operating loss combined with a history and forecast of operating or cash flow losses; and

● A current expectation that, more likely than not, a long-lived asset will be sold or otherwise disposed of significantly before the end of its previously estimated useful life.

Asset valuation analysis, profitability reviews and other periodic control processes assist Imperial in assessing whether events or changes in circumstances indicate the carrying amounts of any of its assets may not be recoverable.

In general, Imperial does not view temporarily low prices or margins as an indication of impairment. Management believes prices over the long term must be sufficient to generate investments in energy supply to meet global demand. Although prices will occasionally drop significantly, industry prices over the long term will continue to be driven by market supply and demand fundamentals. On the supply side, industry production from mature fields is declining. This is being offset by investments to generate production from new discoveries, field developments and technological and efficiency advancements. OPEC investment activities and production policies also have an impact on world oil supplies. The demand side is largely a function of general economic activities and levels of prosperity. Because the lifespans of the company’s major assets are measured in decades, the value of these assets is predominantly based on long-term views of future commodity prices and development and production costs. During the lifespan of these major assets, the company expects that oil and gas prices will experience significant volatility, and consequently these assets will experience periods of higher earnings and periods of lower earnings, or even losses. In assessing whether events or changes in circumstances indicate the carrying value of an asset may not be recoverable, the company considers recent periods of operating losses in the context of its longer-term view of prices. While near-term prices are subject to wide fluctuations, longer-term price views are more stable and meaningful for purposes of assessing future cash flows.

When the industry experiences a prolonged and deep reduction in commodity prices, the market supply and demand conditions may result in changes to the company’s price or margin assumptions it uses for its capital investment decisions. To the extent those changes result in a significant reduction to its oil prices or natural gas prices or margin ranges, the company may consider that situation, in conjunction with other events or changes in circumstances such as a history of operating losses, as an indicator of potential impairment for certain assets.

In the upstream, the standardized measure of discounted cash flows included in the “Supplemental information on oil and gas exploration and production activities” is required to use prices based on the yearly average of first-day-of-the-month prices. These prices represent discrete points in time and could be higher or lower than the company’s price assumptions which are used for impairment assessments. The company believes the standardized measure does not provide a reliable estimate of the expected future cash flows to be obtained from the development and production of its oil and gas properties or of the value of its oil and gas reserves and therefore does not consider it relevant in determining whether events or changes in circumstances indicate the need for an impairment assessment.

The company has a robust process to monitor for indicators of potential impairment across its asset groups throughout the year. This process is aligned with the requirements of ASC 360 and ASC 932, and relies on the company’s planning and budgeting cycle. If events or changes in circumstances indicate that the carrying value of an asset may not be recoverable, the company estimates the future undiscounted cash flows of the affected properties to judge the recoverability of carrying amounts. In performing this assessment, assets are grouped at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets. Cash flows used in recoverability assessments are based on the company’s assumptions which are developed in the annual planning and budgeting process, and are consistent with the criteria management uses to evaluate investment opportunities. These evaluations make use of the company’s assumptions of future capital allocations, crude oil and natural gas commodity prices, including price differentials, refining and chemical margins, volumes, development and operating costs, foreign currency exchange rates and inflation rates. Volumes are based on projected field and facility production profiles, throughput, or sales. Management’s estimate of upstream production volumes used for projected cash flows makes use of proved reserve quantities and may include risk-adjusted unproved reserve quantities. Cash flow estimates for impairment testing exclude the effects of derivative instruments.

An asset group is impaired if its estimated future undiscounted cash flows are less than the asset group’s carrying value. Impairments are measured by the amount by which the carrying value exceeds fair value. The assessment of fair value may be based on market prices if an active market exists for the asset group or may require the use of Level 3 inputs and assumptions that are based upon the views of a likely market participant. The principal parameters used to establish fair value can include estimates of acreage values and flowing production metrics from comparable market transactions, market-based estimates of historical cash flow multiples, and discounted cash flows. Inputs and assumptions used in discounted cash flow models include estimates of future production volumes, commodity prices which are consistent with the average of third-party industry experts and government agencies, drilling and development costs, and discount rates.

Significant unproved properties are assessed for impairment individually, and valuation allowances against the capitalized costs would be recorded based on the company’s future development plans, the estimated economic chance of success and the length of time that the company expects to hold the properties. Properties that are not individually significant are aggregated by groups and amortized based on development risk and average holding period.

Gains on sales of proved and unproved properties are only recognized when there is neither uncertainty about the recovery of costs applicable to any interest retained nor any substantial obligation for future performance by the company. Losses on properties sold are recognized when incurred or when the properties are held for sale and the fair value of the properties is less than the carrying value.

Gains or losses on assets sold are included in “Investment and other income” in the Consolidated statement of income.

Interest capitalization

Interest capitalization

Interest costs incurred to finance expenditures during the construction phase of projects are capitalized as part of property, plant and equipment and are depreciated over the service life of the related assets. The project construction phase commences with the development of the detailed engineering design and ends when the constructed assets are ready for their intended use.

Leases

Leases

In situations where assets are leased, right of use assets and lease liabilities are established on the balance sheet for leases with an expected term greater than one year, by discounting the amounts fixed in the lease agreement for the duration of the lease which is reasonably certain, considering the probability of exercising any early termination and extension options. The portion of the fixed payment related to service costs for tankers and finance leases is excluded from the calculation of right of use assets and lease liabilities. Assets leased for nearly all of their useful lives are accounted for as finance leases. In general, leases are capitalized using the company’s incremental borrowing rate. See note 14 to the consolidated financial statements on page 102 for further details.

Goodwill and other intangible assets

Goodwill and other intangible assets

Goodwill is not subject to amortization. Goodwill is tested for impairment annually or more frequently if events or circumstances indicate it might be impaired. Impairment losses are recognized in current period earnings. The evaluation for impairment of goodwill is based on a comparison of the carrying values of goodwill and associated operating assets with the estimated present value of net cash flows from those operating assets.

Intangible assets with determinable useful lives are amortized over the estimated service lives of the assets. Computer software development costs are amortized over a maximum of 15 years and customer lists are amortized over a maximum of 10 years. The amortization is included in “Depreciation and depletion” in the Consolidated statement of income.

Asset retirement obligations and other environmental liabilities

Asset retirement obligations and other environmental liabilities

Legal obligations associated with site restoration on the retirement of assets with determinable useful lives are recognized when they are incurred, which is typically at the time the assets are installed. These obligations primarily relate to soil reclamation and remediation, and costs of abandonment and demolition of oil and gas wells and related facilities. The company uses estimates, assumptions and judgments regarding such factors as the existence of a legal obligation for an asset retirement obligation, technical assessments of the assets, estimated amounts and timing of settlements, the credit-adjusted risk-free rate to be used, and inflation rates. The obligations are initially measured at fair value and discounted to present value. A corresponding amount equal to that of the initial obligation is added to the capitalized costs of the related asset. Over time, the discounted asset retirement obligation amount will be accreted for the change in its present value, and the initial capitalized costs will be depreciated over the useful lives of the related assets.

No asset retirement obligations are set up for those manufacturing, distribution, marketing and office facilities with an indeterminate useful life. Asset retirement obligations for these facilities generally become firm at the time the facilities are permanently shut down and dismantled. These obligations may include the costs of asset disposal and additional soil remediation. However, these sites have indeterminate lives based on plans for continued operations, and as such, the fair value of the conditional legal obligations cannot be measured, since it is impossible to estimate the future settlement dates of such obligations. Provision for environmental liabilities of these assets is made when it is probable that obligations have been incurred and the amount can be reasonably estimated. Provisions for environmental liabilities are determined based on engineering estimated costs, taking into account the anticipated method and extent of remediation consistent with legal requirements, current technology and the possible use of the location. These provisions are not reduced by possible recoveries from third parties and projected cash expenditures are not discounted.

Foreign-currency translation

Foreign-currency translation

Monetary assets and liabilities in foreign currencies have been translated at the rates of exchange prevailing on December 31. Any exchange gains or losses are recognized in income.

Share-based compensation

Share-based compensation

The company awards share-based compensation to certain employees in the form of restricted stock units. Compensation expense is measured each reporting period based on the company’s current stock price and is recorded as “Selling and general” expenses in the Consolidated statement of income over the requisite service period of each award. See note 8 to the consolidated financial statements on page 97 for further details.

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Business segments (Tables)

12 Months Ended

Dec. 31, 2020

Business Segments

	Upstream									Downstream									Chemical
millions of Canadian dollars	2020			2019			2018			2020			2019			2018			2020			2019			2018
Revenues and other income
Revenues (a)		6,263			9,479			8,525			15,178			23,591			25,200			843			932			1,239
Intersegment sales		2,527			3,763			2,634			1,480			1,597			1,542			165			229			279
Investment and other income (note 9)		7			17			11			78			47			95			-			-			-
		8,797			13,259			11,170			16,736			25,235			26,837			1,008			1,161			1,518
Expenses
Exploration (note 16)		13			47			19			-			-			-			-			-			-
Purchases of crude oil and products		4,834			6,528			5,833			12,047			19,332			19,326			579			667			831
Production and manufacturing (note 12)		3,852			4,440			4,305			1,468			1,829			1,606			215			251			210
Selling and general		-			-			-			619			774			773			92			86			87
Federal excise tax and fuel charge		-			-			-			1,736			1,808			1,667			-			-			-
Depreciation and depletion (b) (note 12)		3,084			1,374			1,278			166			186			242			19			16			14
Non-service pension and postretirement benefit		-			-			-			-			-			-			-			-			-
Financing (note 13)		3			3			1			-			-			2			-			-			-
Total expenses		11,786			12,392			11,436			16,036			23,929			23,616			905			1,020			1,142
Income (loss) before income taxes		(2,989	)		867			(266	)		700			1,306			3,221			103			141			376
Income tax expense (benefit) (c) (note 4)		(671	)		(481	)		(128	)		147			345			855			25			33			101
Net income (loss)		(2,318	)		1,348			(138	)		553			961			2,366			78			108			275
Cash flows from (used in) operating activities		286			2,423			916			470			1,965			2,749			114			172			354
Capital and exploration expenditures (d)		561			1,248			991			251			484			383			21			34			25
Property, plant and equipment
Cost		47,693			47,050			46,435			6,321			6,123			5,900			975			954			916
Accumulated depreciation and depletion		(18,786	)		(15,889	)		(15,050	)		(3,962	)		(3,830	)		(3,763	)		(699	)		(680	)		(662	)
Net property, plant and equipment (e)		28,907			31,161			31,385			2,359			2,293			2,137			276			274			254
Total assets (f) (g)		31,835			34,554			34,829			4,554			5,179			5,119			408			416			438

