UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 40-F
(Check One)
o |
Registration statement pursuant to Section 12 of the Securities Exchange Act of 1934 | |
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or | |
ý |
Annual report pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934 |
For fiscal year ended:
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December 31, 2019
No. 1-12384 |
SUNCOR ENERGY INC.
(Exact name of registrant as specified in its charter)
Canada
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1311,1321,2911,
4613,5171,5172 (Primary standard industrial classification code number, if applicable) |
98-0343201
(I.R.S. employer identification number, if applicable) |
150 - 6th Avenue S.W.
P.O. Box 2844
Calgary, Alberta, Canada T2P 3E3
(403) 296-8000
(Address and telephone number of registrant's principal executive office)
CT Corporation System
28 Liberty St.
New York, New York 10005
(212) 894-8940
(Name, address and telephone number of agent for service in the United States)
Securities registered pursuant to Section 12(b) of the Act:
Title of each class: |
Trading Symbol(s): |
Name of each exchange on
which registered: |
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Common shares |
SU |
New York Stock Exchange |
Securities registered or to be registered pursuant to Section 12(g) of the Act:
None
Securities for which there is a reporting obligation pursuant to Section 15(d) of the Act:
None
For annual reports, indicate by check mark the information filed with this form:
ý |
Annual Information Form | ý | Annual Audited Financial Statements |
Indicate the number of outstanding shares of each of the issuer's classes of capital or common stock as of the close of the period covered by the annual report:
Common Shares |
As of December 31, 2019 there were
1,531,873,743 Common Shares issued and outstanding |
Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Exchange Act 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 |
ý | No | o |
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 (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).
Yes |
ý | No | o |
Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 12b-2 of the Exchange Act.
Emerging growth company o
If an emerging growth company that prepares its financial statements in accordance with U.S. GAAP, 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. o
This annual report on Form 40-F is incorporated by reference into and as an exhibit to, as applicable, each of the following Registration Statements of the Registrant under the Securities Act of 1933: Form S-8 (File No. 333-87604), Form S-8 (File No. 333-112234), Form S-8 (File No. 333-118648), Form S-8 (File No. 333-124415), Form S-8 (File No. 333-149532), Form S-8 (File No. 333-161021) and Form S-8 (File No. 333-161029). The Registrant's Annual Information Form dated February 26, 2020, included in this annual report on Form 40-F, and Audited Consolidated Financial Statements and Management's Discussion and Analysis for the year ended December 31, 2019, included as Exhibit 99-1 and Exhibit 99-2, respectively, to this annual report on Form 40-F, are incorporated by reference into and as an exhibit to, as applicable, the Registrant's Registration Statement on Form F-10 (File No. 333- 225338).
ANNUAL INFORMATION FORM DATED FEBRUARY 26, 2020
TABLE OF CONTENTS
1 | Advisories | |
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2 | Glossary of Terms and Abbreviations | |
2 | Common Industry Terms | |
4 | Common Abbreviations | |
4 | Conversion Table | |
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5 | Corporate Structure | |
5 | Name, Address and Incorporation | |
5 | Intercorporate Relationships | |
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6 | General Development of the Business | |
6 | Overview | |
7 | Three-Year History | |
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10 | Narrative Description of Suncor's Businesses | |
10 | Oil Sands | |
15 | Exploration and Production | |
19 | Refining and Marketing | |
23 | Other Suncor Businesses | |
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24 | Suncor Employees | |
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24 | Ethics, Social and Environmental Policies | |
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26 | Statement of Reserves Data and Other Oil and Gas Information | |
28 | Oil and Gas Reserves Tables and Notes | |
33 | Future Net Revenues Tables and Notes | |
39 | Additional Information Relating to Reserves Data | |
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51 | Industry Conditions | |
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59 | Risk Factors | |
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70 | Dividends | |
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71 | Description of Capital Structure | |
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73 | Market for Securities | |
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74 | Directors and Executive Officers | |
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80 | Audit Committee Information | |
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82 | Legal Proceedings and Regulatory Actions | |
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82 | Interests of Management and Others in Material Transactions | |
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82 | Transfer Agent and Registrar | |
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82 | Material Contracts | |
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82 | Interests of Experts | |
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83 | Disclosure Pursuant to the Requirements of the NYSE | |
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83 | Additional Information | |
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84 | Advisory Forward-Looking Information and Non-GAAP Financial Measures | |
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Schedules | ||
A-1 | SCHEDULE "A" AUDIT COMMITTEE MANDATE | |
B-1 | SCHEDULE "B" SUNCOR ENERGY INC. POLICY AND PROCEDURES FOR PRE-APPROVAL OF AUDIT AND NON-AUDIT SERVICES | |
C-1 | SCHEDULE "C" FORM 51-101F2 REPORT ON RESERVES DATA BY INDEPENDENT QUALIFIED RESERVES EVALUATOR OR AUDITOR | |
D-1 | SCHEDULE "D" FORM 51-101F2 REPORT ON RESERVES DATA BY INDEPENDENT QUALIFIED RESERVES EVALUATOR OR AUDITOR | |
E-1 | SCHEDULE "E" FORM 51-101F3 REPORT OF MANAGEMENT AND DIRECTORS ON RESERVES DATA AND OTHER INFORMATION |
In this Annual Information Form (AIF), references to "Suncor" or "the company" mean Suncor Energy Inc., its subsidiaries, partnerships and joint arrangements (including those identified in Note 27 of the company's 2019 audited Consolidated Financial Statements), unless the context otherwise requires. References to the "Board of Directors" or the "Board" mean the Board of Directors of Suncor Energy Inc.
All financial information is reported in Canadian dollars, unless otherwise noted. Production volumes are presented on a working-interest basis, before royalties, unless otherwise noted. Libyan production volumes are presented on an economic basis.
References to the 2019 audited Consolidated Financial Statements mean Suncor's audited Consolidated Financial Statements prepared in accordance with Canadian generally accepted accounting principles (GAAP), which is within the framework of International Financial Reporting Standards (IFRS), the notes thereto and the auditor's report thereon, as at and for each year in the two-year period ended December 31, 2019. References to the MD&A mean Suncor's Management's Discussion and Analysis, dated February 26, 2020.
This AIF contains forward-looking statements based on Suncor's current plans, expectations, estimates, projections and assumptions. This information is subject to a number of risks and uncertainties, including those discussed in this document in the Risk Factors section, many of which are beyond the company's control. Users of this information are cautioned that actual results may differ materially. Refer to the Advisory Forward-Looking Information and Non-GAAP Financial Measures section of this AIF for information regarding risk factors and material assumptions underlying the forward-looking statements.
Information contained in or otherwise accessible through Suncor's website www.suncor.com does not form a part of this AIF and is not incorporated into this AIF by reference.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 1
GLOSSARY OF TERMS AND ABBREVIATIONS
Common Industry Terms
Products
Crude oil is a mixture, consisting mainly of pentanes and heavier hydrocarbons, that exists in the liquid phase in reservoirs and remains liquid at atmospheric pressure and temperature. Crude oil may contain small amounts of sulphur and other non-hydrocarbons, but does not include liquids obtained in the processing of natural gas.
Bitumen is a naturally occurring solid or semi-solid hydrocarbon, consisting mainly of heavier hydrocarbons that are too heavy or thick to flow or be pumped without being diluted or heated, and that is not primarily recoverable at economic rates through a well without the implementation of enhanced recovery methods. After it is extracted, bitumen may be upgraded into crude oil and other petroleum products.
Light crude oil is crude oil with a relative density greater than 31.1 degrees API gravity.
Medium crude oil is crude oil with a relative density greater than 22.3 degrees API gravity and less than or equal to 31.1 degrees API gravity.
Heavy crude oil is crude oil with a relative density greater than 10.0 degrees API gravity and less than or equal to 22.3 degrees API gravity.
Synthetic crude oil (SCO) is a mixture of liquid hydrocarbons derived by upgrading bitumen and may contain sulphur or other non-hydrogen compounds. SCO with lower sulphur content is referred to as sweet synthetic crude oil, while SCO with higher sulphur content is referred to as sour synthetic crude oil.
Natural gas is a mixture of lighter hydrocarbons that exist either in the gaseous phase or in solution in crude oil in reservoirs but are gaseous at atmospheric conditions. Natural gas may contain sulphur or other non-hydrocarbon compounds.
Conventional natural gas is natural gas that occurs in a normal, porous, permeable reservoir rock and that, at a particular time, can be technically and economically produced using normal production practices.
Natural gas liquids (NGLs) are hydrocarbon components that can be recovered from natural gas as liquids, including, but not limited to, ethane, propane, butanes, pentanes plus, condensate, and small quantities of non-hydrocarbons. Liquefied petroleum gas (LPG) consists predominantly of propane and/or butane and, in Canada, frequently includes ethane.
Oil and gas exploration and development terms
Development costs are costs incurred to obtain access to reserves and to provide facilities for extracting, treating, gathering and storing oil and gas from reserves.
Exploration costs are costs incurred in identifying areas that may warrant examination and in examining specific areas that are considered to have prospects that may contain oil and gas reserves, including costs of drilling exploratory wells and exploratory-type stratigraphic test wells.
Field is a defined geographical area consisting of one or more pools containing hydrocarbons.
Oil sands are deposits of sand, sandstone or other sedimentary rocks that contain crude bitumen.
Reservoir is a subsurface rock unit that contains a potentially recoverable accumulation of petroleum.
Wells
Appraisal wells are drilled into a discovered hydrocarbon accumulation to further understand the extent and size of the accumulation.
Cuttings reinjection wells are drilled for the safe disposal of drilling waste, including drill cuttings, mud slurry, old drilling fluids and waste water, in order to minimize the environmental impact.
Delineation wells are drilled to define the extent of known accumulations of petroleum for the assignment of reserves. This includes wells drilled for the purpose of assessing the stratigraphy, structure and bitumen saturation of an oil sands lease.
Development wells are drilled inside the established limits of an oil or gas reservoir, or in close proximity to the edge of the reservoir, to the depth of a stratigraphic horizon known to be productive.
Disposal wells are drilled in areas where excess fluids from operations can be safely injected for safe disposal. The fluid is pumped into a subsurface formation sealed off from other formations by impervious strata of rock. These wells are operated within limits approved by the appropriate regulatory bodies.
Dry holes are exploratory or development wells found to be incapable of producing either oil or gas in sufficient quantities to justify the completion as an oil or gas well.
Exploratory wells are drilled with the intention of discovering commercial reservoirs or deposits of crude oil and/or natural gas.
2 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Infill wells are drilled within a known accumulation of petroleum, between existing development wells, to target regions of the reservoir containing bypassed hydrocarbons or to accelerate production.
Observation wells are used to monitor changes in a producing field. Parameters being monitored may include fluid saturations, temperature or reservoir pressure.
Service wells are development wells drilled or completed for the purpose of supporting production in an existing field, such as wells drilled for the purpose of injecting gas, steam or water, or observation wells.
Stratigraphic test wells are usually drilled without the intention of being completed for production and are geologically directed to obtain information pertaining to a specific geologic condition, such as core hole drilling or delineation wells on oil sands leases, or to measure the commercial potential (i.e., size and quality) of a discovery, such as appraisal wells for offshore discoveries.
Production terms
Crude feedstock generally refers either to (i) the bitumen required in the production of SCO for the company's oil sands operations, or (ii) crude oil and/or other components required in the production of refined petroleum products for the company's downstream operations.
Diluent is a light hydrocarbon mixture used to blend with bitumen or heavy crude oil to reduce its viscosity so that it can be transported by pipeline.
Downstream refers to the refining of crude oil and the distribution and selling of refined products in retail and wholesale channels.
Extraction refers to the process of separating bitumen from oil sands.
Froth treatment refers to the process of adding a light hydrocarbon to bitumen froth produced in the extraction process in order to separate the bitumen from the water and fine solids in the bitumen froth.
In situ refers to methods of extracting bitumen from oil sands other than by surface mining.
Midstream refers to transportation, storage and wholesale marketing of crude or refined petroleum products.
Overburden is the material overlying oil sands that must be removed before mining. Overburden is removed on an ongoing basis to continually expose the ore.
Paraffinic froth treatment (PFT) refers to a froth treatment process whereby a lighter diluent or solvent that contains paraffin is used, which provides the capability to selectively remove some of the asphaltines (the highest carbon component of the barrel) from the final product. This results in a lower carbon, higher quality bitumen that can be sold directly to market without further upgrading.
Production sharing contracts (PSCs) are a common type of contract, outside North America, signed between a government and a resource extraction company that states how much of the resource produced each party will receive and which parties are responsible for the development of the resource and operation of associated facilities. The resource extraction company does not obtain title to the product; however, the company is subject to the upstream risks and rewards. An exploration and production sharing agreement (EPSA) is a form of PSC, which also states which parties are responsible for exploration activities.
Steam-assisted gravity drainage (SAGD) is an enhanced oil recovery technology for producing bitumen. It requires drilling pairs of horizontal wells with one located above the other. To help reduce land disturbance and improve cost efficiency, well pairs are drilled from multi-well pads. Low pressure steam is injected into the upper wellbore to heat the bitumen. This process reduces the viscosity of the bitumen, allowing heated bitumen and condensed steam to drain into the lower wellbore and flow up to the surface aided by subsurface pumps or circulating gas.
Steam-to-oil ratio (SOR) is a metric used to quantify the efficiency of an in situ oil recovery process, which measures the cubic metres of water (converted to steam) required to produce one cubic metre of oil. A lower ratio indicates more efficient use of steam.
Upgrading is the two-stage process by which bitumen is converted into SCO.
Primary upgrading, also referred to as coking or thermal cracking, heats the bitumen in coke drums to remove excess carbon. The superheated hydrocarbon vapours are sent to fractionators where they condense into naphtha, kerosene and gas oil. Carbon residue, or coke, is removed from the coke drums periodically and later sold as a byproduct.
Secondary upgrading, a purification process also referred to as hydrotreating, adds hydrogen to, and reduces the sulphur and nitrogen of, primary upgrading output to create sweet SCO and diesel.
Upstream refers to the exploration, development and production of crude oil, bitumen or natural gas.
Reserves
Please refer to the Definitions for Reserves Data Tables section of the Statement of Reserves Data and Other Oil and Gas Information in this AIF.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 3
Common Abbreviations
The following is a list of abbreviations that may be used in this AIF:
Measurement | ||
bbl(s) | barrel(s) | |
bbls/d | barrels per day | |
mbbls | thousands of barrels | |
mbbls/d | thousands of barrels per day | |
mmbbls | millions of barrels | |
mmbbls/d | millions of barrels per day | |
boe | barrels of oil equivalent | |
boe/d | barrels of oil equivalent per day | |
mboe | thousands of barrels of oil equivalent | |
mboe/d | thousands of barrels of oil equivalent per day | |
mmboe | millions of barrels of oil equivalent | |
mmboe/d | millions of barrels of oil equivalent per day | |
mcf | thousands of cubic feet of natural gas | |
mcf/d | thousands of cubic feet of natural gas per day | |
mcfe | thousands of cubic feet of natural gas equivalent | |
mmcf | millions of cubic feet of natural gas | |
mmcf/d | millions of cubic feet of natural gas per day | |
mmcfe | millions of cubic feet of natural gas equivalent | |
mmcfe/d | millions of cubic feet of natural gas equivalent per day | |
bcf | billions of cubic feet of natural gas | |
bcfe | billions of cubic feet of natural gas equivalent | |
GJ | gigajoules | |
mmbtu | millions of British thermal units | |
API | American Petroleum Institute | |
CO2 | carbon dioxide | |
CO2e | carbon dioxide equivalent | |
m3 | cubic metres | |
m3/d | cubic metres per day | |
m3/s | cubic metres per second | |
km | kilometres | |
MW | Megawatts | |
GWh | Gigawatt hours | |
Mt | Megatonnes | |
Places and Currencies |
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U.S. | United States | |
U.K. | United Kingdom | |
B.C. | British Columbia | |
$ or Cdn$ | Canadian dollars | |
US$ | United States dollars | |
£ | Pounds sterling | |
€ | Euros | |
Products, Markets and Processes |
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WTI | West Texas Intermediate | |
WCS | Western Canadian Select | |
NGL(s) | natural gas liquid(s) | |
LPG | liquefied petroleum gas | |
SCO | synthetic crude oil | |
NYMEX | New York Mercantile Exchange | |
TSX | Toronto Stock Exchange | |
NYSE | New York Stock Exchange |
Suncor converts certain natural gas volumes to boe, boe/d, mboe, mboe/d and mmboe on the basis of six mcf to one boe. Any figure presented in boe, boe/d, mboe, mboe/d or mmboe may be misleading, particularly if used in isolation. A conversion ratio of six mcf of natural gas to one bbl of crude oil or NGLs is based on an energy equivalency conversion method primarily applicable at the burner tip and does not necessarily represent value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, conversion on a 6:1 basis may be misleading as an indication of value.
Conversion Table(1)(2)
1 m3 liquids = 6.29 barrels | 1 tonne = 0.984 tons (long) | |
1 m3 natural gas = 35.49 cubic feet | 1 tonne = 1.102 tons (short) | |
1 m3 overburden = 1.31 cubic yards | 1 kilometre = 0.62 miles | |
1 hectare = 2.5 acres |
4 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
CORPORATE STRUCTURE
Name, Address and Incorporation
Suncor Energy Inc. (formerly Suncor Inc.) was originally formed by the amalgamation under the Canada Business Corporations Act (the CBCA) on August 22, 1979 of Sun Oil Company Limited, incorporated in 1923, and Great Canadian Oil Sands Limited, incorporated in 1953. On January 1, 1989, the company further amalgamated with a wholly owned subsidiary under the CBCA. The company amended its articles in 1995 to move its registered office from Toronto, Ontario, to Calgary, Alberta, and again in April 1997 to adopt the name, "Suncor Energy Inc." In April 1997, May 2000, May 2002, and May 2008, the company amended its articles to divide its issued and outstanding shares on a two-for-one basis.
Pursuant to an arrangement under the CBCA, which was completed effective August 1, 2009, Suncor amalgamated with Petro-Canada to form a single corporation continuing under the name "Suncor Energy Inc." On January 1, 2017, Suncor amalgamated with certain of its wholly owned subsidiaries under the CBCA.
Suncor's
registered and head office is located at
150 6th Avenue S.W., Calgary, Alberta, T2P 3E3.
Intercorporate Relationships
Material subsidiaries, each of which is wholly owned, either directly or indirectly, by the company as at December 31, 2019, are shown below:
Name |
Jurisdiction
Where Organized |
Description | |||
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Canadian operations | |||||
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Suncor Energy Oil Sands Limited Partnership | Alberta | This partnership holds most of the company's Oil Sands operations assets. | |||
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Suncor Energy Products Partnership | Alberta | This partnership holds substantially all of the company's Canadian refining and marketing assets. | |||
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Suncor Energy Marketing Inc. | Alberta | Through this subsidiary, production from the upstream Canadian businesses is marketed. This subsidiary also administers Suncor's energy trading activities and power business, markets certain third-party products, procures crude oil feedstock and natural gas for its downstream business, and procures and markets natural gas liquids (NGLs) and liquefied petroleum gas (LPG) for its downstream business. | |||
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Suncor Energy Ventures Corporation | Alberta | A subsidiary which indirectly owns a 36.74% ownership in the Syncrude joint operation. | |||
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Suncor Energy Ventures Partnership | Alberta | A subsidiary which owns a 22% ownership in the Syncrude joint operation. | |||
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U.S. operations | |||||
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Suncor Energy (U.S.A.) Marketing Inc. | Delaware | A subsidiary that procures and markets third-party crude oil, in addition to procuring crude oil feedstock for the company's refining operations. | |||
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Suncor Energy (U.S.A.) Inc. | Delaware | A subsidiary through which the company's U.S. refining and marketing operations are conducted. | |||
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International operations | |||||
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Suncor Energy UK Limited | U.K. | A subsidiary through which the majority of the company's North Sea operations are conducted. | |||
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The company's remaining subsidiaries each accounted for (i) less than 10% of the company's consolidated assets as at December 31, 2019, and (ii) less than 10% of the company's consolidated operating revenues for the fiscal year ended December 31, 2019. In aggregate, the remaining subsidiaries accounted for less than 20% of the company's consolidated assets as at December 31, 2019, and less than 20% of the company's consolidated operating revenues for the fiscal year ended December 31, 2019.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 5
GENERAL DEVELOPMENT OF THE BUSINESS
Overview
Suncor is an integrated energy company headquartered in Calgary, Alberta, Canada. The company is strategically focused on developing one of the world's largest petroleum resource basins Canada's Athabasca oil sands. In addition, Suncor explores for, acquires, develops, produces and markets crude oil in Canada and internationally; the company transports and refines crude oil, and markets petroleum and petrochemical products primarily in Canada. Suncor also operates a renewable energy business and conducts energy trading activities focused principally on the marketing and trading of crude oil, natural gas, byproducts, refined products, and power.
Suncor has classified its operations into the following segments:
OIL SANDS
Suncor's Oil Sands segment, with assets located in the Athabasca oil sands of northeast Alberta, recovers bitumen from mining and in situ operations. Bitumen is either upgraded into SCO for refinery feedstock and diesel fuel, or blended with diluent for direct sale to market through the company's midstream infrastructure and its marketing activities. The Oil Sands segment includes:
EXPLORATION AND PRODUCTION
Suncor's Exploration and Production (E&P) segment consists of offshore operations off the east coast of Canada and in the North Sea, and onshore assets in Libya and Syria.
6 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
REFINING AND MARKETING
Suncor's Refining and Marketing segment consists of two primary operations, the refining and supply and marketing operations discussed below, as well as the infrastructure supporting the marketing and supply of refined products, crude oil, natural gas, power and byproducts.
CORPORATE AND ELIMINATIONS
The Corporate and Eliminations segment includes the company's investments in renewable energy projects and other activities not directly attributable to any other operating segment. Beginning in the first quarter of 2019, results from the company's Energy Trading business have been included within each of the respective reporting business segments to which the respective trading activity relates. The Energy Trading business was previously reported within the Corporate, Energy Trading and Eliminations segment.
Three-Year History
Over the last three years, several events have influenced the general development of Suncor's business.
2017
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 7
2018
8 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
technologies, offer a number of advantages over existing truck and shovel operations, including enhanced safety performance, better operating efficiency and lower operating costs. Full implementation at Fort Hills and Millennium is expected to be completed in 2020 and 2023, respectively.
2019
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 9
NARRATIVE DESCRIPTION OF SUNCOR'S BUSINESSES
For a discussion of the environmental and other regulatory conditions, and competitive conditions and seasonal impacts affecting Suncor's segments, refer to the Industry Conditions and Risk Factors sections of this AIF.
Oil Sands
Oil Sands Operations Assets and Operations
Oil Sands Base Operations
Suncor's integrated Oil Sands Base operations, located in the Athabasca oil sands region of northeast Alberta, involve numerous activities:
After overburden is removed, open-pit mining operations use shovels to excavate oil sands bitumen ore, which is trucked to sizers and breaker units that reduce the size of the ore. Next, a slurry of hot water, sand and bitumen is created and delivered via a pipeline to extraction plants. The raw bitumen is separated from the slurry using a hot water process that creates a bitumen froth. Naphtha is added to the bitumen froth to form a diluted bitumen, which is subsequently sent to a centrifuge plant that removes most of the remaining impurities and minerals. Coarse tailings produced in this process are placed directly into sand placement areas.
After the diluted bitumen is transferred to upgrading facilities, the naphtha is removed and recycled to be used again as diluent in the extraction processes. Bitumen is upgraded through a coking and distillation process. The upgraded product, referred to as sour SCO, is either sold to market or upgraded further into sweet SCO by removing sulphur and nitrogen using a hydrotreating process. In addition to sweet and sour SCO, upgrading processes also produce ultra-low sulphur diesel fuel and other byproducts.
To generate steam for the mining and extraction process, the company uses either a cogeneration unit or coke-fired boilers. Electricity is generated by turbine generators, most of which are part of the Oil Sands Base cogeneration unit, or provided by cogeneration units at Firebag. Process water is used in extraction processes and then recycled.
Suncor regularly conducts planned maintenance events at its facilities. Large planned maintenance events that require units to be taken offline to be completed are often referred to as turnarounds. Turnaround maintenance provides opportunities for both preventive maintenance and capital replacement, which are expected to improve reliability and operational efficiency. Planned maintenance events generally occur on routine cycles, determined by historical operating performance, recommended usage factors or regulatory requirements. A turnaround typically involves shutting down the unit, inspecting it for wear or other damage, repairing or replacing components, and then restarting the unit. Production levels and product mix are typically impacted during these activities.
Mining processes disturb areas of land that must be reclaimed. Land reclamation activities involve soil salvage and replacement, wetlands research, the protection of fish, waterfowl and other wildlife, and re-vegetation.
Oil sands tailings are the remaining sand, water, clay, silt and residual hydrocarbons left after the majority of hydrocarbons are extracted from the ore during the water-based bitumen extraction process. Suncor's updated and approved tailings management plan involves an increase in treatment capacity using accelerated dewatering and treatment of mature fine tailings at Oil Sands Base, including the construction of a Permanent Aquatic Storage Structure (PASS). This approach is supported by the construction, operation and ongoing monitoring of a Demonstration Pit Lake, and aligns with the Government of Alberta's Tailings Management Framework (TMF) and the Alberta Energy Regulator's (AER) Directive 085 Fluid Tailings Management for Oil Sands Mining Projects (the Tailings Directive).
Oil Sands Base Assets
Millennium and North Steepbank
Suncor pioneered the commercial development of the Athabasca oil sands beginning in 1962, achieving first production in 1967. Bitumen is currently mined from the Millennium area, which began production in 2001, and the North Steepbank area, which began production in 2011. During 2019, the company mined approximately 159 million tonnes of bitumen ore (2018 138 million tonnes) and processed an average of 290 mbbls/d of mined bitumen in its extraction facilities (2018 259 mbbls/d).
The company expects to file a regulatory application within the first quarter of 2020 to potentially replace Suncor's Millennium and North Steepbank mines as they reach the end of their useful life in approximately 2035. The application is not a project sanction and a final sanctioning decision is not expected until 2030 at the earliest.
10 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Upgrading Facilities
Suncor's upgrading facilities consist of two upgraders: Upgrader 1, which has capacity of approximately 110 mbbls/d of SCO, and Upgrader 2, which has capacity of approximately 240 mbbls/d of SCO. Suncor's secondary upgrading facilities consist of three hydrogen plants, three naphtha hydrotreaters, two gas oil hydrotreaters, one diesel hydrotreater, and one kerosene hydrotreater.
In the third quarter of 2019, Suncor announced that it is replacing its coke-fired boilers with a new 800 MW cogeneration facility at Oil Sands Base. The project is expected to provide reliable steam generation required for Suncor's extraction and upgrading operations and is expected to reduce the GHG emissions intensity associated with steam production at Oil Sands Base by approximately 25%. In addition, the electricity produced will be transmitted to Alberta's power grid, providing reliable, baseload, low-carbon electricity, equivalent to approximately 8% of Alberta's current electricity demand. In total, this project will reduce the GHG emissions in the province of Alberta by approximately 2.5 Mt per year. The project is estimated to cost approximately $1.4 billion with an expected in-service date in the second half of 2023.
During 2019, Suncor averaged 313 mbbls/d of upgraded (SCO and diesel) production net of the company's internal consumption (2018 280 mbbls/d), mainly sourced from bitumen provided by both Oil Sands Base and In Situ operations.
Other Mining Leases
Suncor, directly and indirectly, owns interests in several other mineable oil sands leases, including Voyageur South and Audet. Suncor undertakes exploratory drilling programs on such leases from time to time as part of its mine replacement projects. Suncor holds a 100% working interest in both Voyageur South and Audet.
In Situ Operations
Suncor's In Situ operations at Firebag and MacKay River use SAGD technology to produce bitumen from oil sands deposits that are too deep to be mined.
SAGD is an enhanced oil recovery technology for producing bitumen. It requires drilling pairs of horizontal wells with one located above the other. To help reduce land disturbance and improve cost efficiency, well pairs are drilled from multi-well pads. Low pressure steam is injected into the upper wellbore to create a high-temperature steam chamber underground. This process reduces the viscosity of the bitumen, allowing the heated bitumen and condensed steam to drain into the lower wellbore and flow up to the surface aided by subsurface pumps or circulating gas.
The bitumen and water mixture is pumped to separation units at central processing facilities, where the water is removed from the bitumen, treated and recycled for use in steam generation. To facilitate shipment, In Situ operations blend diluent with the bitumen, or transport it through an insulated pipeline as hot bitumen.
To generate steam for operations, the company uses Once Through Steam Generators (OTSGs) or cogeneration units. OTSGs are fuelled by both purchased natural gas and produced natural gas recovered at central processing facilities. Cogeneration units are energy-efficient systems, which use natural gas combustion to power turbines that generate electricity and steam used in SAGD operations. Excess electricity generation from cogeneration units is used at Oil Sands Base facilities or sold to the Alberta power grid.
Central processing facilities, steam generation units and well pads are all subject to routine inspection and maintenance cycles.
SAGD production volumes are impacted by reservoir characteristics and the capacity of central processing facilities and steam generation units to process liquids and generate steam. As with conventional oil and gas properties, SAGD wells experience natural production declines after several years. In an effort to maintain bitumen supply, Suncor drills new well pairs from existing well pads or constructs new well pads to facilitate future well pair drilling and production.
In Situ Assets
Firebag
Production from Suncor's Firebag operations commenced in 2004. The Firebag complex has central processing facilities with a total capacity of 203 mbbls/d. Actual production from Firebag varies based on steaming and ramp-up periods for new wells, planned and unplanned maintenance, reservoir conditions and other factors.
As at December 31, 2019, Firebag had 17 well pads in operation, with 242 SAGD well pairs and 52 infill wells either producing or on initial steam injection. Central processing facilities have been designed to be flexible as to which well pads supply bitumen. Steam generated at the various facilities can be used at multiple well pads. In addition, Firebag includes five cogeneration units that generate steam, which are capable of producing approximately 474 MW of electricity. The Firebag site power load requirements are approximately 116 MW and, in 2019, Firebag exported approximately 285 MW of electricity to the Alberta power
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 11
grid and Oil Sands Base. There are also 13 OTSGs at the site for additional steam generation.
During 2019, Firebag production averaged 187 mbbls/d (2018 204 mbbls/d) with a SOR of 2.7 (2018 2.7). Production in 2019 was impacted by mandatory production curtailment.
Suncor has identified opportunities to debottleneck Firebag, including the completion of an emulsion handling project, an integrated well pad development and expansion of the company's Solvent SAGD program which could potentially add up to an additional 30 mbbls/d above nameplate capacity by 2024-25.
MacKay River
Production from Suncor's MacKay River operations commenced in 2002. The MacKay River central processing facilities have a bitumen processing capacity of 38 mbbls/d. As at December 31, 2019, MacKay River included seven well pads with 114 well pairs either producing or on initial steam injection. A third party owns the on-site cogeneration unit, which Suncor operates under a commercial agreement that generates steam and electricity. There are also four OTSGs at the site for additional steam generation.
During 2019, MacKay River production averaged 29 mbbls/d (2018 36 mbbls/d) with a SOR of 2.95 (2018 2.90). Production in 2019 was impacted by mandatory production curtailment. Following an outage in late 2019, MacKay River is expected to return to normal operations early in the second quarter of 2020. This follows completion of planned maintenance which has been accelerated to the first quarter of 2020 to coincide with the outage in an effort to minimize the impacts to annual production.
Other In Situ Leases
Suncor owns and operates several other oil sands leases which may support future in situ production, including Lewis, Meadow Creek, OSLO, Chard and Kirby. Suncor holds a 100% working interest in Lewis, a 75% working interest in Meadow Creek, a 77.78% working interest in OSLO, interests varying from 25% to 50% in Chard, and a non-operated interest in Kirby (10%). In 2018, Suncor acquired a 100% working interest in leases within the Gregoire area adjacent to its Meadow Creek lands. Meadow Creek is a SAGD project that is part of Suncor's planned in situ replication strategy. Suncor holds a 75% interest and is operator of the project, located approximately 40 km south of Fort McMurray. Meadow Creek consists of two independent In Situ projects: Meadow Creek East and Meadow Creek West.
In early 2017, Suncor received AER approval for the Meadow Creek East project. The project is expected to be developed in two stages with anticipated gross production of 40 mbbls/d up to 80 mbbls/d.
In early 2020, Suncor received AER approval for the Meadow Creek West project. Meadow Creek West is expected to be developed in a single stage and has an anticipated gross production capacity of 40 mbbls/d. Timing of project sanction for Meadow Creek East and West will depend on future market conditions.
In February 2018, Suncor submitted an application for the Lewis project to the AER. Lewis is a SAGD project and is also part of Suncor's planned in situ replication strategy. Suncor holds a 100% interest in the project, located approximately 25 km northeast of Fort McMurray. The project is expected to be developed in stages, with anticipated peak production of 160 mbbls/d. Timing of project sanction for Lewis will depend on future market conditions.
Fort Hills
Fort Hills is an oil sands mining area comprising leases on the east side of the Athabasca River, north of Oil Sands Base operations. Fort Hills operations are substantially similar to those of Suncor's Oil Sands Base assets; however, Fort Hills uses a PFT process to produce a marketable bitumen product that is partially decarbonized, resulting in a higher quality bitumen requiring less diluent and eliminating the need for on-site upgrading facilities.
Suncor holds a 54.11% working interest in Fort Hills and is the operator of the asset. Fort Hills began producing PFT bitumen from secondary extraction in early 2018. Fort Hills has a nameplate capacity of 194 mbbls/d (gross) of bitumen (105 mbbls/d, net to Suncor). During 2019, Suncor's share of Fort Hills production averaged 85.3 mbbls/d (2018 67.4 mbbls/d) from approximately 51.3 million tonnes of bitumen ore mined (2018 38.9 million tonnes). Production in 2019 was impacted by mandatory production curtailment.
Due to a decline in forecasted heavy crude oil prices the company recorded an after-tax impairment charge of $2.803 billion on its share of Fort Hills in the fourth quarter of 2019.
Syncrude
Suncor holds a 58.74% interest in the Syncrude joint operation, which has gross bitumen conversion to SCO capacity of 350 mbbls/d (206 mbbls/d, net to Suncor). Syncrude began producing in 1978 and is operated by Syncrude Canada Ltd. (SCL). In 2006, SCL entered into a Management Services Agreement (MSA) with Imperial Oil Resources Limited (Imperial Oil) to provide business services. Imperial Oil provided notice of termination of the MSA in 2019 and the parties to the joint operation are working on a transition plan to cover the business services as provided by Imperial Oil under the MSA. The project is located near Fort McMurray and includes mining operations at Mildred Lake and Aurora North. In 2012, the Syncrude joint operating partners announced a plan to develop two mining areas adjacent to the current mine, Mildred Lake West Extension (MLX-W) and Mildred Lake East Extension (MLX-E), which, subject to approvals, would consequently extend the life of Mildred Lake
12 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
by a minimum of 10 years. In 2015, a decision was made by the joint operating partners to progress with the MLX-W program. The MLX-E program is expected to follow MLX-W development if economic conditions prove suitable. The MLX-W program is expected to sustain bitumen production levels at the Mildred Lake site after resource depletion at the North Mine. The plan proposes to use existing mining and extraction facilities. The Syncrude MLX-W mining area received AER approval in 2019 and remaining approvals are expected in 2020.
Suncor has been collaborating with Syncrude for several years to achieve sustained reliability improvements and reduce costs. In January 2019, Suncor and SCL entered into a master business services agreement designed to enable Suncor to provide certain business services to SCL. The proximity of Syncrude to Oil Sands Base affords an opportunity for cost management and collaboration between the company and Syncrude in order to provide opportunities to optimize assets, including during periods of planned maintenance or interruption.
In 2018, Suncor reached a formal agreement with its Syncrude joint operation partners to build bi-directional interconnecting pipelines, which will connect Syncrude's Mildred Lake site and Suncor's Oil Sands Base operations. The pipelines are expected to provide increased operational flexibility through the ability to transfer bitumen and gas oils between the two plants, enabling higher reliability and utilization. The pipelines are expected to be in-service by the second half of 2020.
Syncrude mining operations use truck, shovel and pipeline systems, similar to those at Oil Sands Base. Extraction and upgrading technologies at Syncrude are similar to those used at Oil Sands Base, with the exception that Syncrude uses a fluid coking process that involves the continuous thermal cracking of the heaviest hydrocarbons. At Mildred Lake, electricity is provided by a utility plant fuelled by natural gas and rich fuel gas from upgrading operations. At Aurora North, Syncrude operates two cogeneration units which provide heat and power.
Syncrude produces a single sweet SCO product. Marketing of this product is the responsibility of the individual joint venture partners.
Land reclamation activities are similar to those at Oil Sands Base; however, certain aspects of the tailings management processes are different. Syncrude's tailings plan uses freshwater capping, a composite tails mixture of fine tails and gypsum, and centrifuge technology that separates water from tailings. The updated tailings management plans for Syncrude Aurora North and Syncrude Mildred Lake were approved by the AER in June 2018 and June 2019, respectively.
In 2019, Suncor's share of Syncrude production was limited by mandatory production curtailment, and averaged 172.3 mbbls/d (2018 144.2 mbbls/d). Since returning to normal operating rates in the third quarter of 2018 following a site-wide power outage in the second quarter of 2018, Syncrude has achieved reliable operations without any significant unplanned incidents. On October 29, 2019, Syncrude achieved a historic milestone, producing the three billionth (gross) barrel of crude oil at the Mildred Lake upgrading complex. Asset sustainment and maintenance capital expenditures in 2020 for Syncrude are expected to focus on a planned turnaround and reliability improvements.
Other Oil Sands Leases
Suncor indirectly owns interests in other mineable oil sands leases, including Mildred Lake West, Mildred Lake East, Lease 29, Lease 30 and Aurora South, through the company's 58.74% working interest in the Syncrude joint operation. During 2018, the company disposed of its previous 36.75% working interest in the Joslyn mining project.
New Technology
Technology is a fundamental component of Suncor's business. Suncor pioneered commercial oil sands development and continues to advance technology through innovation and collaboration to improve efficiencies, lower costs and increase environmental performance. Development of new technology can take extended periods of time, first to demonstrate technical feasibility and then to demonstrate commercial viability. The necessary validation typically occurs through a series of progressive steps which allow results to be reliably scaled and assessed for implementation.
Following a successful commercial-scale evaluation in 2018, the company began a phased implementation of AHS at its operated mine sites. Full implementation was completed at the North Steepbank mine in 2018, with full implementation at Fort Hills and Millennium is expected to be completed in 2020 and 2023, respectively. Autonomous haul trucks, which operate using GPS, wireless communication and perceptive technologies, have demonstrated an ability to maneuver safely, effectively and efficiently in Suncor's operating environment and offer a number of advantages over existing truck and shovel operations, including enhanced safety performance, better operating efficiency and lower operating costs. During 2019, the company moved a total of 48.5 million gross tonnes of ore and overburden (2018 39.5 million tonnes) with AHS.
In 2018, Suncor completed the implementation of PASS technology as part of the company's accelerated dewatering project. PASS enables the dewatering of fine tailings from existing tailings ponds and the eventual reclamation and closure of tailings ponds. PASS technology consists of a proprietary mixture of coagulants and flocculants that enable water release and sequestering of fine tailings. Drainage of the first pond, Pond 8B, using the PASS technology commenced in 2018. PASS is expected to treat Suncor's legacy and new fluid tailings inventory over the life
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 13
of mine operations. During 2019, PASS increased the company's tailings treatment capacity to 230% of total annual fluid tailings produced (2018 165%).
Suncor is also working on, or has completed, several new technology projects that are proceeding with the next phase of field testing. Examples of Suncor's new technology projects include:
Sales of Principal Products
Primary markets for SCO and bitumen production from Suncor's Oil Sands segment, including PFT bitumen from Fort Hills, include refining operations in Alberta, Ontario, Quebec, the U.S. Midwest and the U.S. Rocky Mountain regions, and markets on the U.S. Gulf Coast. Diesel production from upgrading operations is sold primarily in Western Canada and the United States.
For bitumen production from In Situ operations, Suncor's marketing strategy allows it to take advantage of changes in market conditions by either upgrading the bitumen at the company's Oil Sands Base facilities, refining diluted bitumen at Suncor's Edmonton refinery, or selling diluted bitumen to third parties. Increased bitumen sales may also be required during upgrading facility outages. In Situ bitumen production processed by Oil Sands Base upgrading facilities in 2019 increased to 116 mbbls/d or 54% (2018 106 mbbls/d or 44%) of total In Situ bitumen production as a result of mandatory production curtailment.
2019
|
2018
|
||||||||
|
|
||||||||
Sales Volumes and Operating Revenues Principal Products | mbbls/d |
% operating
revenues |
mbbls/d |
% operating
revenues |
|||||
|
|||||||||
SCO and diesel (including Syncrude) | 483.6 | 77 | 431.7 | 83 | |||||
|
|||||||||
Bitumen | 187.5 | 22 | 191.3 | 15 | |||||
|
|||||||||
Byproducts and other operating revenues(1) | n/a | 1 | n/a | 2 | |||||
|
|||||||||
671.1 | 623.0 | ||||||||
|
In the normal course of business, Suncor processes its proprietary sour SCO at the company's refineries or enters into long-term sales agreements for its proprietary sour SCO, which contain varying terms with respect to pricing, volume, expiry and termination.
Distribution of Products
Production from Oil Sands operations and Fort Hills, is gathered into Suncor's Fort McMurray facilities at the Athabasca Terminal, which is operated by Enbridge Inc. (Enbridge), or the East Tank Farm, which is operated by Suncor and connected to the Athabasca Terminal. Suncor has arrangements with Enbridge to store SCO, diluted bitumen and diesel at this facility. Product moves from the Athabasca Terminal in the following ways:
14 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
From Edmonton and Hardisty, where Suncor has both owned storage capacity and additional capacity under contract, the company has various options for delivering product to customers:
Production from Syncrude is moved to market via the Pembina Athabasca Oil Sands Pipeline.
Royalties
Oil Sands Royalties
Oil sands projects are subject to the royalty framework issued by the Government of Alberta (the Royalty Framework), and regulated by the Oil Sands Royalty Regulation 2009 (OSRR 2009) and supporting regulations, which were sanctioned in 2008. Under the Royalty Framework, royalties for oil sands projects are based on a sliding-scale rate of 25% to 40% of net revenue (net revenue royalty or NRR), subject to a minimum royalty within a range of 1% to 9% of gross revenue (gross revenue royalty or GRR). Revenues used in royalty formulas are driven primarily by benchmark prices for WCS, while sliding-scale percentages in royalty formulas depend on prices for WTI from Cdn$55/bbl for the minimum rate to the maximum rate at a WTI price of Cdn$120/bbl. A royalty project remains subject to the minimum royalty (the pre-payout phase) until the project's cumulative gross revenue exceeds its cumulative costs, including an annual investment allowance (the post-payout phase). During the post-payout phase, the annual royalty paid to the province is the greater of the GRR and NRR.
In 2019, Suncor incurred royalties at an average rate of 2% of gross revenue for Oil Sands Base (2018 1%) and at an average rate of 12% of gross revenue for Syncrude operations (2018 3%). Syncrude experienced a higher royalty rate in 2019 compared to the prior year due to a shift from GRR to NRR as a result of higher WCS prices. Oil Sands Base and the Syncrude project are both in the post-payout phase.
Fort Hills is subject to the same Royalty Framework as Oil Sands Base and Syncrude; however, Fort Hills is in the pre-payout phase. In 2019, Fort Hills incurred royalties at an average rate of 2% of gross revenue (2018 2%).
In 2019, Suncor incurred royalties for MacKay River, which is in the post-payout phase, at an average rate of 9% of gross revenue at the NRR (2018 14%), and royalties at an average rate of 3% of gross revenue for Firebag (2018 5%), which continues in the pre-payout phase.
Exploration and Production
E&P Canada Assets and Operations
East Coast Canada
Based in St. John's, Newfoundland and Labrador, this business includes interests in four producing fields and future developments and extensions. Suncor is also involved in exploration drilling for new opportunities. Suncor is the only company in this region with interests in every field currently in production.
Terra Nova
The Terra Nova oilfield is approximately 350 km southeast of St. John's. Terra Nova was discovered in 1984 and was the second oilfield to be developed offshore Newfoundland and Labrador. Operated by Suncor, the production system uses a Floating Production, Storage and Offloading (FPSO) vessel that is moored on location, and has gross production capacity of 180 mbbls/d (68 mbbls/d, net to Suncor) and oil storage capacity of 960 mbbls. Terra Nova was the first harsh environment development in North America to use a FPSO vessel. Actual annual production levels are lower than production capacity, reflecting current reservoir capability, including natural declines, gas and water injection and production limits, and asset and facility reliability. The Terra Nova oilfield is divided into three distinct areas, known as the Graben, the East Flank and the Far East. Production from Terra Nova began in January 2002. Drilling activities took place at Terra Nova throughout 2018 and 2019. As at December 31, 2019, there were 29 wells: 18 oil production wells, nine water injection wells and two gas injection wells. The Terra Nova ALE project is expected to commence in the second quarter of 2020 with the FPSO returning to service in the fourth quarter of 2020. Production at Terra Nova is planned to resume once the project is completed. The project is expected to extend the life of Terra Nova by approximately a decade.
In 2019, Suncor's share of Terra Nova production averaged 11.6 mbbls/d (2018 11.7 mbbls/d). Annual turnaround maintenance was completed at the Terra Nova facility in May 2019, which lasted approximately 10 days.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 15
Hibernia and the Hibernia Southern Extension Unit (HSEU)
The Hibernia oilfield, encompassing the Hibernia and Ben Nevis Avalon reservoirs, is approximately 315 km southeast of St. John's and was the first field to be developed in the Jeanne d'Arc Basin. Operated by Hibernia Management and Development Company Ltd., the production system is a fixed Gravity Based Structure (GBS) that sits on the ocean floor, and has gross production capacity of 230 mbbls/day (46 mbbls/d, net to Suncor) and oil storage capacity of 1,300 mbbls. Actual production levels are lower, reflecting current reservoir capability, including natural declines, gas and water injection and production limits, and asset and facility reliability. Hibernia commenced production in November 1997. As at December 31, 2019, there were 72 wells: 40 oil production wells, 26 water injection wells, five gas injection wells, and one water-alternating-gas injection well.
In 2010, final agreements were signed between the Hibernia co-venturers and the Government of Newfoundland and Labrador that established the fiscal, equity and operational principles for the development of the HSEU. At the end of 2019, there were eight oil production wells and nine water injection wells in the HSEU. The production wells were drilled from the GBS platform and are included in the Hibernia well count above. All nine of the water injection wells were drilled using a mobile offshore drill rig. Water for injection purposes is supplied from the GBS platform via a subsea flowline.
In 2019, Suncor's share of Hibernia production averaged 20.1 mbbls/d (2018 22.1 mbbls/d). Production in 2019 was impacted by an unplanned outage in the third quarter of 2019.
White Rose and the White Rose Extensions
White Rose is approximately 350 km southeast of St. John's. Operated by Husky Oil Operations Limited (Husky), White Rose uses a FPSO vessel and has gross production capacity of 140 mbbls/d (39 mbbls/d, net to Suncor) and oil storage capacity of 940 mbbls. Actual annual production levels are lower than production capacity, reflecting current reservoir capability, including natural declines, gas and water injection and production limits, and asset and facility reliability. Production from White Rose began in November 2005. As at December 31, 2019, there were 45 wells: 24 oil production wells, 16 water injection wells, three gas storage wells, and two gas injection wells.
In 2007, the White Rose co-venturers signed an agreement with the Government of Newfoundland and Labrador for the development of the White Rose Extensions, which include the North Amethyst, South White Rose Extension, and West White Rose satellite fields. First oil was achieved at North Amethyst in May 2010. Development of the South White Rose Extension began in 2013, with first oil being achieved in June 2015.
Development of the West White Rose field has been divided into two stages. The first stage was approved in 2010 and first oil was achieved in September 2011. The second stage, West White Rose Project (WWRP), was sanctioned during the second quarter of 2017, with first oil targeted for the end of 2022. The project is expected to extend the life of the existing White Rose assets, with Suncor's share of peak oil production estimated to be 20 mbbls/d. Major development activity began in 2018 and will continue in 2020. Due to increased capital cost estimates for the WWRP the company recorded an after-tax impairment charge of $393 million on its share of White Rose in the fourth quarter of 2019.
In 2019, Suncor's share of White Rose production averaged 4.7 mbbls/d (2018 6.6 mbbls/d). Turnaround maintenance was completed at White Rose in June 2019, which lasted approximately three weeks. Production at the White Rose field was shut in from mid-November 2018 to late January 2019 due to operational complications. White Rose began a staged return to normal operations, which was completed by the third quarter of 2019.
Hebron
The Hebron oilfield is located 340 km southeast of St. John's and is operated by ExxonMobil Canada Properties (ExxonMobil Canada). The development includes a concrete GBS that sits on the ocean floor and supports an integrated topsides deck used for production, drilling and accommodations. At peak, the Hebron project is expected to produce 31.6 mbbls/d, net to Suncor, ramping up over the next several years. Hebron has a gross oil storage capacity of 1,200 mbbls and 52 well slots. First oil was achieved in November 2017.
During 2019, drilling activities continued at Hebron and will continue throughout 2020. In 2019, Suncor's share of production averaged 23.5 mbbls/d (2018 13.0 mbbls/d). As at December 31, 2019, there were 15 wells: 10 oil production wells, three water injection wells, one gas injection well, and one cuttings reinjection well. Annual turnaround maintenance was completed at the Hebron facility in September 2019, which lasted approximately 10 days.
Other Assets
Suncor continues to pursue opportunities offshore Newfoundland and Labrador. During 2018, Suncor was the successful bidder on two exploration licences, including operatorship of one of the two licences, west of the Terra Nova field. In addition, Suncor became an interest holder, with Equinor Canada Ltd., in a licence east of the White Rose field. These licences carry work commitments from 2019 to 2024. The company also holds interests in 48 significant discovery licences and five exploration licences offshore in this area.
16 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
E&P International Assets and Operations
Offshore U.K. & Norway
Buzzard
The Buzzard oilfield is located in the Outer Moray Firth, 95 km northeast of Aberdeen, Scotland. Operated by CNOOC Petroleum Europe Limited (CNOOC Europe), a subsidiary of China National Offshore Oil Corporation Limited, the Buzzard facilities have gross installed production capacity of approximately 220 mbbls/d (66 mbbls/d, net to Suncor) of oil and 80 mmcf/d (24 mmcf/d, net to Suncor) of natural gas. Actual annual production levels are lower than production capacity, reflecting current reservoir capability, including natural declines, water injection limits, gas and water production limits, and asset and infrastructure reliability. Buzzard commenced production in January 2007 and consists of four bridge-linked platforms supporting wellhead facilities, production facilities, living quarters and utilities, as well as sulphur handling. Drilling activities took place at Buzzard during 2019 with two active rigs. Four new infill wells were drilled in 2019 and Buzzard Phase 2 drilling activities took place concurrently. As at December 31, 2019, there were 48 wells: 34 oil and gas production wells and 14 water injection wells. In 2019, Suncor's share of Buzzard production averaged 31.9 mboe/d (2018 34.2 mboe/d). Buzzard Phase 2 was sanctioned in 2018 with production anticipated in 2021. Project execution has progressed throughout 2019 and will be tied back to the existing Buzzard complex.
Golden Eagle Area Development (GEAD)
GEAD, which is operated by CNOOC Europe, is approximately 20 km north of the Buzzard oilfield and consists of the unitization of the Peregrine, Hobby, Golden Eagle and Solitaire discoveries. The development incorporates a production, utilities and accommodation platform, linked to a separate wellhead platform, with first oil achieved in October 2014. The facilities have gross production capacity of approximately 76 mboe/d (20 mboe/d, net to Suncor). As at December 31, 2019, there were 20 wells: 15 oil and gas production wells and five water injection wells. In 2019, Suncor's share of GEAD production averaged 9 mboe/d (2018 12.4 mboe/d).
Rosebank
The Rosebank future development project, in which Suncor has a 40% working interest, was discovered in December 2004 and is operated by Equinor U.K. Limited (Equinor). It is located approximately 130 km northwest of the Shetland Islands, in the U.K. North Sea, in water depths of approximately 1,100 metres. The project is currently in the pre-sanction phase with a sanction decision planned for late 2022.
Oda
The Oda field (PL405 licence) was discovered in 2011 and is located 13 km east of the producing Ula field in the southern part of the Norwegian North Sea. Spirit Energy is the operator and Suncor has a 30% working interest. Oda was sanctioned in November 2016. The field is a subsea tie-back to the Ula platform, with peak production expected to reach 35 mbbls/d (11 mbbls/d, net to Suncor). Drilling activities were completed in 2018, and first oil was achieved in March 2019. As at December 31, 2019, there were three wells: two production wells and one water injection well.
Fenja
In 2018, Suncor acquired a 17.5% participating interest in the Fenja development project (PL586 licence). The Fenja field, which was discovered in 2014 and is operated by Neptune Energy, is located approximately 30 km southwest of the Equinor-operated Njord field in the Norwegian Sea. The project was sanctioned by the owners in late 2017, and the plan for development and operation was approved by the Ministry of Petroleum and Energy in the first half of 2018. The field will be developed with two subsea templates with six wells tied back to the Equinor-operated Njord platform. First oil is planned for 2021, with peak production expected to reach 34 mbbls/d (6 mbbls/d, net to Suncor) between 2021 and 2022.
Other Assets
Suncor continues to pursue other opportunities offshore of the U.K. and Norway. The company holds interests in 18 exploration licences in these areas.
Other International
Libya
In Libya, Suncor is a signatory to seven EPSAs with the National Oil Corporation (NOC). Five of the seven EPSAs relate to fields with developed production and exploration prospects; the remaining two are exploration EPSAs related to properties that do not contain reserves, one of which is to be relinquished following an unsuccessful exploration program. Under the EPSAs, Suncor pays 100% of the exploration costs, 50% of the development costs and 12% of the operating costs. The development, operating and eligible exploration costs are recovered through a 12% share of production (Cost Recovery oil). Any Cost Recovery oil remaining after Suncor's costs have been recovered is referred to as excess petroleum, and is shared between Suncor and the NOC based on several factors. The total oil Suncor receives for cost recovery and its share of excess petroleum is referred to as entitlement volumes. The EPSAs expire on December 31, 2032, but include an initial five-year extension through the end of 2037. Libya is a member of the Organization of Petroleum Exporting Countries (OPEC) and is subject to quotas that can affect the company's production in Libya.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 17
Since 2013, production and liftings in Libya have been intermittent due to political unrest, and the remaining value of Suncor's assets in Libya was impaired in 2015. Suncor had production and liftings from some of its oilfields in 2019, but others remain shut in due to political unrest. The timing of a return to normal operations in Libya remains uncertain.
The estimated cost of Suncor's remaining exploration work program commitment at December 31, 2019, is US$359 million. Suncor declared force majeure for all exploration commitments in Libya effective December 14, 2014, and this declaration remains in effect. During 2019, the company received $264 million after-tax in risk mitigation proceeds for its Libyan assets. The proceeds may be subject to a provisional repayment which is dependent on the future performance and cash flows from Suncor's Libyan assets.
Suncor's share of production in Libya on an economic basis averaged 2.3 mbbls/d in 2019 (2018 2.9 mbbls/d).
Syria
In December 2011, amid continuing unrest in Syria, sanctions were imposed and Suncor declared force majeure under its contractual obligations, suspending its operations in the country. Consequently, the company has ceased recording all production and revenue associated with its Syrian assets. Since 2011, Suncor has not been able to monitor the status of any of its assets in the country, including whether certain facilities have suffered damage, although the company believes some assets have sustained significant damage. As a result of continued uncertainty about Suncor's future in the country, the remaining value of the Suncor assets was impaired in 2013.
Sales of Principal Products
Oil and gas production from East Coast Canada and Offshore U.K. & Norway is either marketed by Suncor's Energy Trading business acting as a marketing agent, or sold to the company's Energy Trading business, which then markets the products to customers under direct sales arrangements. Suncor does not typically enter into long-term supply arrangements to sell its production from its Exploration and Production segment. Contracts for these direct sales arrangements are all made on a spot basis, and incorporate pricing that is generally determined on a daily or monthly basis in relation to a specified market reference price.
In Libya, crude oil is marketed by the NOC on behalf of Suncor.
Exploration and Production Sales Summary:
2019
|
2018
|
|||||||||
|
||||||||||
Sales Volumes | mboe/d |
% operating
revenues |
mboe/d |
% operating
revenues |
||||||
|
||||||||||
E&P Canada | ||||||||||
|
||||||||||
Crude oil and NGLs | 60.8 | 57 | 52.8 | 52 | ||||||
|
||||||||||
Natural gas | | | 0.5 | | ||||||
|
||||||||||
E&P International | ||||||||||
|
||||||||||
Crude oil and NGLs(1) | 44.3 | 42 | 48.7 | 47 | ||||||
|
||||||||||
Natural gas | 0.8 | 1 | 0.8 | 1 | ||||||
|
||||||||||
Total Exploration and Production | ||||||||||
|
||||||||||
Crude oil and NGLs | 105.1 | 99 | 101.5 | 99 | ||||||
|
||||||||||
Natural gas | 0.8 | 1 | 1.3 | 1 | ||||||
|
Distribution of Products
18 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Royalties
East Coast Canada
Suncor's East Coast projects are subject to Royalty Agreements and Regulations issued by the Government of Newfoundland and Labrador. To date, the royalty regime for each project has been negotiated on an individual basis. On November 1, 2017, the Province of Newfoundland and Labrador promulgated the Generic Royalty Regime (GORR) for future projects. The current East Coast royalty regime has a tiered rate structure ranging from a minimum of 1% of gross revenue to a maximum of 42.5% of net revenue (gross revenue less eligible operating and capital costs). The tiered structure is based upon various profitability levels. An East Coast project will be subject to the minimum royalty (the pre-payout phase) until the project's cumulative gross revenue exceeds its cumulative costs, including an annual investment allowance (the post-payout phase).
Terra Nova has reached the net royalty stage, consisting of a two tier profit-sensitive royalty. Tier one is the greater of 10% of gross revenue or 30% of net revenue. Tier two is an additional 12.5% of net revenue. During 2019, Terra Nova royalties averaged 17% of gross revenue (2018 20%).
Hibernia production from the original oilfields and the AA Block has reached the net royalty stage, consisting of a two tier profit-sensitive royalty and an additional net profits interest (NPI) of 10% of net revenue. Tier one is the greater of 5% of gross revenue or 30% of net revenue. Tier two is an additional 12.5% of net revenue; however, this has not yet been triggered. For the portion of the HSEU that is contained within the original Hibernia licence area, a tier three royalty ranges between 7.5% and 12.5% of net revenue, depending on the price of WTI.
The HSEU royalty structure is similar to the Hibernia arrangement, but is subject to an additional tier three royalty that ranges between 2.5% and 7.5% of net revenue, depending on the price of WTI. The HSEU tier three royalty will coincide with the triggering of the tier one royalty which occurred in 2019.
Hibernia royalties (including the HSEU) and NPI combined to average 32% of gross revenue for 2019 (2018 23%).
The White Rose base project has reached the net royalty stage, consisting of a two tier profit-sensitive royalty. Tier one is the greater of 7.5% of gross revenue or 20% of net revenue. Tier two is an additional 10% of net revenue. The White Rose Extension tier one and tier two royalty structures are the same as the base project, and there is an additional tier three royalty of 6.5% of net revenue, payable if WTI is greater than US$50/bbl. The White Rose Extension is currently paying tier one and tier three royalties, but has not yet triggered tier two. During 2019, total White Rose royalties averaged 4% of gross revenue (2018 7%).
The Hebron royalty consists of an initial sliding-scale basic royalty, followed by a three-tiered royalty which will become payable upon the achievement of specified levels of profitability. The basic royalty will start at 1% and increase to 7.5% of gross revenue depending on certain milestones. The tier one royalty is equal to 20% of net revenue. The tier two royalty is equal to an additional 10% of net revenue. The tier three royalty is equal to 6.5% of net revenue, payable if WTI is greater than US$50/bbl. During 2019, Hebron royalties averaged 1% of gross revenue (2018 1%).
E&P International
There are no royalties on oil and gas production from Offshore U.K. & Norway; however, oil and gas profits offshore U.K. are subject to a 40% income tax rate. In addition, oil and gas profits offshore Norway are subject to a 78% income tax rate. For operations in Libya, all government interests, except for income taxes, are presented as royalties.
Refining and Marketing
Refining and Supply Assets and Operations
Eastern North America
Montreal Refinery
The Montreal refinery has a crude oil capacity of 137 mbbls/d, with a flexible configuration that allows processing of sweet SCO from the company's Oil Sands operations, WCS, conventional crude oil, as well as intermediate feedstock. Crude oil is procured at market prices on a spot basis or under contracts that can be terminated on short notice. Crude oil for the refinery can be supplied through several channels, including via Enbridge's Line 9, the Portland-Montreal Pipeline, by marine transportation, and by rail for inland crudes. The Montreal refinery received inland-sourced crude volumes averaging 123.8 mbbls/d in 2019 (2018 124.1 mbbls/d).
Production from the Montreal refinery includes gasoline, distillate, heavy fuel oil, solvents, asphalt and petrochemicals, which are distributed primarily across Quebec and Ontario. The Montreal refinery also continues to produce feedstock sold under a long-term supply contract with HollyFrontier, following the completion of the sale of Suncor's Mississauga lubricants facility in early 2017. Refined products are delivered to distribution terminals and customers via the Trans-Northern Pipeline, truck, rail and marine vessel.
Sarnia Refinery
The Sarnia refinery has a crude oil capacity of 85 mbbls/d, processing both SCO from the company's Oil Sands operations and conventional crude oil purchased from third
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 19
parties on a spot basis or under contracts that can be terminated on short notice. Crude oil is supplied to the Sarnia refinery primarily via the Enbridge mainline and Lakehead pipeline systems. Suncor procures conventional crude oil feedstock primarily from Western Canada and has the ability to supplement supply with purchases from the U.S.
Production yield from the Sarnia refinery includes gasoline, kerosene, and jet and diesel fuels, which are primarily distributed in Ontario. Refined products are delivered to distribution terminals in Ontario via the Sun-Canadian Pipeline, or delivered to customers directly via marine vessel and rail. The Sarnia refinery also has limited access to pipelines delivering refined products into the U.S.
To meet the demands of Suncor's marketing network in Eastern North America, the company also purchases gasoline and distillate from other refiners. Suncor enters into reciprocal exchange arrangements with other refiners in Eastern North America, primarily for gasoline and distillate, as a means of minimizing transportation costs and balancing product availability. Specialty products, such as asphalt and petrochemicals, are also exported to customers in the U.S.
Other Facilities
Suncor holds a 51% interest in ParaChem Chemicals L.P. (ParaChem), which owns and operates a petrochemicals plant located adjacent to the Montreal refinery. Feedstock for the plant includes xylene and toluene produced by the Montreal and Sarnia refineries. The plant primarily produces paraxylene, which is used by customers to manufacture polyester textiles and plastic bottles. Paraxylene production was approximately 355,000 metric tonnes in 2019 (2018 372,000 metric tonnes). ParaChem also produces benzene, hydrogen and heavy aromatics. Benzene production is delivered back to the Montreal refinery to be marketed with production from that facility.
Suncor operates Canada's largest ethanol facility, the St. Clair Ethanol plant in the Sarnia-Lambton region of Ontario, with a nameplate capacity of 396 million litres per year. In 2019, the plant produced 400 million litres of ethanol (2018 402 million litres).
Western North America
Edmonton Refinery
The Edmonton refinery has a crude oil capacity of 142 mbbls/d and has the capability to run a full slate of feedstock sourced from Suncor's Oil Sands operations. Crude oil is supplied to the refinery via company-owned and third-party pipelines.
Feedstock is supplied from Suncor's Oil Sands operations, Syncrude operations (including volumes purchased by Suncor from the other Syncrude joint venture partners' share of production) and other producers from the Wood Buffalo and Cold Lake regions of Alberta. The refinery can process approximately 41 mbbls/d of blended heavy feedstock (comprised of 29 mbbls/d of bitumen and 12 mbbls/d of diluent) and process approximately 44 mbbls/d of sour SCO. The refinery can also process approximately 57 mbbls/d of sweet SCO through its synthetic crude train.
Production yield from the Edmonton refinery includes primarily gasoline, distillate and other light oils, which are delivered to distribution terminals across Western Canada via the Alberta Products Pipeline, the TransMountain Pipeline and the Enbridge pipeline system, as well as via truck and rail.
Commerce City Refinery
The Commerce City refinery has a crude throughput capacity of 98 mbbls/d. The refinery processes primarily conventional crude oil, and has the capacity to process up to 16 mbbls/d of sour SCO and diluted bitumen from Suncor's Oil Sands operations. A majority of crude feedstock is supplied from sources in the U.S., including the Rocky Mountain region, while the remainder is purchased from Canadian sources. Crude oil purchase contracts have terms ranging from month-to-month to multi-year. Crude oil is supplied to the Commerce City refinery primarily by pipeline, with the remainder transported via truck.
Production yield from the Commerce City refinery includes primarily gasoline, distillate and paving-grade asphalt.
The majority of the refined products are sold to commercial and wholesale customers in Colorado and Wyoming, and a retail network in Colorado and Wyoming. Refined products are distributed by truck, rail and pipeline.
Other Facilities
To support the supply and demand balance in the Vancouver area, Suncor imports and exports finished products through its Burrard distribution terminal located on the west coast of B.C. Suncor also enters into reciprocal exchange arrangements with other refiners in Western North America as a means of minimizing transportation costs and balancing product availability.
20 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Refinery Throughputs, Utilizations and Yields
The following tables summarize the crude feedstock, utilizations and production yield mix for Suncor's refineries for the years ended December 31, 2019 and 2018.
Average Daily Crude Throughput |
Montreal
|
Sarnia
|
Edmonton
|
Commerce City
|
|||||||||||||
(mbbls/d, except as noted) | 2019 | 2018 | 2019 | 2018 | 2019 | 2018 | 2019 | 2018 | |||||||||
|
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Sweet synthetic | 7.9 | 8.9 | 24.8 | 29.7 | 54.9 | 50.1 | | | |||||||||
|
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Sour synthetic | | | 31.8 | 25.7 | 45.3 | 32.8 | 9.4 | 9.2 | |||||||||
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Diluted bitumen | 20.6 | 22.1 | | | 43.0 | 35.6 | 9.9 | 11.2 | |||||||||
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Sweet conventional | 89.0 | 90.0 | 0.3 | 3.1 | | | 63.9 | 65.7 | |||||||||
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Sour conventional | 8.0 | 9.2 | 21.0 | 19.4 | | 4.7 | 9.4 | 13.4 | |||||||||
|
|||||||||||||||||
Total | 125.5 | 130.2 | 77.9 | 77.9 | 143.2 | 123.2 | 92.6 | 99.5 | |||||||||
|
|||||||||||||||||
Utilization (%) | 92 | 95 | 92 | 92 | 101 | 87 | 94 | 102 | |||||||||
|
|||||||||||||||||
Equity Crude Processed(1) | 7.7 | 7.0 | 51.6 | 45.0 | 121.3 | 99.3 | 9.4 | 9.2 | |||||||||
|
Refined Petroleum Production Yield Mix |
Montreal
|
Sarnia
|
Edmonton
|
Commerce City
|
|||||||||||||
(%) | 2019 | 2018 | 2019 | 2018 | 2019 | 2018 | 2019 | 2018 | |||||||||
|
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Gasoline | 38 | 41 | 47 | 51 | 43 | 44 | 49 | 48 | |||||||||
|
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Distillates | 38 | 37 | 39 | 37 | 52 | 50 | 34 | 35 | |||||||||
|
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Other | 24 | 22 | 14 | 12 | 5 | 6 | 17 | 17 | |||||||||
|
Distribution Terminals and Pipelines
Suncor owns and operates 13 major refined product terminals across Canada (including terminals adjacent to refineries) and three product terminals in Colorado. Combined with access to facilities under long-term contractual arrangements with other parties, Suncor's North American assets are sufficient to meet the Refining and Marketing segment's current storage and distribution needs.
As at December 31, 2019, Suncor's ownership interests in certain pipelines were as follows:
Pipeline | Ownership | Type | Origin | Destinations | ||||
|
||||||||
Portland-Montreal Pipeline | 23.80% | Crude oil | Portland, Maine | Montreal, Quebec | ||||
|
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Trans-Northern Pipeline | 33.30% | Refined product | Montreal, Quebec | Ontario Ottawa, Toronto & Oakville | ||||
|
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Sun-Canadian Pipeline | 55.00% | Refined product | Sarnia, Ontario | Ontario Toronto, London & Hamilton | ||||
|
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Alberta Products Pipeline | 35.00% | Refined product | Edmonton, Alberta | Calgary, Alberta | ||||
|
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Rocky Mountain Crude Pipeline | 100.00% | Crude oil | Guernsey, Wyoming | Denver, Colorado | ||||
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Centennial Pipeline | 100.00% | Crude oil | Guernsey, Wyoming | Cheyenne, Wyoming | ||||
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Oil Sands Pipeline | 100.00% | Crude oil | Fort McMurray, Alberta | Edmonton, Alberta | ||||
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Marketing Assets and Operations
Suncor's retail service station network operates nationally in Canada primarily under the Petro-Canada brand. As at December 31, 2019, this network consisted of 1,547 outlets across Canada, of which 796 locations are company-owned locations and 751 are branded-dealers. Selected locations along the Trans-Canada highway comprise the coast-to-coast Electric Highway network of fast charging EV stations. In addition, refined products are marketed through independent dealers and joint operations. Suncor's Canadian retail network had sales of gasoline motor fuels averaging approximately 4.9 million litres per site in 2019 (2018 4.8 million litres).
Suncor's Colorado retail network consists of 44 owned or leased Shell, Exxon or Mobil branded outlets. Suncor also has product supply agreements with 142 Shell-branded sites in both Colorado and Wyoming, and with 53 Exxon and Mobil-branded sites in Colorado. Marketing activities from the retail network also generate non-petroleum revenues from convenience store sales and car washes.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 21
Suncor's wholesale operations sell refined products into farm, home heating, paving, small industrial, commercial and truck markets. Through its PETRO-PASS network, Suncor is a national marketer to the commercial road transport segment in Canada. Suncor also sells refined products directly to large industrial and commercial customers and independent marketers.
Retail and Wholesale Summary
As at December 31
|
||||||
Locations | 2019 | 2018 | ||||
|
||||||
Retail Service Stations Canada | ||||||
|
||||||
Petro-Canada -branded | 1 546 | 1 527 | ||||
|
||||||
Sunoco -branded | 1 | 1 | ||||
|
||||||
1 547 | 1 528 | |||||
|
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Retail Service Stations(1) U.S. | ||||||
|
||||||
Shell -branded retail service stations Colorado/Wyoming | 177 | 180 | ||||
|
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Exxon -branded retail service stations Colorado | 42 | 40 | ||||
|
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Mobil -branded retail service stations Colorado | 20 | 18 | ||||
|
||||||
239 | 238 | |||||
|
||||||
Wholesale Cardlock Sites Canada | ||||||
|
||||||
Petro-Canada-branded cardlock sites (PETRO-PASS) | 310 | 307 | ||||
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Refined Products Sales Volumes
2019
|
2018
|
|||||||||
|
|
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Sales Volumes | mbbls/d |
% operating
revenues |
mbbls/d |
% operating
revenues |
||||||
|
||||||||||
Gasoline (includes motor and aviation gasoline) | ||||||||||
|
||||||||||
Eastern North America | 119.8 | 117.8 | ||||||||
|
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Western North America | 126.8 | 127.8 | ||||||||
|
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246.6 | 46 | 245.6 | 47 | |||||||
|
||||||||||
Distillates (includes diesel and heating oils, and aviation jet fuels) | ||||||||||
|
||||||||||
Eastern North America | 102.9 | 95.8 | ||||||||
|
||||||||||
Western North America | 115.2 | 107.6 | ||||||||
|
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218.1 | 40 | 203.4 | 39 | |||||||
|
||||||||||
Other (includes heavy fuel oil, asphalts, petrochemicals, other) | ||||||||||
|
||||||||||
Eastern North America | 48.8 | 52.7 | ||||||||
|
||||||||||
Western North America | 25.9 | 25.6 | ||||||||
|
||||||||||
74.7 | 14 | 78.3 | 15 | |||||||
|
||||||||||
539.4 | 527.3 | |||||||||
|
Sales volumes for specific products are moderately affected by seasonal cycles: gasoline sales are typically higher during the summer driving season; heating oil sales are typically higher during the winter season; diesel sales are typically higher during the drilling season at the beginning of the year in Western Canada and during agricultural planting and harvest seasons in early spring and late summer, respectively; and asphalt sales are typically higher during the summer construction paving period. Suncor has the flexibility to modify refinery inputs and outputs to match production yields with anticipated product demands.
22 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Sales volumes can also be impacted when refineries undergo maintenance events, which reduce production. Suncor is able to partially mitigate this impact through its integrated facilities: the Edmonton refinery and Oil Sands Base upgrading facilities, and the Sarnia and Montreal refineries. In addition, Suncor may purchase refined products from third-party suppliers.
Other Suncor Businesses
Energy Trading
Suncor's Energy Trading business is organized around five main commodity groups crude oil, transportation fuels, specialty products and feedstock, natural gas, and electricity and has trading offices in Canada, the U.K. and the U.S. Energy Trading manages open price exposure along the Suncor value chain and provides commodity supply, transportation and storage while optimizing price realizations for Suncor's products. The company's customers include mid- to large-sized commercial and industrial consumers, utility companies and energy producers. Beginning in the first quarter of 2019, results from the company's Energy Trading business have been included within each of the respective reporting business segments to which the respective trading activity relates. The Energy Trading business was previously reported within the Corporate, Energy Trading and Eliminations segment.
The Energy Trading business supports the company's Oil Sands and E&P production by optimizing price realizations, managing inventory levels and managing the impacts of external market factors, such as pipeline disruptions or outages at refining customers. The Energy Trading business has entered into contractual arrangements for other midstream infrastructure, such as pipeline, storage capacity and rail access, to optimize delivery of existing and future growth production, while generating earnings on select trading strategies and opportunities.
The Energy Trading business supports the company's Refining and Marketing business by optimizing the supply of crude and NGLs feedstock to the company's four refineries, managing crude inventory levels during refinery turnarounds and periods of unplanned maintenance, as well as managing external impacts from pipeline disruptions. Energy Trading also moves Suncor's refinery production to market and ensures supply to Suncor's branded retail and wholesale marketing channels. The business provides reliable natural gas supply to Suncor's upstream and downstream operations and generates incremental revenue through trading and asset optimization.
Renewable Energy
Suncor's renewable energy investment activities include development, construction and ownership of Suncor-operated and joint venture partner-operated renewable power assets across Canada. This currently includes a portfolio of four operating wind power facilities located in Alberta, Saskatchewan and Ontario with a gross installed capacity of 111 MW. In addition, Suncor has secured a number of sites for potential future wind and solar power projects that are in various stages of development, including the Forty Mile Wind Power Project in southeast Alberta. Suncor sanctioned the Forty Mile Wind Power Project in late 2019; this 200 MW renewable power project has an estimated total capital spend of $300 million with completion expected in late 2021.
Suncor's wind power projects as at December 31, 2019:
Wind Power Projects |
Ownership
Interest (%) |
Gross (MW) | Turbines | Completed | ||||||||
|
||||||||||||
Operated by Suncor | ||||||||||||
|
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Adelaide | Strathroy, Ontario | 75.0 | 40 | 18 | 2014 | |||||||
|
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Non-operated | ||||||||||||
|
||||||||||||
Chin Chute | Taber, Alberta | 33.3 | 30 | 20 | 2006 | |||||||
|
||||||||||||
Magrath | Magrath, Alberta | 33.3 | 30 | 20 | 2004 | |||||||
|
||||||||||||
SunBridge | Gull Lake, Saskatchewan | 50.0 | 11 | 17 | 2002 | |||||||
|
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 23
The following table shows the distribution of employees among Suncor's business units and corporate office.
As at December 31 | 2019 | 2018 | |||
|
|||||
Oil Sands(1)(2) | 6 400 | 6 297 | |||
|
|||||
Exploration and Production(2) | 351 | 340 | |||
|
|||||
Refining and Marketing(2) | 2 824 | 2 939 | |||
|
|||||
Corporate and Eliminations(2)(3) | 3 314 | 2 904 | |||
|
|||||
Total | 12 889 | 12 480 | |||
|
In addition to Suncor's employees, the company also uses independent contractors to supply a range of services.
Approximately 31% or 4,322 of the company's employees were covered by collective agreements at the end of 2019. The company completed negotiations in 2019 and collective agreements are now in place with United Steelworkers at the Commerce City refinery and with Unifor at Oil Sands Base and Firebag, as well as the Edmonton refinery, the Montreal refinery and the Burrard, Edmonton, London, Montreal and Oakville terminals. Negotiations are in progress for the Terra Nova and Ottawa Terminal collective agreements, representing approximately 71 employees.
ETHICS, SOCIAL AND ENVIRONMENTAL POLICIES
Suncor has adopted several policies focused on ethics, social and environmental matters.
Suncor's standards for the ethical conduct of the company's business are set forth in a Standards of Business Conduct Code (the Code), which applies to Suncor's directors, officers, employees and independent contractors, and requires strict compliance with legal requirements and Suncor's values. Topics addressed in the Code include competition, conflict of interest, the protection and proper use of corporate assets and opportunities, confidentiality, disclosure of material information, trading in shares and securities, communications to the public, improper payments, harassment, fair dealing in trade relations, and accounting, reporting and business controls. The Code is supported by detailed policy guidance and standards and a Code compliance program, under which every Suncor director, officer, employee and independent contractor is required to annually complete a Code training course, read a summary of the Code, affirm that they understand the requirements of the Code, and provide confirmation of compliance with the Code since their last affirmation or confirmation that any instance of non-compliance has been discussed and resolved with the individual's supervisor. Compliance is then reported to Suncor's Governance Committee of the Board of Directors. A copy of the Code is available on Suncor's website at www.suncor.com.
Suncor has a Supplier Code of Conduct that highlights the values that are important to Suncor and is a guide to the standard of behaviour required of all suppliers, contractors, consultants and other third parties with whom Suncor does business. The Supplier Code of Conduct addresses topics such as safety, human rights, harassment, bribery and corruption, and confidential information, among others. It also reinforces Suncor's commitment to sustainable development and encourages Suncor's business associates to work with the company to seek ways to reduce environmental impacts, support the communities in which Suncor works and collectively achieve economic growth. Compliance with the Supplier Code of Conduct is a standard requirement for all Suncor supply chain contracts.
Suncor has a Human Rights Policy, which affirms Suncor's responsibility to respect human rights and is intended to ensure that Suncor is not complicit in human rights abuses. Suncor is subject to the laws of the countries in which it operates and is committed to complying with all such laws while honouring international human rights principles, such as those described in the Universal Declaration of Human Rights. The policy contains guiding principles, including: the belief that a process for human rights impact assessment undertaken regularly is essential to identify, prevent, mitigate and remedy potential impacts on human rights; a commitment to providing a working environment that is free from harassment, violence, intimidation and
24 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
other disruptive behaviours; a commitment to respecting the cultures, customs and values of the communities in which the company operates; the belief that security policies should be consistent with international human rights standards; and the belief that employees and stakeholders affected by the company's activities should have access to grievance mechanisms that are legitimate, accessible, predictable, equitable and transparent. The policy makes clear that the scope of Suncor's human rights due diligence should include its own operations and, where it can influence its third-party business relationships, the operations of others.
Suncor has a Stakeholder Relations Policy, which reflects Suncor's values. The policy provides that Suncor is committed to developing and maintaining positive, meaningful relationships with stakeholders in all of its operating areas and provides Suncor's principles for guiding the development of stakeholder relations (respect, responsibility, transparency, timeliness and mutual benefit). The policy states Suncor's belief that successful stakeholder relations provide significant mutual benefits, including enabling informed decision-making, resolving issues with timely, cost-effective and mutually beneficial solutions, building stronger communities and supporting shared learning.
Suncor has a Canadian Indigenous Relations Policy, which affirms Suncor's desire to work in collaboration with Indigenous Peoples to create shared value. The policy sets the foundation for a consistent approach to the company's relationships with Indigenous Peoples and outlines Suncor's responsibilities and commitments, and is intended to guide Suncor's business decisions on a day-to-day basis. Suncor is committed to working closely with Indigenous Peoples and communities to build and maintain effective, long-term and mutually beneficial relationships. The policy makes it clear that responsible development takes into account Indigenous interests regarding the opportunities and impacts of energy development on communities and on their traditional and current uses of lands and resources.
Suncor has an Environment, Health and Safety (EH&S) policy, which affirms Suncor's commitment to be a sustainable energy company by working to achieve or exceed levels of performance governed by legislation and by the evolving environmental, social and economic expectations of the company's stakeholders. The policy reflects Suncor's belief that the company's EH&S efforts are complementary and interdependent with the company's economic and social performance. The policy states that Suncor management is responsible for ensuring that employees and contractors under their direction are competent to manage their EH&S responsibilities and are knowledgeable of the hazards and risks associated with their jobs, and that all Suncor employees and contractors are accountable for compliance with relevant acts, codes, regulations, standards and procedures, and for their own personal safety and the safety of their co-workers.
The Environment, Health, Safety and Sustainable Development (EHS&SD) Committee of the Board of Directors meets quarterly to review Suncor's effectiveness in meeting its EHS&SD obligations. The committee also reviews the company's strategies and policies, with respect to EHS&SD, given legal, industry and community standards. The EHS&SD Committee also monitors management's performance and emerging trends and issues in these areas. In addition, the EHS&SD Committee has oversight over Suncor's performance with respect to the company's social goal regarding building mutual trust and respect with the Indigenous Peoples of Canada, and reviews Suncor's annual Report on Sustainability reporting on Suncor's EHS&SD progress, plans and performance objectives, as well as disclosure on lobbying.
Suncor's annual President's Operational Excellence Awards support and highlight the goals of the EH&S policy by honouring employees and contractors who demonstrate an exceptional commitment to EH&S performance. The awards program highlights progress on safety and environmental initiatives and provides educational opportunities for all employees.
The aforementioned policies are reviewed regularly, and are accessible to employees and contractors on the company's intranet. Additional workshops and targeted training sessions on various matters under the policies are also conducted as warranted throughout the year. The Canadian Indigenous Relations Policy is available in Cree and Dene audio translations.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 25
STATEMENT OF RESERVES DATA AND OTHER OIL AND GAS INFORMATION
Date of Statement
The Statement of Reserves Data and Other Oil and Gas Information outlined below is dated February 26, 2020, with an effective date of December 31, 2019. Reserves evaluations have not been updated since the effective date and, thus, do not reflect changes in the company's reserves since that date. The preparation date of the information is January 27, 2020.
Disclosure of Reserves Data
Suncor is subject to the reporting requirements of Canadian securities regulatory authorities, including the reporting of reserves data in accordance with National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities (NI 51-101).
The reserves data included in this section of the AIF for Suncor's Mining and In Situ operations is based upon evaluations conducted by GLJ Petroleum Consultants Ltd. (GLJ), contained in their reports dated February 21, 2020 (the GLJ Reports). The reserves data set forth below for all other reserves, which includes Suncor's interests in its conventional assets offshore Newfoundland and Labrador (collectively, E&P Canada), and conventional assets offshore of the U.K. and Norway (collectively, Offshore U.K. & Norway), is based upon evaluations conducted by Sproule Associates Limited or Sproule International Limited (collectively, Sproule), contained in their reports dated February 21, 2020 (the Sproule Reports). Each of GLJ and Sproule (collectively, the Evaluators) are independent qualified reserves evaluators as defined in NI 51-101.
The reserves data summarizes Suncor's SCO, bitumen, light crude oil and medium crude oil (combined, including immaterial amounts of heavy crude oil) and conventional natural gas (including immaterial amounts of NGLs) reserves and the net present values of future net revenues for these reserves using forecast prices and costs prior to provision for interest and general and administrative expense.
Advisories Reserves Data
It should not be assumed that the estimates of future net revenues presented in the tables below represent the fair market value of the reserves. There is no assurance that the forecast prices and cost assumptions will be attained and variances could be material. There is no guarantee that the estimates for SCO, bitumen, light crude oil and medium crude oil, heavy crude oil, conventional natural gas and NGLs reserves provided herein will be recovered. Actual SCO, bitumen, light crude oil and medium crude oil, heavy crude oil, conventional natural gas and NGLs volumes recovered may be greater than or less than the estimates provided herein. Readers should review the Glossary of Terms and Abbreviations and the definitions and information contained in the Notes to Reserves Data Tables, Definitions for Reserves Data Tables and Notes to Future Net Revenues Tables in conjunction with the following notes and tables.
Significant Risk Factors and Uncertainties Affecting Reserves
The evaluation of reserves is a continuous process, one that can be significantly impacted by a variety of internal and external influences. Revisions are often required as a result of newly acquired technical data, technology improvements, or changes in historical performance, pricing, economic conditions, market availability, or regulatory requirements. Additional technical information regarding geology, hydrogeology, reservoir properties and reservoir fluid properties is obtained through seismic programs, drilling programs, updated reservoir performance studies and analysis, and production history, and may result in revisions to reserves. Pricing, market availability and economic conditions affect the profitability of reserves development. Royalty regimes and environmental regulations and other regulatory changes cannot be predicted but may have positive or negative effects on reserves. Future technology improvements would be expected to have a favourable impact on the economics of reserves development and exploitation, and therefore may result in an increase to reserves. Political unrest, such as is occurring in Syria and Libya, has resulted in volumes that would otherwise be classified as reserves being classified as contingent resources.
While the above factors, and many others, are relevant to the evaluation of reserves, certain judgments and assumptions are always required. As new information becomes available, these areas are reviewed and revised accordingly.
The reserves included in this AIF represent estimates only. There are numerous uncertainties inherent in estimating quantities and quality of these reserves, including many factors beyond the company's control. In general, estimates of reserves and the future net cash flows from these reserves are based upon a number of variable factors and assumptions such as production forecasts, regulations, pricing, the timing and amount of capital expenditures, future royalties, future operating costs, yield rates for upgraded production of SCO from bitumen, and future abandonment and reclamation costs all of which may vary considerably from actual results and may be affected by many of the factors identified under Industry Conditions and Risk Factors herein. The accuracy of any reserves estimate is a matter of interpretation and judgment and is a function of the quality and quantity of available data, which may have been gathered over time. For these reasons, estimates of the reserves and categorization of such reserves based on the certainty of recovery, prepared by different engineers or by the same engineers at different times, may vary.
26 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Reserves estimates are based upon geological assessment, including drilling and laboratory tests. Mining reserves estimates also consider production capacity and upgrading yields, mine plans, operating life and regulatory constraints. In Situ reserves estimates are also based upon the testing of core samples and seismic operations and demonstrated commercial success of in situ processes. Suncor's actual production, revenues, royalties, taxes, and development and operating expenditures with respect to the company's reserves will vary from such estimates, and such variances could be material. Production performance subsequent to the date of the estimate may justify future revision, either upward or downward, if material.
The reserves evaluations are based in part on the assumed success of activities the company intends to undertake in future years. The reserves and estimated cash flow to be derived from the reserves contained in the reserves evaluations may be increased or reduced to the extent that such activities do or do not achieve the level of success assumed in the reserves evaluations.
Specific significant risk factors and uncertainties affecting Suncor's reserves include, among others:
Commodity pricing affects the profitability of reserves development. For example, higher commodity prices may result in higher reserves by making more projects economically viable or extending their economic life; conversely, lower commodity prices may result in lower reserves. Low commodity prices could have a material adverse effect on Suncor's reserves. Refer to the Risk Factors Volatility of Commodity Prices section of this AIF.
Suncor operates in jurisdictions that have regulated, or have proposed to regulate, industrial GHG emissions, including the laws enacted by the Government of Alberta impacting Suncor's current and future Oil Sands assets, a summary of which is set forth in the Industry Conditions Environmental Regulation Climate Change section of this AIF. Such laws could impose significant compliance costs on Suncor, which could potentially impact the economic viability of certain projects recorded as reserves, or could require that new technologies be developed. Future development could be adversely impacted if compliance costs result in projects not being economically viable or if required technologies are not developed. Refer to the Risk Factors Carbon Risk section of this AIF.
As a result of political unrest in Syria, Suncor reclassified all Syria reserves to contingent resources, effective December 31, 2012. Suncor also reclassified all Libya reserves to contingent resources, effective December 31, 2016, due to political unrest in Libya. All Syria and Libya volumes remain classified as contingent resources as at December 31, 2019. The criteria for the reclassification of the aforementioned volumes back to reserves include sustained periods of political stability, operational and production stability, and normalization of business relations including financial transactions. Refer to the Risk Factors Foreign Operations section of this AIF.
Refer to the Additional Information Relating to Reserves Data Abandonment and Reclamation Costs section of this AIF.
Government intervention, including mandatory production curtailments, could create long-term market uncertainty, which could have a material adverse effect on Suncor's reserves. Refer to the Risk Factors Government/Regulatory and Policy Effectiveness section of this AIF.
Refer to the Risk Factors section of this AIF for additional information on significant risk factors and uncertainties affecting Suncor's reserves.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 27
Oil and Gas Reserves Tables and Notes
Summary of Oil and Gas Reserves(1)
as at December 31, 2019
(forecast prices and costs)(2)
SCO(3)
|
Bitumen
|
Light Crude &
Medium Crude Oil(4) |
Conventional
Natural Gas(6) |
Total
|
||||||||||||||||||
|
|
(mmbbls) |
|
(mmbbls) |
|
(mmbbls) |
|
(bcfe) |
|
(mmboe) |
||||||||||||
|
|
Gross |
|
Net |
|
Gross |
|
Net |
|
Gross |
|
Net |
|
Gross |
|
Net |
|
Gross |
|
Net |
|
|
|
||||||||||||||||||||||
Proved Developed Producing | ||||||||||||||||||||||
Mining | 1 966 | 1 800 | 896 | 833 | | | | | 2 862 | 2 632 | ||||||||||||
In Situ | 231 | 201 | 99 | 85 | | | | | 330 | 286 | ||||||||||||
E&P Canada | | | | | 72 | 63 | | | 72 | 63 | ||||||||||||
|
||||||||||||||||||||||
Total Canada | 2 197 | 2 001 | 996 | 917 | 72 | 63 | | | 3 265 | 2 981 | ||||||||||||
|
||||||||||||||||||||||
Offshore U.K. & Norway | | | | | 47 | 47 | 2 | 2 | 48 | 48 | ||||||||||||
|
||||||||||||||||||||||
Total Proved Developed Producing | 2 197 | 2 001 | 996 | 917 | 120 | 110 | 2 | 2 | 3 313 | 3 029 | ||||||||||||
|
||||||||||||||||||||||
Proved Developed Non-Producing | ||||||||||||||||||||||
Mining | | | | | | | | | | | ||||||||||||
In Situ | | | | | | | | | | | ||||||||||||
E&P Canada | | | | | | | | | | | ||||||||||||
|
||||||||||||||||||||||
Total Canada | | | | | | | | | | | ||||||||||||
|
||||||||||||||||||||||
Offshore U.K. & Norway | | | | | | | | | | | ||||||||||||
|
||||||||||||||||||||||
Total Proved Developed Non-Producing | | | | | | | | | | | ||||||||||||
|
||||||||||||||||||||||
Proved Undeveloped | ||||||||||||||||||||||
Mining | | | | | | | | | | | ||||||||||||
In Situ | 627 | 520 | 679 | 558 | | | | | 1 306 | 1 079 | ||||||||||||
E&P Canada | | | | | 44 | 41 | | | 44 | 41 | ||||||||||||
|
||||||||||||||||||||||
Total Canada | 627 | 520 | 679 | 558 | 44 | 41 | | | 1 350 | 1 120 | ||||||||||||
|
||||||||||||||||||||||
Offshore U.K. & Norway | | | | | 8 | 8 | 13 | 13 | 10 | 10 | ||||||||||||
|
||||||||||||||||||||||
Total Proved Undeveloped | 627 | 520 | 679 | 558 | 51 | 49 | 13 | 13 | 1 359 | 1 130 | ||||||||||||
|
||||||||||||||||||||||
Proved | ||||||||||||||||||||||
Mining | 1 966 | 1 800 | 896 | 833 | | | | | 2 862 | 2 632 | ||||||||||||
In Situ | 858 | 721 | 779 | 643 | | | | | 1 636 | 1 365 | ||||||||||||
E&P Canada | | | | | 116 | 104 | | | 116 | 104 | ||||||||||||
|
||||||||||||||||||||||
Total Canada | 2 824 | 2 521 | 1 675 | 1 476 | 116 | 104 | | | 4 615 | 4 101 | ||||||||||||
|
||||||||||||||||||||||
Offshore U.K. & Norway | | | | | 56 | 56 | 15 | 15 | 58 | 58 | ||||||||||||
|
||||||||||||||||||||||
Total Proved | 2 824 | 2 521 | 1 675 | 1 476 | 172 | 160 | 15 | 15 | 4 673 | 4 159 | ||||||||||||
|
||||||||||||||||||||||
Probable | ||||||||||||||||||||||
Mining | 601 | 547 | 469 | 402 | | | | | 1 070 | 950 | ||||||||||||
In Situ | 1 143 | 902 | 325 | 242 | | | | | 1 468 | 1 144 | ||||||||||||
E&P Canada | | | | | 162 | 131 | | | 162 | 131 | ||||||||||||
|
||||||||||||||||||||||
Total Canada | 1 744 | 1 450 | 794 | 644 | 162 | 131 | | | 2 700 | 2 224 | ||||||||||||
|
||||||||||||||||||||||
Offshore U.K. & Norway | | | | | 32 | 32 | 16 | 16 | 35 | 35 | ||||||||||||
|
||||||||||||||||||||||
Total Probable | 1 744 | 1 450 | 794 | 644 | 194 | 163 | 16 | 16 | 2 735 | 2 259 | ||||||||||||
|
||||||||||||||||||||||
Proved Plus Probable | ||||||||||||||||||||||
Mining | 2 567 | 2 347 | 1 365 | 1 235 | | | | | 3 932 | 3 582 | ||||||||||||
In Situ | 2 001 | 1 624 | 1 103 | 885 | | | | | 3 104 | 2 509 | ||||||||||||
E&P Canada | | | | | 278 | 235 | | | 278 | 235 | ||||||||||||
|
||||||||||||||||||||||
Total Canada | 4 568 | 3 971 | 2 469 | 2 120 | 278 | 235 | | | 7 314 | 6 325 | ||||||||||||
|
||||||||||||||||||||||
Offshore U.K. & Norway | | | | | 88 | 88 | 31 | 31 | 93 | 93 | ||||||||||||
|
||||||||||||||||||||||
Total Proved Plus Probable | 4 568 | 3 971 | 2 469 | 2 120 | 366 | 323 | 31 | 31 | 7 407 | 6 419 | ||||||||||||
|
Please see Notes (1) through (4) and (6) at the end of the reserves data section for important information about volumes in this table.
28 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Reconciliation of Gross Reserves(1)
as at December 31, 2019
(forecast prices and costs)(2)
SCO(3)
|
Bitumen
|
Light Crude & Medium
Crude Oil(4)(5) |
Conventional
Natural Gas(6) |
Total
|
|||||||||||||||||||||||||||||
|
|
|
|
|
|||||||||||||||||||||||||||||
Proved | Probable |
Proved
Plus Probable |
Proved | Probable |
Proved
Plus Probable |
Proved | Probable |
Proved
Plus Probable |
Proved | Probable |
Proved
Plus Probable |
Proved | Probable |
Proved
Plus Probable |
|||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
mmbbls | mmbbls | mmbbls | mmbbls | mmbbls | mmbbls | mmbbls | mmbbls | mmbbls | bcfe | bcfe | bcfe | mmboe | mmboe | mmboe | |||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Mining | |||||||||||||||||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
December 31, 2018 | 2 069 | 621 | 2 690 | 942 | 496 | 1 438 | | | | | | | 3 011 | 1 117 | 4 128 | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Extensions & Improved Recovery(7) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Technical Revisions(8) | 41 | (20 | ) | 21 | (15 | ) | (27 | ) | (42 | ) | | | | | | | 26 | (47 | ) | (21 | ) | ||||||||||||
|
|||||||||||||||||||||||||||||||||
Discoveries(9) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Acquisitions(10) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Dispositions(11) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Economic Factors(12) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Production(13) | (144 | ) | | (144 | ) | (31 | ) | | (31 | ) | | | | | | | (174 | ) | | (174 | ) | ||||||||||||
|
|||||||||||||||||||||||||||||||||
December 31, 2019 | 1 966 | 601 | 2 567 | 896 | 469 | 1 365 | | | | | | | 2 862 | 1 070 | 3 932 | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
In Situ | |||||||||||||||||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
December 31, 2018 | 729 | 1 175 | 1 904 | 770 | 387 | 1 157 | | | | | | | 1 499 | 1 562 | 3 061 | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Extensions & Improved Recovery(7) | 122 | (36 | ) | 86 | 71 | (42 | ) | 29 | | | | | | | 193 | (78 | ) | 115 | |||||||||||||||
|
|||||||||||||||||||||||||||||||||
Technical Revisions(8) | 37 | 4 | 41 | (22 | ) | (20 | ) | (41 | ) | | | | | | | 15 | (16 | ) | | ||||||||||||||
|
|||||||||||||||||||||||||||||||||
Discoveries(9) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Acquisitions(10) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Dispositions(11) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Economic Factors(12) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Production(13) | (30 | ) | | (30 | ) | (41 | ) | | (41 | ) | | | | | | | (71 | ) | | (71 | ) | ||||||||||||
|
|||||||||||||||||||||||||||||||||
December 31, 2019 | 858 | 1 143 | 2 001 | 779 | 325 | 1 103 | | | | | | | 1 636 | 1 468 | 3 104 | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
E&P Canada | |||||||||||||||||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
December 31, 2018 | | | | | | | 123 | 174 | 297 | | | | 123 | 174 | 297 | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Extensions & Improved Recovery(7) | | | | | | | 4 | 7 | 11 | | | | 4 | 7 | 11 | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Technical Revisions(8) | | | | | | | 12 | (19 | ) | (8 | ) | | | | 12 | (19 | ) | (8 | ) | ||||||||||||||
|
|||||||||||||||||||||||||||||||||
Discoveries(9) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Acquisitions(10) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Dispositions(11) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Economic Factors(12) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Production(13) | | | | | | | (22 | ) | | (22 | ) | | | | (22 | ) | | (22 | ) | ||||||||||||||
|
|||||||||||||||||||||||||||||||||
December 31, 2019 | | | | | | | 116 | 162 | 278 | | | | 116 | 162 | 278 | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Total Canada | |||||||||||||||||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
December 31, 2018 | 2 798 | 1 796 | 4 593 | 1 712 | 883 | 2 595 | 123 | 174 | 297 | | | | 4 632 | 2 853 | 7 485 | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Extensions & Improved Recovery(7) | 122 | (36 | ) | 86 | 71 | (42 | ) | 29 | 4 | 7 | 11 | | | | 196 | (71 | ) | 125 | |||||||||||||||
|
|||||||||||||||||||||||||||||||||
Technical Revisions(8) | 78 | (16 | ) | 62 | (36 | ) | (47 | ) | (83 | ) | 12 | (19 | ) | (8 | ) | | | | 53 | (82 | ) | (28 | ) | ||||||||||
|
|||||||||||||||||||||||||||||||||
Discoveries(9) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Acquisitions(10) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Dispositions(11) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Economic Factors(12) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Production(13) | (173 | ) | | (173 | ) | (72 | ) | | (72 | ) | (22 | ) | | (22 | ) | | | | (268 | ) | | (268 | ) | ||||||||||
|
|||||||||||||||||||||||||||||||||
December 31, 2019 | 2 824 | 1 744 | 4 568 | 1 675 | 794 | 2 469 | 116 | 162 | 278 | | | | 4 615 | 2 700 | 7 314 | ||||||||||||||||||
|
Please see Notes (1) through (13) at the end of the reserves data section for important information about volumes in this table.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 29
Reconciliation of Gross Reserves(1) (continued)
as at December 31, 2019
(forecast prices and costs)(2)
SCO(3)
|
Bitumen
|
Light Crude & Medium
Crude Oil(4)(5) |
Conventional
Natural Gas(6) |
Total
|
|||||||||||||||||||||||||||||
|
|
|
|
|
|||||||||||||||||||||||||||||
Proved | Probable |
Proved
Plus Probable |
Proved | Probable |
Proved
Plus Probable |
Proved | Probable |
Proved
Plus Probable |
Proved | Probable |
Proved
Plus Probable |
Proved | Probable |
Proved
Plus Probable |
|||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
mmbbls | mmbbls | mmbbls | mmbbls | mmbbls | mmbbls | mmbbls | mmbbls | mmbbls | bcfe | bcfe | bcfe | mmboe | mmboe | mmboe | |||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Offshore U.K. & Norway | |||||||||||||||||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
December 31, 2018 | | | | | | | 52 | 37 | 88 | 14 | 17 | 32 | 54 | 40 | 94 | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Extensions & Improved Recovery(7) | | | | | | | 1 | 1 | 2 | | | 1 | 1 | 1 | 3 | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Technical Revisions(8) | | | | | | | 19 | (6 | ) | 13 | 2 | (2 | ) | 1 | 19 | (6 | ) | 13 | |||||||||||||||
|
|||||||||||||||||||||||||||||||||
Discoveries(9) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Acquisitions(10) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Dispositions(11) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Economic Factors(12) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Production(13) | | | | | | | (16 | ) | | (16 | ) | (2 | ) | | (2 | ) | (16 | ) | | (16 | ) | ||||||||||||
|
|||||||||||||||||||||||||||||||||
December 31, 2019 | | | | | | | 56 | 32 | 88 | 15 | 16 | 31 | 58 | 35 | 93 | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Other International (14) | |||||||||||||||||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
December 31, 2018 | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Extensions & Improved Recovery(7) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Technical Revisions(8) | | | | | | | 6 | | 6 | | | | 6 | | 6 | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Discoveries(9) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Acquisitions(10) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Dispositions(11) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Economic Factors(12) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Production(13)(14) | | | | | | | (6 | ) | | (6 | ) | | | | (6 | ) | | (6 | ) | ||||||||||||||
|
|||||||||||||||||||||||||||||||||
December 31, 2019 | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Total | |||||||||||||||||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
December 31, 2018 | 2 798 | 1 796 | 4 593 | 1 712 | 883 | 2 595 | 174 | 211 | 385 | 14 | 17 | 32 | 4 686 | 2 892 | 7 579 | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Extensions & Improved Recovery(7) | 122 | (36 | ) | 86 | 71 | (42 | ) | 29 | 5 | 8 | 13 | | | 1 | 198 | (70 | ) | 128 | |||||||||||||||
|
|||||||||||||||||||||||||||||||||
Technical Revisions(8) | 78 | (16 | ) | 62 | (36 | ) | (47 | ) | (83 | ) | 36 | (25 | ) | 11 | 2 | (2 | ) | 1 | 78 | (88 | ) | (10 | ) | ||||||||||
|
|||||||||||||||||||||||||||||||||
Discoveries(9) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Acquisitions(10) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Dispositions(11) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Economic Factors(12) | | | | | | | | | | | | | | | | ||||||||||||||||||
|
|||||||||||||||||||||||||||||||||
Production(13) | (173 | ) | | (173 | ) | (72 | ) | | (72 | ) | (44 | ) | | (44 | ) | (2 | ) | | (2 | ) | (289 | ) | | (289 | ) | ||||||||
|
|||||||||||||||||||||||||||||||||
December 31, 2019 | 2 824 | 1 744 | 4 568 | 1 675 | 794 | 2 469 | 172 | 194 | 366 | 15 | 16 | 31 | 4 673 | 2 735 | 7 407 | ||||||||||||||||||
|
Please see Notes (1) through (14) at the end of the reserves data section for important information about volumes in this table.
30 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Notes to Reserves Data Tables
as at December 31, 2019
Definitions for Reserves Data Tables
In the tables set forth above and elsewhere in this AIF, the following definitions and other notes are applicable:
Gross means:
Net means:
Reserves Categories
The reserves estimates presented are based on the definitions and guidelines contained in the Canadian Oil and Gas Evaluation (COGE) Handbook. A summary of those definitions is set forth below.
Reserves are estimated remaining quantities of oil and natural gas and related substances anticipated to be recoverable from known accumulations, as of a given date, based on analyses of drilling, geological, geophysical and engineering data, the use of established technology, and specified economic conditions, which are generally accepted as being reasonable.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 31
Reserves are classified according to the degree of certainty associated with the estimates:
Proved reserves are those reserves that can be estimated with a high degree of certainty to be recoverable. It is likely that the actual remaining quantities recovered will exceed the estimated Proved reserves. Proved reserves estimates should target at least a 90% probability that the quantities actually recovered will equal or exceed the estimate.
Probable reserves are those additional reserves that are less certain to be recovered than Proved reserves. It is equally likely that the actual remaining quantities recovered will be greater or less than the sum of the estimated Proved Plus Probable reserves. That is, Proved Plus Probable reserves estimates should target at least a 50% probability that the quantities actually recovered will equal or exceed the estimate.
Other criteria that must also be met for the categorization of reserves are provided in the COGE Handbook.
Proved and Probable reserves categories may be divided into Developed and Undeveloped categories:
Developed reserves are those reserves that are expected to be recovered (i) from existing wells and installed facilities or, if facilities have not been installed, that would involve a low expenditure (for example, when compared to the cost of drilling a well) to put the reserves on production, or (ii) for mining assets, through installed extraction equipment and infrastructure that is operational at the time of the reserves estimate. The Developed category may be subdivided into Producing and Non-Producing.
Undeveloped reserves are those reserves expected to be recovered from known accumulations where a significant expenditure (for example, when compared to the cost of drilling a well) is required to render them capable of production. They must fully meet the requirements of the reserves category (Proved or Probable) to which they are assigned.
For any given pool, it may be appropriate to allocate total pool reserves between the Developed and Undeveloped categories or to subdivide the Developed reserves for the pool between Developed Producing and Developed Non-Producing. This allocation should be based on the estimator's assessment as to the reserves that will be recovered from specific wells, facilities and completion intervals in the pool and their respective development and production status.