	Corporate and other									Eliminations									Consolidated
millions of Canadian dollars	2020			2019			2018			2020			2019			2018			2020			2019			2018
Revenues and other income
Revenues (a)		-			-			-			-			-			-			22,284			34,002			34,964
Intersegment sales		-			-			-			(4,172	)		(5,589	)		(4,455	)		-			-			-
Investment and other income (note 9)		19			35			29			-			-			-			104			99			135
		19			35			29			(4,172	)		(5,589	)		(4,455	)		22,388			34,101			35,099
Expenses
Exploration (note 16)		-			-			-			-			-			-			13			47			19
Purchases of crude oil and products		-			-			-			(4,167	)		(5,581	)		(4,449	)		13,293			20,946			21,541
Production and manufacturing (note 12)		-			-			-			-			-			-			5,535			6,520			6,121
Selling and general		35			48			54			(5	)		(8	)		(6	)		741			900			908
Federal excise tax and fuel charge		-			-			-			-			-			-			1,736			1,808			1,667
Depreciation and depletion (b) (note 12)		24			22			21			-			-			-			3,293			1,598			1,555
Non-service pension and postretirement benefit		121			143			107			-			-			-			121			143			107
Financing (note 13)		61			90			105			-			-			-			64			93			108
Total expenses		241			303			287			(4,172	)		(5,589	)		(4,455	)		24,796			32,055			32,026
Income (loss) before income taxes		(222	)		(268	)		(258	)		-			-			-			(2,408	)		2,046			3,073
Income tax expense (benefit) (c) (note 4)		(52	)		(51	)		(69	)		-			-			-			(551	)		(154	)		759
Net income (loss)		(170	)		(217	)		(189	)		-			-			-			(1,857	)		2,200			2,314
Cash flows from (used in) operating activities		(64	)		(124	)		(116	)		(8	)		(7	)		19			798			4,429			3,922
Capital and exploration expenditures (d)		41			48			28			-			-			-			874			1,814			1,427
Property, plant and equipment
Cost		782			741			693			-			-			-			55,771			54,868			53,944
Accumulated depreciation and depletion		(290	)		(266	)		(244	)		-			-			-			(23,737	)		(20,665	)		(19,719	)
Net property, plant and equipment (e)		492			475			449			-			-			-			32,034			34,203			34,225
Total assets (f) (g)		1,632			2,536			1,548			(398	)		(498	)		(478	)		38,031			42,187			41,456

(a) Includes export sales to the United States of $4,614 million (2019 - $7,190 million, 2018 - $6,661 million). Export sales to the United States were recorded in all operating segments, with the largest effects in the Upstream segment.

(b) In 2020, the Upstream segment included a non-cash impairment charge of $1,531 million, before-tax, related to the company’s decision not to further develop a significant portion of its unconventional portfolio. In 2018, the Downstream segment included a non-cash impairment charge of $46 million, before-tax, associated with the Government of Ontario’s revocation of its cap and trade legislation.

(c) Segment results in 2019 include a largely non-cash favourable impact of $662 million associated with the Alberta corporate income tax rate decrease, with the largest impact in the Upstream segment.

(d) Capital and exploration expenditures (CAPEX) include exploration expenses, additions to property, plant and equipment, additions to finance leases, additional investments and acquisitions. CAPEX excludes the purchase of carbon emission credits.

(e) Includes property, plant and equipment under construction of $1,874 million (2019 - $2,149 million, 2018 - $1,553 million).

(f) Effective January 1, 2019, Imperial adopted the Financial Accounting Standards Board’s standard, Leases (Topic 842), as amended. As at December 31, 2020, Total assets include operating lease right of use assets of $188 million (2019 - $260 million). An election was made not to restate prior periods. See note 14 for additional details.

(g) In 2019, the company removed $570 million from Total assets and corresponding liabilities in the Downstream segment associated with the Government of Ontario’s revocation of its cap and trade legislation.

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Income taxes (Tables)

12 Months Ended

Dec. 31, 2020

Summary of Income Tax Expense (Benefit)

millions of Canadian dollars	2020		2019		2018
Current income tax expense (benefit) (a)	(27	)	140		(14	)
Deferred income tax expense (benefit) (a)	(524	)	(294	)	773
Total income tax expense (benefit) (a)	(551	)	(154	)	759
Statutory corporate tax rate (percent)	25.0		26.0		26.9
Increase (decrease) resulting from:
Enacted tax rate change (a)	0.1		(31.9	)	-
Other (b)	(2.2	)	(1.6	)	(2.2	)
Effective income tax rate	22.9		(7.5	)	24.7

(a) On June 28, 2019 the Alberta government enacted a 4 percent decrease in the provincial tax rate, from 12 percent to 8 percent by 2022. On December 9, 2020 the Alberta government enacted an accelerated decrease in the province’s general corporate income tax rate from 10 percent to 8 percent, effective July 1, 2020. The cumulative effect of the 2020 legislative tax changes on the company’s financial statements were immaterial.

(b) Other decreases primarily relate to prior year adjustments, re-assessments and disposals.

Components of Deferred Income Tax Liabilities and Assets

Components of deferred income tax liabilities and assets as at December 31 were:

millions of Canadian dollars	2020		2019		2018
Depreciation and amortization	5,319		5,164		5,726
Successful drilling and land acquisitions	363		750		856
Pension and benefits	(534	)	(469	)	(336	)
Asset retirement obligation	(403	)	(336	)	(381	)
Capitalized interest	120		117		121
LIFO inventory valuation	(150	)	(276	)	(107	)
Tax loss carryforwards	(460	)	(141	)	(658	)
Other	(154	)	(161	)	(150	)
Net deferred income tax liabilities	4,101		4,648		5,071

Unrecognized Tax Benefits

The following table summarizes the movement in unrecognized tax benefits:

millions of Canadian dollars	2020		2019		2018
Balance as of January 1	35		36		78
Additions based on current year’s tax position	2		-		-
Additions for prior years’ tax positions	-		1		9
Reductions for prior years’ tax positions	-		-		(2	)
Settlements with tax authorities	(1	)	(2	)	(49	)
Balance as of December 31	36		35		36

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Employee retirement benefits (Tables)

12 Months Ended

Dec. 31, 2020

Assumptions Used to Determine Benefit Obligations

The benefit obligations and plan assets associated with the company’s defined benefit plans are measured on December 31.

	Pension benefits			Other postretirement benefits
		2020	2019		2020	2019
Assumptions used to determine benefit obligations at December 31 (percent)
Discount rate		2.50	3.10		2.50	3.10
Long-term rate of compensation increase		4.00	4.50		4.00	4.50

millions of Canadian dollars
Change in projected benefit obligation
Projected benefit obligation at January 1	9,786		8,359		693		582
Current service cost	305		228		24		16
Interest cost	308		324		24		20
Actuarial loss (gain) (a)	811		1,053		152		99
Amendments	-		283		-		-
Benefits paid (b)	(494	)	(461	)	(20	)	(24	)
Projected benefit obligation at December 31	10,716		9,786		873		693
Accumulated benefit obligation at December 31	9,619		8,814

(a) Actuarial loss primarily driven by a decrease in the year-end discount rate from 3.10 percent to 2.50 percent, partially offset by the impact of a reduction in the long-term rate of compensation increase assumption from 4.50 percent to 4.00 percent.

(b) Benefit payments for funded and unfunded plans.

Change in Plan Assets of Pension and Other Postretirement Benefits

	Pension benefits					Other postretirement benefits
millions of Canadian dollars		2020		2019			2020		2019
Change in plan assets
Fair value at January 1		8,599		7,691
Actual return (loss) on plan assets		1,073		1,114
Company contributions		195		211
Benefits paid (a)		(441	)	(417	)
Fair value at December 31		9,426		8,599
Plan assets in excess of (less than) projected benefit obligation at December 31
Funded plans		(641	)	(590	)
Unfunded plans		(649	)	(597	)		(873	)	(693	)
Total (b)		(1,290	)	(1,187	)		(873	)	(693	)

(a) Benefit payments for funded plans only.

(b) Fair value of assets less projected benefit obligation shown above.

Amounts Recorded in Consolidated Balance Sheet and Accumulated Other Comprehensive Income

	Pension benefits					Other postretirement              benefits
millions of Canadian dollars		2020		2019			2020		2019
Amounts recorded in the Consolidated balance sheet consist of:
Current liabilities		(27	)	(27	)		(31	)	(31	)
Other long-term obligations		(1,263	)	(1,160	)		(842	)	(662	)
Total recorded		(1,290	)	(1,187	)		(873	)	(693	)
Amounts recorded in accumulated other comprehensive income consist of:
Net actuarial loss (gain)		2,232		2,256			272		133
Prior service cost		269		283			-		-
Total recorded in accumulated other comprehensive income, before-tax		2,501		2,539			272		133

Assumptions Used to Determine Periodic Benefit Cost

	Pension benefits									Other postretirement          benefits
	2020			2019			2018			2020			2019			2018
Assumptions used to determine net periodic benefit cost for years ended December 31 (percent)
Discount rate		3.10			3.90			3.40			3.10			3.90			3.40
Long-term rate of return on funded assets		4.50			4.50			5.00			-			-			-
Long-term rate of compensation increase		4.50			4.50			4.50			4.50			4.50			4.50
millions of Canadian dollars
Components of net periodic benefit cost
Current service cost		305			228			239			24			16			17
Interest cost		308			324			302			24			20			22
Expected return on plan assets		(391	)		(349	)		(402	)		-			-			-
Amortization of prior service cost		14			-			4			-			-			-
Amortization of actuarial loss (gain)		153			149			175			13			(1	)		6
Net periodic benefit cost		389			352			318			61			35			45
Changes in amounts recorded in accumulated other comprehensive income
Net actuarial loss (gain)		129			288			(116	)		152			99			(101	)
Amortization of net actuarial (loss) gain included in net periodic benefit cost		(153	)		(149	)		(175	)		(13	)		1			(6	)
Prior service cost		-			283			-			-			-			-
Amortization of prior service cost included in net periodic benefit cost		(14	)		-			(4	)		-			-			-
Total recorded in other comprehensive income		(38	)		422			(295	)		139			100			(107	)
Total recorded in net periodic benefit cost and other comprehensive income, before-tax		351			774			23			200			135			(62	)

Summary of Change in Accumulated Other Comprehensive Income

A summary of the change in accumulated other comprehensive income is shown in the table below:

	Total pension and other postretirement benefits
millions of Canadian dollars	2020			2019			2018
(Charge) credit to other comprehensive income, before-tax		(101	)		(522	)		402
Deferred income tax (charge) credit (note 18)		23			128			(104	)
(Charge) credit to other comprehensive income, after-tax		(78	)		(394	)		298

Fair Value of Pension Plan Assets Including Level within Fair Value Hierarchy

The 2020 fair value of the pension plan assets, including the level within the fair value hierarchy, is shown in the table below:

			Fair value measurements at December 31, 2020, using:
millions of Canadian dollars	Total		Level 1		Level 2	Level 3	Net Asset Value
Asset class
Equity securities
Canadian		222						222
Non-Canadian		2,690						2,690
Debt securities - Canadian
Corporate		1,426						1,426
Government		4,825						4,825
Asset backed		-						-
Equities – Venture capital		214						214
Cash		49		41				8
Total plan assets at fair value		9,426		41				9,385

The 2019 fair value of the pension plan assets, including the level within the fair value hierarchy, is shown in the table below:

			Fair value measurements at December 31, 2019, using:
millions of Canadian dollars	Total		Level 1		Level 2	Level 3	Net Asset Value
Asset class
Equity securities
Canadian		210						210
Non-Canadian		2,449						2,449
Debt securities - Canadian
Corporate		1,379						1,379
Government		4,299						4,299
Asset backed		1						1
Equities – Venture capital		204						204
Cash		57		40				17
Total plan assets at fair value		8,599		40				8,559

Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets

A summary of pension plans with accumulated benefit obligation and projected benefit obligation in excess of plan assets is shown in the table below:

	Pension benefits
millions of Canadian dollars	2020		2019
For funded pension plans with accumulated benefit obligation in excess of plan assets: (a)
Accumulated benefit obligation		1,034		942
Fair value of plan assets		954		870
Accumulated benefit obligation less fair value of plan assets		80		72
For funded pension plans with projected benefit obligation in excess of plan assets:
Projected benefit obligation		10,067		9,189
Fair value of plan assets		9,426		8,599
Projected benefit obligation less fair value of plan assets		641		590
For unfunded plans covered by book reserves:
Projected benefit obligation		649		597
Accumulated benefit obligation		565		536

(a) The amounts shown for funded pension plans with accumulated benefit obligation in excess of plan assets represent the company’s proportionate share of a joint venture sponsored pension plan. For the company sponsored funded plan, the fair value of plan assets exceeded the accumulated benefit obligation in both 2020 and 2019.

Benefit Payments Expected

Benefit payments expected in:

millions of Canadian dollars	Pension benefits		Other postretirement benefits
2021		460		31
2022		460		32
2023		465		32
2024		465		33
2025		465		34
2026 - 2030		2,325		175

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Other long-term obligations (Tables)

12 Months Ended

Dec. 31, 2020

Other Long-Term Obligations

millions of Canadian dollars	2020		2019
Employee retirement benefits (a) (note 5)		2,105		1,822
Asset retirement obligations and other environmental liabilities (b) (c)		1,676		1,388
Share-based incentive compensation liabilities (note 8)		45		65
Operating lease liability (note 14)		95		143
Other obligations		179		219
Total other long-term obligations		4,100		3,637

(a) Total recorded employee retirement benefits obligations also included $58 million in current liabilities (2019 – $58 million).

(b) Total asset retirement obligations and other environmental liabilities also included $100 million in current liabilities (2019 – $124 million).

(c) For 2020, the asset retirement obligations were discounted at 6 percent (2019 - 6 percent).

Schedule of Asset Retirement Obligations

Asset retirement obligations incurred in the current period were Level 3 fair value measurements. The following table summarizes the activity in the liability for asset retirement obligations:

millions of Canadian dollars	2020			2019			2018
Balance as at January 1		1,400			1,417			1,397
Additions (deductions)		265			(23	)		(5	)
Accretion		82			80			85
Settlement		(73	)		(74	)		(60	)
Balance as at December 31		1,674			1,400			1,417

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Financial and derivative instruments (Tables)

12 Months Ended

Dec. 31, 2020

Schedule of Net Long Short Position Of Derivative Instruments

The net notional long/(short) position of derivative instruments was:

At December 31	2020			2019
Crude (barrels)		(800,000	)		(590,000	)
Products (barrels)		(390,000	)		-

Summary of Realized and Unrealized Gain or (Loss) on Derivative Instruments

Realized and unrealized gain or (loss) on derivative instruments recognized in the Consolidated statement of income is included in the following lines on a before-tax basis:

millions of Canadian dollars	2020			2019			2018
Revenues		(13	)		(3	)		6
Purchases of crude oil and products		(21	)		(7	)		(24	)
Total		(34	)		(10	)		(18	)

Summary of estimated fair value of financial instruments

The estimated fair value of derivative instruments, and the related hierarchy level for the fair value measurement is as follows:

millions of Canadian dollars At December 31, 2020
	Fair value								Effect of counterparty netting			Effect of collateral netting			Net carrying value
	Level 1		Level 2		Level 3		Total
Assets
Derivative assets (a)		2		-		-		2		(2	)		-			-
Liabilities
Derivative liabilities (b)		12		-		-		12		(2	)		(10	)		-

(a) Included in the Consolidated balance sheet line: “Materials, supplies and prepaid expenses”.

(b) Included in the Consolidated balance sheet line: “Accounts payable and accrued liabilities”.

millions of Canadian dollars At December 31, 2019
	Fair value								Effect of		Effect of		Net
									counterparty		collateral		carrying
	Level 1		Level 2		Level 3		Total		netting		netting		value
Assets
Derivative assets (a)		-		-		-		-		-		-		-
Liabilities
Derivative liabilities (b)		2		-		-		2		-		(2)		-

(a) Included in the Consolidated balance sheet line: “Materials, supplies and prepaid expenses”.

(b) Included in the Consolidated balance sheet line: “Accounts payable and accrued liabilities”.

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Share-based incentive compensation programs (Tables)

12 Months Ended

Dec. 31, 2020

Summarized Information about Incentive Share, Deferred Share and Restricted Stock Units

The following table summarizes information about these units for the year ended December 31, 2020:

	Restricted			Deferred
	stock units			share units
Outstanding at January 1, 2020		4,912,805			170,163
Granted		747,040			34,811
Vested / Exercised		(1,187,630	)		(57,569	)
Forfeited and cancelled		(8,895	)		-
Outstanding at December 31, 2020		4,463,320			147,405

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Investment and other income (Tables)

12 Months Ended

Dec. 31, 2020

Gains and Losses on Asset Sales

Investment and other income includes gains and losses on asset sales as follows:

millions of Canadian dollars	2020		2019		2018
Proceeds from asset sales		82		82		59
Book value of asset sales		47		36		5
Gain (loss) on asset sales, before-tax		35		46		54
Gain (loss) on asset sales, after-tax		32		42		38

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Common shares (Tables)

12 Months Ended

Dec. 31, 2020

Summary of Common Shares

thousands of shares At December 31	2020		2019
Authorized		1,100,000		1,100,000
Common shares outstanding		734,077		743,902

Common Share Activities

The company’s common share activities are summarized below:

	Thousands of			Millions of
	shares			dollars
Balance as at January 1, 2018		831,242			1,536
Issued under employee share-based awards		2			-
Purchases at stated value		(48,679	)		(90	)
Balance as at December 31, 2018		782,565			1,446
Issued under employee share-based awards		1			-
Purchases at stated value		(38,664	)		(71	)
Balance as at December 31, 2019		743,902			1,375
Issued under employee share-based awards		7			-
Purchases at stated value		(9,832	)		(18	)
Balance as at December 31, 2020		734,077			1,357

Calculation of Basic and Diluted Earnings Per Share

The following table provides the calculation of basic and diluted earnings per common share and the dividends declared by the company on its outstanding common shares:

	2020			2019		2018
Net income (loss) per common share – basic
Net income (loss) (millions of Canadian dollars)		(1,857	)		2,200		2,314
Weighted average number of common shares outstanding (millions of shares)		735.3			762.7		807.5
Net income (loss) per common share (dollars)		(2.53	)		2.88		2.87
Net income (loss) per common share – diluted
Net income (loss) (millions of Canadian dollars)		(1,857	)		2,200		2,314
Weighted average number of common shares outstanding (millions of shares)		735.3			762.7		807.5
Effect of employee share-based awards (millions of shares) (a)		-			2.3		2.6
Weighted average number of common shares outstanding, assuming dilution (millions of shares)		735.3			765.0		810.1
Net income (loss) per common share (dollars)		(2.53	)		2.88		2.86
Dividends per common share – declared (dollars)		0.88			0.85		0.73

a) For 2020, the Net income (loss) per common share – diluted excludes the effect of 1.9 million employee share-based awards. Share-based awards have the potential to dilute basic earnings per share in the future.