32 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Future Net Revenues Tables and Notes
Net Present Values of Future Net Revenues Before Income Taxes(1)
as at December 31, 2019
(forecast prices and costs)
(in $ millions, discounted at % per year)
|
Unit Value(2) | |||||||||||||
|
|
|||||||||||||
0% | 5% | 10% | 15% | 20% | ($/boe) | |||||||||
|
||||||||||||||
Proved Developed Producing | ||||||||||||||
|
||||||||||||||
Mining | 37 000 | 28 445 | 19 865 | 14 479 | 11 104 | 7.55 | ||||||||
In Situ | 8 986 | 7 891 | 6 997 | 6 275 | 5 691 | 24.49 | ||||||||
E&P Canada | 1 833 | 2 047 | 2 066 | 2 006 | 1 919 | 32.88 | ||||||||
|
||||||||||||||
Total Canada | 47 820 | 38 383 | 28 927 | 22 760 | 18 714 | 9.70 | ||||||||
|
||||||||||||||
Offshore U.K. & Norway | 2 142 | 2 103 | 2 022 | 1 927 | 1 834 | 42.31 | ||||||||
|
||||||||||||||
Total Proved Developed Producing | 49 961 | 40 486 | 30 949 | 24 688 | 20 547 | 10.22 | ||||||||
|
||||||||||||||
Proved Developed Non-Producing | ||||||||||||||
|
||||||||||||||
Mining | | | | | | | ||||||||
In Situ | | | | | | | ||||||||
E&P Canada | | | | | | | ||||||||
|
||||||||||||||
Total Canada | | | | | | | ||||||||
|
||||||||||||||
Offshore U.K. & Norway | 38 | 35 | 34 | 32 | 31 | 74.23 | ||||||||
|
||||||||||||||
Total Proved Developed Non-Producing | 38 | 35 | 34 | 32 | 31 | 74.23 | ||||||||
|
||||||||||||||
Proved Undeveloped | ||||||||||||||
|
||||||||||||||
Mining | | | | | | | ||||||||
In Situ | 36 739 | 19 520 | 11 333 | 7 085 | 4 696 | 10.50 | ||||||||
E&P Canada | 1 972 | 1 723 | 1 484 | 1 283 | 1 121 | 35.97 | ||||||||
|
||||||||||||||
Total Canada | 38 711 | 21 243 | 12 817 | 8 368 | 5 817 | 11.44 | ||||||||
|
||||||||||||||
Offshore U.K. & Norway | 437 | 359 | 294 | 240 | 196 | 29.93 | ||||||||
|
||||||||||||||
Total Proved Undeveloped | 39 147 | 21 601 | 13 111 | 8 609 | 6 013 | 11.60 | ||||||||
|
||||||||||||||
Proved | ||||||||||||||
|
||||||||||||||
Mining | 37 000 | 28 445 | 19 865 | 14 479 | 11 104 | 7.55 | ||||||||
In Situ | 45 725 | 27 411 | 18 329 | 13 360 | 10 387 | 13.43 | ||||||||
E&P Canada | 3 805 | 3 770 | 3 550 | 3 290 | 3 039 | 34.11 | ||||||||
|
||||||||||||||
Total Canada | 86 530 | 59 626 | 41 744 | 31 129 | 24 530 | 10.18 | ||||||||
|
||||||||||||||
Offshore U.K. & Norway | 2 616 | 2 497 | 2 349 | 2 200 | 2 061 | 40.46 | ||||||||
|
||||||||||||||
Total Proved | 89 146 | 62 123 | 44 093 | 33 329 | 26 591 | 10.60 | ||||||||
|
||||||||||||||
Probable | ||||||||||||||
|
||||||||||||||
Mining | 27 472 | 11 922 | 6 432 | 4 010 | 2 758 | 6.77 | ||||||||
In Situ | 71 102 | 19 872 | 7 521 | 3 792 | 2 378 | 6.57 | ||||||||
E&P Canada | 7 163 | 5 076 | 3 584 | 2 589 | 1 915 | 27.40 | ||||||||
|
||||||||||||||
Total Canada | 105 737 | 36 869 | 17 536 | 10 391 | 7 052 | 7.88 | ||||||||
|
||||||||||||||
Offshore U.K. & Norway | 2 079 | 1 690 | 1 366 | 1 117 | 929 | 38.99 | ||||||||
|
||||||||||||||
Total Probable | 107 816 | 38 559 | 18 903 | 11 508 | 7 980 | 8.37 | ||||||||
|
||||||||||||||
Proved Plus Probable | ||||||||||||||
|
||||||||||||||
Mining | 64 472 | 40 367 | 26 297 | 18 489 | 13 862 | 7.34 | ||||||||
In Situ | 116 827 | 47 283 | 25 850 | 17 152 | 12 765 | 10.30 | ||||||||
E&P Canada | 10 968 | 8 846 | 7 134 | 5 879 | 4 955 | 30.37 | ||||||||
|
||||||||||||||
Total Canada | 192 267 | 96 495 | 59 281 | 41 520 | 31 582 | 9.37 | ||||||||
|
||||||||||||||
Offshore U.K. & Norway | 4 696 | 4 187 | 3 715 | 3 317 | 2 989 | 39.91 | ||||||||
|
||||||||||||||
Total Proved Plus Probable | 196 963 | 100 682 | 62 996 | 44 837 | 34 571 | 9.81 | ||||||||
|
Please see the Notes at the end of the Future Net Revenues Tables.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 33
Net Present Values of Future Net Revenues After Income Taxes(1)
as at December 31, 2019
(forecast prices and costs)
(in $ millions, discounted at % per year)
|
||||||||||||
|
||||||||||||
0% | 5% | 10% | 15% | 20% | ||||||||
|
||||||||||||
Proved Developed Producing | ||||||||||||
|
||||||||||||
Mining | 28 142 | 23 022 | 16 293 | 11 982 | 9 272 | |||||||
In Situ | 7 042 | 6 204 | 5 505 | 4 937 | 4 475 | |||||||
E&P Canada | 1 473 | 1 715 | 1 758 | 1 718 | 1 647 | |||||||
|
||||||||||||
Total Canada | 36 657 | 30 941 | 23 555 | 18 637 | 15 394 | |||||||
|
||||||||||||
Offshore U.K. & Norway | 1 246 | 1 228 | 1 186 | 1 137 | 1 088 | |||||||
|
||||||||||||
Total Proved Developed Producing | 37 902 | 32 169 | 24 741 | 19 774 | 16 482 | |||||||
|
||||||||||||
Proved Developed Non-Producing | ||||||||||||
|
||||||||||||
Mining | | | | | | |||||||
In Situ | | | | | | |||||||
E&P Canada | | | | | | |||||||
|
||||||||||||
Total Canada | | | | | | |||||||
|
||||||||||||
Offshore U.K. & Norway | 23 | 22 | 21 | 20 | 19 | |||||||
|
||||||||||||
Total Proved Developed Non-Producing | 23 | 22 | 21 | 20 | 19 | |||||||
|
||||||||||||
Proved Undeveloped | ||||||||||||
|
||||||||||||
Mining | | | | | | |||||||
In Situ | 28 032 | 14 747 | 8 466 | 5 228 | 3 418 | |||||||
E&P Canada | 1 459 | 1 281 | 1 097 | 941 | 814 | |||||||
|
||||||||||||
Total Canada | 29 490 | 16 027 | 9 563 | 6 169 | 4 232 | |||||||
|
||||||||||||
Offshore U.K. & Norway | 395 | 325 | 266 | 219 | 179 | |||||||
|
||||||||||||
Total Proved Undeveloped | 29 885 | 16 352 | 9 829 | 6 387 | 4 411 | |||||||
|
||||||||||||
Proved | ||||||||||||
|
||||||||||||
Mining | 28 142 | 23 022 | 16 293 | 11 982 | 9 272 | |||||||
In Situ | 35 074 | 20 950 | 13 971 | 10 165 | 7 893 | |||||||
E&P Canada | 2 932 | 2 996 | 2 855 | 2 659 | 2 461 | |||||||
|
||||||||||||
Total Canada | 66 147 | 46 968 | 33 118 | 24 806 | 19 626 | |||||||
|
||||||||||||
Offshore U.K. & Norway | 1 663 | 1 574 | 1 473 | 1 376 | 1 286 | |||||||
|
||||||||||||
Total Proved | 67 810 | 48 542 | 34 591 | 26 181 | 20 912 | |||||||
|
||||||||||||
Probable | ||||||||||||
|
||||||||||||
Mining | 21 595 | 9 138 | 4 813 | 2 937 | 1 981 | |||||||
In Situ | 54 598 | 15 186 | 5 756 | 2 919 | 1 841 | |||||||
E&P Canada | 5 283 | 3 739 | 2 593 | 1 828 | 1 315 | |||||||
|
||||||||||||
Total Canada | 81 476 | 28 063 | 13 162 | 7 685 | 5 137 | |||||||
|
||||||||||||
Offshore U.K. & Norway | 1 051 | 892 | 746 | 628 | 535 | |||||||
|
||||||||||||
Total Probable | 82 527 | 28 954 | 13 907 | 8 312 | 5 672 | |||||||
|
||||||||||||
Proved Plus Probable | ||||||||||||
|
||||||||||||
Mining | 49 737 | 32 159 | 21 106 | 14 920 | 11 253 | |||||||
In Situ | 89 672 | 36 136 | 19 727 | 13 084 | 9 734 | |||||||
E&P Canada | 8 214 | 6 735 | 5 448 | 4 487 | 3 776 | |||||||
|
||||||||||||
Total Canada | 147 623 | 75 030 | 46 280 | 32 490 | 24 763 | |||||||
|
||||||||||||
Offshore U.K. & Norway | 2 714 | 2 466 | 2 219 | 2 003 | 1 821 | |||||||
|
||||||||||||
Total Proved Plus Probable | 150 337 | 77 496 | 48 499 | 34 494 | 26 584 | |||||||
|
Please see the Notes at the end of the Future Net Revenues Tables.
34 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Total Future Net Revenues(1)
as at December 31, 2019
(forecast prices and costs)
(in $ millions, undiscounted) | Revenue | Royalties |
Operating
Costs |
Development
Costs |
Abandonment
and Reclamation Costs |
Future Net
Revenues Before Deducting Future Income Tax Expenses |
Future
Income Tax Expenses |
Future Net
Revenues After Deducting Future Income Tax Expenses |
||||||||||
|
||||||||||||||||||
Proved Developed Producing | ||||||||||||||||||
|
||||||||||||||||||
Mining | 245 328 | 20 587 | 139 235 | 30 021 | 18 485 | 37 000 | 8 859 | 28 142 | ||||||||||
In Situ | 24 586 | 3 111 | 9 653 | 2 277 | 559 | 8 986 | 1 944 | 7 042 | ||||||||||
E&P Canada | 6 475 | 826 | 1 890 | 372 | 1 554 | 1 833 | 360 | 1 473 | ||||||||||
|
||||||||||||||||||
Total Canada | 276 390 | 24 524 | 150 779 | 32 670 | 20 597 | 47 820 | 11 163 | 36 657 | ||||||||||
|
||||||||||||||||||
Offshore U.K. & Norway | 4 282 | | 1 383 | 91 | 665 | 2 142 | 896 | 1 246 | ||||||||||
|
||||||||||||||||||
Total Proved Developed Producing | 280 671 | 24 524 | 152 162 | 32 762 | 21 262 | 49 961 | 12 059 | 37 902 | ||||||||||
|
||||||||||||||||||
Proved Developed Non-Producing | ||||||||||||||||||
|
||||||||||||||||||
Mining | | | | | | | | | ||||||||||
In Situ | | | | | | | | | ||||||||||
E&P Canada | | | | | | | | | ||||||||||
|
||||||||||||||||||
Total Canada | | | | | | | | | ||||||||||
|
||||||||||||||||||
Offshore U.K. & Norway | 38 | | 1 | | | 38 | 15 | 23 | ||||||||||
|
||||||||||||||||||
Total Proved Developed Non-Producing | 38 | | 1 | | | 38 | 15 | 23 | ||||||||||
|
||||||||||||||||||
Proved Undeveloped | ||||||||||||||||||
|
||||||||||||||||||
Mining | | | | | | | | | ||||||||||
In Situ | 107 454 | 18 257 | 33 569 | 17 687 | 1 202 | 36 739 | 8 707 | 28 032 | ||||||||||
E&P Canada | 4 090 | 227 | 1 058 | 503 | 331 | 1 972 | 513 | 1 459 | ||||||||||
|
||||||||||||||||||
Total Canada | 111 544 | 18 484 | 34 626 | 18 190 | 1 533 | 38 711 | 9 220 | 29 490 | ||||||||||
|
||||||||||||||||||
Offshore U.K. & Norway | 835 | | 98 | 234 | 66 | 437 | 42 | 395 | ||||||||||
|
||||||||||||||||||
Total Proved Undeveloped | 112 379 | 18 484 | 34 724 | 18 424 | 1 599 | 39 147 | 9 262 | 29 885 | ||||||||||
|
||||||||||||||||||
Proved | ||||||||||||||||||
|
||||||||||||||||||
Mining | 245 328 | 20 587 | 139 235 | 30 021 | 18 485 | 37 000 | 8 859 | 28 142 | ||||||||||
In Situ | 132 040 | 21 368 | 43 222 | 19 964 | 1 761 | 45 725 | 10 652 | 35 074 | ||||||||||
E&P Canada | 10 565 | 1 053 | 2 948 | 875 | 1 884 | 3 805 | 873 | 2 932 | ||||||||||
|
||||||||||||||||||
Total Canada | 387 934 | 43 008 | 185 405 | 50 860 | 22 131 | 86 530 | 20 383 | 66 147 | ||||||||||
|
||||||||||||||||||
Offshore U.K. & Norway | 5 155 | | 1 482 | 326 | 731 | 2 616 | 953 | 1 663 | ||||||||||
|
||||||||||||||||||
Total Proved | 393 089 | 43 008 | 186 887 | 51 186 | 22 862 | 89 146 | 21 336 | 67 810 | ||||||||||
|
||||||||||||||||||
Probable | ||||||||||||||||||
|
||||||||||||||||||
Mining | 111 437 | 12 889 | 59 234 | 9 849 | 1 993 | 27 472 | 5 877 | 21 595 | ||||||||||
In Situ | 188 644 | 38 759 | 52 355 | 25 077 | 1 352 | 71 102 | 16 503 | 54 598 | ||||||||||
E&P Canada | 16 622 | 3 106 | 3 743 | 1 981 | 629 | 7 163 | 1 881 | 5 283 | ||||||||||
|
||||||||||||||||||
Total Canada | 316 703 | 54 754 | 115 332 | 36 907 | 3 974 | 105 737 | 24 261 | 81 476 | ||||||||||
|
||||||||||||||||||
Offshore U.K. & Norway | 3 366 | | 1 034 | 144 | 108 | 2 079 | 1 029 | 1 051 | ||||||||||
|
||||||||||||||||||
Total Probable | 320 069 | 54 754 | 116 366 | 37 051 | 4 082 | 107 816 | 25 289 | 82 527 | ||||||||||
|
||||||||||||||||||
Proved Plus Probable | ||||||||||||||||||
|
||||||||||||||||||
Mining | 356 766 | 33 476 | 198 470 | 39 870 | 20 478 | 64 472 | 14 735 | 49 737 | ||||||||||
In Situ | 320 685 | 60 127 | 95 577 | 45 041 | 3 113 | 116 827 | 27 155 | 89 672 | ||||||||||
E&P Canada | 27 187 | 4 159 | 6 691 | 2 856 | 2 513 | 10 968 | 2 754 | 8 214 | ||||||||||
|
||||||||||||||||||
Total Canada | 704 637 | 97 762 | 300 737 | 87 767 | 26 104 | 192 267 | 44 644 | 147 623 | ||||||||||
|
||||||||||||||||||
Offshore U.K. & Norway | 8 521 | | 2 516 | 470 | 839 | 4 696 | 1 981 | 2 714 | ||||||||||
|
||||||||||||||||||
Total Proved Plus Probable | 713 158 | 97 762 | 303 253 | 88 237 | 26 944 | 196 963 | 46 625 | 150 337 | ||||||||||
|
Please see the Notes at the end of the Future Net Revenues Tables.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 35
Future Net Revenues by Product Type(1)
as at December 31, 2019
(forecast prices and costs)
(before income taxes, discounted at 10% per year) | $ millions |
Unit Value
$/boe(2) |
||||
|
||||||
Proved Developed Producing | ||||||
|
||||||
SCO | 21 529 | 10.76 | ||||
|
||||||
Bitumen | 5 333 | 5.81 | ||||
|
||||||
Light Crude & Medium Crude Oil | 2 594 | 30.52 | ||||
|
||||||
Heavy Crude Oil | 1 483 | 58.65 | ||||
|
||||||
Conventional Natural Gas(3) | 10 | 31.12 | ||||
|
||||||
Total Proved Developed Producing | 30 949 | 10.22 | ||||
|
||||||
Proved | ||||||
|
||||||
SCO | 28 129 | 11.16 | ||||
|
||||||
Bitumen | 10 065 | 6.82 | ||||
|
||||||
Light Crude & Medium Crude Oil | 3 331 | 31.01 | ||||
|
||||||
Heavy Crude Oil | 2 521 | 48.21 | ||||
|
||||||
Conventional Natural Gas(3) | 47 | 19.50 | ||||
|
||||||
Total Proved | 44 093 | 10.60 | ||||
|
||||||
Proved Plus Probable | ||||||
|
||||||
SCO | 40 642 | 10.23 | ||||
|
||||||
Bitumen | 11 506 | 5.43 | ||||
|
||||||
Light Crude & Medium Crude Oil | 7 296 | 30.28 | ||||
|
||||||
Heavy Crude Oil | 3 465 | 42.29 | ||||
|
||||||
Conventional Natural Gas(3) | 89 | 17.40 | ||||
|
||||||
Total Proved Plus Probable | 62 997 | 9.81 | ||||
|
36 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Notes to Future Net Revenues Tables
In Situ Future Net Revenues
Future net revenues for In Situ properties reflect the flexibility of Suncor's operations, which allows production from these properties to be either upgraded to SCO or sold as non-upgraded bitumen. The proportion of upgraded production is based on estimated available upgrading capacity and can vary depending on pricing of the respective products, maintenance, fluctuations in production from mining and extraction operations, or changes in the company's overall Oil Sands development strategy.
In Situ future net revenues disclosed above include estimates of production volumes upgraded to SCO and the associated estimated future sales prices and upgrader operating and sustaining capital costs, based on estimates of upgrader capacity available for processing In Situ volumes. For total Proved Plus Probable reserves, approximately 49% to 57% of Firebag bitumen production is estimated to be upgraded to SCO from 2020 to 2035 and 100% thereafter. These assumptions have resulted in a $3.4 billion increase in the net present value of future net revenues (total Proved Plus Probable reserves, before tax, discounted at 10%) attributable to In Situ production relative to the scenario where none of the bitumen is upgraded.
Revenues and the natural gas fuel expense associated with excess power generated from cogeneration facilities at Firebag are included in future net revenues.
Forecast Prices and Costs
The forecast price and cost assumptions include changes in wellhead selling prices, take into account escalation with respect to future operating and capital costs, and assume the continuance of current laws and regulations. Crude oil, natural gas and other important benchmark reference pricing, as well as inflation and exchange rates utilized in the GLJ Reports and the Sproule Reports, were derived using averages of forecasts developed by GLJ, Sproule and McDaniel & Associates Consultants Ltd., all of whom are independent qualified reserves evaluators, dated January 1, 2020. Resultant forecasts are set out below. To the extent there are fixed or presently determinable future prices to which Suncor is legally bound by contractual or other obligations to supply a physical product, including those for an extension period of a contract that is likely to be extended, those prices have been incorporated into the forecast prices as applied to the pertinent properties. Benchmark forecast prices have been adjusted for quality differentials and transportation costs applicable to the specific evaluation areas and products. The inflation rates utilized in cost forecasts were nil in 2020, 1.7% in 2021, and 2.0% thereafter.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 37
Prices Impacting Reserves Tables
Forecast |
Brent North
Sea(1) |
WTI
Cushing Oklahoma(2) |
WCS
Hardisty Alberta(3) |
Light Sweet
Edmonton Alberta(4) |
Pentanes
Plus Edmonton Alberta(5) |
AECO Gas(6) |
National
Balancing Point North Sea(7) |
||||||||
|
|||||||||||||||
Year | US$/bbl | US$/bbl | Cdn$/bbl | Cdn$/bbl | Cdn$/bbl | Cdn$/mmbtu | Cdn$/mmbtu | ||||||||
|
|||||||||||||||
2019(8) | 64.18 | 57.03 | 58.75 | 69.21 | 70.14 | 1.75 | 3.98 | ||||||||
|
|||||||||||||||
2020 | 66.33 | 61.00 | 57.57 | 72.64 | 76.83 | 2.04 | 7.48 | ||||||||
|
|||||||||||||||
2021 | 67.94 | 63.75 | 62.35 | 76.06 | 79.82 | 2.32 | 7.90 | ||||||||
|
|||||||||||||||
2022 | 70.06 | 66.18 | 64.33 | 78.35 | 82.30 | 2.62 | 8.23 | ||||||||
|
|||||||||||||||
2023 | 71.66 | 67.91 | 66.23 | 80.71 | 84.72 | 2.71 | 8.70 | ||||||||
|
|||||||||||||||
2024 | 73.27 | 69.48 | 67.96 | 82.64 | 86.71 | 2.81 | 8.97 | ||||||||
|
|||||||||||||||
2025 | 74.57 | 71.07 | 69.72 | 84.60 | 88.73 | 2.89 | 9.24 | ||||||||
|
|||||||||||||||
2026 | 76.22 | 72.68 | 71.49 | 86.57 | 90.77 | 2.96 | 9.47 | ||||||||
|
|||||||||||||||
2027 | 77.83 | 74.24 | 73.19 | 88.49 | 92.76 | 3.03 | 9.61 | ||||||||
|
|||||||||||||||
2028 | 79.36 | 75.73 | 74.80 | 90.31 | 94.65 | 3.10 | 9.76 | ||||||||
|
|||||||||||||||
2029 | 80.92 | 77.24 | 76.43 | 92.17 | 96.57 | 3.17 | 9.90 | ||||||||
|
|||||||||||||||
2030 | 82.54 | 78.79 | 77.96 | 94.01 | 98.53 | 3.24 | 10.10 | ||||||||
|
|||||||||||||||
2031 | 84.19 | 80.36 | 79.52 | 95.89 | 100.50 | 3.30 | 10.30 | ||||||||
|
|||||||||||||||
2032 | 85.87 | 81.97 | 81.11 | 97.81 | 102.51 | 3.37 | 10.51 | ||||||||
|
|||||||||||||||
2033 | 87.59 | 83.61 | 82.73 | 99.76 | 104.56 | 3.43 | 10.72 | ||||||||
|
|||||||||||||||
2034 | 89.35 | 85.28 | 84.39 | 101.76 | 106.65 | 3.50 | 10.93 | ||||||||
|
|||||||||||||||
2035+ | +2.0%/yr | +2.0%/yr | +2.0%/yr | +2.0%/yr | +2.0%/yr | +2.0%/yr | +2.0%/yr | ||||||||
|
Forecast Foreign Exchange Rates Impacting Forecast Prices
Forecast |
US$/Cdn$
Exchange Rate |
Cdn$/€
Exchange Rate |
Cdn$/£
Exchange Rate |
||||
|
|||||||
Year | |||||||
|
|||||||
2020 | 0.760 | 1.474 | 1.678 | ||||
|
|||||||
2021 | 0.770 | 1.474 | 1.656 | ||||
|
|||||||
2022 | 0.785 | 1.465 | 1.624 | ||||
|
|||||||
2023 | 0.785 | 1.465 | 1.624 | ||||
|
|||||||
2024 | 0.785 | 1.465 | 1.624 | ||||
|
|||||||
2025+ | 0.785 | 1.465 | 1.624 | ||||
|
Disclosure of Net Present Values of Future Net Revenues After Income Taxes
Values presented in the table for Net Present Values of Future Net Revenues After Income Taxes reflect income tax burdens of assets at a business area or legal entity level based on tax pools associated with that business area or legal entity. Suncor's actual corporate legal entity structure for income taxes and income tax planning has not been considered, and, therefore, the total value for income taxes presented in the total future net revenues table may not provide an estimate of the value at the corporate entity level, which may be significantly different. The 2019 audited Consolidated Financial Statements and the MD&A should be consulted for information on income taxes at the corporate entity level.
38 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Additional Information Relating to Reserves Data
Future Development Costs(1)
as at December 31, 2019
(forecast prices and costs)
($ millions) | 2020 | 2021 | 2022 | 2023 | 2024 | Remainder | Total |
Discounted
At 10% |
||||||||||
|
||||||||||||||||||
Proved | ||||||||||||||||||
|
||||||||||||||||||
Mining | 1 553 | 2 279 | 2 559 | 2 602 | 2 028 | 19 000 | 30 021 | 15 909 | ||||||||||
|
||||||||||||||||||
In Situ | 821 | 1 021 | 796 | 425 | 547 | 16 353 | 19 964 | 7 700 | ||||||||||
|
||||||||||||||||||
E&P Canada | 286 | 149 | 119 | 41 | 57 | 222 | 875 | 727 | ||||||||||
|
||||||||||||||||||
Total Canada | 2 660 | 3 449 | 3 475 | 3 068 | 2 633 | 35 576 | 50 860 | 24 336 | ||||||||||
|
||||||||||||||||||
Offshore U.K. & Norway | 241 | 22 | 6 | 11 | 7 | 38 | 326 | 301 | ||||||||||
|
||||||||||||||||||
Total Proved | 2 901 | 3 471 | 3 481 | 3 079 | 2 640 | 35 613 | 51 186 | 24 637 | ||||||||||
|
||||||||||||||||||
Proved Plus Probable | ||||||||||||||||||
|
||||||||||||||||||
Mining | 1 768 | 2 622 | 3 003 | 3 184 | 2 562 | 26 731 | 39 870 | 19 182 | ||||||||||
|
||||||||||||||||||
In Situ | 807 | 860 | 779 | 502 | 430 | 41 664 | 45 041 | 8 563 | ||||||||||
|
||||||||||||||||||
E&P Canada | 730 | 408 | 414 | 278 | 197 | 828 | 2 856 | 2 263 | ||||||||||
|
||||||||||||||||||
Total Canada | 3 305 | 3 890 | 4 196 | 3 964 | 3 189 | 69 224 | 87 767 | 30 008 | ||||||||||
|
||||||||||||||||||
Offshore U.K. & Norway | 339 | 22 | 6 | 11 | 7 | 84 | 470 | 413 | ||||||||||
|
||||||||||||||||||
Total Proved Plus Probable | 3 644 | 3 912 | 4 202 | 3 975 | 3 196 | 69 307 | 88 237 | 30 421 | ||||||||||
|
Development costs include costs associated with both Developed and Undeveloped reserves. Significant development activities and costs for 2020 are expected to include:
Future development costs disclosed above are associated with reserves as evaluated by GLJ and Sproule and are subject to change based on many factors, including economic conditions. Management currently believes that internally generated cash flows, existing and future credit facilities, issuing commercial paper and accessing capital markets will be sufficient to fund future development costs. There can be no guarantee that funds will be available or that Suncor will allocate funding to develop all of the reserves attributed in the GLJ Reports and the Sproule Reports. Failure to develop those reserves would have a negative impact on future cash flow provided by operating activities.
Interest expense or other costs of external funding are not included in the reserves and future net revenues estimates and could reduce future net revenues to some degree depending upon the funding sources utilized. Suncor does not anticipate that interest expense or other funding costs on their own would make development of any property uneconomic.
Abandonment and Reclamation Costs
The company completes an annual review of its consolidated abandonment and reclamation cost estimates. The estimates are based on the anticipated method and extent of restoration, consistent with legal requirements, technological advances and the possible future use of the site.
As at December 31, 2019, Suncor estimated its undiscounted, uninflated abandonment and reclamation costs for its upstream assets to be approximately $12.7 billion (discounted at 10%, approximately $2.7 billion) excluding Refining and Marketing liabilities ($0.2 billion, undiscounted
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 39
and uninflated). Abandonment and reclamation costs are limited to current disturbances at December 31, 2019 for Suncor's assets, except for Syncrude, which is estimated on a life of mine basis, where it is assumed that material from future disturbances will be required to settle the existing obligation at December 31, 2019. Suncor estimates that it will incur $1.0 billion of its identified abandonment and reclamation costs during the next three years (undiscounted: 2020 $0.5 billion, 2021 $0.2 billion, 2022 $0.2 billion), more than 82% of which is associated with Oil Sands mining operations.
The abandonment and reclamation cost estimates included in the net present values of the company's Proved and Probable reserves include costs related to the reclamation of disturbed land from oil sands mining activities, future mining disturbances, the treatment of legacy oil sands tailings, the decommissioning of oil sands and natural gas processing facilities and well pads, existing and future reserve wells and associated service wells, disturbed lease sites, and future lease site disturbances. Approximately $26.9 billion (inflated and undiscounted) has been deducted as abandonment and reclamation costs in estimating the future net revenues from Proved Plus Probable reserves, including $23.6 billion related to the company's oil sands upgraders, extraction facilities, tailings ponds, subsurface wells and central processing facilities, which includes amounts related to current disturbances.
Gross Proved and Probable Undeveloped Reserves
The tables below outline the gross Proved and Probable Undeveloped reserves and represent Undeveloped reserves additions resulting from acquisitions, discoveries, infill drilling, improved recovery and/or extensions in the year when the events first occurred.
40 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Gross Proved Undeveloped Reserves(1)
(forecast prices and costs)
2017
|
2018
|
2019
|
||||||||||||
|
|
|
|
|||||||||||
First
Attributed |
Total as at
December 31, 2017 |
First
Attributed |
Total as at
December 31, 2018 |
First
Attributed |
Total as at
December 31, 2019 |
|||||||||
|
||||||||||||||
SCO (mmbbls) | ||||||||||||||
|
||||||||||||||
Mining | | | | | | | ||||||||
|
||||||||||||||
In Situ | | 575 | | 548 | 53 | 627 | ||||||||
|
||||||||||||||
Total SCO | | 575 | | 548 | 53 | 627 | ||||||||
|
||||||||||||||
Bitumen (mmbbls) | ||||||||||||||
|
||||||||||||||
Mining | 40 | 929 | | | | | ||||||||
|
||||||||||||||
In Situ | | 675 | | 653 | 52 | 679 | ||||||||
|
||||||||||||||
Total Bitumen | 40 | 1 603 | | 653 | 52 | 679 | ||||||||
|
||||||||||||||
Light Crude & Medium Crude Oil (mmbbls) | ||||||||||||||
|
||||||||||||||
E&P Canada | 1 | 13 | 1 | 15 | 2 | 16 | ||||||||
|
||||||||||||||
Offshore U.K. & Norway | | | 8 | 8 | 1 | 8 | ||||||||
|
||||||||||||||
Total Light Crude & Medium Crude Oil | 1 | 13 | 9 | 23 | 3 | 24 | ||||||||
|
||||||||||||||
Heavy Crude Oil (mmbbls) | ||||||||||||||
|
||||||||||||||
E&P Canada | | 34 | | 46 | | 28 | ||||||||
|
||||||||||||||
Offshore U.K. & Norway | | | | | | | ||||||||
|
||||||||||||||
Total Heavy Crude Oil | | 34 | | 46 | | 28 | ||||||||
|
||||||||||||||
Conventional Natural Gas (bcfe) | ||||||||||||||
|
||||||||||||||
E&P Canada | | | | | | | ||||||||
|
||||||||||||||
Offshore U.K. & Norway(2) | | | 13 | 13 | | 13 | ||||||||
|
||||||||||||||
Total Conventional Natural Gas | | | 13 | 13 | | 13 | ||||||||
|
||||||||||||||
Total (mmboe) | 41 | 2 226 | 11 | 1 273 | 108 | 1 359 | ||||||||
|
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 41
Gross Probable Undeveloped Reserves(1)
(forecast prices and costs)
2017
|
2018
|
2019
|
||||||||||||
|
|
|
|
|||||||||||
First
Attributed |
Total as at
December 31, 2017 |
First
Attributed |
Total as at
December 31, 2018 |
First
Attributed |
Total as at
December 31, 2019 |
|||||||||
|
||||||||||||||
SCO (mmbbls) | ||||||||||||||
|
||||||||||||||
Mining | | 282 | 26 | 308 | | 321 | ||||||||
|
||||||||||||||
In Situ | | 1 167 | | 1 114 | | 1 070 | ||||||||
|
||||||||||||||
Total SCO | | 1 449 | 26 | 1 423 | | 1 391 | ||||||||
|
||||||||||||||
Bitumen (mmbbls) | ||||||||||||||
|
||||||||||||||
Mining | 25 | 581 | | | | | ||||||||
|
||||||||||||||
In Situ | | 275 | | 330 | | 267 | ||||||||
|
||||||||||||||
Total Bitumen | 25 | 856 | | 330 | | 267 | ||||||||
|
||||||||||||||
Light Crude & Medium Crude Oil (mmbbls) | ||||||||||||||
|
||||||||||||||
E&P Canada | 33 | 104 | 1 | 95 | 6 | 96 | ||||||||
|
||||||||||||||
Offshore U.K. & Norway | 2 | 12 | 8 | 9 | 1 | 8 | ||||||||
|
||||||||||||||
Total Light Crude & Medium Crude Oil | 34 | 116 | 9 | 104 | 7 | 104 | ||||||||
|
||||||||||||||
Heavy Crude Oil (mmbbls) | ||||||||||||||
|
||||||||||||||
E&P Canada | | 73 | | 28 | | 15 | ||||||||
|
||||||||||||||
Offshore U.K. & Norway | | | | | | | ||||||||
|
||||||||||||||
Total Heavy Crude Oil | | 73 | | 28 | | 15 | ||||||||
|
||||||||||||||
Conventional Natural Gas (bcfe) | ||||||||||||||
|
||||||||||||||
E&P Canada | | | | | | | ||||||||
|
||||||||||||||
Offshore U.K. & Norway(2) | | 3 | 15 | 15 | | 15 | ||||||||
|
||||||||||||||
Total Conventional Natural Gas | | 3 | 15 | 15 | | 15 | ||||||||
|
||||||||||||||
Total (mmboe) | 59 | 2 494 | 37 | 1 886 | 7 | 1 780 | ||||||||
|
42 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Generally, Proved Undeveloped and Proved Plus Probable Undeveloped reserves are attributed based on the associated confidence levels required for Proved and Proved Plus Probable reserves, respectively, arising from the consideration of factors such as regulatory approvals, availability of markets and infrastructure, development timing, and technical aspects, and have been assigned in accordance with COGE Handbook guidelines. Probable reserves are calculated as the difference between Proved and Proved Plus Probable reserves.
In Situ
Undeveloped In Situ reserves, which constitute approximately 96% of Suncor's gross Proved Undeveloped reserves and 75% of Suncor's gross Probable Undeveloped reserves have been assigned to reserves areas which are not classified as Developed and are related only to those sustaining pads and well pairs required for current producing or sanctioned projects. Suncor has delineated In Situ reserves to a high degree of certainty through seismic data and core hole drilling, consistent with COGE Handbook guidelines. In most cases, reserves have been drilled to a density of 16 delineation wells per section (i.e., 40-acre spacing), which is in excess of the eight delineation wells per section (80-acre spacing) required for regulatory approval. Further delineation is pursued through annual core hole drilling programs to refine development plans. Proved Undeveloped reserves have been assigned to areas delineated with vertical wells on 80-acre well spacing with 3D seismic control or 40-acre spacing without 3D seismic control. Probable Undeveloped areas are limited to areas delineated with vertical wells on 320-acre spacing with seismic control or 160-acre spacing without seismic control. Development of undeveloped In Situ reserves is an ongoing process and is a function of processing capacity and the forecasts of the declining production from existing In Situ wells. When production is forecast to decline, Suncor makes application for and, upon approval, commences development of the reserves and wells surrounding the declining areas. This entails drilling replacement well pairs and constructing sustaining pads and may take several years. Management uses integrated plans to forecast future Proved Undeveloped and Probable Undeveloped reserves development activity. These detailed plans align current production, processing and pipeline constraints (which, in the case of processing constraints, do not permit Suncor to develop all of its undeveloped In Situ reserves within two years), capital spending commitments and future development for the next 10 years, and are updated and approved annually for internal and external factors affecting planned activity. The economic viability of developing sustaining pads and associated well pairs is tested to ensure that ongoing development is economic as required for reserves assessment.
Mining
Undeveloped Mining reserves constitute approximately 18% of Suncor's gross Probable Undeveloped reserves, and relate to the Syncrude MLX-W mining area, which is well-delineated by core hole drilling. The Syncrude MLX-W mining area received AER approval in 2019 and remaining approvals are expected in 2020.
E&P
Undeveloped conventional reserves (light crude oil and medium crude oil, heavy crude oil and natural gas) constitute approximately 4% of Suncor's gross Proved Undeveloped reserves and approximately 7% of Suncor's gross Probable Undeveloped reserves and relate to the company's offshore assets at E&P Canada, mainly associated with future drilling at Hebron, and under-drilled or undrilled fault blocks related to areas in Hibernia, White Rose and Terra Nova, infill drilling in Buzzard and at the Fenja development project offshore Norway. Attribution of Proved Undeveloped and Probable Undeveloped reserves reflect, where applicable, the respective degrees of certainty with respect to various reservoir parameters, primarily drainage areas and recovery factors. In developing undeveloped conventional reserves, Suncor considers existing facility capacity, capital allocation plans, and remaining reserves availability. Suncor plans to proceed with development of essentially all Proved Undeveloped reserves within the next three years and with the development of all Probable Undeveloped reserves within the next five years.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 43
Properties with no Attributed Reserves
The following table is a summary of properties to which no reserves are attributed as at December 31, 2019. For lands in which Suncor holds interests in different formations under the same surface area pursuant to separate leases, the area has been counted for each lease.
Country |
Gross
Hectares |
Net
Hectares |
|||
|
|||||
Canada | 4 679 968 | 3 380 340 | |||
|
|||||
Libya | 3 117 800 | 1 422 900 | |||
|
|||||
Syria | 345 194 | 345 194 | |||
|
|||||
Norway | 264 981 | 96 642 | |||
|
|||||
U.K. | 54 589 | 20 034 | |||
|
|||||
Total | 8 462 532 | 5 265 110 | |||
|
Suncor's unproved properties include exploration properties in a preliminary phase of evaluation, to discovery areas where tenure to the property is held indefinitely on the basis of hydrocarbon test results, but where economic development is not currently possible or has not yet been sanctioned. Certain properties may be in a relatively mature phase of evaluation, where a significant amount of appraisal or even development has occurred; however, reserves cannot be attributed due to one or more contingencies, such as project sanction, or, in the case of Libya and Syria, political unrest. In many cases where reserves are not attributed to lands containing one or more discovery wells, the key limiting factor is the lack of available production infrastructure. Each year, as part of the company's process to review the economic viability of its properties, some properties are selected for further development activities, while others are temporarily deferred, sold, swapped or relinquished back to the mineral rights owner. Refer to the Risk Factors section of this AIF for additional information on risks and uncertainties.
In 2020, Suncor's rights to 61,261 net hectares in Canada, nil net hectares in Norway and 8,732 net hectares in the U.K. are scheduled to expire. The expiries include approximately 27,775 net hectares in In Situ and nil net hectares in Mining. Substantial portions of expiring lands may have their tenure continued beyond 2020 through the conduct of work programs and/or the payment of prescribed fees to the mineral rights owner.
44 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Oil and Gas Properties and Wells
For descriptions of Suncor's important properties, plants, facilities and installations, refer to the Narrative Description of Suncor's Businesses section within this AIF.
The following table is a summary of the company's oil and gas wells as at December 31, 2019.
Oil Wells(1)
|
Natural Gas Wells(1)
|
||||||||||||||||
|
|
||||||||||||||||
Producing
|
Non-Producing(2)(3)
|
Producing
|
Non-Producing(2)(3)
|
||||||||||||||
|
|
|
|
||||||||||||||
Gross | Net | Gross | Net | Gross | Net | Gross | Net | ||||||||||
|
|||||||||||||||||
Alberta In Situ(4) | 408.0 | 408.0 | 34.0 | 34.0 | | | | | |||||||||
|
|||||||||||||||||
Newfoundland and Labrador | 86.0 | 21.5 | 6.0 | 1.7 | | | | | |||||||||
|
|||||||||||||||||
Offshore U.K. & Norway | 50.0 | 14.5 | 1.0 | 0.3 | | | | | |||||||||
|
|||||||||||||||||
Other International(5) | | | 419.0 | 211.1 | | | 6.0 | 6.0 | |||||||||
|
|||||||||||||||||
Total | 544.0 | 444.0 | 460.0 | 247.1 | | | 6.0 | 6.0 | |||||||||
|
There are no producing wells associated with Mining properties. Suncor has no Proved Developed Non-Producing reserves or Probable Developed Non-Producing reserves in its Mining reserves.
For In Situ properties, Proved Non-Producing reserves and Probable Non-Producing reserves, if any, are associated with SAGD well pairs that have typically been drilled within the last three years, yet require further capital for completion and tie in to facilities to bring the wells on-stream. Because this capital is small relative to the cost to drill, complete and tie in a well pair, the associated reserves are considered Developed.
Costs Incurred
The table below summarizes the company's costs incurred related to its oil and gas activities for the year ended December 31, 2019.
($ millions) |
Exploration
Costs |
Proved
Property Acquisition Costs |
Unproved
Property Acquisition Costs |
Development
Costs |
Total | ||||||
|
|||||||||||
Canada Mining and In Situ | 204 | | | 3 580 | 3 784 | ||||||
|
|||||||||||
Canada E&P Canada | 105 | | | 673 | 778 | ||||||
|
|||||||||||
Total Canada | 309 | | | 4 253 | 4 562 | ||||||
|
|||||||||||
Offshore U.K. & Norway | 135 | | | 319 | 454 | ||||||
|
|||||||||||
Other International | 8 | | | | 8 | ||||||
|
|||||||||||
Total | 452 | | | 4 572 | 5 024 | ||||||
|
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 45
Exploration and Development Activities
The table below outlines the gross and net exploratory and development wells the company completed during the year ended December 31, 2019.
Exploratory Wells(1)
|
Development Wells
|
|||||||||
|
|
|||||||||
Total number of wells completed | Gross | Net | Gross | Net | ||||||
|
||||||||||
Canada Oil Sands | ||||||||||
|
||||||||||
Oil | | | 9.0 | 9.0 | ||||||
|
||||||||||
Service(2) | 38.0 | 38.0 | 14.0 | 14.0 | ||||||
|
||||||||||
Stratigraphic Test(3) | 223.0 | 223.0 | 783.0 | 539.7 | ||||||
|
||||||||||
Total | 261.0 | 261.0 | 806.0 | 562.7 | ||||||
|
||||||||||
Canada E&P Canada | ||||||||||
|
||||||||||
Oil | 1.0 | 0.2 | 11.0 | 2.6 | ||||||
|
||||||||||
Dry Hole | 1.0 | 0.3 | | | ||||||
|
||||||||||
Natural Gas | | | | | ||||||
|
||||||||||
Service(2) | | | 3.0 | 0.6 | ||||||
|
||||||||||
Stratigraphic Test | | | | | ||||||
|
||||||||||
Total | 2.0 | 0.5 | 14.0 | 3.2 | ||||||
|
||||||||||
Total Canada | ||||||||||
|
||||||||||
Oil | 1.0 | 0.2 | 20.0 | 11.6 | ||||||
|
||||||||||
Dry Hole | 1.0 | 0.3 | | | ||||||
|
||||||||||
Natural Gas | | | | | ||||||
|
||||||||||
Service(2) | 38.0 | 38.0 | 17.0 | 14.6 | ||||||
|
||||||||||
Stratigraphic Test | 223.0 | 223.0 | 783.0 | 539.7 | ||||||
|
||||||||||
Total | 263.0 | 261.5 | 820.0 | 565.9 | ||||||
|
||||||||||
Offshore U.K. & Norway | ||||||||||
|
||||||||||
Oil | 2.0 | 0.5 | 4.0 | 1.2 | ||||||
|
||||||||||
Dry Hole | 1.0 | 0.4 | | | ||||||
|
||||||||||
Service(2) | | | | | ||||||
|
||||||||||
Stratigraphic Test | | | | | ||||||
|
||||||||||
Total | 3.0 | 0.9 | 4.0 | 1.2 | ||||||
|
46 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Significant exploration and development activities in 2019 included:
For significant exploration and development activities expected to occur in 2020 and beyond, refer to the Narrative Description of Suncor's Businesses and Additional Information Relating to Reserves Data Future Development Costs sections in this AIF.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 47
Production History(1)
2019 | Q1 | Q2 | Q3 | Q4 | Year Ended | ||||||||
|
|||||||||||||
Canada Oil Sands | |||||||||||||
|
|||||||||||||
Total production (mbbls/d) | 657.2 | 692.2 | 670.0 | 662.3 | 670.4 | ||||||||
|
|||||||||||||
Oil Sands operations Bitumen (mbbls/d) | 55.4 | 118.7 | 105.2 | 118.1 | 99.5 | ||||||||
|
|||||||||||||
|
|||||||||||||
($/bbl) | |||||||||||||
|
|||||||||||||
Average price realized(2) | 41.59 | 48.26 | 42.21 | 36.73 | 42.08 | ||||||||
|
|||||||||||||
Royalties | (1.37 | ) | (2.96 | ) | (1.98 | ) | (1.23 | ) | (1.94 | ) | |||
|
|||||||||||||
Production costs | (8.56 | ) | (8.86 | ) | (8.07 | ) | (9.10 | ) | (8.68 | ) | |||
|
|||||||||||||
Netback(4) | 31.66 | 36.44 | 32.16 | 26.40 | 31.46 | ||||||||
|
|||||||||||||
Oil Sands operations SCO and diesel (mbbls/d) | 341.2 | 295.5 | 317.0 | 300.0 | 313.3 | ||||||||
|
|||||||||||||
|
|||||||||||||
($/bbl) | |||||||||||||
|
|||||||||||||
Average price realized(2) | 64.90 | 74.97 | 68.11 | 70.93 | 69.65 | ||||||||
|
|||||||||||||
Royalties | (1.38 | ) | (2.98 | ) | (2.17 | ) | (2.02 | ) | (2.13 | ) | |||
|
|||||||||||||
Production costs | (28.98 | ) | (33.33 | ) | (27.74 | ) | (31.54 | ) | (30.31 | ) | |||
|
|||||||||||||
Netback(4) | 34.54 | 38.66 | 38.20 | 37.37 | 37.21 | ||||||||
|
|||||||||||||
Fort Hills Bitumen (mbbls/d) | 78.4 | 89.3 | 85.5 | 87.9 | 85.3 | ||||||||
|
|||||||||||||
|
|||||||||||||
($/bbl) | |||||||||||||
|
|||||||||||||
Average price realized(2) | 49.95 | 57.10 | 48.50 | 41.41 | 48.96 | ||||||||
|
|||||||||||||
Royalties | (1.43 | ) | (1.27 | ) | (1.70 | ) | (1.10 | ) | (1.37 | ) | |||
|
|||||||||||||
Production costs | (25.17 | ) | (24.43 | ) | (22.75 | ) | (25.19 | ) | (24.35 | ) | |||
|
|||||||||||||
Netback(4) | 23.35 | 31.40 | 24.05 | 15.12 | 23.24 | ||||||||
|
|||||||||||||
Syncrude SCO (mbbls/d) | 182.2 | 188.7 | 162.3 | 156.3 | 172.3 | ||||||||
|
|||||||||||||
|
|||||||||||||
($/bbl) | |||||||||||||
|
|||||||||||||
Average price realized(2) | 67.90 | 79.32 | 74.07 | 72.14 | 73.45 | ||||||||
|
|||||||||||||
Royalties | (8.09 | ) | (12.59 | ) | (9.17 | ) | (4.49 | ) | (8.75 | ) | |||
|
|||||||||||||
Production costs | (31.53 | ) | (28.73 | ) | (33.80 | ) | (32.65 | ) | (31.56 | ) | |||
|
|||||||||||||
Netback(4) | 28.28 | 38.00 | 31.10 | 35.00 | 33.14 | ||||||||
|
|||||||||||||
Canada Light Crude & Medium Crude Oil | |||||||||||||
|
|||||||||||||
Total production (mbbls/d) | 58.3 | 61.9 | 49.6 | 69.6 | 59.9 | ||||||||
|
|||||||||||||
|
|||||||||||||
($/bbl) | |||||||||||||
|
|||||||||||||
Average price realized(2) | 84.60 | 90.48 | 79.39 | 84.36 | 84.86 | ||||||||
|
|||||||||||||
Royalties | (19.75 | ) | (13.65 | ) | (6.54 | ) | (13.46 | ) | (13.62 | ) | |||
|
|||||||||||||
Production costs | (15.63 | ) | (10.96 | ) | (16.49 | ) | (11.28 | ) | (13.45 | ) | |||
|
|||||||||||||
Netback(4) | 49.22 | 65.87 | 56.36 | 59.62 | 57.79 | ||||||||
|
|||||||||||||
Offshore U.K. & Norway Light Crude & Medium Crude Oil(3) | |||||||||||||
|
|||||||||||||
Total production (mboe/d) | 47.1 | 47.2 | 40.6 | 43.6 | 44.6 | ||||||||
|
|||||||||||||
|
|||||||||||||
($/boe) | |||||||||||||
|
|||||||||||||
Average price realized(2) | 83.18 | 87.89 | 75.18 | 78.74 | 81.22 | ||||||||
|
|||||||||||||
Royalties | | | | | | ||||||||
|
|||||||||||||
Production costs | (5.09 | ) | (7.08 | ) | (5.29 | ) | (8.30 | ) | (6.45 | ) | |||
|
|||||||||||||
Netback(4)(5) | 78.09 | 80.81 | 69.89 | 70.42 | 74.77 | ||||||||
|
48 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
The following table provides the production volumes(1) on a working-interest basis, before royalties for each of Suncor's important fields for the year ended December 31, 2019.
SCO | Bitumen |
Light &
Medium Oil |
|||||
|
|||||||
mbbls/d | mbbls/d | mboe/d | |||||
|
|||||||
Mining Suncor | 222.9 | | | ||||
|
|||||||
Mining Syncrude | 172.3 | | | ||||
|
|||||||
Mining Fort Hills | | 85.3 | | ||||
|
|||||||
Firebag | 90.4 | 70.3 | | ||||
|
|||||||
MacKay River | | 29.2 | | ||||
|
|||||||
Buzzard | | | 31.9 | ||||
|
|||||||
GEAD | | | 9.0 | ||||
|
|||||||
Hibernia | | | 20.1 | ||||
|
|||||||
White Rose | | | 4.7 | ||||
|
|||||||
Terra Nova | | | 11.6 | ||||
|
|||||||
Hebron | | | 23.5 | ||||
|
Production Estimates
The table below outlines the production estimates for 2020 that are included in the estimates of Proved reserves and Probable reserves as at December 31, 2019.
SCO
|
Bitumen
|
Light &
Medium Crude Oil |
Conventional
Natural Gas |
Total
|
||||||||||||||||||
|
|
(mbbls/d)(1) |
|
(mbbls/d)(1) |
|
(mbbls/d)(1) |
|
(mmcfe/d)(1)(2) |
|
(mboe/d)(1) |
|
|||||||||||
|
|
Gross |
|
Net |
|
Gross |
|
Net |
|
Gross |
|
Net |
|
Gross |
|
Net |
|
Gross |
|
Net |
|
|
|
||||||||||||||||||||||
Canada | ||||||||||||||||||||||
|
||||||||||||||||||||||
Proved | 452 | 433 | 207 | 195 | 59 | 50 | | | 717 | 679 | ||||||||||||
|
||||||||||||||||||||||
Probable | 32 | 30 | 11 | 8 | 7 | 6 | | | 49 | 45 | ||||||||||||
|
||||||||||||||||||||||
Proved Plus Probable | 483 | 463 | 218 | 204 | 65 | 57 | | | 766 | 724 | ||||||||||||
|
||||||||||||||||||||||
Offshore U.K. & Norway | ||||||||||||||||||||||
|
||||||||||||||||||||||
Proved | | | | | 40 | 40 | 4 | 4 | 40 | 40 | ||||||||||||
|
||||||||||||||||||||||
Probable | | | | | 5 | 5 | 2 | 2 | 5 | 5 | ||||||||||||
|
||||||||||||||||||||||
Proved Plus Probable | | | | | 44 | 44 | 6 | 6 | 45 | 45 | ||||||||||||
|
||||||||||||||||||||||
Total(1)(2) | ||||||||||||||||||||||
|
||||||||||||||||||||||
Proved | 452 | 433 | 207 | 195 | 98 | 90 | 4 | 4 | 757 | 719 | ||||||||||||
|
||||||||||||||||||||||
Probable | 32 | 30 | 11 | 8 | 11 | 11 | 2 | 2 | 54 | 50 | ||||||||||||
|
||||||||||||||||||||||
Proved Plus Probable | 483 | 463 | 218 | 204 | 110 | 101 | 6 | 6 | 811 | 769 | ||||||||||||
|
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 49
The following properties each account for approximately 20% or more of total estimated production for 2020.