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Miscellaneous financial information (Tables)

12 Months Ended

Dec. 31, 2020

Inventories of Crude Oil and Products

Inventories of crude oil and products at year-end consisted of the following:

millions of Canadian dollars	2020		2019
Crude oil		630		764
Petroleum products		403		396
Chemical products		55		64
Other		73		72
Total inventories of crude oil and products		1,161		1,296

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Financing and additional notes and loans payable information (Tables)

12 Months Ended

Dec. 31, 2020

Financing and Additional Notes and Loans Payable Information

millions of Canadian dollars	2020			2019			2018
Debt-related interest (a)		102			138			133
Capitalized interest		(41	)		(48	)		(28	)
Net interest expense		61			90			105
Other interest		3			3			3
Total financing (b)		64			93			108

(a) Includes related party interest with ExxonMobil.

(b) The weighted average interest rate on short-term borrowings in 2020 was 0.8 percent (2019 – 1.8 percent, 2018 – 1.5 percent). Average effective rate on the long-term borrowings with ExxonMobil in 2020 was 1.4 percent (2019 – 2.2 percent, 2018 – 2.0 percent).

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Leases (Tables)

12 Months Ended

Dec. 31, 2020

Schedule Of Lease Cost

The table below summarizes the total lease cost incurred:

	2020				2019
millions of Canadian dollars	Operating leases		Finance leases		Operating leases		Finance leases
Operating lease cost		157				151
Short-term and other (net of sublease rental income)		40				76
Amortization of right of use assets				29				55
Interest on lease liabilities				38				40
Total lease cost		197		67		227		95

Schedule Of Operating Leases and Finance Leases Recorded In Balance Sheet

The following table summarizes the amounts related to operating leases and finance leases recorded on the Consolidated balance sheet, weighted average remaining lease term and weighted average discount rates applied at December 31:

	2020			2019
millions of Canadian dollars		Operating leases	Finance leases		Operating leases	Finance leases
Right of use assets
Included in Other assets, including intangibles, net		188			260
Included in Property, plant and equipment, net			532			546
Total right of use assets		188	532		260	546
Lease liability due within one year
Included in Accounts payable and accrued liabilities		97	-		115	15
Included in Notes and loans payable			16			18
Long-term lease liability
Included in Other long-term obligations		95	-		143	-
Included in Long-term debt			510			514
Total lease liability		192	526		258	547
Weighted average remaining lease term (years)		4	38		4	40
Weighted average discount rate (percent)		2.5	7.3		2.6	7.5

Maturity Of Lease Liabilities

The maturity analysis of the company’s lease liabilities as at December 31 are summarized below:

	2020
millions of Canadian dollars, unless noted	Operating leases			Finance leases
Maturity analysis of lease liabilities
2021		96			53
2022		49			52
2023		16			51
2024		12			50
2025		3			47
2026 and beyond		27			1,040
Total lease payments		203			1,293
Discount to present value		(11	)		(767	)
Total lease liability		192			526

Schedule Of Measurement Of Lease Liabilities and Right Of Use Assets

	2020				2019
millions of Canadian dollars	Operating leases		Finance leases		Operating leases		Finance leases
Cash paid for amounts included in the measurement of lease liabilities
Cash flows from operating activities		136		15		147		45
Cash flows from financing activities				20				27
Non-cash right of use assets recorded for lease liabilities
For January 1 adoption of Leases (Topic 842)						298
In exchange for lease liabilities during the year		63				104

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Long-term debt (Tables)

12 Months Ended

Dec. 31, 2020

Long-term Debt

millions of Canadian dollars
At December 31	2020	2019
Long-term debt (a)	4,447	4,447
Finance leases (b)	510	514
Total long-term debt	4,957	4,961

(a) Borrowed under an existing agreement with an affiliated company of ExxonMobil that provides for a long-term, variable-rate, Canadian dollar loan from ExxonMobil to the company of up to $7.75 billion at interest equivalent to Canadian market rates. The agreement is effective until June 30, 2025, cancelable if ExxonMobil provides at least 370 days advance written notice.

(b) Finance leases are primarily associated with transportation facilities and services agreements. The average imputed rate was 7.3 percent in 2020 (2019 – 7.5 percent). Total finance lease obligations also include $16 million in current liabilities (2019 - $18 million). Principal payments on finance leases of approximately $15 million on average per year are due in each of the next four years after December 31, 2021.

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Other comprehensive income (loss) information (Tables)

12 Months Ended

Dec. 31, 2020

Changes in Accumulated Other Comprehensive Income (Loss)

Changes in accumulated other comprehensive income (loss):

millions of Canadian dollars	2020			2019			2018
Balance at January 1		(1,911	)		(1,517	)		(1,815	)
Postretirement benefits liability adjustment:
Current period change excluding amounts reclassified from accumulated other comprehensive income		(212	)		(505	)		158
Amounts reclassified from accumulated other comprehensive income		134			111			140
Balance at December 31		(1,989	)		(1,911	)		(1,517	)

Amounts Reclassified Out of Accumulated Other Comprehensive Income (Loss) - Before-Tax Income (Expense)

millions of Canadian dollars	2020			2019			2018
Amortization of postretirement benefits liability adjustment included in net periodic benefit cost (a)		(180	)		(148	)		(185	)

(a) This accumulated other comprehensive income component is included in the computation of net periodic benefit cost (note 5).

Income Tax Expense (Credit) for Components of Other Comprehensive Income (Loss)

millions of Canadian dollars	2020			2019			2018
Postretirement benefits liability adjustments:
Postretirement benefits liability adjustment (excluding amortization)		(69	)		(165	)		59
Amortization of postretirement benefits liability adjustment included in net periodic benefit cost		46			37			45
Total		(23	)		(128	)		104

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Summary of Significant Accounting Policies - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Significant Accounting Policies [Line Items]
Amortization of computer software development costs, in years	15 years
Amortization of customer lists, in years	10 years
Syncrude Joint Venture
Significant Accounting Policies [Line Items]
Undivided interest in oil and gas activities	25.00%
Kearl Joint Venture
Significant Accounting Policies [Line Items]
Undivided interest in oil and gas activities	70.96%
Refinery And Chemical Process
Significant Accounting Policies [Line Items]
Property plant and equipment, useful life		25 years
Maximum [Member] | Mining Heavy Equipment
Significant Accounting Policies [Line Items]
Property plant and equipment, useful life	15 years
Maximum [Member] | Ore Processing Plant Assets
Significant Accounting Policies [Line Items]
Property plant and equipment, useful life	50 years

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Accounting changes - Additional Information (Detail) - CAD ($) $ in Millions	Dec. 31, 2020	Jan. 01, 2020
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Accounts receivable, net	$ 1,437
Allowance for doubtful accounts receivable	4
Long term investments and receivables	323
Credit allowance recognized as a liability	$ 0
Earnings reinvested | Cumulative effect, period of adoption, adjustment
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cumulative effect of earnings reinvested		$ 2