Proved
Proved Plus Probable
None of the company's Light & Medium Crude Oil production associated with its E&P Canada and Offshore U.K. & Norway assets accounts for 20% or more of the total estimated production for 2020.
Work Commitments
The practice of governments requiring companies to pledge to carry out work commitments in exchange for the right to carry out exploration for and development of hydrocarbons is common, particularly in unexplored or lightly explored regions of the world. The following table shows the estimated values of work commitments Suncor has made in regard to the lands to which it holds rights as at December 31, 2019. These commitments run through 2021 and beyond, and are primarily for conducting seismic programs and drilling exploration wells.
Country/Area
($ millions) |
2020 | 2021 | 2022+ | Total | |||||
|
|||||||||
Canada | | | | | |||||
|
|||||||||
Other International | | | 499 | 499 | |||||
|
Forward Contracts
Suncor may use financial derivatives to manage its exposure to fluctuations in commodity prices. A description of Suncor's use of such instruments is provided in the 2019 audited Consolidated Financial Statements and related MD&A for the year ended December 31, 2019.
Tax Horizon
In 2019, Suncor was subject to cash tax in the majority of the jurisdictions in which it generates earnings, including earnings related to its Canadian, U.S., U.K. and Libyan production. Based on projected future net earnings, Suncor is expected to be cash taxable on the majority of its earnings in 2020.
50 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
The oil and natural gas industry is subject to extensive controls and regulations governing its operations. These regulations are imposed by legislation enacted by various levels of government and, with respect to the export and taxation of oil and natural gas, by agreements among the governments of Canada, Ontario, Quebec, Alberta, British Columbia, and Newfoundland and Labrador, as well as the governments of the United States and other foreign jurisdictions in which Suncor operates, all of which should be carefully considered by investors in the oil and gas industry. Current legislation is a matter of public record. All governments have the ability to change legislation, and the company is unable to predict what additional legislation or amendments to legislation may be enacted. Suncor may engage in government consultation regarding proposed legislative changes to ensure Suncor's interests are recognized. The following discussion outlines some of the principal legislation, regulations and agreements that govern Suncor's operations.
Pricing, Marketing and Exporting Crude Oil
The producers of oil are entitled to negotiate sales and purchase agreements directly with oil purchasers. Most agreements are linked to global oil prices. In Canada, oil exporters are also entitled to enter into export contracts. If the term of an export contract exceeds one year for light and medium crude oil or exceeds two years for oil other than heavy crude oil (in either case, to a maximum of 25 years), the exporter is required to obtain an export licence from the Canada Energy Regulator (CER, formerly the National Energy Board). If the term of an export contract does not exceed one year for oil other than heavy crude oil or does not exceed two years for heavy crude oil, the exporter is required to obtain an order from the CER approving such export.
In June 2019, Parliament adopted Bill C-69, an Act to enact the Impact Assessment Act and the Canadian Energy Regulator Act, to amend the Navigation Protection Act and to make consequential amendments to other Acts (Bill C-69), which, among other things, established the CER and changed the energy regulatory regime. The changes resulting from Bill C-69 have not materially altered the previous requirements concerning oil exports. However, at this stage, it is not certain whether or when the federal government might issue new or revised regulations that might impact the oil export regime.
Under the North American Free Trade Agreement (NAFTA), Canada is free to determine whether exports of energy resources to the United States or Mexico will be allowed, subject to certain conditions, and provided that any export restrictions do not (i) reduce the proportion of energy resources exported by Canada relative to the total supply of goods exported by Canada as compared to the proportion prevailing in the most recent 36-month period; (ii) impose an export price higher than the domestic price (subject to an exception with respect to certain measures which only restrict the volume of exports); or (iii) disrupt normal channels of supply. All three countries are prohibited from imposing minimum or maximum export or import price requirements.
NAFTA requires energy regulators to ensure the orderly and equitable implementation of any regulatory changes and to ensure that the application of those changes will cause minimal disruption to contractual arrangements and avoid undue interference with pricing, marketing and distribution arrangements, all of which are important for Canadian oil and natural gas exports.
In November 2018, Canada, the U.S. and Mexico signed the Canada-United States-Mexico Agreement (CUSMA) with a view to replacing NAFTA. Under CUSMA, Canada will no longer be subject to the proportionality provisions in NAFTA's energy chapter, which should permit the expansion of oil and gas exports beyond the U.S. In addition, CUSMA includes a change to the oil and gas rules of origin that will allow Canadian exporters to more easily qualify for duty-free treatment for shipments to the U.S. Canada must, however, notify the U.S. of its intention to enter free trade talks with any "non-market economies" under CUSMA, which may include China or other potential importers of Canadian oil and gas exports. Legislatures from each of the three countries must ratify CUSMA according to their own legislative processes before it goes into effect and replaces NAFTA. Legislation implementing the CUSMA was passed by the U.S. House of Representatives and the U.S. Senate on December 19, 2019 and January 16, 2020, respectively, and was signed into law by President Trump on January 29, 2020. In addition, CUSMA was ratified by the Senate of Mexico in June 2019, and will be formally ratified in that country when the President of Mexico announces ratification in the Federal Register of Mexico. Canada's implementation bill was introduced in May 2019 but will need to be re-introduced to Parliament. The timeline for ratification of CUSMA is currently uncertain in Canada.
Internationally, prices for crude oil and natural gas fluctuate in response to changes in the supply of and demand for crude oil and natural gas, market uncertainty and a variety of other factors beyond Suncor's control. These factors include, but are not limited to, the actions of OPEC and other large oil and natural gas producing countries, world economic conditions, government regulation, political developments, the foreign supply of oil, the price of foreign imports, the availability of alternate fuel sources and weather conditions.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 51
Royalties and Income Taxes
Canada
The royalty regime is a significant factor in the profitability of SCO, bitumen, crude oil, NGLs and natural gas production. Royalties on production from lands other than Crown lands are determined by negotiations between the mineral freehold owner and the lessee. Crown royalties are determined by governmental regulation or by agreement with governments in certain circumstances, which are subject to change as a result of numerous factors, including political considerations.
For a discussion of the royalties in Alberta and Newfoundland and Labrador, refer to the Narrative Description of Suncor's Businesses section of this AIF.
The Canadian federal corporate income tax rate levied on taxable income for 2019 was 15% for active business income, including resource income. The average provincial income tax rate for Suncor in 2019 was approximately 11.74%.
On May 28, 2019, the Alberta government substantively enacted legislation to effect a staged reduction to the corporate income tax rate. The legislation decreases the corporate income tax rate from 12% to 8% as follows: 11% effective July 1, 2019, 10% effective January 1, 2020, 9% effective January 1, 2021 and 8% effective January 1, 2022. The reduction in the Alberta corporate income tax rate resulted in a reduction to Suncor's blended provincial income tax rate in 2019 as well as a $1.1 billion reduction to Suncor's consolidated deferred income tax liability.
Other Jurisdictions
Operations in the U.S. are subject to the U.S. federal tax rate of 21% and the effective rate for state taxes is approximately 1.6%, resulting in a total U.S. income tax rate of approximately 22.6%.
Operations in the U.K. are subject to a tax rate of 40%, made up of the corporate income tax rate and the supplemental charge. In Norway, operations are subject to a tax rate of 78%.
Amounts presented in Suncor's 2019 audited Consolidated Financial Statements as royalties for production from the company's Libya operations are determined pursuant to EPSAs. The amounts calculated reflect the difference between Suncor's working interest in the particular project and the net revenue attributable to Suncor under the terms of the respective EPSAs. All government interests in these operations, except for income taxes, are presented as royalties.
Land Tenure
In Canada, crude oil and natural gas located in the western provinces are predominantly owned by the respective provincial governments. Provincial governments grant rights to explore for and produce oil and natural gas pursuant to leases, licences and permits for varying terms, and on conditions set forth in provincial legislation, including requirements to perform specific work or make payments. Oil and natural gas located in the western provinces may also be privately owned, and rights to explore for and produce such oil and natural gas resources are granted pursuant to a private lease on the terms and conditions negotiated with the mineral rights holder. In central and eastern provinces and offshore areas of Canada, the mineral rights are primarily owned by the Canadian federal government, which, either directly or through shared jurisdiction agreements with the relevant provincial or territorial authorities, grants tenure in the form of exploration, significant discovery, and production licences.
In many other international jurisdictions, including the ones in which Suncor has operations, crude oil and natural gas are most commonly owned by national governments that grant rights in the form of exploration licences and permits, production licences, PSCs and other similar forms of tenure. In all cases, Suncor's right to explore, develop and produce crude oil and natural gas is subject to ongoing compliance with the regulatory requirements established by the relevant country.
Environmental Regulation
The company is subject to environmental regulation under a variety of Canadian, U.S., U.K. and other foreign, federal, provincial, territorial, state and municipal laws and regulations. Among other things, these environmental regulatory regimes impose restrictions and prohibitions on the spill, release or emission of various substances including oil and gas and the byproducts associated with the production thereof, which apply to Suncor and all other companies in the energy industry. Applicable regulatory regimes require Suncor to obtain operating licences and permits in order to operate, and impose certain standards and controls on activities relating to mining, oil and gas exploration, development and production, as well as the refining, distribution and marketing of petroleum products and petrochemicals. Environmental assessments and regulatory approvals are generally required before most new major projects or significant changes to existing operations can be initiated. In addition, these environmental regulatory regimes require the company to abandon and reclaim mine, well and facility sites to the satisfaction of regulatory authorities. In some cases, abandonment and reclamation obligations may remain with the company even after disposition of an asset to a third party. Compliance with such legislation can require significant expenditures, and a breach of these requirements may result in suspension or revocation of necessary licences and authorizations, civil liability for pollution damage, and/or the imposition of material fines and penalties.
52 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
In addition to the specific requirements outlined above, Suncor anticipates that future amendments to environmental laws will result in the imposition of additional requirements on companies operating in the energy industry.
A number of statutes, regulations and governance frameworks pertaining to environmental regulation are currently under development and, in some cases, proposed amendments have been issued by the provincial regulators that oversee oil sands development for comment by industry. These statutes, regulations and frameworks relate to issues such as tailings management, water use, biodiversity, air emissions including methane emissions reduction, and land use. The company is committed to working with the appropriate regulatory bodies as they develop new policies, and to fully complying with all existing and new statutes, regulations and frameworks as they apply to the company's operations.
In general, the impact of current and future environmental laws and regulations on the company's business and operations, including laws and regulations relating to climate change, remains uncertain. It is not possible to predict the nature of any future legislative requirements, including those currently set out in the Impact Assessment Act and the Canadian Energy Regulator Act, or the impact the future requirements will have on the company and its business, financial condition and results of operations. Suncor continues to actively work to mitigate the company's environmental impact, including taking action to reduce GHG emissions intensity, installing new emissions abatement equipment, investing in renewable forms of energy, such as wind power and biofuels, undertaking land reclamation activities, investing in environmentally focused research and development, and working to advance other environmental technologies. Refer to the Narrative Description of Suncor's Businesses Oil Sands New Technology section of this AIF.
Recent developments in environmental regulation and related government initiatives have had an impact on many areas important to Suncor's operations, some of which are summarized in the following subsections.
Climate Change
Suncor operates in many jurisdictions that regulate, or have proposed to regulate, industrial GHG emissions. Suncor is committed to fully complying with existing regulations and will continue to constructively engage the appropriate governmental bodies in meaningful dialogue to harmonize regulations focused on achieving actual reduction goals and sustainable resource development across jurisdictions where Suncor owns and operates assets.
As part of its ongoing business planning, Suncor estimates future costs associated with CO2 emissions in its operations and in the evaluation of future projects. These estimates use the company's outlook for the carbon price under current and pending GHG regulations which are used in conjunction with other tools to test the company's business strategy against a range of policy designs. Currently, Suncor applies Provincial and Federal carbon regimes and a price of $30 per tonne of CO2e which steadily increases to approximately $100 per tonne of CO2e in 2040 as part of its base case evaluations. The company expects that GHG emissions regulation will continue to evolve with a carbon price that weighs economic, environmental and energy security objectives. Suncor will continue to review the impact of future carbon-constrained scenarios (and changing carbon pricing) on its business strategy.
Environmental regulations and initiatives related to climate change and GHG emissions are described below.
International Climate Change Agreements
The goals of the Paris Agreement on climate change, an agreement within the United Nations Framework Convention on Climate Change that came into force on November 4, 2016, are to prevent the global temperature rise from exceeding 2 degrees Celsius above pre-industrial levels and to pursue efforts to limit the temperature increase to 1.5 degrees Celsius above pre-industrial levels. Pursuant to the Paris Agreement, the Government of Canada set a goal to reduce GHG emissions economy-wide by 30% below 2005 levels by 2030. The federal government has also signalled its intentions to introduce legislation that will commit Canada to a net-zero emissions goal by 2050.
Canadian Federal GHG Regulations
Enacted and Effective
In furtherance of its commitments under the Paris Agreement, the federal government developed the Pan-Canadian Framework on Clean Growth and Climate Change (PCF) in 2016 to meet Canada's emissions target while enabling economic growth.
Under the PCF, the federal government requires all provinces and territories to have a carbon price, starting at $20 per tonne of CO2e in 2019 and rising by $10 per year to $50 per tonne of CO2e in 2022. Jurisdictions can implement: (i) an explicit price-based system (such as the carbon tax adopted by British Columbia), (ii) the carbon levy and performance-based emissions system (adopted in Alberta), or (iii) cap-and-trade system (which has been adopted in Quebec). Within these programs, provinces have discretion to manage competitiveness of their energy intensive trade-exposed industries. The provincial carbon pricing initiatives applied in Alberta, British Columbia, Quebec, Ontario, and Newfoundland and Labrador and their impact on Suncor are described in the Canadian Provincial GHG Regulations section below.
The 2018 federal Greenhouse Gas Pollution Pricing Act (GGPPA) establishes the federal carbon price on GHG emissions applicable as of January 2019. The GGPPA reinforces the approach taken in the PCF and is only
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 53
intended to serve as a regulatory carbon pricing "backstop" to any province or territory that requests it, or to those jurisdictions that have not otherwise implemented a compliant provincial or territorial carbon pricing regime. The GGPPA consists of two parts: (1) an economy-wide consumer carbon levy on the use and combustion of fossil fuels; and (2) an Output Based Pricing System (OBPS) applied to heavy industrial sectors that face international competition.
Under Development
In addition to GGPPA's carbon pricing "backstop", a Clean Fuel Standard (CFS) is being developed by the federal government with the objective of achieving annual reductions of 30 Mt of CO2e emissions by 2030. The CFS will be implemented under the Canadian Environmental Protection Act (CEPA). When implemented, it is expected that the CFS will require reductions in the carbon intensity of the fuels supplied into Canada, based on a new life cycle analysis model under development by the federal government. The approach is not expected to differentiate between crude oil produced in or imported into Canada. CFS is expected to apply to a broad suite of fuels used in transportation, industry, homes and buildings. The CFS regulations are being developed in stages, based on the class of fuel, and are expected to be finalized and enacted between 2022-23. Until such regulations are published, the company is unable to predict the impact, if any, that CFS will have on its business.
Canadian Provincial GHG Regulations
Alberta
Carbon Competitiveness Incentive Regulation (CCIR)
From January 1, 2018 until December 31, 2019, the applicable Alberta legislation was the CCIR. Under the CCIR, regulated facilities (which included Suncor's Oil Sands Base operations, Firebag, MacKay River, Fort Hills and the Edmonton refinery) were incented to reduce GHG emissions through improving performance by establishing product-based performance standards (also called output-based allocations) across all industries.
Suncor's compliance cost under the CCIR for the 2018 compliance year was $47 million in respect of its owned and operated properties. The 2018 compliance cost for Syncrude was $26 million, net to Suncor.
The 2019 compliance cost for all Suncor's owned and operated Alberta assets was $87 million and $21 million, net to Suncor, for Syncrude, respectively. Fort Hills remained exempt from compliance costs as a "new facility" under the CCIR until the end of 2019.
In addition to the regulations under the CCIR, the Alberta Oil Sands Emissions Limit Act (the OSELA) sets a limit of 100 Mt of CO2e per year in the oil sands sector, excluding emissions from cogeneration and new upgrading capacity, allowing for continued growth and development while the sector works to accelerate emissions reduction technologies and operational optimization. Current oil sands emissions in Alberta are estimated to be 71 Mt per year, including existing upgrading capacity, but excluding cogenerated electricity sold to the Alberta power grid. The mechanics of implementation and enforcement of the OSELA remain under review by the Government of Alberta and, therefore, it is not yet possible to predict the long-term impact on Suncor.
Technology Innovation and Emissions Reduction Implementation Act (TIER)
On October 29, 2019, the Government of Alberta introduced TIER, which includes new carbon pricing legislation for large industrial emitters. TIER came into force on January 1, 2020, replacing CCIR. TIER meets the federal government's stringency benchmark criteria for large industrial emitters for 2020. As a result, the federal output-based carbon pricing system applicable to large industrial emitters, described under GGPPA, will not apply to Alberta. TIER applies to large industrial facilities in Alberta with CO2e emissions in excess of 100,000 tonnes per year which, for Suncor, includes Oil Sands Base, Firebag, MacKay River, Fort Hills and the Edmonton refinery. Such facilities will be required to reduce emissions by 10% starting in 2020 with a further 1% per year reduction thereafter. Failure to meet emissions reduction targets results in being assessed at the prevailing carbon price. The carbon price under TIER will remain unchanged from the CCIR price of $30 per tonne of CO2e.
Electricity generators will continue to be subject to the existing "good-as-best-gas" standard of 370 tonnes of CO2e per GWh. Currently, Suncor's facilities are more efficient than the electricity standard and therefore earn credits.
Under TIER, each of Suncor's facilities is required to comply with the least stringent of either: (1) a facility-specific benchmark based on the average historical performance of that facility between 2013-15; or (2) a high-performance benchmark. All of Suncor's operations fall under the facility-specific benchmark. The high-performance benchmark is a product-specific, high-performance benchmark reflecting emissions intensity of high performance in a sector (calculated as average emissions intensity of the top 10% of facilities). Under TIER, facilities emitting over their prescribed benchmarks will be subject to a compliance obligation, while facilities emitting under their respective benchmarks will be able to generate Emissions Performance Credits (EPCs) and offset credits. Suncor will continue to generate such credits from its cogeneration and renewable energy assets.
Compared to CCIR, TIER is expected to result in lower compliance costs to Suncor. The 2020 estimated compliance cost for all of Suncor's owned and operated Alberta assets is $30 million, and $26 million, net to Suncor, for Syncrude.
54 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Effective as of January 1, 2020, the federal fuel charge under GGPPA will apply to Alberta consumers as a $20 per tonne of CO2e carbon levy on GHG emissions resulting from the combustion of fossil fuels for heating and transportation.
British Columbia
The Province of British Columbia enacted a consumption-based carbon tax in 2008. The purchasers or users of fuels pay the carbon tax, which is collected by Suncor and forwarded onto the government. The tax was $40 per tonne of CO2e in 2019 and will rise to $45 per tonne of CO2e in 2020 and $50 per tonne of CO2e in 2021.
Quebec
Implemented in 2013, Quebec's cap and trade system for greenhouse gas emissions allowances applies to companies in the industrial and electricity sectors that emit 25,000 Mt or greater of CO2e per year. Quebec's cap-and-trade system is linked to the Western Climate Initiative (WCI), an organization set up to help member states in the U.S. and Canadian provinces execute their cap-and-trade systems. Allowances and offsets are fungible across the WCI. In Quebec, emitters are required to either reduce their emissions or purchase eligible compliance mechanisms to cover their emissions above a specified cap. The cap and the allocation of free allowances are established by the Province. Suncor's Montreal refinery is subject to stationary emissions, and associated transportation end-users are subject to Quebec's cap-and-trade system.
For the 2018 and 2019 compliance years, the cost of compliance for the Montreal refinery was $1.2 million and $2 million, respectively. The 2020 estimated compliance cost attributed to the Montreal refinery's stationary emissions is $1.7 million. Compliance costs associated with end-user emissions arising from transportation fuels consumption are passed through to the customer at the time of purchase.
Ontario
Enacted and Effective
Effective January 1, 2018, Ontario formally launched its cap-and-trade system under WCI. Due to a change in government, the program was effectively cancelled July 3, 2018. This was finalized by the passage of Bill 4, Cap and Trade Cancellation Act effective October 31, 2018. As a result, Ontario became subject to the two-part federal government GGPPA program in 2019. Pursuant to the program, facilities that generate more than 25,000 tonnes of GHG emissions per year (including Suncor's Sarnia refinery and St. Clair ethanol plant) are subject to the Output Based Pricing System (OBPS). In addition, the federal carbon levy was applied to the combustion of all fossil fuels by consumers in Ontario. Similar to Quebec, costs attributed to the carbon levy on emissions from transportation fuels are passed through to the customer. Carbon prices pursuant to both aspects of the GGPPA program were $20 per tonne of CO2e in 2019 and $30 per tonne of CO2e in 2020.
For the 2018 and 2019 compliance year, the cost of compliance under the WCI and OBPS for the Sarnia refinery was $3.1 million and a credit of $0.43 million, respectively. For the St. Clair ethanol plant, the cost of compliance under the WCI and OBPS was nil and $0.75 million, respectively. The 2020 estimated compliance costs attributed to the Sarnia refinery and the St. Clair ethanol plant are nil and $1 million, respectively.
Under Development
Since the federal government's GGPPA program has been in place, the Government of Ontario has proposed an Emissions Performance Standards (EPS) that would be a "made in Ontario" carbon pricing system for large emitters. However, the federal government has indicated that Ontario will remain under the GGPPA program until the federal government conducts a countrywide review of provincial and territorial programs in 2022.
Newfoundland and Labrador
Enacted and Effective
Newfoundland and Labrador's carbon pricing program is a hybrid system comprised of performance standards for large industrial facilities, including large-scale electricity generation, plus a consumer carbon tax on transportation, building fuels, and other fuels combusted in the province. Performance standards for large industrial facilities are legislated under the Management of Greenhouse Gas Act (MGGA) and associated regulations, which apply to all facilities that emit 15,000 tonnes of CO2e or more per annum and therefore applies to Terra Nova, Hibernia, White Rose, and Hebron. Consistent with the federal carbon pricing scheme, the Newfoundland and Labrador carbon price started in 2019 at $20 per tonne of CO2e and increased to $30 per tonne of CO2e for 2020.
For 2019, onshore facilities are assigned an annual GHG reduction target equal to 6% below the facility's 2016-17 historical average emissions-to-output ratio. The target increases by 2% per year until the reduction target reaches 12% in 2022. To protect the competitiveness of offshore petroleum facilities, each regulated facility will be assigned the same percentage reductions to its average emissions level, excluding federally regulated emissions for methane from venting and fugitive emissions. Consistent with the government's Advance 2030 initiative to encourage oil and gas development in the province, mobile offshore drilling unit activities related to exploration are exempt from the calculation for the unit's annual GHG reduction target.
The 2019 compliance cost attributed to the company's operated E&P Canada assets (Terra Nova), located offshore Newfoundland and Labrador, was $2.3 million. For 2020, the
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 55
forecast compliance cost is nil due to a planned maintenance turnaround program at Terra Nova.
Under Development
The MGGA also contemplates the establishment of a fund for energy efficient and clean technology through compliance payments made by industrial emitters. This is expected to support technology and innovation as well as provide flexible compliance options and protect the competitiveness of energy-intensive, trade-exposed sectors such as the province's offshore petroleum sector. Large industrial emitters, which include the offshore petroleum sector, account for approximately 43% of the province's current emissions.
U.S. GHG Regulations
Enacted and Effective
The U.S. Environmental Protection Agency (U.S. EPA) has established a rule mandating that all large facilities (defined as facilities emitting greater than 25,000 tonnes of CO2e per year, which includes Suncor's refinery in Commerce City, Colorado) must report their GHG emissions.
In 2019, the State of Colorado passed a suite of energy and climate change related legislation that includes, but is not limited to, setting statewide targets to reduce 2025 GHG emissions by at least 26%; 2030 GHG emissions by 50%; and 2050 GHG emissions by 90%, using a 2005 baseline year. The legislation also includes rules to reduce emissions from the oil and gas sector, including the potential introduction of a low-carbon fuel standard, requirements to monitor, measure, report and forecast stationary emissions from large industrial facilities, and leak detection and repair as well as transitioning Colorado's electricity system to become 80% renewable by 2030 and 100% renewable by 2040. The outcome of these changes in approach to GHG emissions is currently unclear and the impact on Suncor, including its Commerce City, Colorado refinery, is unknown at this time.
Under Development
The mandate of the U.S. EPA is under review by the current administration. In June 2017, the withdrawal of the U.S. from the Paris Agreement was announced, with the current administration commencing formal proceedings to withdraw the U.S. from the Paris Agreement in November 2019. The current administration has also overturned a number of regulations promulgated by previous administrations intended to monitor or restrict climate change.
Notwithstanding the above, the United States Climate Alliance, a network consisting of the governors of 24 states, which include Colorado, remain committed to advancing efforts to address climate change through policies that encourage investment in clean energy, energy efficiency and climate resilience. Suncor continues to monitor these developments and constructively participate where appropriate.
International Regulations
The European Union Emissions Trading Scheme (EU ETS) applies to Suncor's non-operated offshore U.K. and Norway assets. The EU ETS requires that member countries set emissions limits for installations in their country covered by the scheme and assigns such installations an emissions cap. Installations may meet their cap by reducing emissions or by buying allowances from other participants. Phase III of EU ETS includes a transition from free allocation to auctioning allowances.
Land Use
In 2012, the Government of Alberta approved the Lower Athabasca Regional Plan (LARP). The LARP addresses land-use management in the Lower Athabasca region of Alberta, which includes the area of the province in which Suncor's Oil Sands business is located. The LARP, which was developed pursuant to the Alberta Land Stewardship Act, is part of Alberta's approach to managing land and natural resources to achieve long-term economic, environmental and social goals, and identifies new conservation areas as well as management frameworks to ensure the continued regional quality of air, surface water and groundwater. The conservation areas established by LARP do not overlap with any of Suncor's or Syncrude's leases.
The management frameworks established under LARP formalize a number of regulatory tools used by the government to manage environmental aspects of oil sands development, including cumulative environmental effects of management on a regional scale. As a result, LARP may require Suncor and Syncrude to have greater participation in the overall evaluation of environmental issues and emissions in the Lower Athabasca region. The frameworks established under LARP include the following:
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actions will occur when triggers or limits are reached or exceeded.
Suncor is committed to reclaiming and remediating lands affected by its operations. Suncor has improved its tailings management efforts and became the first company to reclaim an oil sands tailings pond, convert a second to a fluid tailings treatment area, and make another pond trafficable with coke capping. Under the TMF, updated tailings management plans have been submitted and approved for Oil Sands Base (2017), Syncrude Aurora North (2018), Syncrude Mildred Lake (2019), and Fort Hills (2019).
Another component identified in the TMF is integrated water management. In order to support successful closure and reclamation, water quantity must be reduced and quality must be managed.
Dam Integrity
The Government of Alberta has a rigorous and stringent regulatory system to manage dams within the province. In December 2018, the Water (Ministerial) Regulation was updated and includes new dam regulatory requirements. The primary purpose of these updates is to address regulatory requirements for in-stream dams (i.e., hydroelectric) requirements. However, these new requirements will also apply to all dams in Alberta, including off-stream dams (i.e., tailings dams).
Throughout 2019, the AER developed regulatory tools to provide guidance for how these new requirements apply to tailings facilities that are regulated by the AER, including oil sands tailings dams. The AER released Manual 019: Decommissioning, Closure, and Abandonment of Dams at Energy Projects (Manual 019) in January 2020, which explains how existing regulatory requirements pertaining to the decommissioning, closure, and abandonment of dams will be assessed and enforced by the AER rather than introducing any new requirements. These regulations are supplemented by Suncor's internal programs which are designed to provide additional oversight in accordance with industry best practices. The provincial dam integrity program may result in additional costs associated with monitoring, planning and measurements in addition to or in advance of current plans. Given the recent release of Manual 019, ongoing uncertainty about how the new regulations will apply to oil sands facilities may result in delay in regulatory approvals for facilities being reviewed under the new requirements.
Reclamation
The Government of Alberta's MFSP accounts for the environmental liability associated with the suspension, abandonment, remediation and surface reclamation of oil
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sands mines and plant sites. The MFSP requires a base amount of security for each project. Suncor has provided this security in the form of letters of credit and is in compliance with the MFSP. Additional security may be required under other conditions, such as failure to meet current reclamation plans, or when the estimated remaining production life of the mine reaches certain levels; however, Suncor has not been required to provide any additional security to date. The MFSP has been designed by the Government of Alberta to include a periodic review of the program to ensure it is functioning properly and provides early warning of any potential risks of a tailings management action specific to the TMF. It is expected that revisions to the MFSP will be completed between 2020 to 2023.
Oil Sands Monitoring
In 2012, Canada and Alberta adopted the Joint Canada-Alberta Implementation Plan for Oil Sands Monitoring (Monitoring Plan). The intent of the Monitoring Plan is to provide scientifically rigorous, comprehensive, integrated and transparent environmental monitoring, including an improved understanding of the cumulative environmental impact of oil sands development. The total cost to the oil sands industry of enhanced monitoring under the Monitoring Plan has been estimated at approximately $50 million per year. The 2019 annual cost to Suncor under the Monitoring Plan is estimated to be approximately $11 million, including Suncor's net share of Syncrude compliance costs.
Industry Collaboration Initiatives
Environmentally focused collaboration between companies and stakeholders is an important focus for the oil sands industry. Suncor is a founding member of Canada's Oil Sands Innovation Alliance (COSIA) and is committed to collaborative action to accelerate improvements in environmental performance, including tailings, water, land, monitoring and GHG emissions. COSIA works with other collaborative networks to share knowledge and expertise about new technologies and innovation related to environmental performance.
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Suncor is committed to a proactive program of enterprise risk management intended to enable decision-making through consistent identification and assessment of risks inherent to its assets, activities and operations. Some of these risks are common to operations in the oil and gas industry as a whole, while some are unique to Suncor. The realization of any of the following risks could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Volatility of Commodity Prices
Suncor's financial performance is closely linked to prices for crude oil in the company's upstream business and prices for refined petroleum products in the company's downstream business and, to a lesser extent, to natural gas and electricity prices in the company's upstream business where natural gas and power are both inputs and outputs of production processes. The prices for all of these commodities can be influenced by global and regional supply and demand factors, which are factors that are beyond the company's control and can result in a high degree of price volatility.
Crude oil prices are also affected by, among other things, global economic health (particularly in emerging markets), market access constraints, regional and international supply and demand imbalances, political developments and government action (including the mandatory production curtailments recently imposed by the Government of Alberta), decisions by OPEC to not impose quotas on its members, compliance or non-compliance with quotas agreed upon by OPEC members and other countries, and weather. These factors impact the various types of crude oil and refined products differently and can impact differentials between light and heavy grades of crude oil (including blended bitumen), and between conventional oil and SCO.
Refined petroleum product prices and refining margins are also affected by, among other things, crude oil prices, the availability of crude oil and other feedstock, levels of refined product inventories, regional refinery availability, market access, marketplace competitiveness, and other local market factors. Natural gas prices in North America are affected by, among other things, supply and demand, and by prices for alternative energy sources. Decreases in product margins or increases in natural gas prices could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
In addition, oil and natural gas producers in North America, and particularly in Canada, may receive discounted prices for their production relative to certain international prices, due in part to constraints on the ability to transport and sell such products to international markets. A failure to resolve such constraints may result in continued discounted or reduced commodity prices realized by oil and natural gas producers such as Suncor. Suncor's production from Oil Sands includes significant quantities of bitumen and SCO that may trade at a discount to light and medium crude oil. Bitumen and SCO are typically more expensive to produce and process. In addition, the market prices for these products may differ from the established market indices for light and medium grades of crude oil. As a result, the price received for bitumen and SCO may differ from the benchmark they are priced against. Future quality differentials are uncertain and unfavourable differentials could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
In the fourth quarter of 2018, there was insufficient market access capacity to remove production from the Western Canada Sedimentary Basin causing the differential between WTI and WCS to widen significantly. The situation triggered a response from the Government of Alberta in the form of a mandatory production curtailment, which commenced in early 2019. Such circumstances may result in worsening and/or prolonged price volatility and/or further negative impacts on market dynamics that cannot currently be fully anticipated. Wide differentials, such as those experienced in the fourth quarter of 2018 or a prolonged period of low and/or volatile commodity prices, particularly for crude oil, could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations, and may also lead to the impairment of assets, or to the cancellation or deferral of Suncor's growth projects.
Market Access
Suncor's production of bitumen is expected to grow. The markets for bitumen blends or heavy crude oil are more limited than those for light crude oil, making them more susceptible to supply and demand changes and imbalances (whether as a result of the availability, proximity, and capacity of pipeline facilities, railcars, or otherwise). Heavy crude oil generally receives lower market prices than light crude, due principally to the lower quality and value of the refined product yield and the higher cost to transport the more viscous product on pipelines, and this price differential can be amplified due to supply and demand imbalances.
Market access for Suncor's oil sands production may be constrained by insufficient pipeline takeaway capacity, including the lack of new pipelines due to an inability to secure required approvals and negative public perception. There is a risk that constrained market access for oil sands production, growing inland production and refinery outages could create widening differentials that could impact the profitability of product sales. Market access for refined products may also be constrained by insufficient takeaway capacity, which could create a supply/demand imbalance. The occurrence of any of the foregoing could have a material adverse effect on the company's business, financial condition, reserves and results of operations.
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Major Operational Incidents (Safety, Environmental and Reliability)
Each of Suncor's primary operating businesses Oil Sands, E&P, and Refining and Marketing requires significant levels of investment in the design, operation, and maintenance and decommissioning of facilities, and carries the additional economic risk associated with operating reliably or enduring a protracted operational outage. The breadth and level of integration of Suncor's operations adds complexity.
The company's businesses also carry the risks associated with environmental and safety performance, which is closely scrutinized by governments, the public and the media, and could result in a suspension of or inability to obtain regulatory approvals and permits, or, in the case of a major environmental or safety incident, delays in resuming normal operations, fines, civil suits or criminal charges against the company.
In general, Suncor's operations are subject to operational hazards and risks such as, among others, fires (including forest fires), explosions, blow-outs, power outages, prolonged periods of extreme cold or extreme heat, severe winter climate conditions, flooding, droughts and other extreme weather conditions, railcar incidents or derailments, the migration of harmful substances such as oil spills, gaseous leaks or a release of tailings into water systems, pollution and other environmental risks, and accidents, any of which can interrupt operations or cause personal injury or death, or damage to property, equipment (including information technology and related data and controls systems), and the environment.
The reliable operation of production and processing facilities at planned levels and Suncor's ability to produce higher value products can also be impacted by, among other things, failure to follow the company's policies, standards and operating procedures or operate within established operating parameters, equipment failure through inadequate maintenance, unanticipated erosion or corrosion of facilities, manufacturing and engineering flaws, and labour shortage or interruption. The company is also subject to operational risks such as sabotage, terrorism, trespass, theft and malicious software, network or cyber attacks.
In addition to the foregoing factors that affect Suncor's business generally, each business unit is susceptible to additional risks due to the nature of its business, including, among others, the following:
Although the company maintains a risk management program, which includes an insurance component, such insurance may not provide comprehensive coverage in all circumstances, nor are all such risks insurable. The company self-insures some risks, and the company's insurance coverage does not cover all the costs arising out of the allocation of liabilities and risk of loss arising from Suncor operations.
The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Government/Regulatory and Policy Effectiveness
Suncor's businesses operate under federal, provincial, territorial, state and municipal laws in numerous countries. The company is also subject to regulation and intervention by governments in oil and gas industry matters, such as, among others, land tenure, royalties, taxes (including income taxes), government fees, production rates (including restrictions on production), environmental protection, wildlife, fish, safety performance, the reduction of GHG and other emissions, the export of crude oil, natural gas and other products, interactions with foreign governments, the awarding or acquisition of exploration and production rights, oil sands leases or other interests, the imposition of specific
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drilling obligations, control over the development, reclamation and abandonment of fields and mine sites, mine financial security requirements, approval of logistics infrastructure, and possibly expropriation or cancellation of contract rights. As part of ongoing operations, the company is also required to comply with a large number of EH&S regulations under a variety of Canadian, U.S., U.K., Norwegian and other foreign, federal, provincial, territorial, state and municipal laws and regulations. Failure to comply with applicable laws and regulations may result in, among other things, the imposition of fines and penalties, production constraints, a compulsory shutdown of facilities or suspension of operations, reputational damage, delays, increased costs, denial of operating and growth permit applications, censure, liability for cleanup costs and damages, and the loss of important licences and permits.
Before proceeding with most major projects, including significant changes to existing operations, Suncor must obtain various federal, provincial, territorial, state and municipal permits and regulatory approvals, and must also obtain licences to operate certain assets. These processes can involve, among other things, Indigenous and stakeholder consultation, environmental impact assessments and public hearings, government intervention and may be subject to conditions, including security deposit obligations and other commitments. Compliance can also be affected by the loss of skilled staff, inadequate internal processes and compliance auditing.
Failure to obtain, comply with, satisfy the conditions of or maintain regulatory permits, licences and approvals, or failure to obtain them on a timely basis or on satisfactory terms, could result in prosecution, fines, delays, abandonment or restructuring of projects and increased costs, all of which could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations. Suncor's businesses can also be indirectly impacted by a third party's inability to obtain regulatory approval for a shared infrastructure project or a third-party infrastructure project on which a portion of Suncor's business depends.
Changes in government policy, regulation or other laws, or the interpretation thereof, or opposition to Suncor's projects or third-party pipeline and infrastructure projects that delays or prevents necessary permits or regulatory approvals, or which makes current operations or growth projects less profitable or uneconomic could materially impact Suncor's operations, existing and planned projects, financial condition, reserves and results of operations. Obtaining necessary approvals or permits has become more difficult due to increased public opposition and Indigenous consultation requirements as well as increased political involvement. The federal government's Impact Assessment Act (formerly Bill C-69) also came into force in August 2019 and will impact the manner in which large energy projects are approved. This development could also lead to significant delays and additional compliance costs, and staffing and resource levels, and also increase exposure to other risks to Suncor's business, including environmental or safety non-compliance, permit approvals, and project development and execution, all of which could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations. Refer to the Industry Conditions section of this AIF.
Suncor is subject to the mandatory production curtailments imposed by the Government of Alberta that commenced in early 2019. The duration, extent and consequences of the curtailments to Suncor's business are not fully known; however, prolonged production curtailment or changes to the curtailment levels could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Greenhouse Gas Emissions and Targets
Among other sustainability goals, Suncor has committed to reducing the total GHG emissions intensity of its oil and gas petroleum products by 30% by 2030 (based on a 2014 baseline year). Our ability to lower GHG emissions on both an absolute basis and in respect of our 2030 total emissions reduction target is subject to numerous risks and uncertainties and our actions taken in implementing these objectives may also expose us to certain additional and/or heightened financial and operational risks.
A reduction in GHG emissions relies on, among other things, our ability to implement and improve energy efficiency at all of our facilities, future development and growth opportunities, develop and deploy new technologies, invest in low-carbon power and transition to low-carbon fuels. In the event that we are unable to implement these strategies and technologies as planned without negatively impacting our expected operations or business plans, or in the event that such strategies or technologies do not perform as expected, we may be unable to meet our GHG targets or goals on the current timelines, or at all.
In addition, achieving our GHG emission reductions target and goals could require significant capital expenditures and resources, with the potential that the costs required to achieve our target and goals materially differ from our original estimates and expectations, which differences may be material. In addition, the shift in resources and focus towards emissions reduction could have a negative impact on our operating results. The overall final cost of investing in and implementing an emissions-intensity reduction strategy and technologies in furtherance of such strategy, and the resultant change in the deployment of our resources and focus, could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
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Competition
The global petroleum industry is highly competitive in many aspects, including the exploration for and the development of new sources of supply, the acquisition of crude oil and natural gas interests, and the refining, distribution and marketing of refined petroleum products. Suncor competes in virtually every aspect of its business with other energy companies. The petroleum industry also competes with other industries in supplying energy, fuel and related products to consumers. The increasing volatility of the political and social landscape at provincial, federal, territorial, state, municipal and international levels adds complexity.
For Suncor's Oil Sands business, it is difficult to assess the number, level of production and ultimate timing of all potential new projects or when existing production levels may increase. Although current commodity pricing and increased regulatory requirements have slowed certain larger projects in the short term, an increase in the level of activity may have an impact on regional infrastructure, including pipelines, and could place stress on the availability and cost of all resources required to build and run new and existing oil sands operations.
For Suncor's Refining and Marketing business, management expects that fluctuations in demand for refined products, margin volatility and overall marketplace competitiveness will continue. In addition, to the extent that the company's downstream business unit participates in new product markets, it could be exposed to margin risk and volatility from either cost and/or selling price fluctuations.
There is a risk that increased competition could cause costs to increase, put further strain on existing infrastructure and cause margins for refined and unrefined products to be volatile, and impact demand for Suncor's products, which could have a material adverse effect on Suncor's business, financial condition and results of operations.
Carbon Risk
Public support for climate change action and receptivity to alternative/renewable energy technologies has grown in recent years. Governments in Canada and around the world have responded to these shifting societal attitudes by adopting ambitious emissions reduction targets and supporting legislation, including measures relating to carbon pricing, clean energy and fuel standards, and alternative energy incentives and mandates. There has also been increased activism and public opposition to fossil fuels, and oil sands in particular. Refer to the Industry Conditions Environmental Regulation Climate Change section of this AIF.
Existing and future laws and regulations may impose significant liabilities on a failure to comply with their requirements. Concerns over climate change, fossil fuel extraction, GHG emissions, and water and land-use practices could lead governments to enact additional or more stringent laws and regulations applicable to Suncor and other companies in the energy industry in general, and in the oil sands industry in particular.
Changes to environmental regulations, including regulation relating to climate change, could impact the demand for, formulation or quality of the company's products, or could require increased capital expenditures, operating expenses, abandonment and reclamation obligations and distribution costs, which may not be recoverable in the marketplace and which may result in current operations or growth projects becoming less profitable or uneconomic. In addition, such regulatory changes could necessitate that Suncor develop new technologies. Such technology development could require a significant investment of capital and resources, and any delay in or failure to identify and develop such technologies or obtain regulatory approvals for these technology projects could prevent Suncor from obtaining regulatory approvals for projects or being able to successfully compete with other companies. Increasing environmental regulation in the jurisdictions in which Suncor operates may also make it difficult for Suncor to compete with companies operating in other jurisdictions with fewer or less costly regulations. In addition, legislation or policies that limit the purchase of production from the oil sands may be adopted in domestic and/or foreign jurisdictions, which, in turn, may limit the world market for Suncor's upstream production and reduce the prices the company receives for its products, and could result in delayed development, stranded assets or the company being unable to further develop its resources. The complexity, breadth and velocity of changes in environmental regulation make it extremely difficult to predict the potential impact to Suncor.
Suncor continues to monitor the international and domestic efforts to address climate change. While it currently appears that GHG regulations and targets will continue to become more stringent, and while Suncor continues its efforts to reduce the intensity of its GHG emissions, the absolute GHG emissions of the company may rise as a result of growth. Increases in GHG emissions may impact the profitability of the company's projects, as Suncor will be subject to incremental levies and taxes. There is also a risk that Suncor could face litigation initiated by third parties relating to climate change, including litigation pertaining to GHG emissions, the production, sale, or promotion of fossil fuels and petroleum products, and/or disclosure. For example, the Board of County Commissioners of Boulder County, the Board of County Commissioners of San Miguel County and the City of Boulder, all of Colorado, have brought an action against Suncor and certain of its subsidiaries seeking, among other things, compensation for impacts they allege with respect to climate change. In addition, the mechanics of implementation and enforcement of the OSELA are currently under review and it is not yet possible to predict the impact
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on Suncor. However, such impact could be material. Refer to the Industry Conditions Environmental Regulation Climate Change Canadian Provincial GHG Regulations (Alberta) section of this AIF.
These developments and future developments could adversely impact the demand for Suncor's products, the ability of Suncor to maintain and grow its production and reserves, and Suncor's reputation, and could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Environmental Compliance
Tailings Management and Water Release
Each oil sands mine is required under the Tailings Directive to seek approval for its updated fluid tailings management plans. If a mine fails to meet a condition of its approved plan, the applicable company could be subject to enforcement actions, including being required to curtail production, and financial consequences, including being subject to a compliance levy or being required to post additional security under the MFSP. The full impact of the TMF, the Tailings Directive and updates to the dam regulations including the financial consequences of exceeding compliance levels, is not yet fully known, as certain associated policy updates and regulation updates are still under development. Such updates could also restrict the technologies that the company may employ for tailings management, which could adversely impact the company's business plans. There could also be risks if the company's tailings management operations fail to operate as anticipated. The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations. Refer to the Industry Conditions Environmental Regulation Land Use and Dam Integrity section of this AIF.
In addition, an integrated water management approach to support operations and successful reclamation and closure requires the release of treated oil sands mine water to the environment, which is not currently permitted for oil sands mines under existing laws. There is no certainty as to when regulations authorizing such water release would be enacted, the content of any such regulations, and the ability of and timing for the company to obtain the required approvals under such regulations to permit such water release. The absence of effective government regulations in this area could impact the success and timing of closure and reclamation plans, which could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Alberta's Land-Use Framework (LARP)
The implementation of, and compliance with, the terms of the LARP may adversely impact Suncor's current properties and projects in northern Alberta due to, among other things, environmental limits and thresholds. The impact of the LARP on Suncor's operations may be outside of the control of the company, as Suncor's operations could be impacted as a result of restrictions imposed due to the cumulative impact of development by the other operators in the area and not solely in relation to Suncor's direct impact. The uncertainty of changes in Suncor's future development and existing operations required as a result of the LARP could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Alberta Environment and Parks (AEP) Water Licences
Suncor currently relies on water obtained under licences from AEP to provide domestic and utility water for the company's Oil Sands business. Water licences, like all regulatory approvals, contain conditions to be met in order to maintain compliance with the licence. There can be no assurance that the licences to withdraw water will not be rescinded or that additional conditions will not be added. It is also possible that regional water management approaches may require water-sharing agreements between stakeholders. In addition, the expansion of the company's projects may rely on securing licences for additional water withdrawal, and there can be no assurance that these licences will be granted in a timely manner or that they will be granted on terms favourable to Suncor. There is also a risk that future laws or changes to existing laws or regulations relating to water access could cause capital expenditures and operating expenses relating to water licence compliance to increase. The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Species at Risk Act
Woodland caribou have been identified as "threatened" under the Species at Risk Act (Canada). In response to the Government of Canada's Recovery Strategy for Woodland Caribou, provincial caribou range plans are being developed. Suncor has existing, planned and potential future projects within caribou ranges in Alberta. The development and implementation of range plans in these areas may have an impact on the pace and amount of development in these areas and could potentially increase costs for restoration or offsetting requirements, which could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Air Quality Management
A number of Canadian federal and provincial air quality regulations and frameworks are currently being developed, changed and/or implemented, which could have an impact on the company's existing and planned projects by requiring the company to invest additional capital or incur additional operating and compliance expenses, including, among other things, potentially requiring the company to retrofit
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equipment to meet new requirements and increase monitoring and mitigation plans. The full impact of these regulations and frameworks is not yet known; however, they could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Alberta Wetland Policy
Pursuant to the Alberta Wetland Policy, development in wetland areas may be obligated to avoid wetlands or mitigate the development's effects on wetlands. Although the full impact of the policy on Suncor is not yet fully known, certain Suncor operations and growth projects will be affected by aspects of the policy where avoidance is not possible and wetland reclamation or replacement may be required, which could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Information Security
The efficient operation of Suncor's business is dependent on computer hardware, software and networked systems, including the systems of cloud providers and third parties with which Suncor conducts business. Digital transformation continues to increase the number of, and complexity of, such systems. In the ordinary course of Suncor's business, Suncor collects and stores sensitive data, including intellectual property, proprietary business information and personal information of the company's employees and retail customers. Suncor's operations are also dependent upon a large and complex information framework. Suncor relies on industry accepted security measures, controls and technology to protect Suncor's information systems and securely maintain confidential and proprietary information stored on the company's information systems, and has adopted a continuous process to identify, assess and manage threats to the company's information systems. While Suncor has an information and cyber security program in place, the measures, controls and technology on which the company relies may not be adequate due to the increasing volume, sophistication and rapidly evolving nature of cyber threats. Suncor's information technology and infrastructure, including process control systems, may be vulnerable to attacks by malicious persons or entities motivated by, among others, geopolitical, financial or activist reasons, or breached due to employee error, malfeasance or other disruptions, including natural disasters and acts of war. Any such attack or breach could compromise Suncor's networks, and the information Suncor stores could be accessed, publicly disclosed, lost, stolen or compromised. Any such attack, breach, access, disclosure or loss of information could result in legal claims or proceedings, liability under laws that protect the privacy of personal information, regulatory penalties, disruptions to Suncor's operations, decreased performance and production, increased costs, and damage to Suncor's reputation, physical harm to people or the environment or other negative consequences to Suncor or third parties, which could have a material adverse effect on Suncor's business, financial condition and results of operations. Although the company maintains a risk management program, which includes an insurance component that may provide coverage for the operational impacts from an attack to, or breach of, Suncor's information technology and infrastructure, including process control systems, the company does not maintain stand-alone cyber insurance. Furthermore, not all cyber risks are insurable. As a result, Suncor's existing insurance may not provide adequate coverage for losses stemming from a cyber attack to, or breach of, its information technology and infrastructure.
Security and Terrorist Threats
Security threats and terrorist or activist activities may impact Suncor's personnel, which could result in injury, death, extortion, hostage situations and/or kidnapping, including unlawful confinement. A security threat, terrorist attack or activist incident targeted at a facility or office owned or operated by Suncor could result in the interruption or cessation of key elements of Suncor's operations. Outcomes of such incidents could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Project Development and Execution
There are certain risks associated with the development and execution of Suncor's major projects and the commissioning and integration of new facilities within its existing asset base.
Project development and execution risk consists of four related primary risks:
Project development and execution can also be impacted by, among other things:
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commodity prices were to decline and stay at low levels for an extended period;
The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Technology Risk
There are risks associated with sustainability, growth and other capital projects that rely largely or partly on new technologies and the incorporation of such technologies into new or existing operations, including that the results of the application of new technologies may differ from simulated, test or pilot environments, or that third-party intellectual property protections may impede the development and implementation of new technology. The success of projects incorporating new technologies cannot be assured. Advantages accrue to companies that can develop and adopt emerging technologies in advance of competitors. The inability to develop, implement and monitor new technologies may impact the company's ability to develop its new or existing operations in a profitable manner or comply with regulatory requirements, which could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Cumulative Impact and Pace of Change
In order to achieve Suncor's business objectives, the company must operate efficiently, reliably and safely, and, at the same time, deliver growth and sustaining projects safely, on budget and on schedule. The ability to achieve these two sets of objectives is critically important for Suncor to deliver value to shareholders and stakeholders. These ambitious business objectives compete for resources, and may negatively impact the company should there be inadequate consideration of the cumulative impacts of prior and parallel initiatives on people, processes and systems. The establishment of the Transformation Management Office to support Suncor's digital transformation is expected to assist with the transformation, but there is still a risk that these objectives may exceed Suncor's capacity to adopt and implement change. The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Joint Arrangement Risk
Suncor has entered into joint arrangements and other contractual arrangements with third parties, including arrangements where other entities operate assets in which Suncor has ownership or other interests. These joint arrangements include, among others, those with respect to Syncrude, Fort Hills, In Situ assets, and operations in Suncor's E&P Canada and E&P International businesses. The success and timing of activities relating to assets and projects operated by others, or developed jointly with others, depend upon a number of factors that are outside of Suncor's control, including, among others, the timing and amount of capital expenditures, the timing and amount of operational and maintenance expenditures, the operator's expertise, financial resources and risk management practices, the approval of other participants, and the selection of technology.
These co-owners may have objectives and interests that do not coincide with and may conflict with Suncor's interests. Major capital decisions affecting joint arrangements may require agreement among the co-owners, while certain operational decisions may be made solely at the discretion of the operator of the applicable assets. While joint venture counterparties may generally seek consensus with respect to major decisions concerning the direction and operation of the assets and the development of projects, no assurance can be provided that the future demands or expectations of the parties relating to such assets and projects will be met satisfactorily or in a timely manner. Failure to satisfactorily meet demands or expectations by all of the parties may affect the company's participation in the operation of such assets or in the development of such projects, the company's ability to obtain or maintain necessary licences or approvals, or the timing for undertaking various activities. In addition, disputes may arise pertaining to the timing, scope, funding
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and/or capital commitments with respect to projects that are being jointly developed.
The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Financial Risks
Energy Trading and Risk Management Activities and the Exposure to Counterparties
The nature of Suncor's energy trading and risk management activities, which may make use of derivative financial instruments to manage its exposure to commodity price and other market risks, creates exposure to financial risks, which include, but are not limited to, the following:
The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition and results of operations.