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Business Segments (Detail) - CAD ($) $ in Millions		12 Months Ended
		Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Revenues and other income
Revenues	[1],[2]	$ 22,284	$ 34,002	$ 34,964
Investment and other income (note 9)		104	99	135
TOTAL OPERATING REVENUES, INTERSEGMENT SALES, INVESTMENT AND OTHER INCOME		22,388	34,101	35,099
Expenses
Exploration (note 16)		13	47	19
Purchases of crude oil and products	[3]	13,293	20,946	21,541
Production and manufacturing (note 12)	[4]	5,535	6,520	6,121
Selling and general	[4]	741	900	908
Federal excise tax and fuel charge		1,736	1,808	1,667
Depreciation and depletion (note 12)	[5]	3,293	1,598	1,555
Non-service pension and postretirement benefit		121	143	107
Financing (note 13)	[6],[7]	64	93	108
Total expenses		24,796	32,055	32,026
Income (loss) before income taxes		(2,408)	2,046	3,073
Income tax expense (benefit) (note 4)	[8],[9]	(551)	(154)	759
Net income (loss)		(1,857)	2,200	2,314
Cash flows from (used in) operating activities		798	4,429	3,922
Capital and exploration expenditures	[10]	874	1,814	1,427
Property, plant and equipment Cost		55,771	54,868	53,944
Accumulated depreciation and depletion		(23,737)	(20,665)	(19,719)
Net property, plant and equipment	[11]	32,034	34,203	34,225
Total assets	[12],[13]	38,031	42,187	41,456
Consolidation, Eliminations
Revenues and other income
Intersegment sales		(4,172)	(5,589)	(4,455)
TOTAL OPERATING REVENUES, INTERSEGMENT SALES, INVESTMENT AND OTHER INCOME		(4,172)	(5,589)	(4,455)
Expenses
Purchases of crude oil and products		(4,167)	(5,581)	(4,449)
Selling and general		(5)	(8)	(6)
Total expenses		(4,172)	(5,589)	(4,455)
Cash flows from (used in) operating activities		(8)	(7)	19
Total assets	[12],[13]	(398)	(498)	(478)
Upstream
Revenues and other income
Revenues	[2]	6,263	9,479	8,525
Intersegment sales		2,527	3,763	2,634
Investment and other income (note 9)		7	17	11
TOTAL OPERATING REVENUES, INTERSEGMENT SALES, INVESTMENT AND OTHER INCOME		8,797	13,259	11,170
Expenses
Exploration (note 16)		13	47	19
Purchases of crude oil and products		4,834	6,528	5,833
Production and manufacturing (note 12)		3,852	4,440	4,305
Depreciation and depletion (note 12)	[5]	3,084	1,374	1,278
Financing (note 13)		3	3	1
Total expenses		11,786	12,392	11,436
Income (loss) before income taxes		(2,989)	867	(266)
Income tax expense (benefit) (note 4)	[9]	(671)	(481)	(128)
Net income (loss)		(2,318)	1,348	(138)
Cash flows from (used in) operating activities		286	2,423	916
Capital and exploration expenditures	[10]	561	1,248	991
Property, plant and equipment Cost		47,693	47,050	46,435
Accumulated depreciation and depletion		(18,786)	(15,889)	(15,050)
Net property, plant and equipment	[11]	28,907	31,161	31,385
Total assets	[12],[13]	31,835	34,554	34,829
Downstream
Revenues and other income
Revenues	[2]	15,178	23,591	25,200
Intersegment sales		1,480	1,597	1,542
Investment and other income (note 9)		78	47	95
TOTAL OPERATING REVENUES, INTERSEGMENT SALES, INVESTMENT AND OTHER INCOME		16,736	25,235	26,837
Expenses
Purchases of crude oil and products		12,047	19,332	19,326
Production and manufacturing (note 12)		1,468	1,829	1,606
Selling and general		619	774	773
Federal excise tax and fuel charge		1,736	1,808	1,667
Depreciation and depletion (note 12)	[5]	166	186	242
Financing (note 13)				2
Total expenses		16,036	23,929	23,616
Income (loss) before income taxes		700	1,306	3,221
Income tax expense (benefit) (note 4)	[9]	147	345	855
Net income (loss)		553	961	2,366
Cash flows from (used in) operating activities		470	1,965	2,749
Capital and exploration expenditures	[10]	251	484	383
Property, plant and equipment Cost		6,321	6,123	5,900
Accumulated depreciation and depletion		(3,962)	(3,830)	(3,763)
Net property, plant and equipment	[11]	2,359	2,293	2,137
Total assets	[12],[13]	4,554	5,179	5,119
Chemical
Revenues and other income
Revenues	[2]	843	932	1,239
Intersegment sales		165	229	279
TOTAL OPERATING REVENUES, INTERSEGMENT SALES, INVESTMENT AND OTHER INCOME		1,008	1,161	1,518
Expenses
Purchases of crude oil and products		579	667	831
Production and manufacturing (note 12)		215	251	210
Selling and general		92	86	87
Depreciation and depletion (note 12)	[5]	19	16	14
Total expenses		905	1,020	1,142
Income (loss) before income taxes		103	141	376
Income tax expense (benefit) (note 4)	[9]	25	33	101
Net income (loss)		78	108	275
Cash flows from (used in) operating activities		114	172	354
Capital and exploration expenditures	[10]	21	34	25
Property, plant and equipment Cost		975	954	916
Accumulated depreciation and depletion		(699)	(680)	(662)
Net property, plant and equipment	[11]	276	274	254
Total assets	[12],[13]	408	416	438
Corporate and Other
Revenues and other income
Investment and other income (note 9)		19	35	29
TOTAL OPERATING REVENUES, INTERSEGMENT SALES, INVESTMENT AND OTHER INCOME		19	35	29
Expenses
Selling and general		35	48	54
Depreciation and depletion (note 12)	[5]	24	22	21
Non-service pension and postretirement benefit		121	143	107
Financing (note 13)		61	90	105
Total expenses		241	303	287
Income (loss) before income taxes		(222)	(268)	(258)
Income tax expense (benefit) (note 4)	[9]	(52)	(51)	(69)
Net income (loss)		(170)	(217)	(189)
Cash flows from (used in) operating activities		(64)	(124)	(116)
Capital and exploration expenditures	[10]	41	48	28
Property, plant and equipment Cost		782	741	693
Accumulated depreciation and depletion		(290)	(266)	(244)
Net property, plant and equipment	[11]	492	475	449
Total assets	[12],[13]	$ 1,632	$ 2,536	$ 1,548

[1] Amounts from related parties included in revenues, (note 17). 5,107 8,569 6,383

[2] Includes export sales to the United States of $4,614 million (2019 - $7,190 million, 2018 - $6,661 million). Export sales to the United States were recorded in all operating segments, with the largest effects in the Upstream segment.

[3] Amounts to related parties included in purchases of crude oil and products, (note 17). 2,484 3,305 4,092

[4] Amounts to related parties included in production and manufacturing, and selling and general expenses, (note 17). 579 628 566

[5] In 2020, the Upstream segment included a non-cash impairment charge of $1,531 million, before-tax, related to the company’s decision not to further develop a significant portion of its unconventional portfolio. In 2018, the Downstream segment included a non-cash impairment charge of $46 million, before-tax, associated with the Government of Ontario’s revocation of its cap and trade legislation.

[6] Amounts to related parties included in financing, (note 17). 61 98 89

[7] The weighted average interest rate on short-term borrowings in 2020 was 0.8 percent (2019 – 1.8 percent, 2018 – 1.5 percent). Average effective rate on the long-term borrowings with ExxonMobil in 2020 was 1.4 percent (2019 – 2.2 percent, 2018 – 2.0 percent).

[8] On June 28, 2019 the Alberta government enacted a 4 percent decrease in the provincial tax rate, from 12 percent to 8 percent by 2022. On December 9, 2020 the Alberta government enacted an accelerated decrease in the province’s general corporate income tax rate from 10 percent to 8 percent, effective July 1, 2020. The cumulative effect of the 2020 legislative tax changes on the company’s financial statements were immaterial.

[9] Segment results in 2019 include a largely non-cash favourable impact of $662 million associated with the Alberta corporate income tax rate decrease, with the largest impact in the Upstream segment.

[10] Capital and exploration expenditures (CAPEX) include exploration expenses, additions to property, plant and equipment, additions to finance leases, additional investments and acquisitions. CAPEX excludes the purchase of carbon emission credits.

[11] Includes property, plant and equipment under construction of $1,874 million (2019 - $2,149 million, 2018 - $1,553 million).

[12] Effective January 1, 2019, Imperial adopted the Financial Accounting Standards Board’s standard, Leases (Topic 842), as amended. As at December 31, 2020, Total assets include operating lease right of use assets of $188 million (2019 - $260 million). An election was made not to restate prior periods. See note 14 for additional details.

[13] In 2019, the company removed $570 million from Total assets and corresponding liabilities in the Downstream segment associated with the Government of Ontario’s revocation of its cap and trade legislation.

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Business Segments (Parenthetical) (Detail) - CAD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Segment Reporting Information [Line Items]
Plant and equipment under construction	$ 1,874	$ 2,149	$ 1,553
Right of use assets, Operating leases	188	260
Upstream [Member]
Segment Reporting Information [Line Items]
Impairment charge, before tax	1,531
Upstream [Member] | Alberta
Segment Reporting Information [Line Items]
Noncash impact		662
Downstream [Member]
Segment Reporting Information [Line Items]
Impairment charge, before tax			46
Accounts payable and accrued liabilities
Segment Reporting Information [Line Items]
Non-cash adjustments to accrued liabilities and all other items		570
United States Exports
Segment Reporting Information [Line Items]
Operating revenues	$ 4,614	$ 7,190	$ 6,661

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Income Taxes (Detail) - CAD ($) $ in Millions		12 Months Ended
		Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Schedule Of Income Tax [Line Items]
Current income tax expense (benefit)	[1]	$ (27)	$ 140	$ (14)
Deferred income tax expense (benefit)	[1]	(524)	(294)	773
Total income tax expense (benefit)	[1],[2]	$ (551)	$ (154)	$ 759
Statutory corporate tax rate (percent)		25.00%	26.00%	26.90%
Enacted tax rate change	[1]	0.10%	(31.90%)
Other	[3]	(2.20%)	(1.60%)	(2.20%)
Effective income tax rate		22.90%	(7.50%)	24.70%

[1] On June 28, 2019 the Alberta government enacted a 4 percent decrease in the provincial tax rate, from 12 percent to 8 percent by 2022. On December 9, 2020 the Alberta government enacted an accelerated decrease in the province’s general corporate income tax rate from 10 percent to 8 percent, effective July 1, 2020. The cumulative effect of the 2020 legislative tax changes on the company’s financial statements were immaterial.

[2] Segment results in 2019 include a largely non-cash favourable impact of $662 million associated with the Alberta corporate income tax rate decrease, with the largest impact in the Upstream segment.

[3] Other decreases primarily relate to prior year adjustments, re-assessments and disposals.

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Income Taxes (Parenthetical) (Detail) - Alberta government [Member]	Dec. 09, 2020	Jun. 28, 2019
Schedule Of Income Tax [Line Items]
Increase/Decrease in the provincial tax rate		4.00%
Minimum [Member]
Schedule Of Income Tax [Line Items]
Provincial tax rate	10.00%	12.00%
Maximum [Member]
Schedule Of Income Tax [Line Items]
Provincial tax rate	8.00%	8.00%

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Components of Deferred Income Tax Liabilities and Assets (Detail) - CAD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Components Of Deferred Tax Assets And Liabilities [Line Items]
Depreciation and amortization	$ 5,319	$ 5,164	$ 5,726
Successful drilling and land acquisitions	363	750	856
Pension and benefits	(534)	(469)	(336)
Asset retirement obligation	(403)	(336)	(381)
Capitalized interest	120	117	121
LIFO inventory valuation	(150)	(276)	(107)
Tax loss carryforwards	(460)	(141)	(658)
Other	(154)	(161)	(150)
Net deferred income tax liabilities	$ 4,101	$ 4,648	$ 5,071

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Unrecognized Tax Benefits (Detail) - CAD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Schedule of Unrecognized Tax Benefits [Line Items]
Balance as of January 1	$ 35	$ 36	$ 78
Additions based on current year's tax position	2
Additions for prior years' tax positions		1	9
Reductions for prior years' tax positions			(2)
Settlements with tax authorities	(1)	(2)	(49)
Balance as of December 31	$ 36	$ 35	$ 36

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Assumptions Used to Determine Benefit Obligations (Detail)	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Discount rate	2.50%	3.10%
Long-term rate of compensation increase	4.00%	4.50%
Pension benefits
Defined Benefit Plan Disclosure [Line Items]
Discount rate	2.50%	3.10%
Long-term rate of compensation increase	4.00%	4.50%
Other postretirement benefits
Defined Benefit Plan Disclosure [Line Items]
Discount rate	2.50%	3.10%
Long-term rate of compensation increase	4.00%	4.50%

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Change in Projected Benefit Obligation (Detail) - CAD ($) $ in Millions		12 Months Ended
		Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Pension benefits
Schedule Of Defined Benefit Plans Disclosures [Line Items]
Projected benefit obligation at January 1		$ 9,786	$ 8,359
Current service cost		305	228	$ 239
Interest cost		308	324	302
Actuarial loss (gain)	[1]	811	1,053
Amendments			283
Benefits paid	[2]	(494)	(461)
Projected benefit obligation at December 31		10,716	9,786	8,359
Accumulated benefit obligation at December 31		9,619	8,814
Other postretirement benefits
Schedule Of Defined Benefit Plans Disclosures [Line Items]
Projected benefit obligation at January 1		693	582
Current service cost		24	16	17
Interest cost		24	20	22
Actuarial loss (gain)	[1]	152	99
Benefits paid	[2]	(20)	(24)
Projected benefit obligation at December 31		$ 873	$ 693	$ 582

[1] Actuarial loss primarily driven by a decrease in the year-end discount rate from 3.10 percent to 2.50 percent, partially offset by the impact of a reduction in the long-term rate of compensation increase assumption from 4.50 percent to 4.00 percent.

[2] Benefit payments for funded and unfunded plans.

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Change in Plan Assets and Plan Assets in Excess of Less Than Projected Benefit Obligation (Detail) - CAD ($) $ in Millions		12 Months Ended
		Dec. 31, 2020	Dec. 31, 2019
Schedule Of Defined Benefit Plans Disclosures [Line Items]
Fair value at January 1		$ 8,599
Fair value at December 31		9,426	$ 8,599
Pension benefits
Schedule Of Defined Benefit Plans Disclosures [Line Items]
Fair value at January 1		8,599	7,691
Actual return (loss) on plan assets		1,073	1,114
Company contributions		195	211
Benefits paid	[1]	(441)	(417)
Fair value at December 31		9,426	8,599
Funded plans		(641)	(590)
Unfunded plans		(649)	(597)
Total	[2]	(1,290)	(1,187)
Other postretirement benefits
Schedule Of Defined Benefit Plans Disclosures [Line Items]
Unfunded plans		(873)	(693)
Total	[2]	$ (873)	$ (693)

[1] Benefit payments for funded plans only.

[2] Fair value of assets less projected benefit obligation shown above.

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Amounts Recorded in Consolidated Balance Sheet and Accumulated Other Comprehensive Income (Detail) - CAD ($) $ in Millions		Dec. 31, 2020	Dec. 31, 2019
Schedule Of Defined Benefit Plans Disclosures [Line Items]
Current liabilities		$ (58)	$ (58)
Other long-term obligations	[1]	(2,105)	(1,822)
Pension benefits
Schedule Of Defined Benefit Plans Disclosures [Line Items]
Current liabilities		(27)	(27)
Other long-term obligations		(1,263)	(1,160)
Total recorded		(1,290)	(1,187)
Net actuarial loss (gain)		2,232	2,256
Prior service cost		269	283
Total recorded in accumulated other comprehensive income, before-tax		2,501	2,539
Other postretirement benefits
Schedule Of Defined Benefit Plans Disclosures [Line Items]
Current liabilities		(31)	(31)
Other long-term obligations		(842)	(662)
Total recorded		(873)	(693)
Net actuarial loss (gain)		272	133
Total recorded in accumulated other comprehensive income, before-tax		$ 272	$ 133

[1] Total recorded employee retirement benefits obligations also included $58 million in current liabilities (2019 – $58 million).

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Assumptions Used to Determine Periodic Benefit Cost (Detail)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Schedule Of Defined Benefit Plans Disclosures [Line Items]
Long-term rate of return on funded assets	4.50%
Pension benefits
Schedule Of Defined Benefit Plans Disclosures [Line Items]
Discount rate	3.10%	3.90%	3.40%
Long-term rate of return on funded assets	4.50%	4.50%	5.00%
Long-term rate of compensation increase	4.50%	4.50%	4.50%
Other postretirement benefits
Schedule Of Defined Benefit Plans Disclosures [Line Items]
Discount rate	3.10%	3.90%	3.40%
Long-term rate of compensation increase	4.50%	4.50%	4.50%

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Components of Net Periodic Benefit Cost and Changes in Amounts Recorded in Accumulated Other Comprehensive Income (Detail) - CAD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Total recorded in other comprehensive income	$ 101	$ 522	$ (402)
Pension benefits
Defined Benefit Plan Disclosure [Line Items]
Current service cost	305	228	239
Interest cost	308	324	302
Expected return on plan assets	(391)	(349)	(402)
Amortization of prior service cost	14		4
Amortization of actuarial loss (gain)	153	149	175
Net periodic benefit cost	389	352	318
Net actuarial loss (gain)	129	288	(116)
Amortization of net actuarial (loss) gain included in net periodic benefit cost	(153)	(149)	(175)
Prior service cost		283
Amortization of prior service cost included in net periodic benefit cost	(14)		(4)
Total recorded in other comprehensive income	(38)	422	(295)
Total recorded in net periodic benefit cost and other comprehensive income,before-tax	351	774	23
Other postretirement benefits
Defined Benefit Plan Disclosure [Line Items]
Current service cost	24	16	17
Interest cost	24	20	22
Amortization of actuarial loss (gain)	13	(1)	6
Net periodic benefit cost	61	35	45
Net actuarial loss (gain)	152	99	(101)
Amortization of net actuarial (loss) gain included in net periodic benefit cost	(13)	1	(6)
Total recorded in other comprehensive income	139	100	(107)
Total recorded in net periodic benefit cost and other comprehensive income,before-tax	$ 200	$ 135	$ (62)

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Summary of Change in Accumulated Other Comprehensive Income (Detail) - CAD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
(Charge) credit to other comprehensive income, before-tax	$ (101)	$ (522)	$ 402
Deferred income tax (charge) credit (note 18)	23	128	(104)
(Charge) credit to other comprehensive income, after-tax	$ (78)	$ (394)	$ 298

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Fair Value of Pension Plan Assets Including Level Within Fair Value Hierarchy (Detail) - CAD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	$ 9,426	$ 8,599
Investments that are measured at fair value using net asset value	9,385	8,559
Canadian Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	222	210
Investments that are measured at fair value using net asset value	222	210
Non-Canadian Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	2,690	2,449
Investments that are measured at fair value using net asset value	2,690	2,449
Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	1,426	1,379
Investments that are measured at fair value using net asset value	1,426	1,379
Government Debt Securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	4,825	4,299
Investments that are measured at fair value using net asset value	4,825	4,299
Asset-backed Debt Securities
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value		1
Investments that are measured at fair value using net asset value		1
Equities - Venture Capital
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	214	204
Investments that are measured at fair value using net asset value	214	204
Cash [Member]
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	49	57
Investments that are measured at fair value using net asset value	8	17
Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	41	40
Fair Value, Inputs, Level 1 [Member] | Cash [Member]
Defined Benefit Plan Disclosure [Line Items]
Total plan assets at fair value	$ 41	$ 40

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Pension Plan with Accumulated Benefit Obligation in Excess of Plan Assets (Detail) - CAD ($) $ in Millions		Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		$ 9,426	$ 8,599
Funded Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	[1]	1,034	942
Fair value of plan assets	[1]	954	870
Accumulated benefit obligation less fair value of plan assets	[1]	80	72
Funded pension plans with projected benefit obligation in excess of plan asset [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation		10,067	9,189
Fair value of plan assets		9,426	8,599
Projected benefit obligation less fair value of plan assets		641	590
Unfunded Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation		649	597
Accumulated benefit obligation		$ 565	$ 536

[1] The amounts shown for funded pension plans with accumulated benefit obligation in excess of plan assets represent the company’s proportionate share of a joint venture sponsored pension plan. For the company sponsored funded plan, the fair value of plan assets exceeded the accumulated benefit obligation in both 2020 and 2019.

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Change in Projected Benefit Obligation (Parenthetical) (Detail)	Dec. 31, 2020	Dec. 31, 2019
Retirement Benefits [Abstract]
Discount rate used in computation of actuarial benefits	2.50%	3.10%
Compensation rate used in computation of actuarial benefits	4.00%	4.50%

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Expected Benefit Payments (Detail) $ in Millions	Dec. 31, 2020 CAD ($)
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
2021	$ 460
2022	460
2023	465
2024	465
2025	465
2026 - 2030	2,325
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
2021	31
2022	32
2023	32
2024	33
2025	34
2026 - 2030	$ 175

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Employee Retirement Benefits - Additional Information (Detail) - CAD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Health care cost trend rate assumed for 2021	5.66%
Health care cost trend rate assumed for 2040	3.57%
Long-term expected return	4.50%
Actual rate of return over the last 10 years	8.40%
Actual rate of return over the last 20 years	6.90%
Cost for defined contributions plans	$ 47	$ 43	$ 41
Plan assets invested in venture capital partnerships	3.00%
Cash contributions to pension plans in 2021	$ 164
Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocation securities	30.00%
Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocation securities	67.00%

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Other Long-Term Obligations (Detail) - CAD ($) $ in Millions		Dec. 31, 2020	Dec. 31, 2019
Schedule of Other Liabilities [Line Items]
Employee retirement benefits	[1]	$ 2,105	$ 1,822
Asset retirement obligations and other environmental liabilities	[2],[3]	1,676	1,388
Share-based incentive compensation liabilities		45	65
Other obligations		179	219
Total other long-term obligations		4,100	3,637
Other LongTerm Obligations [Member]
Schedule of Other Liabilities [Line Items]
Operating lease liability		$ 95	$ 143

[1] Total recorded employee retirement benefits obligations also included $58 million in current liabilities (2019 – $58 million).