Exchange Rate Fluctuations
The company's 2019 audited Consolidated Financial Statements are presented in Canadian dollars. The majority of Suncor's revenues from the sale of oil, natural gas and petroleum products are based on prices that are determined by, or referenced to, U.S. dollar benchmark prices, while the majority of Suncor's expenditures are realized in Canadian dollars. The company also owes a portion of its debt in U.S. dollars. Suncor's financial results, therefore, can be affected significantly by the exchange rates between the Canadian dollar and the U.S. dollar. The company also undertakes operations administered through international subsidiaries, and, therefore, to a lesser extent, Suncor's results can be affected by the exchange rates between the Canadian dollar and the euro, the British pound and the Norwegian krone. These exchange rates may vary substantially and may give rise to favourable or unfavourable foreign currency exposure. A decrease in the value of the Canadian dollar relative to the U.S. dollar will increase the revenues received from the sale of commodities. An increase in the value of the Canadian dollar relative to the U.S. dollar will decrease revenue received from the sale of commodities. A decrease in the value of the Canadian dollar relative to the U.S. dollar from the previous balance sheet date increases the amount of Canadian dollars required to settle U.S. dollar denominated obligations. As at December 31, 2019, the Canadian dollar strengthened in relation to the U.S. dollar to $0.77 from $0.73 at the start of 2019. Exchange rate fluctuations could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Interest Rate Risk
The company is exposed to fluctuations in short-term Canadian and U.S. interest rates as Suncor maintains a portion of its debt capacity in revolving and floating rate credit facilities and commercial paper, and invests surplus cash in short-term debt instruments and money market instruments. Suncor is also exposed to interest rate risk when debt instruments are maturing and require refinancing, or when new debt capital needs to be raised. The company is also exposed to changes in interest rates when derivative instruments are used to manage the debt portfolio, including hedges of prospective new debt issuances. Unfavourable changes in interest rates could have a material adverse effect on Suncor's business, financial condition and results of operations.
Issuance of Debt and Debt Covenants
Suncor expects that future capital expenditures will be financed out of cash and cash equivalents balances, cash flow provided by operating activities, available committed credit facilities, issuing commercial paper and accessing capital markets. This ability is dependent on, among other factors, commodity prices, the overall state of the capital markets, and financial institutions and investor appetite for investments in the energy industry generally, and the company's securities in particular. To the extent that external sources of capital become limited or unavailable or available on unfavourable terms, the ability to make capital investments and maintain existing properties may be constrained.
If the company finances capital expenditures in whole or in part with debt, that may increase its debt levels above industry standards for oil and gas companies of similar size. Depending on future development and growth plans, additional debt financing may be required that may not be available or, if available, may not be available on favourable terms, including higher interest rates and fees. Neither the articles of Suncor (the Articles) nor its by-laws limit the amount of indebtedness that may be incurred; however, Suncor is subject to covenants in its existing credit facilities and seeks to avoid an unfavourable cost of debt. The level of the company's indebtedness, from time to time, could impair
66 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
its ability to obtain additional financing on a timely basis to take advantage of business opportunities that may arise and could negatively affect its credit ratings.
Suncor is required to comply with financial and operating covenants under existing credit facilities and debt securities. Covenants are reviewed based on actual and forecast results and the company has the ability to make changes to its development plans, capital structure and/or dividend policy to comply with covenants under the credit facilities. If Suncor does not comply with the covenants under its credit facilities and debt securities, there is a risk that repayment could be accelerated and/or the company's access to capital could be restricted or only be available on unfavourable terms.
Rating agencies regularly evaluate the company, including its subsidiaries. Their ratings of Suncor's long-term and short-term debt are based on a number of factors, including the company's financial strength, as well as factors not entirely within its control, including conditions affecting the oil and gas industry generally, and the wider state of the economy. Credit ratings may be important to customers or counterparties when Suncor competes in certain markets and when it seeks to engage in certain transactions, including transactions involving over-the-counter derivatives. There is a risk that one or more of Suncor's credit ratings could be downgraded, which could potentially limit its access to private and public credit markets and increase the company's cost of borrowing.
The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Royalties and Taxes
Suncor is subject to royalties and taxes imposed by governments in numerous jurisdictions.
Royalties can be impacted by changes in crude oil and natural gas pricing, production volumes, and capital and operating costs, by changes to existing legislation or PSCs, and by results of regulatory audits of prior year filings and other such events. The final determination of these events may have a material impact on the company's royalties expense.
An increase in Suncor's royalties expense, income taxes, property taxes, carbon taxes, levies, tariffs, duties, quotas, border taxes, and other taxes and government-imposed compliance costs could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Dividends and Share Repurchases
Suncor's payment of future dividends on its common shares and future share repurchases by Suncor of its common shares will be dependent on, among other things, legislative and stock exchange requirements, the company's financial condition, results of operations, cash flow, the need for funds to finance ongoing operations and growth projects, debt covenants and other business considerations as the company's Board considers relevant. There can be no assurance that Suncor will continue to pay dividends or repurchase shares in the future.
E&P Reserves Replacement
Suncor's future offshore production, and therefore its cash flows and results of operations from E&P, are highly dependent upon success in exploiting its current reserves base and acquiring or discovering additional reserves. Without additions to its E&P reserves through exploration, acquisition or development activities, Suncor's production from its offshore assets will decline over time as reserves are depleted. The business of exploring for, developing or acquiring reserves is capital intensive. To the extent Suncor's cash flow is insufficient to fund capital expenditures and external sources of capital become limited or unavailable, Suncor's ability to make the necessary capital investments to maintain and expand its reserves will be impaired. In addition, Suncor may be unable to develop or acquire additional reserves to replace its crude oil and natural gas production at acceptable costs.
Uncertainties Affecting Reserves Estimates
There are numerous uncertainties inherent in estimating quantities of reserves, including many factors beyond the company's control. Suncor's actual production, revenues, royalties, taxes, and development and operating expenditures with respect to the company's reserves will vary from its estimates, and such variances could be material. Refer to the Statement of Reserves Data and Other Oil and Gas Information Significant Risk Factors and Uncertainties Affecting Reserves section of this AIF.
Third-Party Service Providers
Suncor's businesses are reliant on the operational integrity of a large number of third-party service providers, including input and output commodity transport (pipelines, rail, trucking, marine) and utilities associated with various Suncor and jointly owned facilities, including electricity. A disruption in service or limited availability by one of these third parties can also have a dramatic impact on Suncor's operations and growth plans. Pipeline constraints that affect takeaway capacity or supply of inputs, such as hydrogen and power for example, could impact the company's ability to produce at capacity levels. Disruptions in pipeline service could adversely affect commodity prices, Suncor's price realizations, refining operations and sales volumes, or limit the company's ability to produce and deliver production. These interruptions may be caused by the inability of the pipeline to operate or by the oversupply of feedstock into the system that exceeds pipeline capacity. Short-term operational constraints on pipeline systems arising from pipeline interruption and/or increased supply of crude oil have occurred in the past and could occur in the future. There is a risk that third-party
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 67
outages could impact Suncor's production or price realizations, which could have a material adverse effect on Suncor's business, financial condition and results of operations.
Foreign Operations
The company has operations in a number of countries with different political, economic and social systems. As a result, the company's operations and related assets are subject to a number of risks and other uncertainties arising from foreign government sovereignty over the company's international operations, which may include, among other things:
If a dispute arises in the company's foreign operations, the company may be subject to the exclusive jurisdiction of foreign courts or may not be able to subject foreign persons to the jurisdiction of a court in Canada or the U.S. In addition, as a result of activities in these areas and a continuing evolution of an international framework for corporate responsibility and accountability for international crimes, there is a risk the company could also be exposed to potential claims for alleged breaches of international or local law.
The impact that future potential terrorist attacks, regional hostilities or political violence, such as that experienced in Libya and Syria, may have on the oil and gas industry, and on our operations in particular, is not known at this time. This uncertainty may affect operations in unpredictable ways, including disruptions of fuel supplies and markets, particularly crude oil, and the possibility that infrastructure facilities, including pipelines, production facilities, processing plants and refineries, could be direct targets of, or collateral damage of, an act of terror, political violence or war. Suncor may be required to incur significant costs in the future to safeguard its assets against terrorist activities or to remediate potential damage to its facilities. There can be no assurance that Suncor will be successful in protecting itself against these risks and the related safety and financial consequences.
Despite Suncor's training and policies around bribery and other forms of corruption, there is a risk that Suncor, or some of its employees or contractors, could be charged with bribery or corruption. Any of these violations could result in onerous penalties. Even allegations of such behaviour could impair Suncor's ability to work with governments or non-government organizations and could result in the formal exclusion of Suncor from a country or area, sanctions, fines, project cancellations or delays, the inability to raise or borrow capital, reputational impacts and increased investor concern.
The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Skills, Resource Shortage and Reliance on Key Personnel
The successful operation of Suncor's businesses and the company's ability to expand operations will depend upon the availability of, and competition for, skilled labour and materials supply. There is a risk that the company may have difficulty sourcing the required labour for current and future operations. The risk could manifest itself primarily through an inability to recruit new staff without a dilution of talent, to train, develop and retain high-quality and experienced staff without unacceptably high attrition, and to satisfy an employee's work/life balance and desire for competitive compensation. The labour market in Alberta has been historically tight, and, while the current economic situation has partially moderated this effect, it remains a risk to be managed. The increasing age of the company's existing workforce and changing skillsets as technology continues to evolve adds further pressure. The availability of competent and skilled contractors for current and future operations is also a risk depending on market conditions. Materials may also be in short supply due to smaller labour forces in many manufacturing operations. Suncor's ability to operate safely and effectively and complete all projects on time and on budget has the potential to be significantly impacted by these risks and this impact could be material.
The company's success also depends in large measure on certain key personnel. The loss of the services of such key personnel could have a material adverse effect on the company. The contributions of the existing management team to the immediate and near-term operations of the company are likely to continue to be of central importance for the foreseeable future.
Labour Relations
Hourly employees at Suncor's oil sands facilities (excluding MacKay River), all of the company's refineries, and the majority of the company's terminal and distribution operations are represented by labour unions or employee
68 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
associations. Approximately 31% of the company's employees were covered by collective agreements at the end of 2019. Negotiations for new collective agreements are in progress for two facilities across the company. Any work interruptions involving the company's employees (including as a result of a strike or lockout), contract trades utilized in the company's projects or operations, or any jointly owned facilities operated by another entity present a significant risk to the company and could have a material adverse effect on Suncor's business, financial condition and results of operations.
Land Claims and Indigenous Consultation
Indigenous Peoples have claimed Indigenous title and rights to portions of Western Canada. In addition, Indigenous Peoples have filed claims against industry participants relating in part to land claims, which may affect the company's business.
The requirement to consult with Indigenous Peoples in respect of oil and gas projects and related infrastructure has also increased in recent years. In addition, in recent years, the Canadian federal government and the provincial government in Alberta have made a commitment to renew their relationships with the Indigenous Peoples of Canada. The federal government has stated it now fully supports the United Nations Declaration on the Rights of Indigenous Peoples (the Declaration) without qualification and that Canada intends "nothing less than to adopt and implement the Declaration in accordance with the Canadian Constitution". At this time, it is unclear how the Declaration will be adopted into Canadian law and the impact of the Declaration on the Crown's duty to consult with Indigenous Peoples.
Suncor is unable to assess the effect, if any, that any such land claims, consultation requirements with Indigenous Peoples or adoption of the Declaration into Canadian law may have on Suncor's business; however, the impact may be material.
Litigation Risk
There is a risk that Suncor or entities in which it has an interest may be subject to litigation, and claims under such litigation may be material. Various types of claims may be raised in these proceedings, including, but not limited to, environmental damage, climate change and the impacts thereof, breach of contract, product liability, antitrust, bribery and other forms of corruption, tax, patent infringement, disclosure, employment matters and in relation to an attack, breach or unauthorized access to Suncor's information technology and infrastructure. Litigation is subject to uncertainty and it is possible that there could be material adverse developments in pending or future cases. Unfavourable outcomes or settlements of litigation could encourage the commencement of additional litigation. Suncor may also be subject to adverse publicity and reputational impacts associated with such matters, regardless of whether Suncor is ultimately found liable. There is a risk that the outcome of such litigation may be materially adverse to the company and/or the company may be required to incur significant expenses or devote significant resources in defence against such litigation, the success of which cannot be guaranteed.
Trade Risk Relating to CUSMA
If CUSMA is ratified, Canada will no longer be subject to the proportionality provisions in NAFTA's energy chapter, enabling Canada to expand oil and gas exports beyond the U.S. Further, a change to the oil and gas rules of origin under CUSMA will allow Canadian exporters to more easily qualify for duty-free treatment for shipments to the U.S. Canada must, however, notify the U.S. of its intention to enter into free trade talks with any "non-market economies" under CUSMA, which may include China or any other importers of Canadian oil and gas exports. Although CUSMA has been signed, Canada has yet to ratify CUSMA according to its legislative processes before it goes into effect and replaces NAFTA. The outcome of the ratification process in Canada is not complete and is therefore uncertain. If CUSMA is not ratified and adopted by all three countries, the sale and transportation of Suncor's products within North America could be affected in a manner which could negatively impact Suncor's business, financial condition and results from operations.
Control Environment
Based on their inherent limitations, disclosure controls and procedures and internal controls over financial reporting may not prevent or detect misstatements, and even those controls determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation. Failure to adequately prevent, detect and correct misstatements could have a material adverse effect on how Suncor's business, financial condition and results of operations are reported.
Insurance Coverage
Suncor maintains insurance coverage as part of its risk management program. However, such insurance may not provide comprehensive coverage in all circumstances, nor are all such risks insurable. The company self-insures some risks, and the company's insurance coverage does not cover all the costs arising out of the allocation of liabilities and risk of loss arising from Suncor operations.
Suncor's insurance policies are generally renewed on an annual basis and, depending on factors such as market conditions, the premiums, policy limits and/or deductibles for certain insurance policies can vary substantially. In some instances, certain insurance may become unavailable or available only for reduced amounts of coverage. Significantly increased costs could lead the company to decide to reduce,
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 69
or possibly eliminate, coverage. In addition, insurance is purchased from a number of third-party insurers, often in layered insurance arrangements, some of whom may discontinue providing insurance coverage for their own policy or strategic reasons. Should any of these insurers refuse to continue to provide insurance coverage, the company's overall risk exposure could be increased.
DIVIDENDS
The Board of Directors has established a practice of paying dividends on Suncor's common shares on a quarterly basis. Suncor reviews its ability to pay dividends from time to time with regard to legislative requirements, the company's financial position, financing requirements for growth, cash flow and other factors. The Board approved a quarterly dividend of $0.32 per common share in each quarter of 2017, a quarterly dividend of $0.36 per common share in each quarter of 2018 and a quarterly dividend of $0.42 per common share in each quarter of 2019. Dividends are paid subject to applicable law, if, as and when declared by the Board.
Year ended December 31 | 2019 | 2018 | 2017 | ||||
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Cash dividends per common share ($) | 1.68 | 1.44 | 1.28 | ||||
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70 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
DESCRIPTION OF CAPITAL STRUCTURE
The company's authorized share capital is comprised of an unlimited number of common shares, an unlimited number of preferred shares issuable in series designated as senior preferred shares, and an unlimited number of preferred shares issuable in series designated as junior preferred shares.
As at December 31, 2019, there were 1,531,873,743 common shares issued and outstanding. To the knowledge of the Board of Directors and executive officers of Suncor, no person beneficially owns, or exercises control or direction over, securities carrying 10% or more of the voting rights attached to any class of voting securities of the company. The holders of common shares are entitled to attend all meetings of shareholders and vote at any such meeting on the basis of one vote for each common share held. Common shareholders are entitled to receive any dividend declared by the Board on the common shares and to participate in a distribution of the company's assets among its shareholders for the purpose of winding up its affairs. The holders of the common shares shall be entitled to share, on a pro rata basis, in all distributions of such assets.
Petro-Canada Public Participation Act
The Petro-Canada Public Participation Act requires that the Articles of Suncor include certain restrictions on the ownership and voting of voting shares of the company. The common shares of Suncor are voting shares. No person, together with associates of that person, may subscribe for, have transferred to that person, hold, beneficially own or control otherwise than by way of security only, or vote in the aggregate, voting shares of Suncor to which are attached more than 20% of the votes attached to all outstanding voting shares of Suncor. Additional restrictions include provisions for suspension of voting rights, forfeiture of dividends, prohibitions against share transfer, compulsory sale of shares, and redemption and suspension of other shareholder rights. The Board may at any time require holders of, or subscribers for, voting shares, and certain other persons, to furnish statutory declarations as to ownership of voting shares and certain other matters relevant to the enforcement of the restrictions. Suncor is prohibited from accepting any subscription for, and issuing or registering a transfer of, any voting shares if a contravention of the individual ownership restrictions results.
Suncor's Articles, as required by the Petro-Canada Public Participation Act, also include provisions requiring Suncor to maintain its head office in Calgary, Alberta; prohibiting Suncor from selling, transferring or otherwise disposing of all or substantially all of its assets in one transaction, or several related transactions, to any one person or group of associated persons, or to non-residents, other than by way of security only in connection with the financing of Suncor; and requiring Suncor to ensure (and to adopt, from time to time, policies describing the manner in which Suncor will fulfil the requirement to ensure) that any member of the public can, in either official language of Canada (English or French), communicate with and obtain available services from Suncor's head office and any other facilities where Suncor determines there is significant demand for communication with, and services from, that facility in that language.
Credit Ratings
The following information regarding the company's credit ratings is provided as it relates to the company's cost of funds and liquidity. In particular, the company's ability to access unsecured funding markets and to engage in certain collateralized business activities on a cost-effective basis is primarily dependent upon maintaining competitive credit ratings. A lowering of the company's credit rating may also have potentially adverse consequences for the company's funding capacity for growth projects or access to the capital markets, may affect the company's ability, and the cost, to enter into normal course derivative or hedging transactions and may require the company to post additional collateral under certain contracts.
The following table shows the ratings issued for Suncor Energy Inc. by the rating agencies noted herein as of February 26, 2020. The credit ratings are not recommendations to purchase, hold or sell the debt securities in as much as such ratings do not comment as to the market price or suitability for a particular investor. Any rating may not remain in effect for any given period of time or may be revised or withdrawn entirely at any time by a rating agency in the future if, in its judgment, circumstances so warrant.
Senior
Unsecured(1) |
Outlook |
Canadian
Commercial Paper Program |
U.S.
Commercial Paper Program |
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Standard & Poor's (S&P) | A- | Stable | A-1 (low) | A-2 | |||||
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Dominion Bond Rating Service (DBRS) | A (low) | Stable | R-1 (low) | Not rated | |||||
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Moody's Investors Service (Moody's) | Baa1 | Stable | Not rated | P-2 | |||||
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2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 71
S&P credit ratings on long-term debt are on a rating scale that ranges from AAA to D, representing the range of such securities rated from highest to lowest quality. A rating of A by S&P is the third highest of 10 categories. An obligation rated A is somewhat more susceptible to the adverse effects of changes in circumstances and economic conditions than obligations in higher rated categories (AA or AAA); however, the obligor's capacity to meet its financial commitment on the obligation is still strong. The addition of a plus (+) or minus (-) designation after the rating indicates the relative standing within a particular rating category. S&P credit ratings on commercial paper are on a short-term debt rating scale that ranges from A-1 to D, representing the range of such securities rated from highest to lowest quality. A Canadian rating by S&P of A-1 (low) is the third highest of eight categories and a U.S. rating of A-2 is the second highest of six categories, indicating a slightly higher susceptibility to the adverse effects of changes in circumstances and economic conditions than obligations in higher categories; the obligor's capacity to meet its financial commitment on the obligation is satisfactory.
DBRS credit ratings on long-term debt are on a rating scale that ranges from AAA to D, representing the range of such securities rated from highest to lowest. A rating of A by DBRS is the third highest of 10 categories and is assigned to debt securities considered to be of good credit quality, with the capacity for the payment of financial obligations being substantial, but of a lesser credit quality than an AA rating. Entities in the A category may be vulnerable to future events, but qualifying negative factors are considered manageable. All rating categories other than AAA and D also contain designations for (high) and (low). The assignment of a (high) or (low) designation within a rating category indicates relative standing within that category. The absence of either a (high) or (low) designation indicates the rating is in the middle of the category. DBRS's credit ratings on commercial paper are on a short-term debt rating scale that ranges from R-1 (high) to D, representing the range of such securities rated from highest to lowest quality. A rating of R-1 (low) by DBRS is the third highest of 10 categories and is assigned to debt securities considered to be of good credit quality. The capacity for the payment of short-term financial obligations as they fall due is substantial, with overall strength not as favourable as higher rating categories. Entities in this category may be vulnerable to future events, but qualifying negative factors are considered manageable. The R-1 and R-2 commercial paper categories are denoted by (high), (middle) and (low) designations.
Moody's credit ratings on long-term debt are on a rating scale that ranges from Aaa to C, which represents the range from highest to lowest quality of such securities rated. A rating of Baa by Moody's is the fourth highest of nine categories. Obligations rated Baa are judged to be medium grade and subject to moderate credit risk and, as such, may possess certain speculative characteristics. A rating of Ba by Moody's is the fifth highest of nine categories. Obligations rated Ba are judged to be speculative and are subject to substantial credit risk. For rating categories Aa through Caa, Moody's appends numerical modifiers 1, 2 or 3 to each generic rating classification. The modifier 1 indicates that the obligation ranks in the higher end of its generic rating category; the modifier 2 indicates a mid-range ranking; and the modifier 3 indicates a ranking in the lower end of that generic rating category. A rating of P-2 by Moody's for commercial paper is the second highest of four rating categories and indicates a strong ability to repay short-term debt obligations.
Suncor has paid each of S&P, DBRS and Moody's their customary fees in connection with the provision of the above ratings. Suncor has not made any payments to S&P, DBRS or Moody's in the past two years for services unrelated to the provision of such ratings.
72 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Suncor's common shares are listed on the TSX in Canada and on the NYSE in the U.S. The price ranges and the volumes traded on the TSX for the year ended December 31, 2019 are as follows:
TSX
Price Range (Cdn$)
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Trading Volume
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High | Low | (000s) | |||||
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2019 | |||||||
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January | 43.28 | 37.28 | 81 482 | ||||
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February | 45.67 | 42.04 | 74 784 | ||||
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March | 46.50 | 43.18 | 102 392 | ||||
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April | 46.00 | 43.11 | 64 879 | ||||
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May | 44.38 | 40.78 | 78 464 | ||||
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June | 42.27 | 40.03 | 72 834 | ||||
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July | 42.77 | 37.54 | 56 307 | ||||
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August | 39.14 | 36.32 | 75 624 | ||||
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September | 43.34 | 37.56 | 95 063 | ||||
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October | 42.11 | 38.05 | 54 710 | ||||
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November | 42.99 | 39.16 | 78 455 | ||||
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December | 43.16 | 40.71 | 78 648 | ||||
|
For information in respect of options to purchase common shares of Suncor and common shares issued upon the exercise of options, see the Share-Based Compensation note to the 2019 audited Consolidated Financial Statements, which is incorporated by reference into this AIF and available on SEDAR at www.sedar.com.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 73
DIRECTORS AND EXECUTIVE OFFICERS
Directors
The following individuals are directors of Suncor on the date hereof. The term of each director is from the date of the meeting at which he or she is elected or appointed until the next annual meeting of shareholders or until a successor is elected or appointed.
Name and Jurisdiction of Residence |
Period Served and
Independence |
Biography | |||
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Patricia M. Bedient(3)(4)
Washington, U.S. |
Director since 2016
Independent |
Patricia Bedient retired as executive vice president of Weyerhaeuser Company (Weyerhaeuser), one of the world's largest integrated forest products companies, effective July 1, 2016. From 2007 until February 2016, she also served as chief financial officer. Prior to this, she held a variety of leadership roles in finance and strategic planning at Weyerhaeuser after joining the company in 2003. Before joining Weyerhaeuser, she spent 27 years with Arthur Andersen LLP and ultimately served as the managing partner for its Seattle office and partner in charge of the firm's forest products practice. Ms. Bedient serves on the board of directors of Alaska Air Group, Inc. and Park Hotels & Resorts Inc. and also serves on the Overlake Hospital Medical Center board of trustees, the Oregon State University board of trustees, and the University of Washington Foster School of Business advisory board. She achieved national recognition in 2012 when The Wall Street Journal named her one of the Top 25 CFOs in the United States. She is a member of the American Institute of CPAs and the Washington Society of CPAs. Ms. Bedient received her bachelor's degree in business administration, with concentrations in finance and accounting, from Oregon State University in 1975. | |||
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Mel E. Benson(1)(2)
Alberta, Canada |
Director since 2000
Independent |
Mel Benson is president of Mel E. Benson Management Services Inc., an international consulting firm working in various countries with a focus on First Nations and corporate negotiations and is currently a director at Tectonic Metals Inc., a mineral exploration company. Mr. Benson retired from Exxon International and Imperial Oil Canada in 2000 after a long career as an operations manager and senior member of project management. While based in Houston, Texas, Mr. Benson worked on international projects based in Africa and the former Soviet Union. Mr. Benson is a member of Beaver Lake Cree Nation, located in northeast Alberta. In 2015, Mr. Benson was inducted into the Aboriginal Business Hall of Fame and received the lifetime achievement award, and he has previously received the Indspire Award for Business. | |||
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74 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
John D. Gass(1)(4)
Florida, U.S. |
Director since 2014
Independent |
John Gass is former vice president, Chevron Corporation, a major integrated oil and gas company, and former president, Chevron Gas and Midstream, positions he held from 2003 until his retirement in 2012. He has extensive international experience, having served in a diverse series of operational positions in the oil and gas industry with increasing responsibility throughout his career. Mr. Gass serves as a director of Southwestern Energy Company. He is also a member of the advisory board for the Vanderbilt Eye Institute. Mr. Gass graduated from Vanderbilt University in Nashville, Tennessee, with a bachelor's degree in civil engineering. He also holds a master's degree in civil engineering from Tulane University in New Orleans, Louisiana. A resident of Florida, he is a member of the American Society of Civil Engineers and the Society of Petroleum Engineers. | |||
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Dennis Houston(1)(2)
Texas, U.S. |
Director since 2018
Independent |
Dennis Houston served as executive vice president of ExxonMobil Refining & Supply Company, chairman and president of ExxonMobil Sales & Supply LLC and chairman of Standard Tankers Bahamas Limited until his retirement in 2010. Prior to that, Mr. Houston held a variety of leadership and engineering roles in the midstream and downstream businesses in the ExxonMobil organization. Mr. Houston has approximately 40 years' experience in the oil and gas industry, including over 35 years with ExxonMobil and its related companies. Mr. Houston serves on the board of directors of Argus Media Limited and GasLog Ltd. Mr. Houston holds a bachelor's degree in chemical engineering from the University of Illinois and an honorary doctorate of public administration degree from Massachusetts Maritime Academy. Mr. Houston has served on a variety of advisory councils, including an appointment by President George H.W. Bush to the National Infrastructure Advisory Council, the Chemical Sciences Leadership Council at the University of Illinois and the Advisory Council Center for Energy, Marine Transportation & Public Policy at Columbia University. Mr. Houston also serves on the Alexander S. Onassis Public Benefit Foundation board, is honorary consul to the Texas Region for the Principality of Liechtenstein and a board member for the American Bureau of Shipping Group of Companies. | |||
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2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 75
Mark Little
Alberta, Canada |
Director since 2019
Non-independent, management |
Mark Little is president and chief executive officer of Suncor. He previously served as the company's president and chief operating officer before being appointed to his current position in May 2019. His past roles include serving as president of Suncor's upstream organization with responsibility for all of Suncor's operated and non-operated oil sands, in situ, conventional exploration and production assets worldwide, as well as executive vice president, Oil Sands and senior vice president, International and Offshore. Mr. Little was also senior vice president, Integration, following Suncor's merger with Petro-Canada and senior vice president, Strategic Growth and Energy Trading. In these roles, Mr. Little's accountabilities have spanned from operations in the Wood Buffalo region to operations in offshore East Coast Canada, the North Sea, and international onshore operations in Latin America, North Africa and the Near East, where he oversaw significant improvements in efficiency and performance, as well as portfolio growth. Before joining Suncor, Mr. Little led the development of oil sands projects for a major international energy company. His past experience also includes leadership roles in oil sands production and refining operations, strategic planning, environment, health and safety, and energy trading. Mr. Little has been active in industry and the community, serving as chair of the board of directors of Syncrude Canada and as a member of Energy Safety Canada until 2018. Mr. Little also was chair of the Oil Sands Safety Association prior to its merger into Energy Safety Canada. Having played an integral role in the signing of agreements with the Fort McKay and Mikisew Cree First Nations relating to Suncor's East Tank Farm, he has actively promoted the partnership as a model for future energy development with Indigenous communities. He is a current member of the Canadian Association of Petroleum Producers, where he also serves as a member of the Executive Committee and Oil Sands CEO Council. He has co-chaired the Canadian Council of Aboriginal Business' procurement initiative and is a past board member of Accenture Global Energy. Mr. Little holds degrees in both computer science from the University of Calgary and applied petroleum engineering technology from SAIT, and is a graduate of the advanced management program at Harvard Business School. | |||
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76 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Brian MacDonald(3)(4)
Florida, U.S. |
Director since 2018
Independent |
Brian MacDonald was the president and chief executive officer of CDK Global, Inc., a leading global provider of integrated information technology and digital marketing solutions to the automotive retail and adjacent industries from 2016 to November 2018. Prior to joining CDK Global, Inc., Mr. MacDonald served as chief executive officer and president of Hertz Equipment Rental Corporation, and served as interim chief executive officer of Hertz Corporation. Mr. MacDonald previously served as president and chief executive officer of ETP Holdco Corporation, an entity formed following Energy Transfer Partners' $5.3 billion acquisition of Sunoco Inc., where Mr. MacDonald had served as chairman, president and chief executive officer. He was the chief financial officer at Sunoco Inc. and held senior financial roles at Dell Inc. Prior to Dell Inc., Mr. MacDonald spent more than 13 years in several financial management roles at General Motors Corporation in North America, Asia and Europe. He previously served on the board of directors for ComputerSciences Corporation (now DXC Technology Company), Ally Financial Inc., Sunoco Inc., Sunoco Logistics L.P. and CDK LGlobal, Inc. Mr. MacDonald earned a MBA from McGill University and a bachelor's of science, with a concentration in chemistry, from Mount Allison University. | |||
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Maureen McCaw(2)(3)
Alberta, Canada |
Director since 2004
(Petro-Canada 2004 to July 31, 2009) Independent |
Maureen McCaw was most recently executive vice-president of Leger Marketing, Canada's largest privately held market research firm and formerly president of Criterion Research, a company she founded. Ms. McCaw currently serves as a director of the Francis Winspear Centre for Music and the Edmonton Symphony Orchestra and the Nature Conservancy of Canada. Ms. McCaw has previously served on a number of boards of directors including as chair of the CBC Pension Plan board of trustees, the Edmonton International Airport and the Edmonton Chamber of Commerce. Ms. Caw has also served on the board of directors of the Canadian Broadcasting Corporation. Ms. Caw holds a bachelor of arts degree in economics from the University of Alberta, completed Columbia Business School's executive program in financial accounting and earned an ICD.D certification from the Institute of Corporate Directors. | |||
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2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 77
Lorraine Mitchelmore(2)(3)
Alberta, Canada |
Director since 2019
Independent |
Lorraine Mitchelmore has over 30 years' international oil and gas industry experience. She most recently served as President and CEO for Field Upgrading, a private equity backed fuel upgrading technology company. Prior to Field Upgrading, she held progressively senior roles at Royal Dutch Shell. Ms. Mitchelmore joined Shell in 2002, becoming President and Country Chair of Shell Canada Limited in 2009. Prior to joining Shell, she worked with Petro-Canada, Chevron and BHP Petroleum in the upstream business units in a combination of technical, exploration & development, and commercial roles. Ms. Mitchelmore has been a director of the Bank of Montreal since 2015 and has served on the Boards of Shell Canada Limited, the Canada Advisory Board at Catalyst, Inc. and Trans Mountain Corporation. Ms. Mitchelmore holds a bachelor's of science in geophysics from Memorial University of Newfoundland, a master's of science in geophysics from the University of Melbourne, Australia and a MBA from Kingston Business School in London, England. | |||
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Eira M. Thomas(1)(4)
Chiswick, United Kingdom |
Director since 2006
Independent |
Eira Thomas is a Canadian geologist with over 25 years of experience in the Canadian diamond business. She is currently the chief executive officer and a director of Lucara Diamond Corp., a publicly traded diamond producing company. Previous roles include serving as chief executive officer and a director of Kaminak Gold Corporation, vice president of Aber Resources, now Dominion Diamond Corp., and as founder and CEO of Stornoway Diamond Corp. Ms. Thomas graduated from the University of Toronto with a bachelor of science degree. Her awards and recognition include: "Canada's Top 40 under 40" by the Caldwell Partners and Report on Business magazine; selected as one of "Top 100 Canada's Most Powerful Women"; and one of only four Canadians in 2008 to be named to the "Young Global Leaders" by the World Economic Forum. | |||
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Michael M. Wilson
Alberta, Canada |
Director since 2014
Independent |
Michael Wilson is former president and chief executive officer of Agrium Inc., a retail supplier of agricultural products and services and a wholesale producer and marketer of agricultural nutrients, a position he held from 2003 until his retirement in 2013. Prior thereto, he served as executive vice president and chief operating officer. Mr. Wilson has significant experience in the petrochemical industry, serving as president of Methanex Corporation, and holding various positions with increasing responsibility in North America and Asia with Dow Chemical Company. Mr. Wilson has a bachelor's degree in chemical engineering from the University of Waterloo and currently serves on the boards of Air Canada and Celestica Inc. | |||
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78 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Executive Officers
The following individuals are the executive officers of Suncor:
Name | Jurisdiction of Residence | Office | |||
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Mark Little | Alberta, Canada | President and Chief Executive Officer | |||
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Alister Cowan | Alberta, Canada | Chief Financial Officer | |||
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Bruno Francoeur | Alberta, Canada | Chief Transformation Officer | |||
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Mike MacSween | Alberta, Canada | Executive Vice President, Upstream | |||
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Steve Reynish | Alberta, Canada | Executive Vice President, Strategy & Operations Services | |||
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Kris Smith | Alberta, Canada | Executive Vice President, Downstream | |||
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Martha Hall Findlay(1) | Alberta, Canada | Chief Sustainability Officer | |||
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Paul Gardner | Alberta, Canada | Chief People Officer | |||
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Arlene Strom | Alberta, Canada | Chief Legal Officer and General Counsel | |||
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All executive officers have held positions with Suncor over the past five years with the exception of Martha Hall Findlay who, immediately prior to joining Suncor in 2019, was President and Chief Executive Officer of the Canada West Foundation.
As at February 21, 2020, the directors and executive officers of Suncor as a group beneficially owned, or controlled or directed, directly or indirectly, 398,419 common shares of Suncor, which represents 0.03% of the outstanding common shares of Suncor.
Cease Trade Orders, Bankruptcies, Penalties or Sanctions
As at the date hereof, no director or executive officer of Suncor is or has been within the last 10 years a director, chief executive officer or chief financial officer of a company (including Suncor) that:
As at the date hereof, no director or executive officer of Suncor, or any of their respective personal holding companies, nor any shareholder holding a sufficient number of securities to affect materially the control of Suncor:
No director or executive officer of Suncor, or any of their respective personal holding companies, nor any shareholder holding a sufficient number of securities to affect materially the control of Suncor, has been subject to:
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 79
AUDIT COMMITTEE INFORMATION
The Audit Committee Mandate is attached as Schedule "A" to this AIF.
Composition of the Audit Committee
The Audit Committee is comprised of Ms. Bedient (Chair), Mr. MacDonald, Ms. McCaw and Ms. Mitchelmore. All members are independent and financially literate. The education and experience of each member that has led to the determination of financial literacy is described in the Directors and Executive Officers section of this AIF.
For the purpose of making appointments to the company's Audit Committee, and in addition to the independence requirements, all directors nominated to the Audit Committee must meet the test of financial literacy as determined in the judgment of the Board of Directors. Also, at least one director so nominated must meet the requirements of being an Audit Committee Financial Expert (as defined below) as determined in the judgment of the Board of Directors. The Audit Committee Financial Experts on the Audit Committee are Ms. Bedient and Mr. MacDonald.
Financial Literacy
Financial literacy can be generally defined as the ability to read and understand a balance sheet, an income statement and a cash flow statement. In assessing a potential appointee's level of financial literacy, the Board of Directors evaluates the totality of the individual's education and experience, including:
Audit Committee Financial Expert
An "Audit Committee Financial Expert" means a person who, in the judgment of the Board of Directors, has the following attributes:
A person shall have acquired the attributes referred to in items (a) through (e) inclusive above through:
80 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
or auditor, or experience in one or more positions that involve the performance of similar functions;
Audit Committee Pre-Approval Policies for Non-Audit Services
Suncor's Audit Committee has considered whether the provision of services other than audit services is compatible with maintaining the company's auditors' independence and has a policy governing the provision of these services. A copy of the company's policy relating to Audit Committee approval of fees paid to the company's auditors, in compliance with the Sarbanes-Oxley Act of 2002 and applicable Canadian securities laws, is attached as Schedule "B" to this AIF.
Fees Paid to Auditors
Fees paid or payable to the company's current auditors, KPMG LLP, in 2019 and to the company's predecessor auditors, PricewaterhouseCoopers LLP, in 2018 are as follows:
($ thousands) | 2019 | 2018 | |||
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Audit Fees | 4 350 | 5 016 | |||
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Audit-Related Fees | 410 | 449 | |||
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Tax Fees | | | |||
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All Other Fees | | 15 | |||
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Total | 4 760 | 5 480 | |||
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Audit Fees were paid, or are payable, for professional services rendered by the auditors for the audit of Suncor's annual financial statements, or services provided in connection with statutory and regulatory filings or engagements. Audit-Related Fees were paid for professional services rendered by the auditors for the review of quarterly financial statements and for the preparation of reports on specified procedures as they relate to audits of joint arrangements and attest services not required by statute or regulation. All Other Fees were subscriptions to auditor-provided and supported tools. All services described beside the captions "Audit Fees", "Audit-Related Fees" and "All Other Fees" were approved by the Audit Committee in compliance with paragraph (c)(7)(i) of Rule 2-01 of Regulation S-X under the U.S. Securities and Exchange Act of 1934, as amended (the Exchange Act). None of the fees described above were approved by the Audit Committee pursuant to paragraph (c)(7)(i)(C) of Regulation S-X under the Exchange Act.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 81
LEGAL PROCEEDINGS AND REGULATORY ACTIONS
There are no legal proceedings in respect of which Suncor is or was a party, or in respect of which any of the company's property is or was the subject during the year ended December 31, 2019, nor are there any such proceedings known by the company to be contemplated, that involve a claim for damages exceeding 10% of the company's current assets. In addition, there have not been any (a) penalties or sanctions imposed against the company by a court relating to securities legislation or by a securities regulatory authority during the year ended December 31, 2019, (b) any other penalties or sanctions imposed by a court or regulatory body against the company that would likely be considered important to a reasonable investor in making an investment decision, or (c) settlement agreements entered into by the company before a court relating to securities legislation or with a securities regulatory authority during the year ended December 31, 2019.
INTERESTS OF MANAGEMENT AND OTHERS IN MATERIAL TRANSACTIONS
No director or executive officer, or any associate or affiliate of these persons has, or has had, any material interest, direct or indirect, in any transaction or any proposed transaction that has materially affected, or is reasonably expected to materially affect, Suncor within the three most recently completed financial years or during the current financial year.
TRANSFER AGENT AND REGISTRAR
The transfer agent and registrar for Suncor's common shares is Computershare Trust Company of Canada at its principal offices in Calgary, Alberta, Montreal, Quebec, Toronto, Ontario and Vancouver, British Columbia, and Computershare Trust Company N.A. in Canton, Massachusetts, Jersey City, New Jersey and Louisville, Kentucky.
MATERIAL CONTRACTS
During the year ended December 31, 2019, Suncor did not enter into any contracts, nor are there any contracts still in effect, that are material to the company's business, other than contracts entered into in the ordinary course of business, which are not required to be filed by Section 12.2 of National Instrument 51-102 Continuous Disclosure Obligations.
INTERESTS OF EXPERTS
Reserves contained in this AIF are based in part upon reports prepared by GLJ and Sproule, Suncor's independent qualified reserves evaluators. As at the date hereof, none of the partners, employees or consultants of GLJ as a group, through registered or beneficial interests, direct or indirect, held or are entitled to receive more than 1% of any class of Suncor's outstanding securities, including the securities of the company's associates and affiliates, and none of the partners, employees or consultants of Sproule, as a group, through registered or beneficial interests, direct or indirect, held or are entitled to receive more than 1% of any class of Suncor's outstanding securities, including the securities of the company's associates and affiliates.
Following the completion of a tender process in 2018, the Board (on the recommendation of the Audit Committee) approved the appointment of KPMG LLP as Suncor's auditor effective March 1, 2019. Pricewaterhouse Coopers LLP, the predecessor auditor, at the request of the company, resigned as auditor of the company effective March 1, 2019.
The company's independent auditors are KPMG LLP, Chartered Professional Accountants, who have issued an independent auditor's report dated February 26, 2020 in respect of the company's Consolidated Financial Statements, which comprise the Consolidated Balance Sheets as at December 31, 2019 and the Consolidated Statements of Comprehensive Income (Loss), Changes in Equity and Cash Flows for the year ended December 31, 2019, and the related notes, and the report on internal control over financial reporting as at December 31, 2019. KPMG LLP has advised 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 and the rules of the United States Securities and Exchange Commission (SEC).
The company's predecessor independent auditors were Pricewaterhouse Coopers LLP, who were the auditors for the company for the year ended December 31, 2018. As of February 28, 2019 and throughout the period covered by the financial statements upon which they reported, PricewaterhouseCoopers LLP were independent with respect to the company within the meaning of the Rules of Professional Conduct of the Chartered Professional Accountants of Alberta and the rules of the SEC.
82 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
DISCLOSURE PURSUANT TO THE REQUIREMENTS OF THE NYSE
As a Canadian issuer listed on the NYSE, Suncor is not required to comply with most of the NYSE's governance rules and instead may comply with Canadian requirements. As a foreign private issuer, the company is only required to comply with four of the NYSE's governance rules. These rules provide that (i) Suncor must have an audit committee that satisfies the requirements of Rule 10A-3 under the Exchange Act; (ii) the Chief Executive Officer of Suncor must promptly notify the NYSE in writing after an executive officer becomes aware of any material non-compliance with the applicable NYSE rules; (iii) Suncor must provide a brief description of any significant differences between the company's corporate governance practices and those followed by U.S. companies listed under the NYSE; and (iv) Suncor must provide annual and, as required, written affirmations of compliance with applicable NYSE Corporate Governance Standards.
The company has disclosed in its 2020 management proxy circular, which is available on Suncor's website at www.suncor.com, significant areas in which the company does not comply with the NYSE Corporate Governance Standards. In certain instances, it is not required to obtain shareholder approval for material amendments to equity compensation plans under TSX requirements, while the NYSE requires shareholder approval of all equity compensation plans. Suncor, while in compliance with the independence requirements of applicable securities laws in Canada (specifically National Instrument 52-110 Audit Committees) and the U.S. (specifically Rule 10A-3 of the Exchange Act), has not adopted, and is not required to adopt, the director independence standards contained in Section 303A.02 of the NYSE's Listed Company Manual, including with respect to its audit committee and compensation committee. The Board has not adopted, nor is it required to adopt, procedures to implement Section 303A.05(c)(iv) of the NYSE's Listed Company Manual in respect of compensation committee advisor independence. Except as described herein, the company is in compliance with the NYSE Corporate Governance Standards in all other significant respects.
ADDITIONAL INFORMATION
Additional information, including directors' and officers' remuneration and indebtedness, principal holders of Suncor's securities, and securities authorized for issuance under equity compensation plans, where applicable, is contained in the company's most recent management proxy circular for the most recent annual meeting of shareholders that involved the election of directors. Additional financial information is provided in Suncor's 2019 audited Consolidated Financial Statements and in the MD&A.
Further information about Suncor, filed with Canadian securities commissions and the SEC, including periodic quarterly and annual reports and the Form 40-F, is available online on SEDAR at www.sedar.com and on EDGAR at www.sec.gov. In addition, Suncor's Standards of Business Conduct Code is available online at www.suncor.com. Information contained in or otherwise accessible through the company's website does not form part of this AIF, and is not incorporated into the AIF by reference.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 83
ADVISORY FORWARD-LOOKING
INFORMATION
AND NON-GAAP FINANCIAL MEASURES
This AIF contains certain forward-looking statements and forward-looking information (collectively, forward-looking statements) within the meaning of applicable Canadian and U.S. securities laws and other information based on Suncor's current expectations, estimates, projections and assumptions that were made by the company in light of information available at the time the statement was made and consider Suncor's experience and its perception of historical trends, including expectations and assumptions concerning: the accuracy of reserves and resources estimates; commodity prices and interest and foreign exchange rates; the performance of assets and equipment; capital efficiencies and cost-savings; applicable laws and government policies; future production rates; the sufficiency of budgeted capital expenditures in carrying out planned activities; the availability and cost of labour, services and infrastructure; the satisfaction by third parties of their obligations to Suncor; the development and execution of projects; and the receipt, in a timely manner, of regulatory and third-party approvals. All statements and information that address expectations or projections about the future, and statements and information about Suncor's strategy for growth, expected and future expenditures or investment decisions, commodity prices, costs, schedules, production volumes, operating and financial results, future financing and capital activities, and the expected impact of future commitments are forward-looking statements. Some of the forward-looking statements may be identified by words like "expects", "anticipates", "will", "estimates", "plans", "scheduled", "intends", "believes", "projects", "indicates", "could", "focus", "vision", "goal", "outlook", "proposed", "target", "objective", "continue", "should", "may", "potential", "future", "opportunity", "would", "forecast" and similar expressions.
Forward-looking statements in this AIF include references to:
Suncor's strategy, business plans and expectations about projects, the performance of assets, production volumes, and capital expenditures, including:
84 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
sustained reliability improvements and reduce costs at Syncrude, the opportunity for cost management and collaboration between the company and Syncrude, expectations for the bi-directional interconnecting pipelines between Syncrude's Mildred Lake site and Suncor's Oil Sands Base, including that the pipelines will provide increased operational flexibility through the ability to transfer bitumen and gas oils between the two plants, enabling higher reliability and utilization, the expectation that the pipelines will be in-service by the second half of 2020, and the expectation that sustaining capital expenditures in 2020 at Syncrude will focus on a planned turnaround and reliability improvements;
Also:
Forward-looking statements are not guarantees of future performance and involve a number of risks and uncertainties, some that are similar to other oil and gas companies and some that are unique to Suncor. Suncor's actual results may differ materially from those expressed or implied by its forward-looking statements, so readers are cautioned not to place undue reliance on them.
The financial and operating performance of the company's reportable operating segments, specifically Oil Sands, Exploration and Production, and Refining and Marketing, may be affected by a number of factors.
Factors that affect Suncor's Oil Sands segment include, but are not limited to, volatility in the prices for crude oil and other production, and the related impacts of fluctuating light/heavy and sweet/sour crude oil differentials; changes in the demand for refinery feedstock and diesel fuel, including the possibility that refiners that process the company's proprietary production will be closed, experience equipment failure or other accidents; Suncor's ability to operate its Oil Sands facilities reliably in order to meet production targets; the output of newly commissioned facilities, the performance
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 85
of which may be difficult to predict during initial operations; Suncor's dependence on pipeline capacity and other logistical constraints, which may affect the company's ability to distribute products to market and which may cause the company to delay or cancel planned growth projects in the event of insufficient takeaway capacity; Suncor's ability to finance Oil Sands economic investment and asset sustainability and maintenance capital expenditures; the availability of bitumen feedstock for upgrading operations, which can be negatively affected by poor ore grade quality, unplanned mine equipment and extraction plant maintenance, tailings storage, and in situ reservoir and equipment performance, or the unavailability of third-party bitumen; changes in operating costs, including the cost of labour, natural gas and other energy sources used in oil sands processes; and the company's ability to complete projects, including planned maintenance events, both on time and on budget, which could be impacted by competition from other projects (including other oil sands projects) for goods and services and demands on infrastructure in Alberta's Wood Buffalo region and the surrounding area (including housing, roads and schools).
Factors that affect Suncor's Exploration and Production segment include, but are not limited to, volatility in crude oil and natural gas prices; operational risks and uncertainties associated with oil and gas activities, including unexpected formations or pressures, premature declines of reservoirs, fires, blow-outs, equipment failures and other accidents, uncontrollable flows of crude oil, natural gas or well fluids, and pollution and other environmental risks; adverse weather conditions, which could disrupt output from producing assets or impact drilling programs, resulting in increased costs and/or delays in bringing on new production; political, economic and socio-economic risks associated with Suncor's foreign operations, including the unpredictability of operating in Libya due to ongoing political unrest; and market demand for mineral rights and producing properties, potentially leading to losses on disposition or increased property acquisition costs.
Factors that affect Suncor's Refining and Marketing segment include, but are not limited to, fluctuations in demand and supply for refined products that impact the company's margins; market competition, including potential new market entrants; the company's ability to reliably operate refining and marketing facilities in order to meet production or sales targets; and risks and uncertainties affecting construction or planned maintenance schedules, including the availability of labour and other impacts of competing projects drawing on the same resources during the same time period.
Additional risks, uncertainties and other factors that could influence the financial and operating performance of all of Suncor's operating segments and activities include, but are not limited to, changes in general economic, market and business conditions, such as commodity prices, interest rates and currency exchange rates; fluctuations in supply and demand for Suncor's products; the successful and timely implementation of capital projects, including growth projects and regulatory projects; risks associated with the development and execution of Suncor's projects and the commissioning and integration of new facilities; the possibility that completed maintenance activities may not improve operational performance or the output of related facilities; the risk that projects and initiatives intended to achieve cash flow growth and/or reductions in operating costs may not achieve the expected results in the time anticipated or at all; competitive actions of other companies, including increased competition from other oil and gas companies or from companies that provide alternative sources of energy; labour and material shortages; actions by government authorities, including the imposition or reassessment of, or changes to, taxes, fees, royalties, duties, tariffs, quotas and other government-imposed compliance costs and mandatory production curtailment orders and changes thereto; changes to laws and government policies that could impact the company's business, including environmental (including climate change), royalty and tax laws and policies; the ability and willingness of parties with whom Suncor has material relationships to perform their obligations to the company; the unavailability of, or outages to, third-party infrastructure that could cause disruptions to production or prevent the company from being able to transport its products; the occurrence of a protracted operational outage, a major safety or environmental incident, or unexpected events such as fires (including forest fires), equipment failures and other similar events affecting Suncor or other parties whose operations or assets directly or indirectly affect Suncor; the potential for security breaches of Suncor's information technology and infrastructure by malicious persons or entities, and the unavailability or failure of such systems to perform as anticipated as a result of such breaches; security threats and terrorist or activist activities; the risk that competing business objectives may exceed Suncor's capacity to adopt and implement change; risks and uncertainties associated with obtaining regulatory, third-party and stakeholder approvals outside of Suncor's control for the company's operations, projects, initiatives, and exploration and development activities and the satisfaction of any conditions to approvals; the potential for disruptions to operations and construction projects as a result of Suncor's relationships with labour unions that represent employees at the company's facilities; the company's ability to find new oil and gas reserves that can be developed economically; the accuracy of Suncor's reserves, resources and future production estimates; market instability affecting Suncor's ability to borrow in the capital debt markets at acceptable rates or to issue other securities at acceptable prices; maintaining an optimal debt to cash flow ratio; the success of the company's risk management activities using
86 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
derivatives and other financial instruments; the cost of compliance with current and future environmental laws, including climate change laws; risks relating to increased activism and public opposition to fossil fuels and oil sands; risks and uncertainties associated with closing a transaction for the purchase or sale of a business, asset or oil and gas property, including estimates of the final consideration to be paid or received; the ability of counterparties to comply with their obligations in a timely manner; risks associated with joint arrangements in which the company has an interest; risks associated with land claims and Indigenous consultation requirements; the risk that the company may be subject to litigation; the impact of technology and risks associated with developing and implementing new technologies; and the accuracy of cost estimates, some of which are provided at the conceptual or other preliminary stage of projects and prior to commencement or conception of the detailed engineering that is needed to reduce the margin of error and increase the level of accuracy. The foregoing important factors are not exhaustive.
Many of these risk factors and other assumptions related to Suncor's forward-looking statements are discussed in further detail throughout this AIF, including under the heading Risk Factors, and the company's MD&A dated February 26, 2020 and Form 40-F on file with Canadian securities commissions at www.sedar.com and the SEC at www.sec.gov. Readers are also referred to the risk factors and assumptions described in other documents that Suncor files from time to time with securities regulatory authorities. Copies of these documents are available without charge from the company.
The forward-looking statements contained in this AIF are made as of the date of this AIF. Except as required by applicable securities laws, we assume no obligation to update publicly or otherwise revise any forward-looking statements or the foregoing risks and assumptions affecting such forward-looking statements, whether as a result of new information, future events or otherwise.