[2] For 2020, the asset retirement obligations were discounted at 6 percent (2019 - 6 percent).

[3] Total asset retirement obligations and other environmental liabilities also included $100 million in current liabilities (2019 – $124 million).

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Other Long-Term Obligations (Parenthetical) (Detail) - CAD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Schedule of Other Liabilities [Line Items]
Employee retirement benefit obligations in current liabilities	$ 58	$ 58
Asset retirement obligations and other environmental liabilities in current liabilities	$ 100	$ 124
Asset retirement obligations discount rate	6.00%	6.00%

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Schedule of Asset Retirement Obligations (Detail) - CAD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Reconciliation of Changes in Asset Retirement Obligations [Line Items]
Balance as at January 1	$ 1,400	$ 1,417	$ 1,397
Additions (deductions)	265	(23)	(5)
Accretion	82	80	85
Settlement	(73)	(74)	(60)
Balance as at December 31	$ 1,674	$ 1,400	$ 1,417

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Financial and derivative instruments - Additional Information (Detail) - CAD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Financial Instruments And Derivatives [Line Items]
Long-term Debt, Fair Value	$ 4,447	$ 4,447
Master netting arrangements [Member]
Financial Instruments And Derivatives [Line Items]
Derivative collateral receivable	$ 5

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Summary of Realized and Unrealized Gain or (Loss) on Derivative Instruments (Detail) - CAD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Financial Instruments And Derivatives [Line Items]
Revenues	$ (13)	$ (3)	$ 6
Purchases of crude oil and products	(21)	(7)	(24)
Total	$ (34)	$ (10)	$ (18)

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Financial and derivative instruments - Summary of estimated fair value of financial instruments (Detail) - CAD ($) $ in Millions		Dec. 31, 2020	Dec. 31, 2019
Derivative Asset [Abstract]
Derivative Asset	[1]	$ 2
Derivative Liability [Abstract]
Derivative liabilities	[2]	12	$ 2
Effect of counterparty netting [Member]
Derivative Asset [Abstract]
Derivative Asset	[1]	(2)
Derivative Liability [Abstract]
Derivative liabilities	[2]	(2)
Derivative fair value of derivative amount effect of collateral netting [Member]
Derivative Liability [Abstract]
Derivative liabilities	[2]	(10)	(2)
Fair Value, Inputs, Level 1 [Member]
Derivative Asset [Abstract]
Derivative Asset	[1]	2
Derivative Liability [Abstract]
Derivative liabilities	[2]	$ 12	$ 2

[1] Included in the Consolidated balance sheet line: “Materials, supplies and prepaid expenses”.

[2] Included in the Consolidated balance sheet line: “Accounts payable and accrued liabilities”.

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Financial and derivative instruments - Summary of net notional long/(short) position of derivative instruments (Detail) - bbl	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Crude barrels [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(800,000)	(590,000)
Products barrels [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(390,000)

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Share-Based Incentive Compensation Programs - Additional Information (Detail) - CAD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense charged against income	$ 2	$ 34	$ 32
Income tax benefit recognized in income related to compensation expense	0	9	9
Cash payment for compensation expense	33	$ 50	$ 59
Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Before-tax unrecognized compensation expense related to non-vested restricted stock	$ 45
Weighted average vesting period of nonvested restricted stock	4 years 1 month 6 days
Restricted Stock Units | Restricted Stock Unit Plan 1
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage restricted stock units vested on third anniversary of the grant date	50.00%
Percentage restricted stock units vested on seventh anniversary of the grant date	50.00%
Restricted Stock Units | Restricted Stock Unit Plan 2
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage restricted stock units vested on fifth anniversary of the grant date	50.00%
Percentage restricted stock units vested on tenth anniversary of the grant date	50.00%

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Summarized Information About Incentive Share, Deferred Share and Restricted Stock Units (Detail)	12 Months Ended
	Dec. 31, 2020 shares
Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Outstanding at January 1, 2020	4,912,805
Granted	747,040
Vested / Exercised	(1,187,630)
Forfeited and cancelled	(8,895)
Outstanding at December 31, 2020	4,463,320
Deferred Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Outstanding at January 1, 2020	170,163
Granted	34,811
Vested / Exercised	(57,569)
Outstanding at December 31, 2020	147,405

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Gains and Losses on Asset Sales (Detail) - CAD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Investment And Other Income [Line Items]
Proceeds from asset sales	$ 82	$ 82	$ 59
Book value of asset sales	47	36	5
Gain (loss) on asset sales, before-tax	35	46	54
Gain (loss) on asset sales, after-tax	$ 32	$ 42	$ 38

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Litigation and Other Contingencies - Additional Information (Detail) - CAD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Litigation And Other Contingencies [Line Items]
Total payment on unconditional purchase obligation	$ 0
Total other third party obligations payable	26	$ 30
Indemnification Agreement [Member]
Litigation And Other Contingencies [Line Items]
Total other third party obligations payable	$ 62	$ 64

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Common Shares - Additional Information (Detail)	Jun. 29, 2020 shares
Class of Stock [Line Items]
Normal course issuer bid share repurchase shares authorized	50,000
Exxon Mobil Corporation's ownership interest in Imperial	69.60%
Normal course issuer bid share repurchase term, months	12 months

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Summary of Common Shares (Detail) - shares	Dec. 31, 2020	Dec. 31, 2019
Class of Stock [Line Items]
Authorized	1,100,000,000	1,100,000,000
Common shares outstanding	734,077,000	743,902,000

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Common Share Activities (Detail) - CAD ($) shares in Thousands, $ in Millions		12 Months Ended
		Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Class of Stock [Line Items]
Common stock beginning balance, shares		743,902
Common stock, ending balance, shares		734,077	743,902
Common stock beginning balance, value	[1]	$ 1,375
Common stock, ending balance, value	[1]	$ 1,357	$ 1,375
Common Stock
Class of Stock [Line Items]
Common stock beginning balance, shares		743,902	782,565	831,242
Issued under employee share-based awards, shares		7	1	2
Purchases at stated value, shares		(9,832)	(38,664)	(48,679)
Common stock, ending balance, shares		734,077	743,902	782,565
Common stock beginning balance, value		$ 1,375	$ 1,446	$ 1,536
Issued under employee share-based awards, value			0	0
Purchases at stated value, value		(18)	(71)	(90)
Common stock, ending balance, value		$ 1,357	$ 1,375	$ 1,446

[1] Number of common shares authorized and outstanding were 1,100 million and 734 million, respectively (2019 – 1,100 million and 744 million, respectively), (note 11).

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Calculation of basic and diluted earnings per common share and the dividend declared by the company on its outstanding common shares (Detail) - CAD ($) $ / shares in Units, shares in Millions, $ in Millions		12 Months Ended
		Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Net income (loss) per common share - basic
Net income (loss) (millions of Canadian dollars)		$ (1,857)	$ 2,200	$ 2,314
Weighted average number of common shares outstanding (millions of shares)		735.3	762.7	807.5
Net income (loss) per common share (dollars)		$ (2.53)	$ 2.88	$ 2.87
Net income (loss) per common share - diluted
Net income (loss) (millions of Canadian dollars)		$ (1,857)	$ 2,200	$ 2,314
Weighted average number of common shares outstanding (millions of shares)		735.3	762.7	807.5
Effect of employee share-based awards (millions of shares)	[1]		2.3	2.6
Weighted average number of common shares outstanding, assuming dilution (millions of shares)		735.3	765.0	810.1
Net income (loss) per common share (dollars)		$ (2.53)	$ 2.88	$ 2.86
Dividends per common share - declared (dollars)		$ 0.88	$ 0.85	$ 0.73

[1] For 2020, the Net income (loss) per common share – diluted excludes the effect of 1.9 million employee share-based awards. Share-based awards have the potential to dilute basic earnings per share in the future.

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Calculation of basic and diluted earnings per common share and the dividend declared by the company on its outstanding common shares (Parenthetical) (Detail) shares in Millions	12 Months Ended
	Dec. 31, 2020 shares
Earnings Per Share [Abstract]
Effect of employee share-based awards excluded from computation	1.9

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Miscellaneous Financial Information - Additional Information (Detail) - CAD ($) $ in Millions	3 Months Ended		12 Months Ended
	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Additional Financial Information [Line Items]
Effect of LIFO inventory liquidation on income (loss)			$ 19	$ (22)	$ 16
Difference between LIFO carrying values and replacement cost of inventories			800	1,200
Research and development costs charged to expenses			105	133	$ 110
Accounts payable and accrued liabilities included accrued taxes other than income taxes			$ 344	$ 397
Production and Manufacturing [Member] | Canada Emergency Wage Subsidy (CEWS) [Member]
Additional Financial Information [Line Items]
Amount received as part of the federal government subsidy program	$ 155
Upstream [Member]
Additional Financial Information [Line Items]
Non-cash impairment of goodwill		$ 20

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Inventories of Crude Oil and Products (Detail) - CAD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Product Information [Line Items]
Crude oil	$ 630	$ 764
Petroleum products	403	396
Chemical products	55	64
Other	73	72
Total inventories of crude oil and products	$ 1,161	$ 1,296

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Financing and Additional Notes and Loans Payable Information (Detail) - CAD ($) $ in Millions		12 Months Ended
		Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Debt-related interest	[1]	$ 102	$ 138	$ 133
Capitalized interest		(41)	(48)	(28)
Net interest expense		61	90	105
Other interest		3	3	3
Total financing	[2],[3]	$ 64	$ 93	$ 108

[1] Includes related party interest with ExxonMobil.

[2] Amounts to related parties included in financing, (note 17). 61 98 89

[3] The weighted average interest rate on short-term borrowings in 2020 was 0.8 percent (2019 – 1.8 percent, 2018 – 1.5 percent). Average effective rate on the long-term borrowings with ExxonMobil in 2020 was 1.4 percent (2019 – 2.2 percent, 2018 – 2.0 percent).

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Financing and Additional Notes and Loans Payable Information (Parenthetical) (Detail)	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Weighted average interest rate on short-term borrowings	0.80%	1.80%	1.50%
Average effective rate for affiliate long-term borrowing	1.40%	2.20%	2.00%

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Financing and Additional Notes and Loans Payable Information - Additional Information (Detail) - CAD ($)	1 Months Ended	3 Months Ended
	Nov. 30, 2020	Jun. 30, 2020	Dec. 31, 2020
Short Term Line of Credit
Financing Activities [Line Items]
Non-interest bearing, revolving demand loan, outstanding amount		$ 500,000,000
Short-term line of credit facility due May 2021
Financing Activities [Line Items]
Non-interest bearing, revolving demand loan, maximum borrowing capacity		$ 500,000,000
Debt instrument, maturity date		May 31, 2021
Non-interest bearing, revolving demand loan, outstanding amount		$ 0
Short-term line of credit facility due June 2021
Financing Activities [Line Items]
Non-interest bearing, revolving demand loan, maximum borrowing capacity		$ 300,000,000
Debt instrument, maturity date		Jun. 30, 2021
Non-interest bearing, revolving demand loan, outstanding amount		$ 0
Short-term line of credit facility due Nov 2021
Financing Activities [Line Items]
Non-interest bearing, revolving demand loan, maximum borrowing capacity	$ 250,000,000
Debt instrument, maturity date	Nov. 30, 2021
Non-interest bearing, revolving demand loan, outstanding amount	$ 0
Short-term line of credit facility remains unchanged Nov 2021
Financing Activities [Line Items]
Non-interest bearing, revolving demand loan, maximum borrowing capacity	$ 250,000,000
Debt instrument, maturity date	Nov. 30, 2021
Non-interest bearing, revolving demand loan, outstanding amount	$ 0
Exxon Mobil | Revolving demand loan
Financing Activities [Line Items]
Non-interest bearing, revolving demand loan, maximum borrowing capacity			$ 150,000,000
Non-interest bearing, revolving demand loan, outstanding amount			$ 111,000,000

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Leases - Additional Information (Detail) - CAD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Operating Leased Assets [Line Items]
Undiscounted Commitments	$ 27	$ 6
Net rental cost incurred for operating leases			$ 221

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Schedule Of Lease Cost (Detail) - CAD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Operating leases [Member]
Lease, Cost [Abstract]
Operating lease cost, Operating leases	$ 157	$ 151
Short-term and other (net of sublease rental income), Operating leases	40	76
Total lease cost	197	227
Finance leases [Member]
Lease, Cost [Abstract]
Amortization of right of use assets	29	55
Interest on lease liabilities, Finance leases	38	40
Total lease cost	$ 67	$ 95

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Schedule Of Operating Leases and Finance Leases Recorded In Balance Sheet (Detail) - CAD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Right of use assets
Right of use assets, Operating leases	$ 188	$ 260
Long-term lease liability
Total Operating leases liability	192
Total Finance leases liability	$ 526
Weighted average remaining lease term (years), Operating leases	4 years	4 years
Weighted average remaining lease term (years), Finance leases	38 years	40 years
Weighted average discount rate (percent), Operating leases	2.50%	2.60%
Weighted average discount rate (percent), Finance leases	7.30%	7.50%
Other Assets Including Intangible Assets [Member]
Right of use assets
Right of use assets, Operating leases	$ 188	$ 260
Accounts Payable and Accrued Liabilities [Member]
Lease liability due within one year
Lease liability due within one year, Operating leases	97	115
Lease liability due within one year, Finance leases		15
Notes and Loans Payable [Member]
Lease liability due within one year
Lease liability due within one year, Finance leases	16	18
Property, Plant and Equipment [Member]
Right of use assets
Right of use assets, Finance leases	532	546
Other LongTerm Obligations [Member]
Long-term lease liability
Long-term lease liability, Operating leases	95	143
Long-term lease liability, Finance leases		0
Long-term Debt [Member]
Right of use assets
Right of use assets, Finance leases	510	514
Other Assets And Property Plant And Equipment Net [Member]
Right of use assets
Right of use assets, Operating leases	188	260
Right of use assets, Finance leases	532	546
Accounts Notes Loans Payable And Long Term Obligations And Debt [Member]
Long-term lease liability
Total Operating leases liability	192	258
Total Finance leases liability	$ 526	$ 547

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Maturity Of Lease Liabilities (Detail) $ in Millions	Dec. 31, 2020 CAD ($)
Operating Lease
2021	$ 96
2022	49
2023	16
2024	12
2025	3
2026 and beyond	27
Total lease payments	203
Discount to present value	(11)
Total lease liability	$ 192
Operating Lease, Liability, Statement of Financial Position [Extensible List]	us-gaap:OperatingLeaseLiability
Finance Lease
2021	$ 53
2022	52
2023	51
2024	50
2025	47
2026 and beyond	1,040
Total lease payments	1,293
Discount to present value	(767)
Total lease liability	$ 526

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Schedule Of Measurement Of Lease Liabilities and Right Of Use Assets (Detail) - CAD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Cash paid for amounts included in the measurement of lease liabilities
Cash flows from operating activities, Operating leases	$ 136	$ 147
Cash flows from operating activities, Finance leases	15	45
Cash flows from financing activities, Finance leases	20	27
Non-cash right of use assets recorded for lease liabilities
For January 1 adoption of Leases	192
Adoption of Leases Topic (842) [Member]
Non-cash right of use assets recorded for lease liabilities
For January 1 adoption of Leases		298
In exchange for lease liabilities during the year	$ 63	$ 104

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Long-Term Debt (Detail) - CAD ($) $ in Millions		Dec. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Long-term debt	[1]	$ 4,447	$ 4,447
Finance leases	[2]	510	514
Total long-term debt	[3]	$ 4,957	$ 4,961

[1] Borrowed under an existing agreement with an affiliated company of ExxonMobil that provides for a long-term, variable-rate, Canadian dollar loan from ExxonMobil to the company of up to $7.75 billion at interest equivalent to Canadian market rates. The agreement is effective until June 30, 2025, cancelable if ExxonMobil provides at least 370 days advance written notice.

[2] Finance leases are primarily associated with transportation facilities and services agreements. The average imputed rate was 7.3 percent in 2020 (2019 – 7.5 percent). Total finance lease obligations also include $16 million in current liabilities (2019 - $18 million). Principal payments on finance leases of approximately $15 million on average per year are due in each of the next four years after December 31, 2021.

[3] Long-term debt included amounts to related parties of $4,447 million (2019 – $4,447 million), (note 17).

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Long-Term Debt (Parenthetical) (Detail) - CAD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Maximum long-term borrowing from affiliate	$ 7,750
Cancellation period long-term borrowing from affiliate, days	370 days
Finance lease obligations for marine services, average imputed rate	7.30%	7.50%
Total finance lease obligations in current liabilities	$ 16	$ 18
Principal payments on finance lease, in two years	15
Principal payments on finance lease, in three years	15
Principal payments on finance lease, in four years	15
Principal payments on finance lease, in five years	$ 15

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Accounting for suspended exploratory well costs - Additional Information (Detail) $ in Millions	Dec. 31, 2020 CAD ($) Project	Dec. 31, 2019 CAD ($) Project	Dec. 31, 2018 CAD ($) Project
Extractive Industries [Abstract]
Projects that have Exploratory Well Costs that have been Capitalized | Project	0	0	0
Capitalized Exploratory Well Costs | $	$ 0	$ 0	$ 0

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Transactions with Related Parties - Additional Information (Detail) - CAD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Related Party Transaction [Line Items]
Amounts of sales by Imperial	$ 5,107	$ 8,569	$ 6,383
Financing costs	61	98	$ 89
Long-Term Loans
Related Party Transaction [Line Items]
Outstanding loans from an affiliate	4,447	4,447
Short-Term Loans
Related Party Transaction [Line Items]
Outstanding loans from an affiliate	111	111
Exxon Mobil
Related Party Transaction [Line Items]
Amounts of purchases by Imperial	2,424	3,245
Amounts of sales by Imperial	5,101	8,552
Financing costs	$ 61	$ 96

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Changes in Accumulated Other Comprehensive Income (Loss) (Detail) - CAD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at January 1	$ (1,911)	$ (1,517)	$ (1,815)
Current period change excluding amounts reclassified from accumulated other comprehensive income	(212)	(505)	158
Amounts reclassified from accumulated other comprehensive income	134	111	140
Balance at December 31	$ (1,989)	$ (1,911)	$ (1,517)

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Amounts Reclassified Out of Accumulated Other Comprehensive Income (Loss) (Detail) - CAD ($) $ in Millions		12 Months Ended
		Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Reclassification Adjustment out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of postretirement benefits liability adjustment included in net periodic benefit cost	[1]	$ (180)	$ (148)	$ (185)

[1] This accumulated other comprehensive income component is included in the computation of net periodic benefit cost (note 5).

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Income Tax Expense (Credit) for Components of Other Comprehensive Income (Loss) (Detail) - CAD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Accumulated Other Comprehensive Income (Loss) [Line Items]
Postretirement benefits liability adjustment (excluding amortization)	$ (69)	$ (165)	$ 59
Amortization of postretirement benefits liability adjustment included in net periodic benefit cost	46	37	45
Total	$ (23)	$ (128)	$ 104