Non-GAAP Financial Measures Netback
Netback is a financial measure that is not prescribed by GAAP. Non-GAAP measures do not have any standardized meaning and therefore are unlikely to be comparable to similar measures presented by other companies and should not be considered in isolation or as a substitute for measures of performance prepared in accordance with GAAP. Netbacks are reconciled to GAAP measures in the Operating Metrics Reconciliation section of the Supplemental Financial and Operating Information within Suncor's Annual Report for the year ended December 31, 2019 and dated February 26, 2020.
Oil Sands Netbacks
Oil Sands operating netbacks are a non-GAAP measure, presented on a crude product and sales barrel basis, and are derived from the Oil Sands segmented statement of net earnings (loss), after adjusting for items not directly attributable to the revenues and costs associated with production and delivery. Management uses Oil Sands operating netbacks to measure crude product profitability on a sales barrel basis, and they may be useful to investors for the same reason.
Exploration and Production (E&P) Netbacks
E&P netbacks are a non-GAAP measure, presented on an asset location and sales barrel basis, and are derived from the E&P segmented statement of net earnings (loss), after adjusting for items not directly attributable to the costs associated with production and delivery. Management uses E&P operating netbacks to measure asset profitability by location on a sales barrel basis, and they may be useful to investors for the same reason.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. 87
SCHEDULE "A"
AUDIT COMMITTEE MANDATE
The Audit Committee
The by-laws of Suncor Energy Inc. provide that the Board of Directors may establish Board committees to whom certain duties may be delegated by the Board. The Board has established, among others, the Audit Committee, and has approved this mandate, which sets out the objectives, functions and responsibilities of the Audit Committee.
Objectives
The Audit Committee assists the Board by:
The Committee does not have decision-making authority, except in the very limited circumstances described herein or where and to the extent that such authority is expressly delegated by the Board of Directors. The Committee conveys its findings and recommendations to the Board of Directors for consideration and, where required, decision by the Board of Directors.
Constitution
The Terms of Reference of Suncor's Board of Directors set out requirements for the composition of Board Committees and the qualifications for committee membership, and specify that the Chair and membership of the committees are determined annually by the Board. As required by Suncor's by-laws, unless otherwise determined by resolution of the Board of Directors, a majority of the members of a committee constitute a quorum for meetings of committees, and in all other respects, each committee determines its own rules of procedure.
Functions and Responsibilities
The Audit Committee has the following functions and responsibilities:
Internal Controls
External and Internal Auditors
A-1 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Financial Reporting and other Public Disclosure
Oil and Gas Reserves
Risk Management
Pension Plan
Security
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. A-2
Other Matters
Reporting to the Board
Approved by resolution of the Board of Directors on November 14, 2017
A-3 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
SCHEDULE "B" SUNCOR ENERGY INC.
POLICY AND PROCEDURES
FOR PRE-APPROVAL OF AUDIT AND NON-AUDIT SERVICES
Pursuant to the Sarbanes-Oxley Act of 2002 and Multilateral Instrument 52-110, the Securities and Exchange Commission and the Ontario Securities Commission respectively has adopted final rules relating to audit committees and auditor independence. These rules require the Audit Committee of Suncor Energy Inc. ("Suncor") to be responsible for the appointment, compensation, retention and oversight of the work of its independent auditor. The Audit Committee must also pre-approve any audit and non-audit services performed by the independent auditor or such services must be entered into pursuant to pre-approval policies and procedures established by the Audit Committee pursuant to this policy.
I. Statement of Policy
The Audit Committee has adopted this Policy and Procedures for Pre-Approval of Audit and Non-Audit Services (the "Policy"), which sets forth the procedures and the conditions pursuant to which services proposed to be performed by the independent auditor will be pre-approved. The procedures outlined in this Policy are applicable to all Audit, Audit-Related, Tax Services and All Other Services provided by the independent auditor.
II. Responsibility
Responsibility for the implementation of this Policy rests with the Audit Committee. The Audit Committee delegates its responsibility for administration of this policy to management. The Audit Committee shall not delegate its responsibilities to pre-approve services performed by the independent auditor to management.
III. Definitions
For the purpose of these policies and procedures and any pre-approvals:
"Audit-related services" include:
Non-financial operational audits are not "audit-related" services.
IV. General Policy
The following general policy applies to all services provided by the independent auditor.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. B-1
V. Responsibilities of External Auditors
To support the independence process, the independent auditors will:
In addition, the external auditors will:
VI. Disclosures
Suncor will, as required by applicable law, annually disclose its pre-approval policies and procedures, and will provide the required disclosure concerning the amounts of audit fees, audit-related fees, tax fees and all other fees paid to its outside auditors in its filings with the SEC.
Approved and Accepted April 28, 2004
B-2 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
Appendix A Prohibited Non-Audit Services
An external auditor is not independent if, at any point during the audit and professional engagement period, the auditor provides the following non-audit services to an audit client.
Bookkeeping or other services related to the accounting records or financial statements of the audit client. Any service, unless it is reasonable to conclude that the results of these services will not be subject to audit procedures during an audit of Suncor's financial statements, including:
Financial information systems design and implementation. Any service, unless it is reasonable to conclude that the results of these services will not be subject to audit procedures during an audit of Suncor's financial statements, including:
Appraisal or valuation services, fairness opinions or contribution-in-kind reports. Any appraisal service, valuation service or any service involving a fairness opinion or contribution-in-kind report for Suncor, unless it is reasonable to conclude that the results of these services will not be subject to audit procedures during an audit of Suncor's financial statements.
Actuarial services. Any actuarially-oriented advisory service involving the determination of amounts recorded in the financial statements and related accounts for Suncor other than assisting Suncor in understanding the methods, models, assumptions, and inputs used in computing an amount, unless it is reasonable to conclude that the results of these services will not be subject to audit procedures during an audit of Suncor's financial statements.
Internal audit outsourcing services. Any internal audit service that has been outsourced by Suncor that relates to Suncor's internal accounting controls, financial systems or financial statements, unless it is reasonable to conclude that the result of these services will not be subject to audit procedures during an audit of Suncor's financial statements.
Management functions. Acting, temporarily or permanently, as a director, officer, or employee of Suncor, or performing any decision-making, supervisory, or ongoing monitoring function for Suncor.
Human resources. Any of the following:
Broker-dealer, investment adviser or investment banking services. Acting as a broker-dealer (registered or unregistered), promoter, or underwriter, on behalf of Suncor, making investment decisions on behalf of Suncor or otherwise having discretionary authority over Suncor's investments, executing a transaction to buy or sell Suncor's investment, or having custody of Suncor's assets, such as taking temporary possession of securities purchased by Suncor.
Legal services. Providing any service to Suncor that, under circumstances in which the service is provided, could be provided only by someone licenced, admitted, or otherwise qualified to practice law in the jurisdiction in which the service is prohibited.
Expert services unrelated to the audit. Providing an expert opinion or other expert service for Suncor, or Suncor's legal representative, for the purpose of advocating Suncor's interest in litigation or in a regulatory or administrative proceeding or investigation. In any litigation or regulatory or administrative proceeding or investigation, an accountant's independence shall not be deemed to be impaired if the accountant provides factual accounts, including testimony, of work performed or explains the positions taken or conclusions reached during the performance of any service provided by the accountant for Suncor.
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. B-3
Appendix B Pre-Approval Request Form
NATURE OF WORK |
ESTIMATED FEES
(Cdn$) |
|
|
||
|
||
|
||
|
||
|
||
Total | ||
|
|
|
|
Date | Signature |
B-4 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
SCHEDULE "C" FORM 51-101F2 REPORT
ON RESERVES DATA BY
INDEPENDENT QUALIFIED RESERVES EVALUATOR OR AUDITOR
To the board of directors of Suncor Energy Inc. (the "Company"):
Independent Qualified | Effective Date of |
Location of Reserves
(Country or Foreign |
Net Present Value of Future Net Revenue
(before income taxes, 10% discount rate, $ millions) |
||||||||||
Reserves Evaluator | Evaluation Report | Geographic Area) | Audited | Evaluated | Reviewed | Total | |||||||
|
|||||||||||||
GLJ Petroleum Consultants Ltd. | December 31, 2019 | Oil Sands In Situ, Canada | | 25 850 | | 25 850 | |||||||
|
|||||||||||||
GLJ Petroleum Consultants Ltd. | December 31, 2019 |
Oil Sands Mining,
Canada |
| 26 297 | | 26 297 | |||||||
|
|||||||||||||
| 52 147 | | 52 147 | ||||||||||
|
EXECUTED
as to our report referred to above:
GLJ Petroleum Consultants Ltd., Calgary, Alberta, Canada, February 26, 2020
"Tim R. Freeborn"
Tim R.
Freeborn, P.Eng.
Vice President and Chief Financial Officer
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. C-1
SCHEDULE "D" FORM 51-101F2 REPORT
ON RESERVES DATA BY
INDEPENDENT QUALIFIED RESERVES EVALUATOR OR AUDITOR
To the board of directors of Suncor Energy Inc. (the "Company"):
Independent Qualified | Effective Date of |
Location of Reserves
(Country or Foreign |
Net Present Value of Future Net Revenue
(before income taxes, 10% discount rate, $ millions) |
||||||||||
Reserves Evaluator | Evaluation Report | Geographic Area) | Audited | Evaluated | Reviewed | Total | |||||||
|
|||||||||||||
Sproule Associates Limited | December 31, 2019 |
East Coast Canada,
Newfoundland Offshore, Canada |
| 7 134 | | 7 134 | |||||||
|
|||||||||||||
Sproule International Limited | December 31, 2019 |
Offshore,
United Kingdom |
| 2 956 | | 2 956 | |||||||
|
|||||||||||||
Sproule International Limited | December 31, 2019 |
Offshore,
Norway |
| 760 | | 760 | |||||||
|
|||||||||||||
| 10 849 | | 10 849 | ||||||||||
|
EXECUTED as to our report referred to above:
Sproule Associates Limited and Sproule International Limited, Calgary, Alberta, Canada, February 26, 2020
"Cameron P. Six"
Cameron
P. Six, P.Eng.
Chief Executive Officer
D-1 2019 ANNUAL INFORMATION FORM Suncor Energy Inc.
SCHEDULE "E" FORM 51-101F3 REPORT OF MANAGEMENT AND DIRECTORS ON RESERVES DATA AND OTHER INFORMATION
Management of Suncor Energy Inc. (the "Company") are responsible for the preparation and disclosure of information with respect to the Company's oil and gas activities in accordance with securities regulatory requirements. This information includes reserves data.
Independent qualified reserves evaluators have evaluated the Company's reserves data. The reports of the independent qualified reserves evaluators will be filed with securities regulatory authorities concurrently with this report.
The Audit Committee of the board of directors of the Company has:
The Audit Committee of the board of directors has reviewed the Company's procedures for assembling and reporting other information associated with oil and gas activities and has reviewed that information with management. The board of directors has, on the recommendation of the Audit Committee, approved:
Because the reserves data are based on judgments regarding future events, actual results will vary and the variations may be material.
"Mark S. Little"
MARK
S. LITTLE
President and Chief Executive Officer
"Alister Cowan"
ALISTER
COWAN
Chief Financial Officer
"Michael M. Wilson"
MICHAEL
M. WILSON
Chair of the Board of Directors
"Patricia M. Bedient"
PATRICIA
M. BEDIENT
Chair of the Audit Committee
February 26, 2020
2019 ANNUAL INFORMATION FORM Suncor Energy Inc. E-1
UNDERTAKING AND CONSENT TO SERVICE OF PROCESS
A. Undertaking
Suncor Energy Inc. (the "Registrant") undertakes to make available, in person or by telephone, representatives to respond to inquiries made by the staff of the Securities and Exchange Commission ("SEC"), and to furnish promptly, when requested to do so by the SEC staff, information relating to the securities in relation to which the obligation to file an annual report on Form 40-F arises, or transactions in said securities.
B. Consent to Service of Process
The Registrant has filed previously with the SEC a Form F-X in connection with the Common Shares.
DISCLOSURE CONTROLS AND PROCEDURES AND INTERNAL CONTROL OVER FINANCIAL REPORTING
See pages 81 and 82 of Exhibit 99-1 and page 70 of Exhibit 99-2.
ATTESTATION REPORT OF THE REGISTERED PUBLIC ACCOUNTING FIRM
See pages 83 and 84 and 85 and 86 of Exhibit 99-1.
AUDIT COMMITTEE FINANCIAL EXPERT
See pages 80 and 81 of Annual Information Form.
See pages 24 and 25 of Annual Information Form.
FEES PAID TO PRINCIPAL ACCOUNTANT
See page 81 of Annual Information Form.
AUDIT COMMITTEE PRE-APPROVAL POLICIES
See Schedule "B" of Annual Information Form.
APPROVAL OF NON-AUDIT SERVICES
See Schedule "B" of Annual Information Form.
OFF-BALANCE SHEET ARRANGEMENTS
See page 53 of Exhibit 99-2.
TABULAR DISCLOSURE OF CONTRACTUAL OBLIGATIONS
See page 53 of Exhibit 99-2.
IDENTIFICATION OF THE AUDIT COMMITTEE
See page 80 of Annual Information Form.
Exhibit No.
|
Description | ||
---|---|---|---|
99-1 |
Audited Consolidated Financial Statements of Suncor Energy Inc. for the fiscal year ended December 31, 2019 | ||
99-2 |
Management's Discussion and Analysis for the fiscal year ended December 31, 2019, dated February 26, 2020 |
||
99-3 |
Consent of KPMG LLP |
||
99-4 |
Consent of PricewaterhouseCoopers LLP |
||
99-5 |
Consent of GLJ Petroleum Consultants Ltd. |
||
99-6 |
Consent of Sproule Associates Limited and Sproule International Limited |
||
99-7 |
Certificate of the Chief Executive Officer Pursuant to Exchange Act Rules 13a-14(a) or 15d-14(a) |
||
99-8 |
Certificate of the Chief Financial Officer Pursuant to Exchange Act Rules 13a-14(a) or 15d-14(a) |
||
99-9 |
Certificate of the Chief Executive Officer Pursuant to 18 U.S.C. Section 1350, as Enacted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 |
||
99-10 |
Certificate of the Chief Financial Officer Pursuant to 18 U.S.C. Section 1350, as Enacted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 |
||
99-11 |
Supplementary Oil and Gas Disclosures |
||
101 |
Interactive data files with respect to the Annual Consolidated Financial Statements of Suncor Energy Inc. for the fiscal year ended December 31, 2019 |
Pursuant to the requirements of the Exchange Act, the registrant certifies that it meets all of the requirements for filing on Form 40-F and has duly caused this annual report to be signed on its behalf by the undersigned, thereto duly authorized.
|
SUNCOR ENERGY INC. | |||
DATE: February 27, 2020 |
||||
|
PER: |
/s/ ALISTER COWAN
|
Audited Consolidated Financial Statements of Suncor Energy Inc. for the fiscal
year ended December 31, 2019
MANAGEMENT'S STATEMENT
OF RESPONSIBILITY FOR FINANCIAL REPORTING
The management of Suncor Energy Inc. is responsible for the presentation and preparation of the accompanying consolidated financial statements of Suncor Energy Inc. and all related financial information contained in the Annual Report, including Management's Discussion and Analysis.
The consolidated financial statements have been prepared in accordance with Canadian generally accepted accounting principles applicable to publicly accountable enterprises, which is within the framework of International Financial Reporting Standards as issued by the International Accounting Standards Board incorporated into the Canadian Institute of Chartered Professional Accountants Handbook Part 1. They include certain amounts that are based on estimates and judgments.
In management's opinion, the consolidated financial statements have been properly prepared within reasonable limits of materiality and within the framework of the significant accounting policies adopted by management. If alternate accounting methods exist, management has chosen those policies it deems the most appropriate in the circumstances. In discharging its responsibilities for the integrity and reliability of the financial statements, management maintains and relies upon a system of internal controls designed to ensure that transactions are properly authorized and recorded, assets are safeguarded against unauthorized use or disposition and liabilities are recognized. These controls include quality standards in hiring and training of employees, formalized policies and procedures, a corporate code of conduct and associated compliance program designed to establish and monitor conflicts of interest, the integrity of accounting records and financial information, among others, and employee and management accountability for performance within appropriate and well-defined areas of responsibility.
The system of internal controls is further supported by the professional staff of an internal audit function who conduct periodic audits of the company's financial reporting.
The Audit Committee of the Board of Directors, currently composed of four independent directors, reviews the effectiveness of the company's financial reporting systems, management information systems, internal control systems and internal auditors. It recommends to the Board of Directors the external auditor to be appointed by the shareholders at each annual meeting and reviews the independence and effectiveness of their work. In addition, it reviews with management and the external auditor any significant financial reporting issues, the presentation and impact of significant risks and uncertainties, and key estimates and judgments of management that may be material for financial reporting purposes. The Audit Committee appoints the independent reserve consultants. The Audit Committee meets at least quarterly to review and approve interim financial statements prior to their release, as well as annually to review Suncor's annual financial statements and Management's Discussion and Analysis, Annual Information Form/Form 40-F, and annual reserves estimates, and recommend their approval to the Board of Directors. The internal auditors and the external auditor, KPMG LLP, have unrestricted access to the company, the Audit Committee and the Board of Directors.
Mark Little |
Alister Cowan |
President and Chief Executive Officer | Chief Financial Officer |
February 26, 2020
2019 ANNUAL REPORT Suncor Energy Inc. 81
The following report is provided by management in respect of the company's internal control over financial reporting (as defined in Rule 13a-15(f) and 15d-15(f) under the U.S. Securities Exchange Act of 1934):
MANAGEMENT'S REPORT ON INTERNAL CONTROL
OVER FINANCIAL REPORTING
Mark Little |
Alister Cowan |
President and Chief Executive Officer | Chief Financial Officer |
February 26, 2020
82 2019 ANNUAL REPORT Suncor Energy Inc.
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Shareholders and Board of Directors of Suncor Energy Inc.
Opinions on the Consolidated Financial Statements and Internal Control Over Financial Reporting
We have audited the accompanying consolidated balance sheet of Suncor Energy Inc. (the Company) as of December 31, 2019, the related consolidated statements of comprehensive income, changes in equity, and cash flows for the year then ended and the related notes (collectively, the consolidated financial statements). We also have audited the Company's internal control over financial reporting as of December 31, 2019, based on criteria established in Internal Control Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.
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, 2019, and the results of its operations and its cash flows for the year ended December 31, 2019, in conformity with International Financial Reporting Standards as issued by the International Accounting Standards Board. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2019 based on criteria established in Internal Control Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.
Change in Accounting Principle
As discussed in Note 5 to the consolidated financial statements, the Company has changed its method of accounting for leases as of January 1, 2019 due to the adoption of International Financial Reporting Standard 16 Leases.
Comparative Information
As discussed in Note 6 of the consolidated financial statements, the 2018 segmented information has been restated to conform with the current year presentation. We have audited the adjustments as part of our audit of the consolidated financial statements as at and for the year ended December 31, 2019.
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 an opinion on the Company's consolidated financial statements and an opinion on the Company's internal control over financial reporting based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was maintained in all material respects.
Our audits of the consolidated financial statements included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.
Definition and Limitations of Internal Control Over Financial Reporting
A company's internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as
2019 ANNUAL REPORT Suncor Energy Inc. 83
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 (3) 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: (1) relate to accounts or disclosures that are material to the consolidated financial statements and (2) 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.
Evaluation of the assessment of indicators of impairment loss or reversal related to Oil Sands and Exploration and Production property, plant and equipment
As discussed in Note 15 to the consolidated financial statements, when circumstances indicate that a cash-generating unit ("CGU") may be impaired or a previous impairment reversed, the Company compares the carrying amount of the CGU to its recoverable amount. At each reporting date, the Company analyzes indicators of impairment loss or reversal ("impairment indicators"), such as significant increases or decreases in forecasted production volumes (which include assumptions related to proved and probable oil reserves), commodity prices, capital expenditures and operating costs (collectively, "reserve assumptions"). The estimate of reserve assumptions requires the expertise of reservoir engineering specialists. The Company engages independent reservoir engineering specialists to evaluate the Company's proved and probable oil reserves. The carrying amount of the Company's property, plant and equipment balance as of December 31, 2019 was $72,640 million.
We identified the evaluation of the assessment of impairment indicators related to the Oil Sands and Exploration and Production property, plant and equipment as a critical audit matter. A high degree of subjective auditor judgment was required to evaluate the reserve assumptions used by the Company in their assessment.
The primary procedures we performed to address this critical audit matter included the following. We tested certain internal controls over the Company's assessment of impairment indicators, including controls related to the reserve assumptions. We evaluated the Company's reserve assumptions by comparing the current year externally evaluated proved and probable oil reserves to historical results. We compared the Company's current year actual production volumes, operating costs and capital expenditures to those respective assumptions used in the prior year estimate of proved and probable reserves to assess the Company's ability to accurately forecast. We evaluated the Company's future commodity price estimates by comparing to a number of publicly available external price curves for the same benchmark pricing. We evaluated the competence, capabilities, and objectivity of the Company's independent reservoir engineering specialists engaged by the Company who evaluated proved and probable oil reserves. We evaluated the methodology used by the independent reservoir engineering specialists to evaluate proved and probable oil reserves for compliance with regulatory standards.
Assessment of the impairment of the Fort Hills and White Rose cash generating units
As discussed in note 15 to the consolidated financial statements, the Company recorded an impairment charge of $4,237 million related to the Fort Hills and White Rose cash generating units ("CGUs"). The Company identified an indicator of impairment at December 31, 2019 for both the Fort Hills and White Rose CGUs and performed impairment tests to determine the recoverable amount of the CGUs. The estimated recoverable amount of these CGUs involves numerous assumptions, including forecasted production volumes, commodity prices, operating costs, capital expenditures ("forecasted cash flow assumptions") and discount rates.
We identified the assessment of the impairment of the Fort Hills and White Rose CGUs as a critical audit matter. A high degree of subjective auditor judgment was required in evaluating the Company's forecasted cash flow and discount rate assumptions as minor changes to these assumptions have a significant effect on the Company's calculation of the recoverable amount of the CGUs. A high degree of subjective auditor judgement was also required to evaluate the externally evaluated proved and probable oil reserves which were used to assess the Company's forecasted cash flow assumptions.
84 2019 ANNUAL REPORT Suncor Energy Inc.
The primary procedures we performed to address this critical audit matter included the following. We tested certain internal controls over the Company's determination of the recoverable amount of the CGUs being tested, including controls related to determination of the forecasted cash flow and discount rate assumptions. We performed sensitivity analyses over the discount rate and forecasted commodity price assumptions to assess their impact on the Company's determination of the recoverable amount for each CGU tested. We evaluated the Company's future commodity price estimates by comparing to a number of publicly available external price curves for the same benchmark pricing. We evaluated the forecasted production volumes, operating costs and capital expenditure assumptions used in the impairment test by comparing to the current year externally evaluated proved and probable oil reserves as well as to historical results. We assessed differences between management's forecasted cash flow assumptions and the externally evaluated proved and probable oil reserves by comparing to recent historical results. We compared the Company's current year actual production volumes, operating costs and capital expenditures to those assumptions used in the prior year externally evaluated proved and probable oil reserves to assess the Company's ability to accurately forecast. We evaluated the competence, capabilities and objectivity of the independent reservoir engineering specialists engaged by the Company, who evaluated the proved and probable oil reserves. We evaluated the methodology used by independent reservoir engineering specialists to estimate proved and probable oil reserves for compliance with regulatory standards. We involved a valuation professional with specialized skills and knowledge, who assisted in evaluating the Company's CGU discount rate assumptions, by comparing them against publicly available market data and other external data. The valuation professional estimated the recoverable amount of the CGUs using the estimate of the CGUs' forecasted cash flows and the discount rate evaluated by the specialist and compared the resulting recoverable amount to market and other external pricing data.
Chartered Professional Accountants
Calgary, Alberta, Canada
February 26, 2020
We have served as the Company's auditor since 2019.
2019 ANNUAL REPORT Suncor Energy Inc. 85
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Shareholders and Board of Directors of Suncor Energy Inc.
Opinion on the Consolidated Financial Statements
We have audited the Consolidated Balance Sheet of Suncor Energy Inc. and its subsidiaries (together, the "Company") as of December 31, 2018, and the related Consolidated Statements of Comprehensive Income, Changes in Equity and Cash Flows for the year then ended, including the related notes (collectively referred to as the Consolidated Financial Statements) before the effects of the adjustments to retrospectively restate and reallocate segmented results as described in Note 6.
In our opinion, the Consolidated Financial Statements, before the effects of the adjustments to retrospectively restate and reallocate segmented results as described in Note 6, present fairly, in all material respects, the financial position of the Company as of December 31, 2018, and the results of operations and cash flows for the year ended December 31, 2018, in conformity with International Financial Reporting Standards as issued by the International Accounting Standards Board ("IFRS") (the 2018 financial statements before the effects of the adjustments discussed in Note 6 are not presented herein).
We were not engaged to audit, review, or apply any procedures to the adjustments to retrospectively restate and reallocate segmented results as described in Note 6 and accordingly, we do not express an opinion or any other form of assurance about whether such adjustments are appropriate and have been properly applied. Those adjustments were audited by other auditors.
Basis for Opinion
These Consolidated Financial Statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company's Consolidated Financial Statements, before the effects of the adjustments described above, based on our audit. 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 audit of these Consolidated Financial Statements, before the effects of the adjustments described above, in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the Consolidated Financial Statements are free of material misstatement, whether due to error or fraud.
Our audit 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 audit 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. We believe that our audit provides a reasonable basis for our opinion.
Chartered Professional Accountants
Calgary, Alberta, Canada
February 28, 2019
We served as the Company's auditor from 1972 to 2019.
86 2019 ANNUAL REPORT Suncor Energy Inc.
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
For the years ended December 31 ($ millions) | Notes | 2019 | 2018 | |||||||
|
||||||||||
Revenues and Other Income | ||||||||||
|
||||||||||
Operating revenues, net of royalties | 6 | 38 344 | 38 542 | |||||||
|
||||||||||
Other income | 7 | 645 | 444 | |||||||
|
||||||||||
38 989 | 38 986 | |||||||||
|
||||||||||
Expenses |
|
|
|
|
|
|
|
|
||
|
||||||||||
Purchases of crude oil and products | 12 562 | 14 133 | ||||||||
|
||||||||||
Operating, selling and general | 8 and 25 | 11 244 | 10 573 | |||||||
|
||||||||||
Transportation | 1 442 | 1 319 | ||||||||
|
||||||||||
Depreciation, depletion, amortization and impairment | 15 | 10 572 | 5 738 | |||||||
|
||||||||||
Exploration | 256 | 122 | ||||||||
|
||||||||||
Gain on asset exchange and disposals | 34 | (253 | ) | (24 | ) | |||||
|
||||||||||
Financing expenses | 9 | 633 | 2 142 | |||||||
|
||||||||||
36 456 | 34 003 | |||||||||
|
||||||||||
Earnings before Income Taxes | 2 533 | 4 983 | ||||||||
|
||||||||||
Income Tax (Recovery) Expense | 10 | |||||||||
|
||||||||||
Current | 1 552 | 1 250 | ||||||||
|
||||||||||
Deferred | 10 and 15 | (1 918 | ) | 440 | ||||||
|
||||||||||
(366 | ) | 1 690 | ||||||||
|
||||||||||
Net Earnings | 2 899 | 3 293 | ||||||||
|
||||||||||
Other Comprehensive (Loss) Income |
|
|
|
|
|
|
|
|
||
|
||||||||||
Items That May be Subsequently Reclassified to Earnings: | ||||||||||
|
||||||||||
Foreign currency translation adjustment | (177 | ) | 267 | |||||||
|
||||||||||
Items That Will Not be Reclassified to Earnings: | ||||||||||
|
||||||||||
Actuarial (loss) gain on employee retirement benefit plans, net of income taxes | (48 | ) | 103 | |||||||
|
||||||||||
Other Comprehensive (Loss) Income |
|
|
|
(225 |
) |
370 |
|
|
||
|
||||||||||
Total Comprehensive Income |
|
|
|
2 674 |
|
3 663 |
|
|
||
|
||||||||||
Per Common Share (dollars) |
|
11 |
|
|
|
|
|
|
||
|
||||||||||
Net earnings basic | 1.86 | 2.03 | ||||||||
|
||||||||||
Net earnings diluted | 1.86 | 2.02 | ||||||||
|
||||||||||
Cash dividends | 1.68 | 1.44 | ||||||||
|
The accompanying notes are an integral part of the consolidated financial statements.
2019 ANNUAL REPORT Suncor Energy Inc. 87
($ millions) | Notes |
December 31
2019 |
December 31
2018 |
||||||
|
|||||||||
Assets | |||||||||
|
|||||||||
Current assets | |||||||||
|
|||||||||
Cash and cash equivalents | 12 | 1 960 | 2 221 | ||||||
|
|||||||||
Accounts receivable | 4 052 | 3 206 | |||||||
|
|||||||||
Inventories | 14 | 3 761 | 3 159 | ||||||
|
|||||||||
Income taxes receivable | 133 | 114 | |||||||
|
|||||||||
Total current assets | 9 906 | 8 700 | |||||||
|
|||||||||
Property, plant and equipment, net | 5, 15, 16, 33 and 34 | 72 640 | 74 245 | ||||||
|
|||||||||
Exploration and evaluation | 17 | 2 428 | 2 319 | ||||||
|
|||||||||
Other assets | 18 | 1 194 | 1 126 | ||||||
|
|||||||||
Goodwill and other intangible assets | 19 | 3 058 | 3 061 | ||||||
|
|||||||||
Deferred income taxes | 10 | 209 | 128 | ||||||
|
|||||||||
Total assets | 89 435 | 89 579 | |||||||
|
|||||||||
Liabilities and Shareholders' Equity |
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|
|
|
|
|
|
||
|
|||||||||
Current liabilities | |||||||||
|
|||||||||
Short-term debt | 20 | 2 155 | 3 231 | ||||||
|
|||||||||
Current portion of long-term debt | 20 | | 229 | ||||||
|
|||||||||
Current portion of long-term lease liabilities | 5 | 310 | | ||||||
|
|||||||||
Accounts payable and accrued liabilities | 6 555 | 5 647 | |||||||
|
|||||||||
Current portion of provisions | 23 | 631 | 667 | ||||||
|
|||||||||
Income taxes payable | 886 | 535 | |||||||
|
|||||||||
Total current liabilities | 10 537 | 10 309 | |||||||
|
|||||||||
Long-term debt | 20 | 12 884 | 13 890 | ||||||
|
|||||||||
Long-term lease liabilities | 5 | 2 621 | | ||||||
|
|||||||||
Other long-term liabilities | 21 | 2 499 | 2 346 | ||||||
|
|||||||||
Provisions | 23 | 8 676 | 6 984 | ||||||
|
|||||||||
Deferred income taxes | 10 and 15 | 10 176 | 12 045 | ||||||
|
|||||||||
Equity | 42 042 | 44 005 | |||||||
|
|||||||||
Total liabilities and shareholders' equity | 89 435 | 89 579 | |||||||
|
The accompanying notes are an integral part of the consolidated financial statements.
Approved on behalf of the Board of Directors:
|
|
|
Mark Little |
|
Patricia M. Bedient |
Director | Director |
February 26, 2020
88 2019 ANNUAL REPORT Suncor Energy Inc.
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the years ended December 31 ($ millions) | Notes | 2019 | 2018 | ||||||
|
|||||||||
Operating Activities | |||||||||
|
|||||||||
Net earnings | 2 899 | 3 293 | |||||||
|
|||||||||
Adjustments for: | |||||||||
|
|||||||||
Depreciation, depletion, amortization and impairment | 10 572 | 5 738 | |||||||
|
|||||||||
Deferred income tax (recovery) expense | 10 and 15 | (1 918 | ) | 440 | |||||
|
|||||||||
Accretion | 270 | 266 | |||||||
|
|||||||||
Unrealized foreign exchange (gain) loss on U.S. dollar denominated debt | (624 | ) | 1 090 | ||||||
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|||||||||
Change in fair value of financial instruments and trading inventory | 107 | (179 | ) | ||||||
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Gain on asset exchange and disposals | 34 | (253 | ) | (24 | ) | ||||
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Share-based compensation | 44 | (117 | ) | ||||||
|
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Exploration | 66 | 11 | |||||||
|
|||||||||
Settlement of decommissioning and restoration liabilities | (464 | ) | (469 | ) | |||||
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Other | 119 | 123 | |||||||
|
|||||||||
(Increase) decrease in non-cash working capital | 13 | (397 | ) | 408 | |||||
|
|||||||||
Cash flow provided by operating activities | 10 421 | 10 580 | |||||||
|
|||||||||
Investing Activities |
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|
|
|
|
|
|
|
|
|
|||||||||
Capital and exploration expenditures | (5 558 | ) | (5 406 | ) | |||||
|
|||||||||
Acquisitions | 32 to 34 | | (1 230 | ) | |||||
|
|||||||||
Proceeds from disposal of assets | 274 | 84 | |||||||
|
|||||||||
Other investments | 34 | (213 | ) | (170 | ) | ||||
|
|||||||||
Decrease in non-cash working capital | 13 | 409 | 25 | ||||||
|
|||||||||
Cash flow used in investing activities | (5 088 | ) | (6 697 | ) | |||||
|
|||||||||
Financing Activities |
|
|
|
|
|
|
|
|
|
|
|||||||||
Net (decrease) increase in short-term debt | (982 | ) | 866 | ||||||
|
|||||||||
Net increase (decrease) in long-term debt | 20 | 557 | (186 | ) | |||||
|
|||||||||
Lease liability payments | 5 | (307 | ) | | |||||
|
|||||||||
Issuance of common shares under share option plans | 90 | 286 | |||||||
|
|||||||||
Purchase of common shares | 24 | (2 274 | ) | (3 053 | ) | ||||
|
|||||||||
Distributions relating to non-controlling interest | (7 | ) | (6 | ) | |||||
|
|||||||||
Dividends paid on common shares | (2 614 | ) | (2 333 | ) | |||||
|
|||||||||
Cash flow used in financing activities | (5 537 | ) | (4 426 | ) | |||||
|
|||||||||
Decrease in Cash and Cash Equivalents |
|
|
|
(204 |
) |
(543 |
) |
|
|
|
|||||||||
Effect of foreign exchange on cash and cash equivalents | (57 | ) | 92 | ||||||
|
|||||||||
Cash and cash equivalents at beginning of year | 2 221 | 2 672 | |||||||
|
|||||||||
Cash and Cash Equivalents at End of Year | 1 960 | 2 221 | |||||||
|
|||||||||
Supplementary Cash Flow Information |
|
|
|
|
|
|
|
|
|
|
|||||||||
Interest paid | 996 | 800 | |||||||
|
|||||||||
Income taxes paid | 1 033 | 645 | |||||||
|
The accompanying notes are an integral part of the consolidated financial statements.
2019 ANNUAL REPORT Suncor Energy Inc. 89
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
($ millions) | Notes |
Share
Capital |
Contributed
Surplus |
Accumulated
Other Comprehensive Income |
Retained
Earnings |
Total |
Number of
Common Shares (thousands) |
||||||||
|
|
||||||||||||||
At December 31, 2017 | 26 606 | 567 | 809 | 17 401 | 45 383 | 1 640 983 | |||||||||
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|
||||||||||||||
Net earnings | | | | 3 293 | 3 293 | | |||||||||
|
|
||||||||||||||
Foreign currency translation adjustment | | | 267 | | 267 | | |||||||||
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|
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Actuarial gain on employee retirement benefit plans, net of income taxes of $39 | 22 | | | | 103 | 103 | | ||||||||
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|
||||||||||||||
Total comprehensive income | | | 267 | 3 396 | 3 663 | | |||||||||
|
|
||||||||||||||
Issued under share option plans | 358 | (73 | ) | | | 285 | 7 927 | ||||||||
|
|
||||||||||||||
Purchase of common shares for cancellation | 24 | (1 040 | ) | | | (2 013 | ) | (3 053 | ) | (64 426 | ) | ||||
|
|
||||||||||||||
Change in liability for share purchase commitment | 24 | (14 | ) | | | 28 | 14 | | |||||||
|
|
||||||||||||||
Share-based compensation | 25 | | 46 | | | 46 | | ||||||||
|
|
||||||||||||||
Dividends paid on common shares | | | | (2 333 | ) | (2 333 | ) | | |||||||
|
|
||||||||||||||
At December 31, 2018 | 25 910 | 540 | 1 076 | 16 479 | 44 005 | 1 584 484 | |||||||||
|
|
||||||||||||||
At January 1, 2019 | 25 910 | 540 | 1 076 | 16 479 | 44 005 | 1 584 484 | |||||||||
|
|
||||||||||||||
Adoption of IFRS 16 impact | 5 | | | | 14 | 14 | | ||||||||
|
|
||||||||||||||
At January 1, 2019, adjusted | 25 910 | 540 | 1 076 | 16 493 | 44 019 | 1 584 484 | |||||||||
|
|
||||||||||||||
Net earnings | | | | 2 899 | 2 899 | | |||||||||
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|
||||||||||||||
Foreign currency translation adjustment | | | (177 | ) | | (177 | ) | | |||||||
|
|
||||||||||||||
Actuarial loss on employee retirement benefit plans, net of income taxes of $23 | 22 | | | | (48 | ) | (48 | ) | | ||||||
|
|
||||||||||||||
Total comprehensive (loss) income | | | (177 | ) | 2 851 | 2 674 | | ||||||||
|
|
||||||||||||||
Issued under share option plans | 116 | (24 | ) | | | 92 | 2 688 | ||||||||
|
|
||||||||||||||
Purchase of common shares for cancellation | 24 | (905 | ) | | | (1 369 | ) | (2 274 | ) | (55 298 | ) | ||||
|
|
||||||||||||||
Change in liability for share purchase commitment | 24 | 46 | | | 49 | 95 | | ||||||||
|
|
||||||||||||||
Share-based compensation | 25 | | 50 | | | 50 | | ||||||||
|
|
||||||||||||||
Dividends paid on common shares | | | | (2 614 | ) | (2 614 | ) | | |||||||
|
|
||||||||||||||
At December 31, 2019 | 25 167 | 566 | 899 | 15 410 | 42 042 | 1 531 874 | |||||||||
|
|
The accompanying notes are an integral part of the consolidated financial statements.
90 2019 ANNUAL REPORT Suncor Energy Inc.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
1. REPORTING ENTITY AND DESCRIPTION OF THE BUSINESS
Suncor Energy Inc. (Suncor or the company) is an integrated energy company headquartered in Calgary, Alberta, Canada. Suncor is strategically focused on developing one of the world's largest petroleum resource basins Canada's Athabasca oil sands. In addition, the company explores for, acquires, develops, produces, transports, refines and markets crude oil in Canada and internationally, Suncor markets petroleum and petrochemical products primarily in Canada, under the Petro-Canada® brand. The company also operates a renewable energy business and conducts energy trading activities focused principally in the marketing and trading of crude oil, natural gas, byproducts, refined products, and power.
The address of the company's registered office is 150 6th Avenue S.W., Calgary, Alberta, Canada, T2P 3E3.
(a) Statement of Compliance
These consolidated financial statements have been prepared in accordance with International Financial Reporting Standards (IFRS) as issued by the International Accounting Standards Board (IASB) and Canadian generally accepted accounting principles (GAAP) as contained within Part 1 of the Canadian Institute of Chartered Professional Accountants Handbook.
Suncor's accounting policies are based on IFRS issued and outstanding for all periods presented in these consolidated financial statements. These consolidated financial statements were approved by the Board of Directors on February 26, 2020.
(b) Basis of Measurement
The consolidated financial statements are prepared on a historical cost basis except as detailed in the accounting policies disclosed in note 3. The accounting policies described in note 3 have been applied consistently to all periods presented in these consolidated financial statements with the exception of IFRS 16 Leases. Refer to note 5.
(c) Functional Currency and Presentation Currency
These consolidated financial statements are presented in Canadian dollars, which is the company's functional currency.
(d) Use of Estimates, Assumptions and Judgments
The timely preparation of financial statements requires that management make estimates and assumptions and use judgment. Accordingly, actual results may differ from estimated amounts as future confirming events occur. Significant estimates and judgments used in the preparation of the consolidated financial statements are described in note 4.
3. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
(a) Principles of Consolidation
The company consolidates its interests in entities it controls. Control comprises the power to govern an entity's financial and operating policies to obtain benefits from its activities, and is a matter of judgment. All intercompany balances and transactions are eliminated on consolidation.
(b) Joint Arrangements
Joint arrangements represent arrangements in which two or more parties have joint control established by a contractual agreement. Joint control only exists when decisions about the activities that most significantly affect the returns of the investee are unanimous. Joint arrangements can be classified as either a joint operation or a joint venture. The classification of joint arrangements requires judgment. In determining the classification of its joint arrangements, the company considers the contractual rights and obligations of each investor and whether the legal structure of the joint arrangement gives the entity direct rights to the assets and obligations for the liabilities.
Where the company has rights to the assets and obligations for the liabilities of a joint arrangement, such arrangement is classified as a joint operation and the company's proportionate share of the joint operation's assets, liabilities, revenues and expenses are included in the consolidated financial statements, on a line-by-line basis.
Where the company has rights to the net assets of an arrangement, the arrangement is classified as a joint venture and accounted for using the equity method of accounting. Under the equity method, the company's initial investment is
2019 ANNUAL REPORT Suncor Energy Inc. 91
recognized at cost and subsequently adjusted for the company's share of the joint venture's income or loss, less distributions received.
(c) Foreign Currency Translation
Functional currencies of the company's individual entities are the currency of the primary economic environment in which the entity operates. Transactions in foreign currencies are translated to the appropriate functional currency at foreign exchange rates that approximate those on the date of the transaction. Monetary assets and liabilities denominated in foreign currencies are translated to the appropriate functional currency at foreign exchange rates as at the balance sheet date. Foreign exchange differences arising on translation are recognized in net earnings. Non-monetary assets that are measured in a foreign currency at historical cost are translated using the exchange rate at the date of the transaction.
In preparing the company's consolidated financial statements, the financial statements of each entity are translated into Canadian dollars. The assets and liabilities of foreign operations are translated into Canadian dollars at exchange rates as at the balance sheet date. Revenues and expenses of foreign operations are translated into Canadian dollars using foreign exchange rates that approximate those on the date of the underlying transaction. Foreign exchange differences are recognized in Other Comprehensive Income.
If the company or any of its entities disposes of its entire interest in a foreign operation, or loses control, joint control, or significant influence over a foreign operation, the accumulated foreign currency translation gains or losses related to the foreign operation are recognized in net earnings.
(d) Revenues
Revenue from the sale of crude oil, natural gas, natural gas liquids, purchased products, refined petroleum products and power represent the company's contractual arrangements with customers. Revenue is recorded when control passes to the customer, in accordance with specified contract terms. All operating revenue is earned at a point in time and is based on the consideration that the company expects to receive for the transfer of the goods to the customer. Revenues are usually collected in the month following delivery except retail gasoline, diesel and ancillary products which are due upon delivery and, accordingly, the company doesn't adjust consideration for the effects of a financing component.
Revenue from oil and natural gas production is recorded net of royalty expense.
International operations conducted pursuant to Production Sharing Contracts (PSCs) are reflected in the consolidated financial statements based on the company's working interest. Each PSC establishes the exploration, development and operating costs the company is required to fund and establishes specific terms for the company to recover these costs and to share in the production profits. Cost recovery is generally limited to a specified percentage of production during each fiscal year (Cost Recovery Oil). Any Cost Recovery Oil remaining after costs have been recovered is referred to as Excess Petroleum and is shared between the company and the respective government. Assuming collection is reasonably assured, the company's share of Cost Recovery Oil and Excess Petroleum are reported as revenue when the sale of product to a third party occurs. Revenue also includes income taxes paid on the company's behalf by government joint venture partners.
(e) Cash and Cash Equivalents
Cash and cash equivalents consist primarily of cash in banks, term deposits, certificates of deposit and all other highly liquid investments at the time of purchase.
(f) Inventories
Inventories of crude oil and refined products, other than inventories held for trading purposes, are valued at the lower of cost, using the first-in, first-out method, and net realizable value. Cost of inventory consists of purchase costs, direct production costs, direct overhead and depreciation, depletion and amortization. Materials and supplies are valued at the lower of average cost and net realizable value.
Inventories held for trading purposes are carried at fair value less costs of disposal, and any changes in fair value are recognized in Other Income within the respective reporting segment to which the trading activity relates.
(g) Assets Held for Sale
Assets and the associated liabilities are classified as held for sale if their carrying amounts are expected to be recovered through a disposition rather than through continued use. The assets or disposal groups are measured at the lower of their carrying amount or estimated fair value less costs of disposal. Impairment losses on initial classification as well as subsequent gains or losses on remeasurement are recognized in Depreciation, Depletion, Amortization and Impairment. When the assets or disposal groups are sold, the gains or losses on the sale are recognized in Gain on Disposal of Assets. Assets classified as held for sale are not depreciated, depleted or amortized.
92 2019 ANNUAL REPORT Suncor Energy Inc.
(h) Exploration and Evaluation Assets
The costs to acquire non-producing oil and gas properties or licences to explore, drill exploratory wells and the costs to evaluate the commercial potential of underlying resources, including related borrowing costs, are initially capitalized as Exploration and Evaluation assets. Certain exploration costs, including geological, geophysical and seismic expenditures and delineation on oil sands properties, are charged to Exploration expense as incurred.
Exploration and Evaluation assets are subject to technical, commercial and management review to confirm the continued intent to develop and extract the underlying resources. If an area or exploration well is no longer considered commercially viable, the related capitalized costs are charged to Exploration expense.
When management determines with reasonable certainty that an Exploration and Evaluation asset will be developed, as evidenced by the classification of proved or probable reserves and the appropriate internal and external approvals, the asset is transferred to Property, Plant and Equipment.
(i) Property, Plant and Equipment
Property, Plant and Equipment are initially recorded at cost.
The costs to acquire developed or producing oil and gas properties, and to develop oil and gas properties, including completing geological and geophysical surveys and drilling development wells, and the costs to construct and install development infrastructure, such as wellhead equipment, well platforms, well pairs, offshore platforms, subsea structures and an estimate of asset retirement costs, are capitalized as oil and gas properties within Property, Plant and Equipment.
The costs to construct, install and commission, or acquire, oil and gas production equipment, including oil sands upgraders, extraction plants, mine equipment, processing and power generation facilities, utility plants, and all renewable energy, refining, and marketing assets, are capitalized as plant and equipment within Property, Plant and Equipment.
Stripping activity required to access oil sands mining resources incurred in the initial development phase is capitalized as part of the construction cost of the mine. Stripping costs incurred in the production phase are charged to expense as they normally relate to production for the current period.
The costs of planned major inspection, overhaul and turnaround activities that maintain Property, Plant and Equipment and benefit future years of operations are capitalized. Recurring planned maintenance activities performed on shorter intervals are expensed as operating costs. Replacements outside of a major inspection, overhaul or turnaround are capitalized when it is probable that future economic benefits will be realized by the company and the associated carrying amount of the replaced component is derecognized.
Borrowing costs relating to assets that take over one year to construct are capitalized as part of the asset. Capitalization of borrowing costs ceases when the asset is in the location and condition necessary for its intended use, and is suspended when construction of an asset is ceased for extended periods.
(j) Depreciation, Depletion and Amortization
Exploration and Evaluation assets are not subject to depreciation, depletion and amortization. Once transferred to oil and gas properties within Property, Plant and Equipment and commercial production commences, these costs are depleted on a unit-of-production basis over proved developed reserves, with the exception of exploration and evaluation costs associated with oil sands mines, which are depreciated on a straight-line basis over the life of the mine, and property acquisition costs, which are depleted over proved reserves.
Capital expenditures are not depreciated or depleted until assets are substantially complete and ready for their intended use.
Costs to develop oil and gas properties other than certain oil sands mining assets, including costs of dedicated infrastructure, such as well pads and wellhead equipment, are depleted on a unit-of-production basis over proved developed reserves. A portion of these costs may not be depleted if they relate to undeveloped reserves. Costs related to offshore facilities are depleted over proved and probable reserves. Costs to develop and construct oil sands mines are depreciated on a straight-line basis over the life of the mine.
2019 ANNUAL REPORT Suncor Energy Inc. 93
Major components of Property, Plant and Equipment are depreciated on a straight-line basis over their expected useful lives.
|
||
Oil sands upgraders, extraction plants and mine facilities | 20 to 40 years | |
|
||
Oil sands mine equipment | 5 to 15 years | |
|
||
Oil sands in situ processing facilities | 30 years | |
|
||
Power generation and utility plants | 30 to 40 years | |
|
||
Refineries and other processing plants | 20 to 40 years | |
|
||
Marketing and other distribution assets | 10 to 40 years | |
|
The costs of major inspection, overhaul and turnaround activities that are capitalized are depreciated on a straight-line basis over the period to the next scheduled activity, which varies from two to five years.
Depreciation, depletion and amortization rates are reviewed annually or when events or conditions occur that impact capitalized costs, reserves or estimated service lives.
Right-of-use assets within Property, Plant and Equipment are depreciated on a straight-line basis over the shorter of the estimated useful life of the right-of-use asset or the lease term.
(k) Goodwill and Other Intangible Assets
The company accounts for business combinations using the acquisition method. The excess of the purchase price over the fair value of the identifiable net assets represents goodwill, and is allocated to the cash generating units (CGUs) or groups of CGUs expected to benefit from the business combination.
Other intangible assets include acquired customer lists and brand value.
Goodwill and brand value have indefinite useful lives and are not subject to amortization. Customer lists are amortized over their expected useful lives, which range from five to ten years. Expected useful lives of other intangible assets are reviewed on an annual basis.
(l) Impairment of Assets
Non-Financial Assets
Property, Plant and Equipment and Exploration and Evaluation assets are reviewed quarterly to assess whether there is any indication of impairment. Goodwill and intangible assets that have an indefinite useful life are tested for impairment annually. Exploration and Evaluation assets are also tested for impairment immediately prior to being transferred to Property, Plant and Equipment.
If any indication of impairment exists, an estimate of the asset's recoverable amount is calculated as the higher of the fair value less costs of disposal and value-in-use. In determining fair value less costs of disposal, recent market transactions are considered, if available. In the absence of such transactions, an appropriate valuation model is used. Value-in-use is assessed using the present value of the expected future cash flows of the relevant asset. If the asset does not generate cash inflows that are largely independent of those from other assets or groups of assets, the asset is tested as part of a CGU, which is the smallest identifiable group of assets that generates cash inflows that are largely independent of the cash inflows from other assets or groups of assets. An impairment loss is the amount by which the carrying amount of the individual asset or CGU exceeds its recoverable amount.
Impairments may be reversed for all CGUs and individual assets, other than goodwill, if there has been a change in the estimates and judgments used to determine the asset's recoverable amount. If such indication exists, the carrying amount of the CGU or asset is increased to its revised recoverable amount, which cannot exceed the carrying amount that would have been determined, net of depletion, depreciation and amortization, had no impairment been recognized.
Impairments and impairment reversals are recognized within Depreciation, Depletion, Amortization and Impairment.
Financial Assets
At each reporting date, the company assesses whether there is evidence indicating that financial assets measured at amortized cost may be impaired. If a financial asset measured at amortized cost is determined to be impaired, the impairment is recognized in Operating, Selling and General expense.
94 2019 ANNUAL REPORT Suncor Energy Inc.
(m) Provisions
Provisions are recognized by the company when it has a legal or constructive obligation as a result of past events, it is probable that an outflow of economic resources will be required to settle the obligation and a reliable estimate can be made of the amount of the obligation.
Provisions are recognized for decommissioning and restoration obligations associated with the company's Exploration and Evaluation assets and Property, Plant and Equipment. Provisions for decommissioning and restoration obligations are measured at the present value of management's best estimate of the future cash flows required to settle the present obligation, using the credit-adjusted risk-free interest rate. The value of the obligation is added to the carrying amount of the associated asset and amortized over the useful life of the asset. The provision is accreted over time through Financing Expense with actual expenditures charged against the accumulated obligation. Changes in the future cash flow estimates resulting from revisions to the estimated timing or amount of undiscounted cash flows are recognized as a change in the decommissioning and restoration provision and related asset.
(n) Income Taxes
The company follows the liability method of accounting for income taxes whereby deferred income taxes are recorded for the effect of differences between the accounting and income tax basis of an asset or liability. Deferred income tax assets and liabilities are measured using enacted or substantively enacted income tax rates as at the balance sheet date that are anticipated to apply to taxable income in the years in which temporary differences are anticipated to be recovered or settled. Changes to these balances are recognized in net earnings or in Other Comprehensive Income in the period they occur. Investment tax credits are recorded as a reduction to the related expenditures.
The company recognizes the financial statement impact of a tax filing position when it is probable, based on the technical merits, that the position will be sustained upon audit. The company assesses possible outcomes and their associated probabilities. If the company determines payment is probable, it measures the tax provision at the best estimate of the amount of tax payable.
(o) Pensions and Other Post-Retirement Benefits
The company sponsors defined benefit pension plans, defined contribution pension plans and other post-retirement benefits.
The cost of pension benefits earned by employees in the defined contribution pension plan is expensed as incurred. The cost of defined benefit pension plans and other post-retirement benefits are actuarially determined using the projected unit credit method based on present pay levels and management's best estimates of demographic and financial assumptions. Pension benefits earned during the current year are recorded in Operating, Selling and General expense. Interest costs on the net unfunded obligation are recorded in Financing Expense. Any actuarial gains or losses are recognized immediately through Other Comprehensive Income and transferred directly to Retained Earnings.
The liability recognized on the balance sheet is the present value of the defined benefit obligations net of the fair value of plan assets.
(p) Share-Based Compensation Plans
Under the company's share-based compensation plans, share-based awards may be granted to executives, employees and non-employee directors. Compensation expense is recorded in Operating, Selling and General expense.
Share-based compensation awards that settle in cash or have the option to settle in cash or shares are accounted for as cash-settled plans. These are measured at fair value each reporting period using the Black-Scholes options pricing model. The expense is recognized over the vesting period, with a corresponding adjustment to the outstanding liability. When awards are surrendered for cash, the cash settlement paid reduces the outstanding liability. When awards are exercised for common shares, consideration paid by the holder and the previously recognized liability associated with the options are recorded to Share Capital.
Stock options that give the holder the right to purchase common shares are accounted for as equity-settled plans. The expense is based on the fair value of the options at the time of grant using the Black-Scholes options pricing model and is recognized over the vesting periods of the respective options. A corresponding increase is recorded to Contributed Surplus. Consideration paid to the company on exercise of options is credited to Share Capital and the associated amount in Contributed Surplus is reclassified to Share Capital.
(q) Financial Instruments
The company classifies its financial instruments into one of the following categories: fair value through profit or loss (FVTPL), fair value through other comprehensive income, or at amortized cost. This determination is made at initial recognition. All
2019 ANNUAL REPORT Suncor Energy Inc. 95
financial instruments are initially recognized at fair value on the balance sheet, net of any transaction costs except for financial instruments classified as FVTPL, where transaction costs are expensed as incurred. Subsequent measurement of financial instruments is based on their classification. The company classifies its derivative financial instruments as FVTPL, cash and cash equivalents and accounts receivable as financial assets at amortized cost, and accounts payable and accrued liabilities, debt, and other long-term liabilities as financial liabilities at amortized cost.
In circumstances where the company consolidates a subsidiary in which there are other owners with a non-controlling interest and the subsidiary has a non-discretionary obligation to distribute cash based on a predetermined formula to the non-controlling owners, the non-controlling interest is classified as a financial liability rather than equity in accordance with IAS 32 Financial Instruments: Presentation. The non-controlling interest liability is classified as an amortized cost liability and is presented within Other Long-Term Liabilities. The balance is accreted based on current period interest expense recorded using the effective interest method and decreased based on distributions made to the non-controlling owners.
The company uses derivative financial instruments, such as physical and financial contracts, either to manage certain exposures to fluctuations in interest rates, commodity prices and foreign exchange rates, as part of its overall risk management program. Earnings impacts from derivatives used to manage a particular risk are reported as part of Other Income in the related reporting segment.
Certain physical commodity contracts, when used for trading purposes, are deemed to be derivative financial instruments for accounting purposes. Physical commodity contracts entered into for the purpose of receipt or delivery in accordance with the company's expected purchase, sale or usage requirements are not considered to be derivative financial instruments and are accounted for as executory contracts.
Derivatives embedded in other financial instruments or other host contracts are recorded as separate derivatives when their risks and characteristics are not closely related to those of the host contract.
(r) Hedging Activities
The company may apply hedge accounting to arrangements that qualify for designated hedge accounting treatment. Documentation is prepared at the inception of a hedge relationship in order to qualify for hedge accounting. Designated hedges are assessed at each reporting date to determine if the relationship between the derivative and the underlying hedged item accomplishes the company's risk management objectives for financial and non-financial risk exposures.
If the derivative is designated as a fair value hedge, changes in the fair value of the derivative and in the fair value of the underlying hedged item are recognized in net earnings. If the derivative is designated as a cash flow hedge, the effective portions of the changes in fair value of the derivative are initially recorded in Other Comprehensive Income and are recognized in net earnings when the hedged item is realized. Ineffective portions of changes in the fair value of cash flow hedges are recognized in net earnings immediately. Changes in the fair value of a derivative designated in a fair value or cash flow hedge are recognized in the same line item as the underlying hedged item.
The company did not apply hedge accounting to any of its derivative instruments for the years ended December 31, 2019 or 2018.
(s) Share Capital
Common shares are classified as equity. Incremental costs directly attributable to the issuance of common shares are recognized as a deduction from equity, net of any tax effects. When the company repurchases its own common shares, share capital is reduced by the average carrying value of the shares repurchased. The excess of the purchase price over the average carrying value is recognized as a deduction from Retained Earnings. Shares are cancelled upon repurchase.
(t) Dividend Distributions
Dividends on common shares are recognized in the period in which the dividends are declared by the company's Board of Directors.
(u) Earnings per Share
Basic earnings per share is calculated by dividing the net earnings for the period by the weighted average number of common shares outstanding during the period.
Diluted earnings per share is calculated by adjusting the weighted average number of common shares outstanding for dilutive common shares related to the company's share-based compensation plans. The number of shares included is computed using the treasury stock method. As these awards can be exchanged for common shares of the company, they are considered potentially dilutive and are included in the calculation of the company's diluted net earnings per share if they have a dilutive impact in the period.
96 2019 ANNUAL REPORT Suncor Energy Inc.
(v) Emissions Obligations
Emissions obligations are measured at the weighted average cost per unit of emissions expected to be incurred in the compliance period and are recorded in the period in which the emissions occur within Operating, Selling and General expense.
Purchases of emissions rights are recognized as Other Assets on the balance sheet and are measured at historical cost. Emissions rights received by way of grant are recorded at a nominal amount.
4. SIGNIFICANT ACCOUNTING ESTIMATES AND JUDGMENTS
The preparation of financial statements in accordance with IFRS requires management to make estimates and judgments that affect reported assets, liabilities, revenues, expenses, gains, losses, and disclosures of contingencies. These estimates and judgments are subject to change based on experience and new information. The financial statement areas that require significant estimates and judgments are as follows:
Oil and Gas Reserves
The company's estimate of oil and gas reserves is considered in the measurement of depletion, depreciation, impairment, and decommissioning and restoration obligations. The estimation of reserves is an inherently complex process and involves the exercise of professional judgment. All reserves have been evaluated at December 31, 2019 by independent qualified reserves evaluators. Oil and gas reserves estimates are based on a range of geological, technical and economic factors, including projected future rates of production, projected future commodity prices, engineering data, and the timing and amount of future expenditures, all of which are subject to uncertainty. Estimates reflect market and regulatory conditions existing at December 31, 2019, which could differ significantly from other points in time throughout the year, or future periods. Changes in market and regulatory conditions and assumptions can materially impact the estimation of net reserves.
Oil and Gas Activities
The company is required to apply judgment when designating the nature of oil and gas activities as exploration, evaluation, development or production, and when determining whether the costs of these activities shall be expensed or capitalized.
Exploration and Evaluation Costs
Certain exploration and evaluation costs are initially capitalized with the intent to establish commercially viable reserves. The company is required to make judgments about future events and circumstances and applies estimates to assess the economic viability of extracting the underlying resources. The costs are subject to technical, commercial and management review to confirm the continued intent to develop the project. Level of drilling success or changes to project economics, resource quantities, expected production techniques, production costs and required capital expenditures are important judgments when making this determination. Management uses judgment to determine when these costs are reclassified to Property, Plant and Equipment based on several factors, including the existence of reserves, appropriate approvals from regulatory bodies, joint arrangement partners and the company's internal project approval process.
Determination of Cash Generating Units (CGUs)
A CGU is the lowest grouping of integrated assets that generate identifiable cash inflows that are largely independent of the cash inflows of other assets or groups of assets. The allocation of assets into CGUs requires significant judgment and interpretations with respect to the integration between assets, the existence of active markets, similar exposure to market risks, shared infrastructure, and the way in which management monitors the operations.
Asset Impairment and Reversals
Management applies judgment in assessing the existence of impairment and impairment reversal indicators based on various internal and external factors.
The recoverable amount of CGUs and individual assets is determined based on the higher of fair value less costs of disposal or value-in-use calculations. The key estimates the company applies in determining the recoverable amount normally include estimated future commodity prices, discount rates, expected production volumes, future operating and development costs, tax rates, and refining margins. In determining the recoverable amount, management may also be required to make judgments regarding the likelihood of occurrence of a future event. Changes to these estimates and judgments will affect the recoverable amounts of CGUs and individual assets and may then require a material adjustment to their related carrying value.
2019 ANNUAL REPORT Suncor Energy Inc. 97
Decommissioning and Restoration Costs
The company recognizes liabilities for the future decommissioning and restoration of Exploration and Evaluation assets and Property, Plant and Equipment based on estimated future decommissioning and restoration costs. Management applies judgment in assessing the existence and extent as well as the expected method of reclamation of the company's decommissioning and restoration obligations at the end of each reporting period. Management also uses judgment to determine whether the nature of the activities performed is related to decommissioning and restoration activities or normal operating activities.
Actual costs are uncertain and estimates may vary as a result of changes to relevant laws and regulations related to the use of certain technologies, the emergence of new technology, operating experience, prices and closure plans. The estimated timing of future decommissioning and restoration may change due to certain factors, including reserves life. Changes to estimates related to future expected costs, discount rates, inflation assumptions, and timing may have a material impact on the amounts presented.
Employee Future Benefits
The company provides benefits to employees, including pensions and other post-retirement benefits. The cost of defined benefit pension plans and other post-retirement benefits received by employees is estimated based on actuarial valuation methods that require professional judgment. Estimates typically used in determining these amounts include, as applicable, rates of employee turnover, future claim costs, discount rates, future salary and benefit levels, the return on plan assets, mortality rates and future medical costs. Changes to these estimates may have a material impact on the amounts presented.
Other Provisions
The determination of other provisions, including, but not limited to, provisions for royalty disputes, onerous contracts, litigation and constructive obligations, is a complex process that involves judgment about the outcomes of future events, the interpretation of laws and regulations, and estimates on the timing and amount of expected future cash flows and discount rates.
Income Taxes
Management evaluates tax positions, annually or when circumstances require, which involves judgment and could be subject to differing interpretations of applicable tax legislation. The company recognizes a tax provision when a payment to tax authorities is considered probable. However, the results of audits and reassessments and changes in the interpretations of standards may result in changes to those positions and, potentially, a material increase or decrease in the company's assets, liabilities and net earnings.
Deferred Income Taxes
Deferred tax assets are recognized when it is considered probable that deductible temporary differences will be recovered in the foreseeable future. To the extent that future taxable income and the application of existing tax laws in each jurisdiction differ significantly from the company's estimate, the ability of the company to realize the deferred tax assets could be impacted.
Deferred tax liabilities are recognized when there are taxable temporary differences that will reverse and result in a future outflow of funds to a taxation authority. The company records a provision for the amount that is expected to be settled, which requires judgment as to the ultimate outcome. Deferred tax liabilities could be impacted by changes in the company's judgment of the likelihood of a future outflow and estimates of the expected settlement amount, timing of reversals, and the tax laws in the jurisdictions in which the company operates.
Fair Value of Financial Instruments
The fair value of a financial instrument is determined, whenever possible, based on observable market data. If not available, the company uses third-party models and valuation methodologies that utilize observable market data that includes forward commodity prices, foreign exchange rates and interest rates to estimate the fair value of financial instruments, including derivatives. In addition to market information, the company incorporates transaction-specific details that market participants would utilize in a fair value measurement, including the impact of non-performance risk.
98 2019 ANNUAL REPORT Suncor Energy Inc.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
Functional Currency
The designation of the functional currency of the company and each of its subsidiaries is a management judgment based on the composition of revenue and costs in the locations in which it operates.
(a) Adoption of New IFRS Standards
IFRS 16 Leases
Effective January 1, 2019, the company adopted IFRS 16 Leases (IFRS 16) which replaces IAS 17 Leases (IAS 17) and requires the recognition of most leases on the balance sheet. IFRS 16 effectively removes the classification of leases as either finance or operating leases and treats all leases as finance leases for lessees with optional exemptions for short-term leases where the term is twelve months or less. The accounting treatment for lessors remains essentially unchanged, with the requirement to classify leases as either finance or operating.
The company has selected the modified retrospective transition approach, electing to adjust opening retained earnings with no restatement of comparative figures. As such, comparative information continues to be reported under IAS 17 and International Financial Reporting Interpretations Committee (IFRIC) 4. The details of accounting policies under IAS 17 and IFRIC 4 are disclosed separately if they are different from those under IFRS 16 and the impact of the change is disclosed below.
The company's accounting policy under IFRS 16 is as follows:
At inception of a contract, the company assesses whether a contract is, or contains, a lease based on whether the contract conveys the right to control the use of an identified asset for a period of time in exchange for consideration.
The company recognizes a right-of-use asset and a lease liability at the lease commencement date. The right-of-use asset is initially measured based on the initial amount of the lease liability adjusted for any lease payments made at or before the commencement date, plus any initial direct costs incurred and an estimate of costs to dismantle and remove the underlying asset or to restore the underlying asset or the site on which it is located, less any lease incentives received. The assets are depreciated to the earlier of the end of the useful life of the right-of-use asset or the lease term, where judgment is applied to determine the lease term of the lease contracts in which the company has a renewal option, using the straight-line method as this most closely reflects the expected pattern of consumption of the future economic benefits. In addition, the right-of-use assets may be periodically reduced by impairment losses, if any, and adjusted for certain remeasurements of the lease liability.
The lease liability is initially measured at the present value of the lease payments that are not paid at the commencement date, discounted using the interest rate implicit in the lease or, if that rate cannot be readily determined, the company's incremental borrowing rate. Lease payments include fixed payments, and variable payments that are based on an index or rate.
Cash payments for the principal portion of the lease liability are presented within the financing activities section and the interest portion of the lease liability is presented within the operating activities section of the statement of cash flows. Short-term lease payments and variable lease payments not included in the measurement of the lease liability are presented within the operating activities section of the statement of cash flows.
The lease liability is measured at amortized cost using the effective interest method. It is remeasured when there is a change in future lease payments arising from a change in an index or rate, if there is a change in the company's estimate of the amount expected to be payable under a residual value guarantee, or if the company changes its assessment of whether it will exercise a purchase, extension or termination option.
When the lease liability is remeasured in this way, a corresponding adjustment is made to the carrying amount of the right-of-use asset, or is recorded in profit or loss if the carrying amount of the right-of-use asset has been reduced to zero.
Under IAS 17
In the comparative period, the company classified leases that transferred substantially all of the risks and rewards of ownership as finance leases. When this was the case, the leased assets were measured initially at an amount equal to the lower of their fair value and the present value of minimum lease payments. Minimum lease payments were the payments over the lease term that the lessee was required to make, excluding any contingent rent.
2019 ANNUAL REPORT Suncor Energy Inc. 99
Subsequently, the assets were accounted for in accordance with the accounting policy applicable to that asset.
Assets held under other leases were classified as operating leases and were not recognized in the company's statement of financial position. Payments made under operating leases were recognized in profit or loss on a straight-line basis over the term of the lease. Lease incentives received were recognized as an integral part of the total lease expense over the term of the lease.
As part of the initial application of IFRS 16, the company also chose to apply the following transitional provisions.
Right-of-use assets are measured at:
The company applied the following practical expedients when applying IFRS 16 to leases previously classified as operating leases under IAS 17:
The following table summarizes the impact of adopting IFRS 16 on the company's Consolidated Balance Sheets at January 1, 2019. Prior period amounts have not been restated. The effects of the transition have been recognized through retained earnings in equity.
($ millions) Increase (Decrease) |
December 31
2018 |
Adjustments due to
IFRS 16 |
January 1
2019 |
||||||
|
|||||||||
Assets | |||||||||
|
|||||||||
Current assets | |||||||||
|
|||||||||
Accounts receivable | 3 206 | (2 | ) | 3 204 | |||||
|
|||||||||
Property, plant and equipment, net | 74 245 | (1 267 | ) | 72 978 | |||||
|
|||||||||
Right-of-use assets, net | | 3 059 | 3 059 | ||||||
|
|||||||||
Liabilities and Shareholders' Equity | |||||||||
|
|||||||||
Current liabilities | |||||||||
|
|||||||||
Current portion of long-term debt | 229 | (38 | ) | 191 | |||||
|
|||||||||
Current portion of lease liabilities | | 276 | 276 | ||||||
|
|||||||||
Current portion of provisions | 667 | (1 | ) | 666 | |||||
|
|||||||||
Long-term debt | 13 890 | (1 222 | ) | 12 668 | |||||
|
|||||||||
Long-term lease liabilities | | 2 777 | 2 777 | ||||||
|
|||||||||
Other long-term liabilities | 2 346 | (1 | ) | 2 345 | |||||
|
|||||||||
Provisions | 6 984 | (20 | ) | 6 964 | |||||
|
|||||||||
Deferred income taxes | 12 045 | 5 | 12 050 | ||||||
|
|||||||||
Equity | 44 005 | 14 | 44 019 | ||||||
|
The following table reconciles the company's operating lease commitments as at December 31, 2018, as previously disclosed in the company's consolidated financial statements as at and for the year ended December 31, 2018, to the additional lease liabilities recognized on initial application of IFRS 16 as at January 1, 2019.
100 2019 ANNUAL REPORT Suncor Energy Inc.
Reconciliation
($ millions) |
January 1
2019 |
|||
|
||||
Operating leases as at December 31, 2018 (1) | 2 457 | |||
|
||||
Exemption for short-term leases | (42 | ) | ||
|
||||
Discounting | (623 | ) | ||
|
||||
Additional lease liabilities recognized due to adoption of IFRS 16 as at January 1, 2019 | 1 792 | |||
|
For leases that were previously classified as finance leases under IAS 17, within Property, Plant and Equipment, the carrying amount of the right-of-use asset and the lease liability recognized upon initial application as at January 1, 2019 was determined to be the carrying amount of the finance lease asset and liability under IAS 17 immediately before transition.
The lease liabilities recognized in accordance with IFRS 16 were discounted using the company's incremental borrowing rate upon initial application. The weighted average discount rate used for additional leases recognized as a result of application of IFRS 16 was 3.85% as at January 1, 2019.
Uncertainty over Income Tax Treatments
In June 2017, the IASB issued IFRIC 23 Uncertainty over Income Tax Treatments. The interpretation clarifies the accounting for current and deferred tax liabilities and assets in circumstances in which there is uncertainty over income tax treatments. The interpretation requires an entity to consider whether it is probable that a taxation authority will accept an uncertain tax treatment. If the entity considers it to be not probable that a taxation authority will accept an uncertain tax provision, the interpretation requires the entity to use the most likely amount or the expected value. The company adopted the amendment on its effective date of January 1, 2019. The adoption of this amendment did not have any impact on the company's consolidated financial statements.
(b) Recently Announced Accounting Pronouncements
The standards, amendments and interpretations that are issued, but not yet effective up to the date of authorization of the company's consolidated financial statements, and that may have an impact on the disclosures and financial position of the company are disclosed below. The company intends to adopt these standards, amendments and interpretations when they become effective.
Definition of a Business
In October 2018, the IASB issued Definition of a Business (Amendments to IFRS 3). The amendments narrowed and clarified the definition of a business. The amendments include an election to use a concentration test. This is a simplified assessment that results in an asset acquisition if substantially all of the fair value of the gross assets is concentrated in a single identifiable asset or a group of similar identifiable assets. If an election to use a concentration test is not made, or the test failed, then the assessment focuses on the existence of a substantive process. One important distinction is that "goodwill" can only be recognized as a result of acquiring a business, but not as a result of an asset acquisition. The amendments are effective for annual periods beginning on or after January 1, 2020 and are to be applied prospectively.
2019 ANNUAL REPORT Suncor Energy Inc. 101
The company's operating segments are reported based on the nature of their products and services and management responsibility. The following summary describes the operations in each of the segments:
The company also reports activities not directly attributable to an operating segment under Corporate and Eliminations. This includes renewable projects such as the wind power facilities of Chin Chute and Magrath in Alberta, SunBridge in Saskatchewan and Adelaide in Ontario as well as an investment in Enerkem Inc., a waste-to-biofuels and chemicals producer headquartered in Quebec.
Intersegment sales of crude oil and natural gas are accounted for at market values and included, for segmented reporting, in revenues of the segment making the transfer and expenses of the segment receiving the transfer. Intersegment balances are eliminated on consolidation. Intersegment profit will not be recognized until the related product has been sold to third parties.
102 2019 ANNUAL REPORT Suncor Energy Inc.
For the years ended December 31(1)(2) | Oil Sands |
Exploration
and Production |
Refining and
Marketing |
Corporate and
Eliminations |
Total | |||||||||||||||||
($ millions) | 2019 | 2018 | 2019 | 2018 | 2019 | 2018 | 2019 | 2018 | 2019 | 2018 | ||||||||||||
|
||||||||||||||||||||||
Revenues and Other Income | ||||||||||||||||||||||
|
||||||||||||||||||||||
Gross revenues | 13 948 | 12 039 | 3 675 | 3 869 | 22 216 | 23 655 | 27 | 29 | 39 866 | 39 592 | ||||||||||||
|
||||||||||||||||||||||
Intersegment revenues | 4 399 | 3 704 | | | 88 | 123 | (4 487 | ) | (3 827 | ) | | | ||||||||||
|
||||||||||||||||||||||
Less: Royalties | (917 | ) | (398 | ) | (605 | ) | (652 | ) | | | | | (1 522 | ) | (1 050 | ) | ||||||
|
||||||||||||||||||||||
Operating revenues, net of royalties | 17 430 | 15 345 | 3 070 | 3 217 | 22 304 | 23 778 | (4 460 | ) | (3 798 | ) | 38 344 | 38 542 | ||||||||||
|
||||||||||||||||||||||
Other income (loss) | 172 | 387 | 430 | (68 | ) | 75 | 68 | (32 | ) | 57 | 645 | 444 | ||||||||||
|
||||||||||||||||||||||
17 602 | 15 732 | 3 500 | 3 149 | 22 379 | 23 846 | (4 492 | ) | (3 741 | ) | 38 989 | 38 986 | |||||||||||
|
||||||||||||||||||||||
Expenses | ||||||||||||||||||||||
|
||||||||||||||||||||||
Purchases of crude oil and products | 1 407 | 1 563 | | | 15 296 | 16 656 | (4 141 | ) | (4 086 | ) | 12 562 | 14 133 | ||||||||||
|
||||||||||||||||||||||
Operating, selling and general | 8 027 | 7 577 | 525 | 507 | 2 173 | 2 043 | 519 | 446 | 11 244 | 10 573 | ||||||||||||
|
||||||||||||||||||||||
Transportation | 1 293 | 1 144 | 80 | 85 | 120 | 147 | (51 | ) | (57 | ) | 1 442 | 1 319 | ||||||||||
|
||||||||||||||||||||||
Depreciation, depletion, amortization and impairment | 8 170 | 4 024 | 1 505 | 967 | 823 | 684 | 74 | 63 | 10 572 | 5 738 | ||||||||||||
|
||||||||||||||||||||||
Exploration | 127 | 44 | 129 | 78 | | | | | 256 | 122 | ||||||||||||
|
||||||||||||||||||||||
(Gain) loss on asset exchange and disposal of assets | (14 | ) | (108 | ) | (228 | ) | 91 | (11 | ) | (7 | ) | | | (253 | ) | (24 | ) | |||||
|
||||||||||||||||||||||
Financing expenses | 318 | 320 | 73 | 46 | 55 | 7 | 187 | 1 769 | 633 | 2 142 | ||||||||||||
|
||||||||||||||||||||||
19 328 | 14 564 | 2 084 | 1 774 | 18 456 | 19 530 | (3 412 | ) | (1 865 | ) | 36 456 | 34 003 | |||||||||||
|
||||||||||||||||||||||
(Loss) earnings before Income Taxes | (1 726 | ) | 1 168 | 1 416 | 1 375 | 3 923 | 4 316 | (1 080 | ) | (1 876 | ) | 2 533 | 4 983 | |||||||||
|
||||||||||||||||||||||
Income Tax (Recovery) Expense | ||||||||||||||||||||||
|
||||||||||||||||||||||
Current | 266 | (128 | ) | 626 | 680 | 972 | 1 090 | (312 | ) | (392 | ) | 1 552 | 1 250 | |||||||||
|
||||||||||||||||||||||
Deferred | (1 565 | ) | 351 | (215 | ) | (112 | ) | (49 | ) | 72 | (89 | ) | 129 | (1 918 | ) | 440 | ||||||
|
||||||||||||||||||||||
(1 299 | ) | 223 | 411 | 568 | 923 | 1 162 | (401 | ) | (263 | ) | (366 | ) | 1 690 | |||||||||
|
||||||||||||||||||||||
Net (Loss) Earnings | (427 | ) | 945 | 1 005 | 807 | 3 000 | 3 154 | (679 | ) | (1 613 | ) | 2 899 | 3 293 | |||||||||
|
||||||||||||||||||||||
Capital and Exploration Expenditures | 3 522 | 3 546 | 1 070 | 946 | 818 | 856 | 148 | 58 | 5 558 | 5 406 | ||||||||||||
|
2019 ANNUAL REPORT Suncor Energy Inc. 103
Disaggregation of Revenue from Contracts with Customers and Intersegment Revenue
The company derives revenue from the transfer of goods mainly at a point in time in the following major commodities, revenue streams and geographical regions:
For the years ended December 31 (1) | 2019 | 2018 | ||||||||||||
($ millions) | North America | International | Total | North America | International | Total | ||||||||
|
||||||||||||||
Oil Sands | ||||||||||||||
|
||||||||||||||
SCO and diesel | 13 368 | | 13 368 | 11 659 | | 11 659 | ||||||||
|
||||||||||||||
Bitumen | 4 979 | | 4 979 | 4 084 | | 4 084 | ||||||||
|
||||||||||||||
18 347 | | 18 347 | 15 743 | | 15 743 | |||||||||
|
||||||||||||||
Exploration and Production | ||||||||||||||
|
||||||||||||||
Crude oil and natural gas liquids | 1 922 | 1 747 | 3 669 | 1 741 | 2 112 | 3 853 | ||||||||
|
||||||||||||||
Natural gas | | 6 | 6 | 3 | 13 | 16 | ||||||||
|
||||||||||||||
1 922 | 1 753 | 3 675 | 1 744 | 2 125 | 3 869 | |||||||||
|
||||||||||||||
Refining and Marketing | ||||||||||||||
|
||||||||||||||
Gasoline | 9 941 | | 9 941 | 10 819 | | 10 819 | ||||||||
|
||||||||||||||
Distillate | 9 447 | | 9 447 | 9 698 | | 9 698 | ||||||||
|
||||||||||||||
Other | 2 916 | | 2 916 | 3 261 | | 3 261 | ||||||||
|
||||||||||||||
22 304 | | 22 304 | 23 778 | | 23 778 | |||||||||
|
||||||||||||||
Corporate and Eliminations | (4 460 | ) | | (4 460 | ) | (3 798 | ) | | (3 798 | ) | ||||
|
||||||||||||||
Total Gross Revenue from Contracts with Customers | 38 113 | 1 753 | 39 866 | 37 467 | 2 125 | 39 592 | ||||||||
|
Geographical Information
Operating Revenues, net of Royalties
($ millions) | 2019 | 2018 | |||
|
|||||
Canada | 31 157 | 30 813 | |||
|
|||||
United States | 5 737 | 5 999 | |||
|
|||||
Other foreign | 1 450 | 1 730 | |||
|
|||||
38 344 | 38 542 | ||||
|
Non-Current Assets(1)
($ millions) |
December 31
2019 |
December 31
2018 |
|||
|
|||||
Canada | 75 190 | 76 708 | |||
|
|||||
United States | 1 957 | 1 889 | |||
|
|||||
Other foreign | 2 173 | 2 154 | |||
|
|||||
79 320 | 80 751 | ||||
|
104 2019 ANNUAL REPORT Suncor Energy Inc.
Other income consists of the following:
($ millions) | 2019 | 2018 | |||
|
|||||
Risk management and trading activities(1) | 155 | 255 | |||
|
|||||
(Losses) gains on valuation of inventory held for trading purposes | (7 | ) | 13 | ||
|
|||||
Investment and interest income | 89 | 34 | |||
|
|||||
Insurance proceeds(2) | 431 | 120 | |||
|
|||||
Other | (23 | ) | 22 | ||
|
|||||
645 | 444 | ||||
|
8. OPERATING, SELLING AND GENERAL
Operating, Selling and General expense consists of the following:
($ millions) | 2019 | 2018 | |||
|
|||||
Contract services(1) | 4 380 | 4 552 | |||
|
|||||
Employee costs(1) | 3 641 | 3 263 | |||
|
|||||
Materials | 869 | 765 | |||
|
|||||
Energy | 1 129 | 1 095 | |||
|
|||||
Equipment rentals and leases | 345 | 360 | |||
|
|||||
Travel, marketing and other | 880 | 538 | |||
|
|||||
11 244 | 10 573 | ||||
|
Financing expenses consist of the following:
($ millions) | 2019 | 2018 | |||||
|
|||||||
Interest on debt | 825 | 897 | |||||
|
|||||||
Interest on lease liabilities(1) | 172 | | |||||
|
|||||||
Capitalized interest at 5.3% (2018 5.4%) | (122 | ) | (156 | ) | |||
|
|||||||
Interest expense | 875 | 741 | |||||
|
|||||||
Interest on partnership liability | 55 | 56 | |||||
|
|||||||
Interest on pension and other post-retirement benefits | 59 | 56 | |||||
|
|||||||
Accretion | 270 | 266 | |||||
|
|||||||
Foreign exchange (gain) loss on U.S. dollar denominated debt | (624 | ) | 1 090 | ||||
|
|||||||
Operational foreign exchange and other | (2 | ) | (67 | ) | |||
|
|||||||
633 | 2 142 | ||||||
|
2019 ANNUAL REPORT Suncor Energy Inc. 105
Income Tax (Recovery) Expense
($ millions) | 2019 | 2018 | |||||
|
|||||||
Current: | |||||||
|
|||||||
Current year | 1 524 | 1 270 | |||||
|
|||||||
Adjustments to current income tax of prior years | 28 | (20 | ) | ||||
|
|||||||
Deferred: | |||||||
|
|||||||
Origination and reversal of temporary differences | (819 | ) | 345 | ||||
|
|||||||
Adjustments in respect of deferred income tax of prior years | 83 | 13 | |||||
|
|||||||
Changes in tax rates and legislation | (1 124 | ) | | ||||
|
|||||||
Movement in unrecognized deferred income tax assets | (58 | ) | 82 | ||||
|
|||||||
Total income tax (recovery) expense | (366 | ) | 1 690 | ||||
|
Reconciliation of Effective Tax Rate
The provision for income taxes reflects an effective tax rate that differs from the statutory tax rate. A reconciliation of the difference is as follows:
($ millions) | 2019 | 2018 | |||||
|
|||||||
Earnings before income tax | 2 533 | 4 983 | |||||
|
|||||||
Canadian statutory tax rate | 26.74% | 27.04% | |||||
|
|||||||
Statutory tax | 677 | 1 347 | |||||
|
|||||||
Add (deduct) the tax effect of: | |||||||
|
|||||||
Non-taxable component of capital (gains) losses | (146 | ) | 146 | ||||
|
|||||||
Share-based compensation and other permanent items | 25 | 31 | |||||
|
|||||||
Assessments and adjustments | 112 | (7 | ) | ||||
|
|||||||
Impact of income tax rate and legislative changes | (1 067 | ) | | ||||
|
|||||||
Foreign tax rate differential | 83 | 111 | |||||
|
|||||||
Non-taxable component of acquisitions and dispositions | | (14 | ) | ||||
|
|||||||
Movement in unrecognized deferred income tax assets | (58 | ) | 82 | ||||
|
|||||||
Other | 8 | (6 | ) | ||||
|
|||||||
Total income tax (recovery) expense | (366 | ) | 1 690 | ||||
|
|||||||
Effective tax rate | (14.4 | )% | 33.9% | ||||
|
In the second quarter of 2019, Suncor recognized a deferred income tax recovery of $1.116 billion related to a decrease in the Alberta corporate tax rate from 12% to 8%. The tax rate decrease will be phased in as follows: 11% effective July 1, 2019, 10% effective January 1, 2020, 9% effective January 1, 2021, and 8% effective January 1, 2022. The deferred income tax recovery of $1.116 billion was comprised of $910 million recovery in the Oil Sands segment, $88 million recovery in the Refining and Marketing segment, $70 million recovery in the Exploration and Production segment, and $48 million recovery in the Corporate and Eliminations segment.
106 2019 ANNUAL REPORT Suncor Energy Inc.
Deferred Income Tax Balances
The significant components of the company's deferred income tax (assets) liabilities and deferred income tax expense (recovery) are comprised of the following:
Deferred Income Tax (Recovery)
Expense |
Deferred Income Tax Liability
(Asset) |
|||||||||
|
|
|||||||||
($ millions) | 2019 | 2018 |
December 31
2019 |
December 31
2018 |
||||||
|
||||||||||
Property, plant and equipment | (2 348 | ) | 484 | 12 814 | 14 666 | |||||
|
||||||||||
Decommissioning and restoration provision | 259 | 46 | (2 092 | ) | (1 854 | ) | ||||
|
||||||||||
Employee retirement benefit plans | 32 | 15 | (576 | ) | (585 | ) | ||||
|
||||||||||
Tax loss carry-forwards | 16 | (63 | ) | (156 | ) | (172 | ) | |||
|
||||||||||
Other | 123 | (42 | ) | (23 | ) | (138 | ) | |||
|
||||||||||
Net deferred income tax (recovery) expense and liability | (1 918 | ) | 440 | 9 967 | 11 917 | |||||
|
Change in Deferred Income Tax Balances
($ millions) | 2019 | 2018 | |||
|
|||||
Net deferred income tax liability, beginning of year | 11 917 | 11 433 | |||
|
|||||
Recognized in deferred income tax expense | (1 918 | ) | 440 | ||
|
|||||
Recognized in other comprehensive income | (23 | ) | 39 | ||
|
|||||
Foreign exchange, disposition and other | (9 | ) | 5 | ||
|
|||||
Net deferred income tax liability, end of year | 9 967 | 11 917 | |||
|
Deferred Tax in Shareholders' Equity
($ millions) | 2019 | 2018 | ||||
|
||||||
Deferred Tax in Other Comprehensive Income | ||||||
|
||||||
Actuarial (loss) gain on employment retirement benefit plans | (23 | ) | 39 | |||
|
||||||
Total income tax (recovery) expense reported in equity | (23 | ) | 39 | |||
|
Deferred income tax assets are recognized for tax loss carry-forwards to the extent that the realization of the related tax benefit is probable based on estimated future earnings. Suncor has not recognized an $87 million (2018 $153 million) deferred income tax asset on $715 million (2018 $1,134 million) of capital losses related to foreign exchange on U.S. dollar denominated debt, which can only be utilized against future capital gains.
No deferred tax liability has been recognized at December 31, 2019, on temporary differences associated with earnings retained in our investments in foreign subsidiaries, as the company is able to control the timing of the reversal of these differences. Based on current plans, repatriation of funds in excess of foreign reinvestment will not result in material additional income tax expense. Deferred distribution taxes associated with international business operations have not been recorded.
2019 ANNUAL REPORT Suncor Energy Inc. 107
($ millions) | 2019 | 2018 | ||||
|
||||||
Net earnings | 2 899 | 3 293 | ||||
|
||||||
(millions of common shares) |
|
|
|
|
|
|
|
||||||
Weighted average number of common shares | 1 559 | 1 623 | ||||
|
||||||
Dilutive securities: | ||||||
|
||||||
Effect of share options | 2 | 6 | ||||
|
||||||
Weighted average number of diluted common shares | 1 561 | 1 629 | ||||
|
||||||
(dollars per common share) |
|
|
|
|
|
|
|
||||||
Basic earnings per share | 1.86 | 2.03 | ||||
|
||||||
Diluted earnings per share | 1.86 | 2.02 | ||||
|
($ millions) |
December 31
2019 |
December 31
2018 |
|||
|
|||||
Cash | 1 232 | 1 285 | |||
|
|||||
Cash equivalents | 728 | 936 | |||
|
|||||
1 960 | 2 221 | ||||
|
13. SUPPLEMENTAL CASH FLOW INFORMATION
The (increase) decrease in non-cash working capital is comprised of:
($ millions) | 2019 | 2018 | |||||
|
|||||||
Accounts receivable | (1 099 | ) | 219 | ||||
|
|||||||
Inventories | (628 | ) | 316 | ||||
|
|||||||
Accounts payable and accrued liabilities | 1 317 | (503 | ) | ||||
|
|||||||
Current portion of provisions | (14 | ) | (110 | ) | |||
|
|||||||
Income taxes payable (net) | 436 | 511 | |||||
|
|||||||
12 | 433 | ||||||
|
|||||||
Relating to: | |||||||
|
|||||||
Operating activities | (397 | ) | 408 | ||||
|
|||||||
Investing activities | 409 | 25 | |||||
|
|||||||
12 | 433 | ||||||
|
108 2019 ANNUAL REPORT Suncor Energy Inc.
Reconciliation of movements of liabilities to cash flows arising from financing activities:
($ millions) |
Short-Term
Debt |
Current
Portion of Long-Term Lease Liabilities |
Long-Term
Lease Liabilities |
Current
Portion of Long-Term Debt |
Long-Term
Debt |
Partnership
Liability |
Dividends
Payable |
||||||||||
|
|||||||||||||||||
At December 31, 2018 | 3 231 | | | 229 | 13 890 | 477 | | ||||||||||
|
|||||||||||||||||
Changes from financing cash flows: | |||||||||||||||||
|
|||||||||||||||||
Net repayment of commercial paper | (982 | ) | | | | | | | |||||||||
|
|||||||||||||||||
Gross proceeds from issuance of long-term debt | | | | | 750 | | | ||||||||||
|
|||||||||||||||||
Debt issuance costs | | | | | (5 | ) | | | |||||||||
|
|||||||||||||||||
Repayment of long-term debt | | | | (188 | ) | | | | |||||||||
|
|||||||||||||||||
Realized foreign exchange losses | | | | 7 | | | | ||||||||||
|
|||||||||||||||||
Dividends paid on common shares | | | | | | | (2 614 | ) | |||||||||
|
|||||||||||||||||
Payments of lease liabilities | | (307 | ) | | | | | | |||||||||
|
|||||||||||||||||
Distributions to non-controlling interest | | | | | | (7 | ) | | |||||||||
|
|||||||||||||||||
Non-cash changes: | |||||||||||||||||
|
|||||||||||||||||
Dividends declared on common shares | | | | | | | 2 614 | ||||||||||
|
|||||||||||||||||
Unrealized foreign exchange gains | (94 | ) | | | (10 | ) | (520 | ) | | | |||||||
|
|||||||||||||||||
Reclassification of debt to lease obligations | | | 1 260 | (38 | ) | (1 222 | ) | | | ||||||||
|
|||||||||||||||||
Reclassification of lease obligations | | 617 | (617 | ) | | | | | |||||||||
|
|||||||||||||||||
Deferred financing costs | | | | | (9 | ) | | | |||||||||
|
|||||||||||||||||
Reassessment of partnership liability | | | | | | (15 | ) | | |||||||||
|
|||||||||||||||||
New leases | | | 1 978 | | | | | ||||||||||
|
|||||||||||||||||
At December 31, 2019 | 2 155 | 310 | 2 621 | | 12 884 | 455 | | ||||||||||
|
($ millions) |
December 31
2019 |
December 31
2018 |
|||
|
|||||
Crude oil(1) | 1 689 | 1 424 | |||
|
|||||
Refined products | 1 290 | 1 033 | |||
|
|||||
Materials, supplies and merchandise | 782 | 702 | |||
|
|||||
3 761 | 3 159 | ||||
|
During 2019, purchased product inventories of $13.3 billion (2018 $14.8 billion) were recorded as an expense.
2019 ANNUAL REPORT Suncor Energy Inc. 109
15. PROPERTY, PLANT AND EQUIPMENT
($ millions) |
Oil and Gas
Properties |
Plant and
Equipment |
Total | ||||||
|
|||||||||
Cost | |||||||||
|
|||||||||
At December 31, 2017 | 36 209 | 78 639 | 114 848 | ||||||
|
|||||||||
Additions | 1 221 | 3 958 | 5 179 | ||||||
|
|||||||||
Transfers from exploration and evaluation | 31 | | 31 | ||||||
|
|||||||||
Acquisitions (notes 32 to 34) | 289 | 948 | 1 237 | ||||||
|
|||||||||
Changes in decommissioning and restoration | 85 | (22 | ) | 63 | |||||
|
|||||||||
Disposals and derecognition | (375 | ) | (4 785 | ) | (5 160 | ) | |||
|
|||||||||
Foreign exchange adjustments | 385 | 291 | 676 | ||||||
|
|||||||||
At December 31, 2018 | 37 845 | 79 029 | 116 874 | ||||||
|
|||||||||
Adoption of IFRS 16 (note 5) | | 1 792 | 1 792 | ||||||
|
|||||||||
Additions | 1 245 | 4 351 | 5 596 | ||||||
|
|||||||||
Changes in decommissioning and restoration | 1 846 | 49 | 1 895 | ||||||
|
|||||||||
Disposals and derecognition | (116 | ) | (439 | ) | (555 | ) | |||
|
|||||||||
Foreign exchange adjustments | (224 | ) | (214 | ) | (438 | ) | |||
|
|||||||||
At December 31, 2019 | 40 596 | 84 568 | 125 164 | ||||||
|
|||||||||
Accumulated provision | |||||||||
|
|||||||||
At December 31, 2017 | (17 975 | ) | (23 380 | ) | (41 355 | ) | |||
|
|||||||||
Depreciation, depletion, amortization and impairment | (1 739 | ) | (3 849 | ) | (5 588 | ) | |||
|
|||||||||
Disposals and derecognition | 255 | 4 545 | 4 800 | ||||||
|
|||||||||
Foreign exchange adjustments | (324 | ) | (162 | ) | (486 | ) | |||
|
|||||||||
At December 31, 2018 | (19 783 | ) | (22 846 | ) | (42 629 | ) | |||
|
|||||||||
Depreciation, depletion, amortization and impairment | (2 871 | ) | (7 764 | ) | (10 635 | ) | |||
|
|||||||||
Disposals and derecognition | 116 | 349 | 465 | ||||||
|
|||||||||
Foreign exchange adjustments | 149 | 126 | 275 | ||||||
|
|||||||||
At December 31, 2019 | (22 389 | ) | (30 135 | ) | (52 524 | ) | |||
|
|||||||||
Net property, plant and equipment |
|
|
|
|
|
|
|
|
|
|
|||||||||
December 31, 2018 | 18 062 | 56 183 | 74 245 | ||||||
|
|||||||||
December 31, 2019 | 18 207 | 54 433 | 72 640 | ||||||
|
At December 31, 2019, the balance of assets under construction and not subject to depreciation or depletion was $5.6 billion (December 31, 2018 $4.7 billion).
110 2019 ANNUAL REPORT Suncor Energy Inc.
Due to continued volatility in the crude oil price environment and resulting declines in forecasted long-term heavy crude oil prices, the company performed an asset impairment test on its Fort Hills CGU in the Oil Sands segment. Due to an increase to forecasted capital expenditures within the White Rose CGU, the company also performed an impairment test within the Exploration and Production segment as at December 31, 2019. The impairment tests were performed using recoverable amounts based on the fair value less cost of disposal. An expected cash flow approach was used with the key assumptions discussed below (Level 3 fair value inputs note 26):
Oil Sands
As a result of the impairment test, the company recorded impairment of $2.80 billion (net of taxes of $0.91 billion) on its share of the Fort Hills project in the Oil Sands segment using the following asset-specific assumptions:
The recoverable amount of the Fort Hills CGU was $7.7 billion as at December 31, 2019, which also includes the cost of carbon compliance in accordance with current provincial and federal regulations which starts at $30/tonne in 2020, reaches $50/tonne by 2022 and escalates at the rate of inflation thereafter. Estimate of the recoverable amount is most sensitive to the WCS price forecast and discount rate. A 5% decrease in price would have resulted in an increase to the impairment charge of approximately $1.2 billion (after-tax) on the company's share of the Fort Hills assets. A 1% increase in the discount rate would have resulted in an increase to the impairment charge of approximately $900 million (after-tax) on the company's share of the Fort Hills assets.
Exploration and Production
As a result of the impairment test, the company recorded impairment of $393 million (net of taxes of $128 million) on its share of the White Rose assets in the Exploration and Production segment using the following asset-specific assumptions:
The recoverable amount of the White Rose CGU was $360 million as at December 31, 2019, which also includes the cost of carbon compliance in accordance with current provincial and federal regulations which starts at $30/tonne in 2020, reaches $50/tonne by 2022 and escalates at the rate of inflation thereafter. Estimate of the recoverable amount is most sensitive to the Brent price forecast and discount rate. A 5% decrease in price would have resulted in an increase to the impairment charge of approximately $85 million (after-tax) on the company's share of the White Rose assets. A 1% increase in the discount rate would have resulted in an increase to the impairment charge of approximately $35 million (after-tax) on the company's share of the White Rose assets.
2019 ANNUAL REPORT Suncor Energy Inc. 111
16. RIGHT-OF-USE ASSETS AND LEASES
The company has lease contracts which include storage tanks, pipelines, railway cars, vessels, buildings, land, and mobile equipment for the purpose of production, storage and transportation of crude oil and related products.
Right-of-use (ROU) assets within Property, Plant and Equipment:
($ millions) |
December 31
2019 |
||
|
|||
Property, plant and equipment, net excluding ROU assets | 69 745 | ||
|
|||
ROU assets | 2 895 | ||
|
|||
72 640 | |||
|
The following table presents the ROU assets by asset class:
($ millions) |
Plant and
Equipment |
|||
|
||||
Cost | ||||
|
||||
At January 1, 2019 | 3 326 | |||
|
||||
Additions and adjustments | 186 | |||
|
||||
Foreign exchange | (7 | ) | ||
|
||||
At December 31, 2019 | 3 505 | |||
|
||||
Accumulated provision | ||||
|
||||
At January 1, 2019 | (267 | ) | ||
|
||||
Depreciation | (343 | ) | ||
|
||||
At December 31, 2019 | (610 | ) | ||
|
||||
Net ROU assets | ||||
|
||||
At January 1, 2019 (note 5) | 3 059 | |||
|
||||
At December 31, 2019 | 2 895 | |||
|
Other lease-related items recognized in the Consolidated Statement of Comprehensive Income
($ millions) |
For the year ended
December 31, 2019 |
|||
|
||||
Operating, selling and general | ||||
|
||||
Short-term lease expense | 236 | |||
|
||||
Variable lease expense | 45 | |||
|
There were no leases with residual value guarantees. Total cash outflow for leases was $464 million for the year ended December 31, 2019.
112 2019 ANNUAL REPORT Suncor Energy Inc.
17. EXPLORATION AND EVALUATION ASSETS
($ millions) |
December 31
2019 |
December 31
2018 |
||||
|
||||||
Beginning of year | 2 319 | 2 052 | ||||
|
||||||
Acquisitions and additions (Note 32) | 193 | 316 | ||||
|
||||||
Transfers to oil and gas assets | | (31 | ) | |||
|
||||||
Dry hole expenses | (66 | ) | (11 | ) | ||
|
||||||
Disposals | (16 | ) | (16 | ) | ||
|
||||||
Amortization | | (1 | ) | |||
|
||||||
Foreign exchange adjustments | (2 | ) | 10 | |||
|
||||||
End of year | 2 428 | 2 319 | ||||
|
($ millions) |
December 31
2019 |
December 31
2018 |
|||
|
|||||
Investments | 289 | 237 | |||
|
|||||
Prepaids and other | 905 | 889 | |||
|
|||||
1 194 | 1 126 | ||||
|
Prepaids and other includes long-term accounts receivable related to deposits paid on Notices of Reassessments that have been received from the Canada Revenue Agency (CRA) and are unlikely to be settled within one year.
19. GOODWILL AND OTHER INTANGIBLE ASSETS
Oil Sands | Refining and Marketing | |||||||||||
|
|
|||||||||||
($ millions) | Goodwill | Goodwill |
Brand
Name |
Customer
Lists |
Total | |||||||
|
||||||||||||
At December 31, 2017 | 2 752 | 140 | 162 | 7 | 3 061 | |||||||
|
||||||||||||
Additions | | | | 4 | 4 | |||||||
|
||||||||||||
Amortization | | | | (4 | ) | (4 | ) | |||||
|
||||||||||||
At December 31, 2018 | 2 752 | 140 | 162 | 7 | 3 061 | |||||||
|
||||||||||||
Amortization | | | | (3 | ) | (3 | ) | |||||
|
||||||||||||
At December 31, 2019 | 2 752 | 140 | 162 | 4 | 3 058 | |||||||
|
The company performed a goodwill impairment test at December 31, 2019 on its Oil Sands segment. Recoverable amounts were based on fair value less costs of disposal calculated using the present value of the segments' expected future cash flows.
Cash flow forecasts are based on past experience, historical trends and third-party evaluations of the company's reserves and resources to determine production profiles and volumes, operating costs, maintenance and capital expenditures. Production profiles, reserves volumes, operating costs, maintenance and capital expenditures are validated against the estimates approved through the company's annual reserves evaluation process and determine the duration of the underlying cash flows used in the discounted cash flow test. Projected cash flows reflect current market assessments of key assumptions, including long-term forecasts of commodity prices, inflation rates, foreign exchange rates and discount rates specific to the asset (Level 3 fair value inputs).
Future cash flow estimates are discounted using after-tax risk-adjusted discount rates. The discount rates are calculated based on the weighted average cost of capital of a group of relevant peers that is considered to represent the rate of return that
2019 ANNUAL REPORT Suncor Energy Inc. 113
would be required by a typical market participant for similar assets. The after-tax discount rate applied to cash flow projections was 7.5% (2018 8%). The company based its cash flow projections on a West Texas Intermediate price of US$60/bbl in 2020 and escalating at an average of 2% thereafter, adjusted for applicable quality and location differentials depending on the underlying CGU. The forecast cash flow period ranged from 20 years to 45 years based on the reserves life of the respective CGU. As a result of this analysis, an impairment of $2.80 billion (net of taxes of $0.91 billion) on company's share of the Fort Hills CGU was recorded (note 15); however, management did not identify any impairment of goodwill within any of the CGUs comprising the Oil Sands operating segment.
The company also performed a goodwill impairment test of its Refining and Marketing CGUs. The recoverable amounts are based on fair value less costs of disposal calculated using the present value of the CGUs' expected future cash flows, based primarily on historical results adjusted for current economic conditions.
20. DEBT AND CREDIT FACILITIES
Debt and credit facilities are comprised of the following:
Short-Term Debt
($ millions) |
December 31
2019 |
December 31
2018 |
|||
|
|||||
Commercial paper(1) | 2 155 | 3 231 | |||
|
114 2019 ANNUAL REPORT Suncor Energy Inc.
Long-Term Debt
($ millions) |
December 31
2019 |
December 31
2018 |
|||||
|
|||||||
Fixed-term debt(2)(3) | |||||||
|
|||||||
7.75% Notes, due 2019 (US$140)(4) | | 191 | |||||
|
|||||||
3.10% Series 5 Medium Term Notes, due 2021 | 749 | 749 | |||||
|
|||||||
9.25% Debentures, due 2021 (US$300) | 403 | 431 | |||||
|
|||||||
9.40% Notes, due 2021 (US$220)(4)(5) | 292 | 315 | |||||
|
|||||||
4.50% Notes, due 2022 (US$182)(4) | 225 | 234 | |||||
|
|||||||
3.60% Notes, due 2024 (US$750) | 968 | 1 020 | |||||
|
|||||||
3.00% Series 5 Medium Term Notes, due 2026 | 698 | 698 | |||||
|
|||||||
7.875% Debentures, due 2026 (US$275) | 372 | 393 | |||||
|
|||||||
8.20% Notes, due 2027 (US$59)(4) | 82 | 87 | |||||
|
|||||||
7.00% Debentures, due 2028 (US$250) | 329 | 346 | |||||
|
|||||||
3.10% Series 6 Medium Term Notes, due 2029 | 750 | | |||||
|
|||||||
7.15% Notes, due 2032 (US$500) | 647 | 681 | |||||
|
|||||||
5.35% Notes, due 2033 (US$300) | 361 | 379 | |||||
|
|||||||
5.95% Notes, due 2034 (US$500) | 646 | 680 | |||||
|
|||||||
5.95% Notes, due 2035 (US$600) | 747 | 786 | |||||
|
|||||||
5.39% Series 4 Medium Term Notes, due 2037 | 599 | 599 | |||||
|
|||||||
6.50% Notes, due 2038 (US$1 150) | 1 487 | 1 565 | |||||
|
|||||||
6.80% Notes, due 2038 (US$900) | 1 186 | 1 249 | |||||
|
|||||||
6.85% Notes, due 2039 (US$750) | 969 | 1 021 | |||||
|
|||||||
6.00% Notes, due 2042 (US$152)(4) | 150 | 158 | |||||
|
|||||||
4.34% Series 5 Medium Term Notes, due 2046 | 300 | 300 | |||||
|
|||||||
4.00% Notes, due 2047 (US$750) | 967 | 1 018 | |||||
|
|||||||
Total unsecured long-term debt | 12 927 | 12 900 | |||||
|
|||||||
Finance leases(6)(7) |
|
|
|
1 260 |
|
|
|
|
|||||||
Lease liabilities(8) (note 5) | 2 931 | | |||||
|
|||||||
Deferred financing costs | (43 | ) | (41 | ) | |||
|
|||||||
15 815 | 14 119 | ||||||
|
|||||||
Current portion of long-term debt and lease liabilities |
|
|
|
|
|
|
|
|
|||||||
Finance leases(6) | | (38 | ) | ||||
|
|||||||
Lease liabilities (note 5) | (310 | ) | | ||||
|
|||||||
Long-term debt | | (191 | ) | ||||
|
|||||||
(310 | ) | (229 | ) | ||||
|
|||||||
Total long-term lease liabilities | 2 621 | | |||||
|
|||||||
Total long-term debt | 12 884 | 13 890 | |||||
|
2019 ANNUAL REPORT Suncor Energy Inc. 115
In 2019, the company re-paid its US$140 million (book value of $188 million) senior unsecured notes at maturity, with a coupon of 7.75%, for US$145 million ($195 million), including US$5 million ($7 million) of accrued interest.
In 2019, the company issued $750 million of senior unsecured Series 6 Medium Term Notes maturing on May 24, 2029. The Series 6 Medium Term Notes have a coupon of 3.10% and were priced at $99.761 per $100 principal amount for an effective yield of 3.128%. Interest is paid semi-annually.
In 2018, the company completed an early retirement of US$83 million (book value of $109 million) of subsidiary debt acquired through the acquisition of COS with a coupon of 7.75% originally scheduled to mature on May 15, 2019 for US$88 million ($116 million). The early retirement payment included US$3 million ($4 million) of accrued interest, resulting in a debt extinguishment loss of $3 million ($2 million after-tax).
Scheduled Debt Repayments
Scheduled principal repayments as at December 31, 2019 for lease liabilities, short-term debt and long-term debt are as follows:
($ millions) | Repayment | ||
|
|||
2020 | 2 457 | ||
|
|||
2021 | 1 699 | ||
|
|||
2022 | 451 | ||
|
|||
2023 | 175 | ||
|
|||
2024 | 1 139 | ||
|
|||
Thereafter | 12 132 | ||
|
|||
18 053 | |||
|
Credit Facilities
A summary of available and unutilized credit facilities is as follows:
($ millions) | 2019 | |||
|
||||
Fully revolving and expires in 2023 | 3 500 | |||
|
||||
Fully revolving and expires in 2022 | 3 241 | |||
|
||||
Fully revolving and expires in 2021 | 1 455 | |||
|
||||
Can be terminated at any time at the option of the lenders | 132 | |||
|
||||
Total credit facilities | 8 328 | |||
|
||||
Credit facilities supporting outstanding commercial paper | (2 155 | ) | ||
|
||||
Credit facilities supporting standby letters of credit(1) | (1 284 | ) | ||
|
||||
Total unutilized credit facilities(2) | 4 889 | |||
|
116 2019 ANNUAL REPORT Suncor Energy Inc.
21. OTHER LONG-TERM LIABILITIES
($ millions) |
December 31
2019 |
December 31
2018 |
|||
|
|||||
Pensions and other post-retirement benefits (note 22) | 1 577 | 1 420 | |||
|
|||||
Share-based compensation plans (note 25) | 289 | 259 | |||
|
|||||
Partnership liability(1) | 446 | 470 | |||
|
|||||
Deferred revenue | 40 | 46 | |||
|
|||||
Libya Exploration and Production Sharing Agreement (EPSA) signature bonus(2) | 79 | 83 | |||
|
|||||
Other | 68 | 68 | |||
|
|||||
2 499 | 2 346 | ||||
|
22. PENSIONS AND OTHER POST-RETIREMENT BENEFITS
The company's defined benefit pension plans provide pension benefits at retirement based on years of service and final average earnings (if applicable). These obligations are met through funded registered retirement plans and through unregistered supplementary pensions that are funded through retirement compensation arrangements, and/or paid directly to recipients. The company's contributions to the funded plans are deposited with independent trustees who act as custodians of the plans' assets, as well as the disbursing agents of the benefits to recipients. Plan assets are managed by a pension committee on behalf of beneficiaries. The committee retains independent managers and advisors.
Asset-liability matching studies are performed by a third-party consultant to set the asset mix by quantifying the risk-and-return characteristics of possible asset mix strategies. Investment and contribution policies are integrated within this study, and areas of focus include asset mix as well as interest rate sensitivity.
Funding of the registered retirement plans complies with applicable regulations that require actuarial valuations of the pension funds at least once every three years in Canada and the U.K., and every year in the United States and Germany. The most recent valuations for the registered Canadian plans and U.K. were performed as at December 31, 2019. The company uses a measurement date of December 31 to value the plan assets and remeasure the accrued benefit obligation for accounting purposes.
The company's other post-retirement benefits programs are unfunded and include certain health care and life insurance benefits provided to retired employees and eligible surviving dependants.
The company reports its share of Syncrude's defined benefit and defined contribution pension plans and Syncrude's other post-retirement benefits plan.
The company also provides a number of defined contribution plans, including a U.S. 401(k) savings plan, that provide for an annual contribution of 5% to 11.5% of each participating employee's pensionable earnings.
2019 ANNUAL REPORT Suncor Energy Inc. 117
Defined Benefit Obligations and Funded Status
Pension Benefits
|
Other
Post-Retirement Benefits |
|||||||||||
($ millions) | 2019 | 2018 | 2019 | 2018 | ||||||||
|
||||||||||||
Change in benefit obligation | ||||||||||||
|
||||||||||||
Benefit obligation at beginning of year | 6 730 | 6 717 | 557 | 597 | ||||||||
|
||||||||||||
Obligations acquired through acquisition (note 32) | | 185 | | 8 | ||||||||
|
||||||||||||
Current service costs | 220 | 235 | 13 | 13 | ||||||||
|
||||||||||||
Plan participants' contributions | 16 | 15 | | | ||||||||
|
||||||||||||
Benefits paid | (293 | ) | (296 | ) | (24 | ) | (23 | ) | ||||
|
||||||||||||
Interest costs | 255 | 236 | 22 | 21 | ||||||||
|
||||||||||||
Foreign exchange | (13 | ) | 14 | (1 | ) | 1 | ||||||
|
||||||||||||
Settlements | 5 | 5 | | | ||||||||
|
||||||||||||
Actuarial remeasurement: | ||||||||||||
|
||||||||||||
Experience gain arising on plan liabilities | (11 | ) | (26 | ) | (2 | ) | (18 | ) | ||||
|
||||||||||||
Actuarial gain arising from changes in demographic assumptions | | (1 | ) | | | |||||||
|
||||||||||||
Actuarial loss (gain) arising from changes in financial assumptions | 799 | (354 | ) | 66 | (42 | ) | ||||||
|
||||||||||||
Benefit obligation at end of year | 7 708 | 6 730 | 631 | 557 | ||||||||
|
||||||||||||
Change in plan assets |
|
|
|
|
|
|
|
|
|
|
||
|
||||||||||||
Fair value of plan assets at beginning of year | 5 795 | 5 799 | | | ||||||||
|
||||||||||||
Assets acquired through acquisition (note 32) | | 153 | | | ||||||||
|
||||||||||||
Employer contributions | 157 | 182 | | | ||||||||
|
||||||||||||
Plan participants' contributions | 16 | 15 | | | ||||||||
|
||||||||||||
Benefits paid | (269 | ) | (273 | ) | | | ||||||
|
||||||||||||
Foreign exchange | (8 | ) | 14 | | | |||||||
|
||||||||||||
Settlements | 5 | 5 | | | ||||||||
|
||||||||||||
Administrative costs | (2 | ) | (2 | ) | | | ||||||
|
||||||||||||
Income on plan assets | 218 | 201 | | | ||||||||
|
||||||||||||
Actuarial remeasurement: | ||||||||||||
|
||||||||||||
Return on plan assets greater than (less than) discount rate | 781 | (299 | ) | | | |||||||
|
||||||||||||
Fair value of plan assets at end of year | 6 693 | 5 795 | | | ||||||||
|
||||||||||||
Net unfunded obligation | 1 015 | 935 | 631 | 557 | ||||||||
|
Of the total net unfunded obligations as at December 31, 2019, 97% relates to Canadian pension plans and other post-retirement benefits obligation (December 31, 2018 98%). The weighted average duration of the defined benefit obligation under the Canadian pension plans and other post-retirement plans is 14.60 years (2018 14.75 years).
118 2019 ANNUAL REPORT Suncor Energy Inc.
The net unfunded obligation is recorded in Accounts Payable and Accrued Liabilities and Other Long-Term Liabilities (note 21) in the Consolidated Balance Sheets.
Pension Benefits |
Other
Post-Retirement Benefits |
|||||||||
($ millions) | 2019 | 2018 | 2019 | 2018 | ||||||
|
||||||||||
Analysis of amount charged to earnings: | ||||||||||
|
||||||||||
Current service costs | 220 | 235 | 13 | 13 | ||||||
|
||||||||||
Interest costs | 37 | 35 | 22 | 21 | ||||||
|
||||||||||
Defined benefit plans expense | 257 | 270 | 35 | 34 | ||||||
|
||||||||||
Defined contribution plans expense | 82 | 77 | | | ||||||
|
||||||||||
Total benefit plans expense charged to earnings | 339 | 347 | 35 | 34 | ||||||
|
Components of defined benefit costs recognized in Other Comprehensive Income:
Actuarial Assumptions
The cost of the defined benefit pension plans and other post-retirement benefits received by employees is actuarially determined using the projected unit credit method of valuation that includes employee service to date and present pay levels, as well as the projection of salaries and service to retirement.
The significant weighted average actuarial assumptions were as follows:
Pension Benefits
|
Other
Post-Retirement Benefits |
||||||||
(%) |
December 31
2019 |
December 31
2018 |
December 31
2019 |
December 31
2018 |
|||||
|
|||||||||
Discount rate | 3.10 | 3.80 | 3.10 | 3.90 | |||||
|
|||||||||
Rate of compensation increase | 3.00 | 3.00 | 3.00 | 3.00 | |||||
|
The discount rate assumption is based on the interest rate on high-quality bonds with maturity terms equivalent to the benefit obligations.
The defined benefit obligation reflects the best estimate of the mortality of plan participants both during and after their employment. The mortality assumption is based on a standard mortality table adjusted for actual experience over the past five years.
In order to measure the expected cost of other post-retirement benefits, it was assumed for 2019 that the health care costs would increase annually by 6.50% per person (2018 6.50%). From 2020, this rate will decrease 0.5% annually to 5% by 2022, and remain at that level thereafter.
2019 ANNUAL REPORT Suncor Energy Inc. 119
Assumed discount rates and health care cost trend rates may have a significant effect on the amounts reported for pensions and other post-retirement benefits obligations for the company's Canadian plans. A change of these assumptions would have the following effects:
Pension Benefits
|
||||||
($ millions) | Increase | Decrease | ||||
|
||||||
1% change in discount rate | ||||||
|
||||||
Effect on the aggregate service and interest costs | (25 | ) | 31 | |||
|
||||||
Effect on the benefit obligations | (988 | ) | 1 271 | |||
|
Plan Assets and Investment Objectives
The company's long-term investment objective is to secure the defined pension benefits while managing the variability and level of its contributions. The portfolio is rebalanced periodically, as required, to the plans' target asset allocation as prescribed in the Statement of Investment Policies and Procedures approved by the Board of Directors. Plan assets are restricted to those permitted by legislation, where applicable. Investments are made through pooled, mutual, segregated or exchange traded funds.
The company's weighted average pension plan asset allocations, based on market values as at December 31, are as follows:
(%) | 2019 | 2018 | ||||
|
||||||
Equities, comprised of: | ||||||
|
||||||
Canada | 12 | 13 | ||||
|
||||||
United States | 19 | 17 | ||||
|
||||||
Foreign | 19 | 18 | ||||
|
||||||
50 | 48 | |||||
|
||||||
Fixed income, comprised of: | ||||||
|
||||||
Canada | 41 | 43 | ||||
|
||||||
Real estate, comprised of: | ||||||
|
||||||
Canada | 9 | 9 | ||||
|
||||||
Total | 100 | 100 | ||||
|
Equity securities do not include any direct investments in Suncor shares. The fair value of equity and fixed income securities is based on the trading price of the underlying fund. The fair value of real estate investments is based on independent third-party appraisals.
During the year, the company made cash contributions of $157 million (2018 $182 million) to its defined benefit pension plans, of which $2 million (2018 $2 million) was contributed to the solvency reserve account in Alberta. The company expects to make cash contributions to its defined benefit pension plans in 2020 of $176 million.
120 2019 ANNUAL REPORT Suncor Energy Inc.
($ millions) |
Decommissioning
and Restoration(1) |
Royalties | Other(2) | Total | ||||||
|
||||||||||
At December 31, 2017 | 7 465 | 240 | 254 | 7 959 | ||||||
|
||||||||||
Liabilities incurred | 345 | 9 | 101 | 455 | ||||||
|
||||||||||
Change in discount rate | (663 | ) | | | (663 | ) | ||||
|
||||||||||
Changes in estimates | 114 | (67 | ) | (16 | ) | 31 | ||||
|
||||||||||
Liabilities settled | (469 | ) | (84 | ) | (25 | ) | (578 | ) | ||
|
||||||||||
Accretion | 266 | | | 266 | ||||||
|
||||||||||
Asset acquisitions | 133 | | | 133 | ||||||
|
||||||||||
Foreign exchange | 48 | | | 48 | ||||||
|
||||||||||
At December 31, 2018 | 7 239 | 98 | 314 | 7 651 | ||||||
|
||||||||||
Less: current portion | (538 | ) | (98 | ) | (31 | ) | (667 | ) | ||
|
||||||||||
6 701 | | 283 | 6 984 | |||||||
|
||||||||||
At December 31, 2018 | 7 239 | 98 | 314 | 7 651 | ||||||
|
||||||||||
Adoption of IFRS 16 impact (note 5) | | | (21 | ) | (21 | ) | ||||
|
||||||||||
At January 1, 2019, adjusted | 7 239 | 98 | 293 | 7 630 | ||||||
|
||||||||||
Liabilities incurred | 346 | 60 | (4 | ) | 402 | |||||
|
||||||||||
Change in discount rate | 1 344 | | | 1 344 | ||||||
|
||||||||||
Changes in estimates | 193 | (25 | ) | 1 | 169 | |||||
|
||||||||||
Liabilities settled | (464 | ) | | (14 | ) | (478 | ) | |||
|
||||||||||
Accretion | 270 | | | 270 | ||||||
|
||||||||||
Asset disposals | (1 | ) | | | (1 | ) | ||||
|
||||||||||
Foreign exchange | (29 | ) | | | (29 | ) | ||||
|
||||||||||
At December 31, 2019 | 8 898 | 133 | 276 | 9 307 | ||||||
|
||||||||||
Less: current portion | (475 | ) | (133 | ) | (23 | ) | (631 | ) | ||
|
||||||||||
8 423 | | 253 | 8 676 | |||||||
|
Sensitivities
Changes to the discount rate would have the following impact on Decommissioning and Restoration liabilities:
As at December 31 | 2019 | 2018 | ||||
|
||||||
1% Increase | (1 629 | ) | (1 099 | ) | ||
|
||||||
1% Decrease | 2 365 | 1 521 | ||||
|
2019 ANNUAL REPORT Suncor Energy Inc. 121
Authorized
Common Shares
The company is authorized to issue an unlimited number of common shares without nominal or par value.
Preferred Shares
The company is authorized to issue an unlimited number of senior and junior preferred shares in series, without nominal or par value.
Normal Course Issuer Bid
On May 1, 2018, the company announced its intent to continue its normal course issuer bid program (the 2018 NCIB) to repurchase common shares through the facilities of the Toronto Stock Exchange (the TSX), New York Stock Exchange (the NYSE) and/or alternative trading platforms. Pursuant to the 2018 NCIB, the company was permitted to purchase for cancellation up to 52,285,330 of its common shares between May 4, 2018 and May 3, 2019. On November 14, 2018, Suncor announced an amendment to the 2018 NCIB, effective as of November 19, 2018, which increased the maximum number of aggregate common shares that it was permitted to repurchase for cancellation between May 4, 2018 and May 3, 2019 to 81,695,830.
On May 1, 2019, the company announced its intention to renew its existing normal course issuer bid program (the 2019 NCIB) to continue to repurchase shares under its previously announced buyback program through the facilities of the TSX, NYSE and/or alternative trading platforms. Pursuant to the 2019 NCIB, the company is permitted to purchase for cancellation up to 50,252,231 of its common shares between May 6, 2019 and May 5, 2020. On December 23, 2019, Suncor announced an amendment to the 2019 NCIB, effective as of December 30, 2019, which allows the company to increase the maximum number of aggregate common shares that may be repurchased between May 6, 2019 and May 5, 2020 to 78,549,178. Subsequent to the year end, the Board of Directors approved a further share repurchase program of up to $2.0 billion beginning on March 1, 2020.
The following table summarizes the share repurchase activities during the period:
Under an automatic repurchase plan agreement with an independent broker, the company has recorded the following liability for share repurchases that may take place during its internal blackout period:
($ millions) |
December 31
2019 |
December 31
2018 |
||||
|
||||||
Amounts charged to | ||||||
|
||||||
Share capital | 65 | 111 | ||||
|
||||||
Retained earnings | 103 | 152 | ||||
|
||||||
Liability for share purchase commitment | 168 | 263 | ||||
|
122 2019 ANNUAL REPORT Suncor Energy Inc.
Share-Based Compensation Expense
Reflected in the Consolidated Statements of Comprehensive Income within Operating, Selling and General expense are the following share-based compensation amounts:
($ millions) | 2019 | 2018 | |||
|
|||||
Equity-settled plans | 50 | 46 | |||
|
|||||
Cash-settled plans | 274 | 181 | |||
|
|||||
Total share-based compensation expense | 324 | 227 | |||
|
Liability Recognized for Share-Based Compensation
Reflected in the Consolidated Balance Sheets within accounts payable and accrued liabilities and other long-term liabilities are the following fair value amounts for the company's cash-settled plans:
($ millions) | 2019 | 2018 | |||
|
|||||
Current liability | 242 | 286 | |||
|
|||||
Long-term liability (note 21) | 289 | 259 | |||
|
|||||
Total Liability | 531 | 545 | |||
|
The intrinsic value of the vested awards at December 31, 2019 was $300 million (December 31, 2018 $328 million).
Stock Option Plans
Suncor grants stock option awards as a form of retention and incentive compensation.
(a) Active Stock Option Plan
Stock options granted by the company on or after August 1, 2010 provide the holder with the right to purchase common shares at the market price on the grant date, subject to fulfilling vesting terms. This plan replaced the pre-merger stock option plan of legacy Suncor and legacy Petro-Canada. Options granted have a seven-year life, vest annually over a three-year period and are accounted for as equity-settled awards.
The weighted average fair value of options granted during the period and the weighted average assumptions used in their determination are as noted below:
2019 | 2018 | ||||
|
|||||
Annual dividend per share (dollars) | 1.68 | 1.44 | |||
|
|||||
Risk-free interest rate | 1.78% | 2.03% | |||
|
|||||
Expected life | 5 years | 5 years | |||
|
|||||
Expected volatility | 26% | 24% | |||
|
|||||
Weighted average fair value per option (dollars) | 6.61 | 6.73 | |||
|
The expected life is based on historical stock option exercise data and current expectations. The expected volatility considers the historical volatility in the price of Suncor's common shares over a period similar to the life of the options, and is indicative of future trends.
(b) Discontinued Stock Option Plans
Executive and Key Contributor Stock Options
Options granted under these plans generally have a seven- to ten-year life and vest over a three-year period. These plans were in place prior to August 1, 2009, at the time of the merger between Petro-Canada and Suncor, and are accounted for as equity-settled awards.
2019 ANNUAL REPORT Suncor Energy Inc. 123
The following table presents a summary of the activity related to Suncor's stock option plans:
2019 | 2018 | ||||||||
|
|
||||||||
Number
(thousands) |
Weighted
Average Exercise Price ($) |
Number
(thousands) |
Weighted
Average Exercise Price ($) |
||||||
|
|||||||||
Outstanding, beginning of year | 28 935 | 38.25 | 31 110 | 36.96 | |||||
|
|||||||||
Granted | 7 756 | 42.96 | 7 231 | 43.19 | |||||
|
|||||||||
Exercised as options for common shares | (2 688 | ) | 33.37 | (7 927 | ) | 35.95 | |||
|
|||||||||
Forfeited/expired | (121 | ) | 42.57 | (1 479 | ) | 47.88 | |||
|
|||||||||
Outstanding, end of year | 33 882 | 39.70 | 28 935 | 38.25 | |||||
|
|||||||||
Exercisable, end of year | 21 535 | 37.86 | 15 374 | 36.10 | |||||
|
Options are exercised regularly throughout the year. Therefore, the weighted average share price during the year of $40.82 (2018 $46.99) is representative of the weighted average share price at the date of exercise.
For the options outstanding at December 31, 2019, the exercise price ranges and weighted average remaining contractual lives are shown below:
Common shares authorized for issuance by the Board of Directors that remain available for the granting of future options:
(thousands) | 2019 | 2018 | |||
|
|||||
14 295 | 21 929 | ||||
|
Share Unit Plans
Suncor grants share units as a form of retention and incentive compensation. Share unit plans are accounted for as cash-settled awards.
(a) Performance Share Units (PSUs)
A PSU is a time-vested award entitling employees to receive varying degrees of cash (0% 200% of the company's share price at time of vesting) contingent upon Suncor's total shareholder return (stock price appreciation and dividend income) relative to a peer group of companies. Cash payments for awards granted in 2019 and onwards are contingent upon Suncor's total shareholder return and annual return on capital employed performance. PSUs vest approximately three years after the grant date.
(b) Restricted Share Units (RSUs)
A RSU is a time-vested award entitling employees to receive cash calculated based on an average of the company's share price leading up to vesting. RSUs vest approximately three years after the grant date.
124 2019 ANNUAL REPORT Suncor Energy Inc.
(c) Deferred Share Units (DSUs)
A DSU is redeemable for cash or a common share for a period of time after a unitholder ceases employment or Board membership. The DSU Plan is limited to executives and members of the Board of Directors. Members of the Board of Directors receive an annual grant of DSUs as part of their compensation and may elect to receive their fees in cash only or in increments of 50% or 100% allocated to DSUs. Executives may elect to receive their annual incentive bonus in cash only or in increments of 25%, 50%, 75% or 100% allocated to DSUs.
The following table presents a summary of the activity related to Suncor's share unit plans:
(thousands) | PSU | RSU | DSU | ||||||
|
|||||||||
Outstanding, December 31, 2017 | 2 267 | 16 072 | 1 302 | ||||||
|
|||||||||
Granted | 1 553 | 4 796 | 192 | ||||||
|
|||||||||
Redeemed for cash | (1 623 | ) | (5 962 | ) | (189 | ) | |||
|
|||||||||
Forfeited/expired | | (314 | ) | | |||||
|
|||||||||
Outstanding, December 31, 2018 | 2 197 | 14 592 | 1 305 | ||||||
|
|||||||||
Granted | 1 212 | 4 861 | 200 | ||||||
|
|||||||||
Redeemed for cash | (1 210 | ) | (5 577 | ) | (217 | ) | |||
|
|||||||||
Forfeited/expired | (6 | ) | (274 | ) | (1 | ) | |||
|
|||||||||
Outstanding, December 31, 2019 | 2 193 | 13 602 | 1 287 | ||||||
|
Stock Appreciation Rights (SARs)
A SAR entitles the holder to receive a cash payment equal to the difference between the stated exercise price and the market price of the company's common shares on the date the SAR is exercised, and is accounted for as a cash-settled award.
SARs have a seven-year life and vest annually over a three-year period.
The following table presents a summary of the activity related to Suncor's SARs plan:
2019 ANNUAL REPORT Suncor Energy Inc. 125
26. FINANCIAL INSTRUMENTS AND RISK MANAGEMENT
The company's financial instruments consist of cash and cash equivalents, accounts receivable, derivative contracts, substantially all accounts payable and accrued liabilities, debt, and certain portions of other assets and other long-term liabilities.
Non-Derivative Financial Instruments
The fair values of cash and cash equivalents, accounts receivable, short-term debt, and accounts payable and accrued liabilities approximate their carrying values due to the short-term maturities of those instruments.
The company's long-term debt and long-term financial liabilities are recorded at amortized cost using the effective interest method. At December 31, 2019, the carrying value of fixed-term debt accounted for under amortized cost was $12.9 billion (December 31, 2018 $12.9 billion) and the fair value at December 31, 2019 was $16.1 billion (December 31, 2018 $14.2 billion). The increase in fair value of debt is mainly due to the decline in interest rates during the year. The estimated fair value of long-term debt is based on pricing sourced from market data, which is considered a Level 2 fair value input.
Suncor entered into a partnership with Fort McKay First Nation (FMFN) and Mikisew Cree First Nation (MCFN) in 2018 where FMFN and MCFN acquired a combined 49% partnership interest in the East Tank Farm Development. The partnership liability is recorded at amortized cost using the effective interest method. At December 31, 2019, the carrying value of the Partnership liability accounted for under amortized cost was $455 million (December 31, 2018 $477 million).
Derivative Financial Instruments
(a) Non-Designated Derivative Financial Instruments
The company uses derivative financial instruments, such as physical and financial contracts, to manage certain exposures to fluctuations in interest rates, commodity prices and foreign currency exchange rates, as part of its overall risk management program, as well as for trading purposes.
The changes in the fair value of non-designated derivatives are as follows:
($ millions) | 2019 | 2018 | |||||
|
|||||||
Fair value outstanding, beginning of year | 60 | (105 | ) | ||||
|
|||||||
Cash Settlements received during the year | (254 | ) | (90 | ) | |||
|
|||||||
Changes in fair value recognized in earnings during the year (note 7) | 155 | 255 | |||||
|
|||||||
Fair value outstanding, end of year | (39 | ) | 60 | ||||
|
(b) Fair Value Hierarchy
To estimate the fair value of derivatives, the company uses quoted market prices when available, or third-party models and valuation methodologies that utilize observable market data. In addition to market information, the company incorporates transaction-specific details that market participants would utilize in a fair value measurement, including the impact of non-performance risk. However, these fair value estimates may not necessarily be indicative of the amounts that could be realized or settled in a current market transaction. The company characterizes inputs used in determining fair value using a hierarchy that prioritizes inputs depending on the degree to which they are observable. The three levels of the fair value hierarchy are as follows:
126 2019 ANNUAL REPORT Suncor Energy Inc.
In forming estimates, the company utilizes the most observable inputs available for valuation purposes. If a fair value measurement reflects inputs of different levels within the hierarchy, the measurement is categorized based upon the lowest level of input that is significant to the fair value measurement.
The following table presents the company's derivative financial instrument assets and liabilities and assets available for sale measured at fair value for each hierarchy level as at December 31, 2019 and 2018.
($ millions) | Level 1 | Level 2 | Level 3 |
Total Fair
Value |
|||||||
|
|||||||||||
Accounts receivable | 63 | 152 | | 215 | |||||||
|
|||||||||||
Accounts payable | (43 | ) | (112 | ) | | (155 | ) | ||||
|
|||||||||||
Balance at December 31, 2018 | 20 | 40 | | 60 | |||||||
|
|||||||||||
Accounts receivable | 33 | 61 | | 94 | |||||||
|
|||||||||||
Accounts payable | (66 | ) | (67 | ) | | (133 | ) | ||||
|
|||||||||||
Balance at December 31, 2019 | (33 | ) | (6 | ) | | (39 | ) | ||||
|
During the year ended December 31, 2019, there were no transfers between Level 1 and Level 2 fair value measurements.
Offsetting Financial Assets and Liabilities
The company enters into arrangements that allow for offsetting of derivative financial instruments and accounts receivable (payable), which are presented on a net basis on the balance sheet, as shown in the table below as at December 31, 2019 and 2018.
Financial Assets
($ millions) |
Gross
Assets |
Gross
Liabilities Offset |
Net
Amounts Presented |
||||
|
|||||||
Fair value of derivative assets | 1 599 | (1 384 | ) | 215 | |||
|
|||||||
Accounts receivable | 1 837 | (882 | ) | 955 | |||
|
|||||||
Balance at December 31, 2018 | 3 436 | (2 266 | ) | 1 170 | |||
|
|||||||
Fair value of derivative assets | 1 737 | (1 643 | ) | 94 | |||
|
|||||||
Accounts receivable | 2 860 | (1 289 | ) | 1 571 | |||
|
|||||||
Balance at December 31, 2019 | 4 597 | (2 932 | ) | 1 665 | |||
|
Financial Liabilities
($ millions) |
Gross
Liabilities |
Gross
Assets Offset |
Net
Amounts Presented |
|||||
|
||||||||
Fair value of derivative liabilities | (1 539 | ) | 1 384 | (155 | ) | |||
|
||||||||
Accounts payable | (1 798 | ) | 882 | (916 | ) | |||
|
||||||||
Balance at December 31, 2018 | (3 337 | ) | 2 266 | (1 071 | ) | |||
|
||||||||
Fair value of derivative liabilities | (1 776 | ) | 1 643 | (133 | ) | |||
|
||||||||
Accounts payable | (2 532 | ) | 1 289 | (1 243 | ) | |||
|
||||||||
Balance at December 31, 2019 | (4 308 | ) | 2 932 | (1 376 | ) | |||
|
Risk Management
The company is exposed to a number of different risks arising from financial instruments. These risk factors include market risks, comprising commodity price risk, foreign currency risk and interest rate risk, as well as liquidity risk and credit risk.
The company maintains a formal governance process to manage its financial risks. The company's Commodity Risk Management Committee (CRMC) is charged with the oversight of the company's trading and credit risk management activities. These activities are intended to manage risk associated with open price exposure of specific volumes in transit or storage, enhance the company's operations, and enhance profitability through informed market calls, market diversification, economies of scale, improved transportation access, and leverage of assets, both physical and contractual. The CRMC, acting
2019 ANNUAL REPORT Suncor Energy Inc. 127
under the authority of the company's Board of Directors, meets regularly to monitor limits on risk exposures, review policy compliance and validate risk-related methodologies and procedures.
The nature of the risks faced by the company and its policies for managing such risks remain unchanged from December 31, 2018.
1) Market Risk
Market risk is the risk or uncertainty arising from market price movements and their impact on the future performance of the business. The market price movements that could adversely affect the value of the company's financial assets, liabilities and expected future cash flows include commodity price risk, foreign currency exchange risk and interest rate risk.
(a) Commodity Price Risk
Suncor's financial performance is closely linked to crude oil prices (including pricing differentials for various product types) and, to a lesser extent, natural gas and refined product prices. The company may reduce its exposure to commodity price risk through a number of strategies. These strategies include entering into derivative contracts to limit exposure to changes in crude oil prices during transportation.
An increase of US$10/bbl of crude oil as at December 31, 2019 would decrease pre-tax earnings for the company's outstanding derivative financial instruments by approximately $46 million (2018 $39 million).
(b) Foreign Currency Exchange Risk
The company is exposed to foreign currency exchange risk on revenues, capital expenditures, or financial instruments that are denominated in a currency other than the company's functional currency (Canadian dollars). As crude oil is priced in U.S. dollars, fluctuations in US$/Cdn$ exchange rates may have a significant impact on revenues. This exposure is partially offset through the issuance of U.S. dollar denominated debt. A 1% strengthening in the Cdn$ relative to the US$ as at December 31, 2019 would increase pre-tax earnings related to the company's debt by approximately $146 million (2018 $167 million).
(c) Interest Rate Risk
The company is exposed to interest rate risk as changes in interest rates may affect future cash flows and the fair values of its financial instruments. The primary exposure is related to its revolving-term debt of commercial paper and future debt issuances.
To manage the company's exposure to interest rate volatility, the company may periodically enter into interest rate swap contracts to fix the interest rate of future debt issuances. As at December 31, 2019, the company had no outstanding forward starting swaps. The weighted average interest rate on total debt, including lease liabilities, for the year ended December 31, 2019 was 5.6% (2018 5.4%).
The company's net earnings are sensitive to changes in interest rates on the floating rate portion of the company's debt, which are offset by cash balances. To the extent interest expense is not capitalized, if interest rates applicable to floating rate instruments increased by 1%, it is estimated that the company's pre-tax earnings would decrease by approximately $2 million (2018 approximately $10 million). This assumes that the amount and mix of fixed and floating rate debt remains unchanged from December 31, 2019. The proportion of floating interest rate exposure at December 31, 2019 was 12.0% of total debt outstanding (2018 18.6%).
2) Liquidity Risk
Liquidity risk is the risk that Suncor will not be able to meet its financial obligations when due. The company mitigates this risk by forecasting spending requirements as well as cash flow from operating activities, and maintaining sufficient cash, credit facilities, and debt shelf prospectuses to meet these requirements. Suncor's cash and cash equivalents and total credit facilities at December 31, 2019 were $2.0 billion and $8.3 billion, respectively. Of Suncor's $8.3 billion in total credit facilities, $4.9 billion were available at December 31, 2019. In addition, Suncor has $2.25 billion of unused capacity under a Canadian debt shelf prospectus and an unused capacity of US$3.0 billion under a U.S. debt shelf prospectus. The ability of the company to raise additional capital utilizing these shelf prospectuses is dependent on market conditions. The company believes it has sufficient funding through the use of these facilities and access to capital markets to meet its future capital requirements.
Surplus cash is invested into a range of short-dated money market securities. Investments are only permitted in high credit quality government or corporate securities. Diversification of these investments is managed through counterparty credit limits.
128 2019 ANNUAL REPORT Suncor Energy Inc.
The following table shows the timing of cash outflows related to trade and other payables and debt.
December 31, 2018
|
|||||||
|
|||||||
($ millions) |
Trade and
Other Payables(1) |
Gross
Derivative Liabilities(2) |
Debt(3) | ||||
|
|||||||
Within one year | 5 492 | 1 539 | 4 314 | ||||
|
|||||||
1 to 3 years | 42 | | 3 362 | ||||
|
|||||||
3 to 5 years | 42 | | 1 827 | ||||
|
|||||||
Over 5 years | | | 20 611 | ||||
|
|||||||
5 576 | 1 539 | 30 114 | |||||
|
3) Credit Risk
Credit risk is the risk that a customer or counterparty will fail to perform an obligation or fail to pay amounts due, causing a financial loss. The company's credit policy is designed to ensure there is a standard credit practice throughout the company to measure and monitor credit risk. The policy outlines delegation of authority, the due diligence process required to approve a new customer or counterparty and the maximum amount of credit exposure per single entity. Before transactions begin with a new customer or counterparty, its creditworthiness is assessed, a credit rating and a maximum credit limit are assigned. The assessment process is outlined in the credit policy and considers both quantitative and qualitative factors. The company constantly monitors the exposure to any single customer or counterparty along with the financial position of the customer or counterparty. If it is deemed that a customer or counterparty has become materially weaker, the company will work to reduce the credit exposure and lower the assigned credit limit. Regular reports are generated to monitor credit risk and the Credit Committee meets quarterly to ensure compliance with the credit policy and review the exposures.
A substantial portion of the company's accounts receivable are with customers in the oil and gas industry and are subject to normal industry credit risk. At December 31, 2019, substantially all of the company's trade receivables were current.
The company may be exposed to certain losses in the event that counterparties to derivative financial instruments are unable to meet the terms of the contracts. The company's exposure is limited to those counterparties holding derivative contracts owing to the company at the reporting date. At December 31, 2019, the company's exposure was $1 737 million (December 31, 2018 $1 599 million).
2019 ANNUAL REPORT Suncor Energy Inc. 129
27. CAPITAL STRUCTURE FINANCIAL POLICIES
The company's primary capital management strategy is to maintain a conservative balance sheet, which supports a solid investment grade credit rating profile. This objective affords the company the financial flexibility and access to the capital it requires to execute on its growth objectives.
The company's capital is primarily monitored by reviewing the ratios of net debt to funds from operations(1) and total debt to total debt plus shareholders' equity.
Net debt to funds from operations is calculated as short-term debt plus total long-term debt less cash and cash equivalents, divided by funds from operations for the year then ended.
Total debt to total debt plus shareholders' equity is calculated as short-term debt plus total long-term debt divided by short-term debt plus total long-term debt plus shareholders' equity. This financial covenant under the company's various banking and debt agreements shall not be greater than 65%.
The company's financial covenant is reviewed regularly and controls are in place to maintain compliance with the covenant. The company complied with financial covenants for the years ended December 31, 2019 and 2018. The company's financial measures, as set out in the following schedule, were unchanged from 2018. The company believes that achieving its capital target helps to provide the company access to capital at a reasonable cost by maintaining solid investment grade credit ratings. The company operates in a fluctuating business environment and ratios may periodically fall outside of management's targets. The company addresses these fluctuations by capital expenditure reductions and sales of non-core assets to ensure net debt achieves management's targets.
($ millions) |
Capital
Measure Target |
December 31,
2019 |
December 31,
2018 |
||||||
|
|||||||||
Components of ratios | |||||||||
|
|||||||||
Short-term debt | 2 155 | 3 231 | |||||||
|
|||||||||
Current portion of long-term debt | | 229 | |||||||
|
|||||||||
Current portion of long-term lease liabilities | 310 | | |||||||
|
|||||||||
Long-term debt | 12 884 | 13 890 | |||||||
|
|||||||||
Long-term lease liabilities | 2 621 | | |||||||
|
|||||||||
Total debt | 17 970 | 17 350 | |||||||
|
|||||||||
Less: Cash and cash equivalents | 1 960 | 2 221 | |||||||
|
|||||||||
Net debt | 16 010 | 15 129 | |||||||
|
|||||||||
Shareholders' equity | 42 042 | 44 005 | |||||||
|
|||||||||
Total capitalization (total debt plus shareholders' equity) | 60 012 | 61 355 | |||||||
|
|||||||||
Funds from operations(1) | 10 818 | 10 172 | |||||||
|
|||||||||
Net debt to funds from operations | <3.0 times | 1.5 | 1.5 | ||||||
|
|||||||||
Total debt to total debt plus shareholders' equity | 20% 35% | 30% | 28% | ||||||
|
130 2019 ANNUAL REPORT Suncor Energy Inc.
Joint Operations
The company's material joint operations as at December 31 are set out below:
Material Joint Operations | Principal Activity |
Country of
Incorporation and Principal Place of Business |
Ownership %
2019 |
Ownership %
2018 |
||||||
|
||||||||||
Oil Sands | ||||||||||
|
||||||||||
Operated by Suncor: | ||||||||||
|
||||||||||
Fort Hills Energy Limited Partnership | Oil sands development | Canada | 54.11 | 54.11 | ||||||
|
||||||||||
Meadow Creek | Oil sands development | Canada | 75.00 | 75.00 | ||||||
|
||||||||||
Non-operated: | ||||||||||
|
||||||||||
Syncrude | Oil sands development | Canada | 58.74 | 58.74 | ||||||
|
||||||||||
Exploration and Production | ||||||||||
|
||||||||||
Operated by Suncor: | ||||||||||
|
||||||||||
Terra Nova | Oil and gas production | Canada | 37.68 | 37.68 | ||||||
|
||||||||||
Non-operated: | ||||||||||
|
||||||||||
Buzzard | Oil and gas production | United Kingdom | 29.89 | 29.89 | ||||||
|
||||||||||
Fenja Development JV | Oil and gas production | Norway | 17.50 | 17.50 | ||||||
|
||||||||||
Golden Eagle Area Development | Oil and gas production | United Kingdom | 26.69 | 26.69 | ||||||
|
||||||||||
Hibernia and the Hibernia South Extension Unit | Oil and gas production | Canada | 19.19-20.00 | 19.19-20.00 | ||||||
|
||||||||||
Hebron | Oil and gas production | Canada | 21.03 | 21.03 | ||||||
|
||||||||||
Harouge Oil Operations | Oil and gas production | Libya | 49.00 | 49.00 | ||||||
|
||||||||||
North Sea Rosebank Project | Oil and gas production | United Kingdom | 40.00 | 40.00 | ||||||
|
||||||||||
Oda | Oil and gas production | Norway | 30.00 | 30.00 | ||||||
|
||||||||||
White Rose and the White Rose Extensions | Oil and gas production | Canada | 26.13-27.50 | 26.13-27.50 | ||||||
|
Joint Ventures and Associates
The company does not have any joint ventures or associates that are considered individually material. Summarized aggregate financial information of the joint ventures and associates, which are all included in the company's Exploration and Production and Refining and Marketing operations, are shown below:
Joint ventures | Associates | |||||||||
|
|
|||||||||
($ millions) | 2019 | 2018 | 2019 | 2018 | ||||||
|
||||||||||
Net (loss) earnings | (7 | ) | 11 | | (19 | ) | ||||
|
||||||||||
Other comprehensive income | | | | | ||||||
|
||||||||||
Total comprehensive (loss) income | (7 | ) | 11 | | (19 | ) | ||||
|
||||||||||
Carrying amount as at December 31 | 68 | 75 | 76 | 110 | ||||||
|
2019 ANNUAL REPORT Suncor Energy Inc. 131
Material subsidiaries, each of which is wholly owned, either directly or indirectly, by the company as at December 31, 2019 are shown below:
Material Subsidiaries | Principal Activity | ||
|
|||
Canadian Operations | |||
Suncor Energy Oil Sands Limited Partnership |
|
This partnership holds most of the company's Oil Sands operations assets. |
|
|
|||
Suncor Energy Ventures Corporation | A subsidiary which indirectly owns a 36.74% ownership in the Syncrude joint operation. | ||
|
|||
Suncor Energy Ventures Partnership | A subsidiary which owns a 22% ownership in the Syncrude joint operation. | ||
|
|||
Suncor Energy Products Partnership | This partnership holds substantially all of the company's Canadian refining and marketing assets. | ||
|
|||
Suncor Energy Marketing Inc. | Through this subsidiary, production from the upstream Canadian businesses is marketed. This subsidiary also administers Suncor's energy trading activities and power business, markets certain third-party products, procures crude oil feedstock and natural gas for its downstream business, and procures and markets natural gas liquids (NGLs) and liquefied petroleum gas (LPG) for its downstream business. | ||
|
|||
U.S. Operations | |||
Suncor Energy (U.S.A.) Marketing Inc. |
|
A subsidiary that procures, markets and trades crude oil, in addition to procuring crude oil feedstock for the company's refining operations. |
|
|
|||
Suncor Energy (U.S.A.) Inc. | A subsidiary through which the company's U.S. refining and marketing operations are conducted. | ||
|
|||
International Operations | |||
Suncor Energy UK Limited |
|
A subsidiary through which the majority of the company's North Sea operations are conducted. |
|
|
The table does not include wholly owned subsidiaries that are immediate holding companies of the operating subsidiaries. For certain foreign operations of the company, there are restrictions on the sale or transfer of production licences, which would require approval of the applicable foreign government.
132 2019 ANNUAL REPORT Suncor Energy Inc.
Related Party Transactions
The company enters into transactions with related parties in the normal course of business, which includes purchases of feedstock, distribution of refined products, and sale of refined products and byproducts. These transactions are with joint ventures and associated entities in the company's Refining and Marketing operations, including pipeline, refined product and petrochemical companies. A summary of the significant related party transactions as at and for the year ended December 31, 2019 and 2018 are as follows:
($ millions) | 2019 | 2018 | |||
|
|||||
Sales(1) | 676 | 723 | |||
|
|||||
Purchases | 215 | 237 | |||
|
|||||
Accounts receivable | 38 | 33 | |||
|
|||||
Accounts payable and accrued liabilities | 19 | 15 | |||
|
Compensation of Key Management Personnel
Compensation of the company's Board of Directors and members of the Executive Leadership Team for the years ended December 31 is as follows:
($ millions) | 2019 | 2018 | |||
|
|||||
Salaries and other short-term benefits | 14 | 15 | |||
|
|||||
Pension and other post-retirement benefits | 3 | 5 | |||
|
|||||
Share-based compensation | 47 | 32 | |||
|
|||||
64 | 52 | ||||
|
31. COMMITMENTS, CONTINGENCIES AND GUARANTEES
(a) Commitments
Future payments under the company's commitments, including service arrangements for pipeline transportation agreements and for other property and equipment, are as follows:
The company has also entered into a pipeline commitment of $5.9 billion with a contract term of 20 years, which is awaiting regulatory approval.
In addition to the commitments in the above table, the company has other obligations for goods and services and raw materials entered into in the normal course of business, which may terminate on short notice. Such obligations include commodity purchase obligations which are transacted at market prices.
2019 ANNUAL REPORT Suncor Energy Inc. 133
(b) Contingencies
Legal and Environmental Contingent Liabilities
The company is defendant and plaintiff in a number of legal actions that arise in the normal course of business. The company believes that any liabilities that might arise pertaining to such matters would not have a material effect on its consolidated financial position.
The company may also have environmental contingent liabilities, beyond decommissioning and restoration liabilities (recognized in note 23), which are reviewed individually and are reflected in the company's consolidated financial statements if material and more likely than not to be incurred. These contingent environmental liabilities primarily relate to the mitigation of contamination at sites where the company has had operations. For any unrecognized environmental contingencies, the company believes that any liabilities that might arise pertaining to such matters would not have a material effect on its consolidated financial position.
Costs attributable to these commitments and contingencies are expected to be incurred over an extended period of time and to be funded from the company's cash flow from operating activities. Although the ultimate impact of these matters on net earnings cannot be determined at this time, the impact is not expected to be material.
(c) Guarantees
At December 31, 2019, the company has provided loan guarantees to certain retail licensees and wholesale marketers. Suncor's maximum potential amount payable under these loan guarantees is $125 million.
The company has also agreed to indemnify holders of all notes and debentures and the company's credit facility lenders (see note 20) for added costs relating to withholding taxes. Similar indemnity terms apply to certain facility and equipment leases. There is no limit to the maximum amount payable under these indemnification agreements. The company is unable to determine the maximum potential amount payable as government regulations and legislation are subject to change without notice. Under these agreements, the company has the option to redeem or terminate these contracts if additional costs are incurred.
The company also has guaranteed its working-interest share of certain joint operation undertakings related to transportation services agreements entered into with third parties. The guaranteed amount is limited to the company's share in the joint arrangement. As at December 31, 2019, the probability is remote that these guarantee commitments will impact the company.
32. ACQUISITION OF ADDITIONAL OWNERSHIP INTEREST IN THE SYNCRUDE PROJECT
On February 23, 2018, Suncor completed the purchase of an additional 5% working interest in the Syncrude project from Mocal Energy Limited for $923 million cash. Suncor's share in the Syncrude project has increased to 58.74%.
The acquisition has been accounted for as a business combination using the acquisition method. The purchase price allocation is based on management's best estimates of fair values of Syncrude's assets and liabilities as at February 23, 2018.
134 2019 ANNUAL REPORT Suncor Energy Inc.
The fair values of accounts receivable and accounts payable approximate their carrying values due to the short-term maturity of the instruments. The fair value of materials and supplies inventory approximates book value due to short-term turnover rates. The fair values of property, plant and equipment, and the decommissioning provision were determined using an expected future cash flow approach. Key assumptions used in the calculations were discount rates, future commodity prices and costs, timing of development activities, projections of oil reserves, and cost estimates to abandon and reclaim the mine and facilities.
The additional working interest in Syncrude contributed $270 million to gross revenues and a $7 million net loss to consolidated net earnings from the acquisition date to December 31, 2018.
Had the acquisition occurred on January 1, 2018, the additional working interest would have contributed an additional $64 million to gross revenues and $4 million to consolidated net earnings, which would have resulted in gross revenues of $39.66 billion and consolidated net earnings of $3.30 billion for the twelve months ended December 31, 2018.
During the first quarter of 2018, Suncor acquired an additional 1.05% interest in the Fort Hills project for consideration of $145 million. The additional interest was an outcome of the commercial dispute settlement agreement reached among the Fort Hills partners in December 2017. Teck Resources Limited (Teck) also acquired an additional 0.42% in the project. Suncor's share in the project has increased to 54.11% and Teck's share has increased to 21.31% with Total E&P Canada Ltd.'s share decreasing to 24.58%.
In the third quarter of 2019, the company recognized a gain on sale of $65 million ($48 million after-tax) in the Exploration and Production segment related to the sale of its non-core Australian assets.
On June 28, 2019, the company completed a transaction to sell its 37% equity interest in Canbriam Energy Inc. (Canbriam) and recognized a gain on sale for the full proceeds of $151 million ($139 million after-tax) in the Exploration and Production segment. The investment in Canbriam was acquired early in 2018 through the exchange of Suncor's northeast British Columbia mineral landholdings, including associated production, and consideration of $52 million.
During the first quarter of 2019, the company received $363 million in insurance proceeds for its Libyan assets ($264 million after-tax). The proceeds may be subject to a provisional repayment, which may be dependent on the future performance and cash flows from Suncor's Libyan assets.
On September 29, 2018, Suncor along with the other working-interest partners in the Joslyn Oil Sands Mining project, agreed to sell 100% of their respective working interests to Canadian Natural Resources Limited for gross proceeds of $225 million, $82.7 million, net to Suncor. Suncor held a 36.75% working interest in Joslyn prior to the transaction. The working-interest partners received cash proceeds of $100 million ($36.8 million, net to Suncor) upon closing, with the remaining $125 million ($45.9 million, net to Suncor) to be received in equal instalments over the next five years. As a result, Suncor has recorded a long-term receivable of $36.7 million within the Other Assets line item and the first instalment of $9.2 million is recorded within the Accounts Receivable line item. The transaction resulted in a gain of $83 million in the Oil Sands segment.
On May 31, 2018, the company completed the previously announced transaction to acquire a 17.5% interest in the Fenja development project in Norway from Faroe Petroleum Norge AS for acquisition costs of US$55 million (approximately $70 million), plus interim settlement costs of $22 million under the acquisition method. This project was sanctioned by its owners in December 2017.
2019 ANNUAL REPORT Suncor Energy Inc. 135
Management's Discussion and Analysis for the fiscal year ended December 31, 2019,
dated February 26, 2020
MANAGEMENT'S DISCUSSION AND ANALYSIS February 26, 2020 |
|
This Management's Discussion and Analysis (this MD&A) should be read in conjunction with Suncor's December 31, 2019 audited Consolidated Financial Statements and the accompanying notes. Additional information about Suncor filed with Canadian securities regulatory authorities and the United States Securities and Exchange Commission (SEC), including quarterly and annual reports and Suncor's Annual Information Form dated February 26, 2020 (the 2019 AIF), which is also filed with the SEC under cover of Form 40-F, is available online at www.sedar.com, www.sec.gov and our website www.suncor.com. Information on or connected to our website, even if referred to in this MD&A, does not constitute part of this MD&A.
References to "we", "our", "Suncor", or "the company" mean Suncor Energy Inc. and the company's subsidiaries and interests in associates and joint arrangements, unless the context requires otherwise. For a list of abbreviations that may be used in this MD&A, refer to the Advisories Common Abbreviations section of this MD&A.
18 2019 ANNUAL REPORT Suncor Energy Inc.
|
MD&A Table of Contents | ||
|
||
20 | Financial and Operating Summary | |
|
||
22 | Suncor Overview | |
|
||
25 | Financial Information | |
|
||
29 | Segment Results and Analysis | |
|
||
44 | Fourth Quarter 2019 Analysis | |
|
||
46 | Quarterly Financial Data | |
|
||
48 | Capital Investment Update | |
|
||
50 | Financial Condition and Liquidity | |
|
||
55 | Accounting Policies and Critical Accounting Estimates | |
|
||
59 | Risk Factors | |
|
||
70 | Other Items | |
|
||
71 | Advisories | |
|
Basis of Presentation
Unless otherwise noted, all financial information has been prepared in accordance with International Financial Reporting Standards (IFRS) as issued by the International Accounting Standards Board (IASB) and Canadian generally accepted accounting principles (GAAP) as contained within Part 1 of the Canadian Institute of Chartered Professional Accountants Handbook.
Effective January 1, 2019, the company adopted IFRS 16 Leases (IFRS 16), which replaced the previous leasing standard IAS 17 Leases (IAS 17), and requires the recognition of all leases on the balance sheet, with optional exemptions for short-term leases where the term is twelve months or less and for leases of low value. IFRS 16 effectively removes the classification of leases as either finance or operating leases and treats all leases as finance leases for lessees. The accounting treatment for lessors remains essentially unchanged, with the requirement to classify leases as either finance or operating. Please refer to note 5 in the company's December 31, 2019 audited Consolidated Financial Statements for further information. The company has selected the modified retrospective transition approach, electing to adjust opening retained earnings with no re-statement of comparative figures. As such, comparative information continues to be reported under IAS 17 and International Financial Reporting Interpretations Committee (IFRIC) 4.
All financial information is reported in Canadian dollars, unless otherwise noted. Production volumes, apart from Libya, are presented on a working-interest basis, before royalties, unless otherwise noted. Libyan production volumes are presented on an economic basis.
Beginning in 2019, results from the company's Energy Trading business have been included within each of the respective operating business segments to which the respective trading activity relates. The Energy Trading business was previously reported within the Corporate, Energy Trading and Eliminations segment. Prior periods have been restated to reflect this change.
Also beginning in 2019, the company revised the classification of its capital expenditures into "asset sustainment and maintenance" and "economic investment" to better reflect the types of capital investments being made by the company. There is no impact to overall capital expenditures, and comparative periods have been restated to reflect this change. Refer to the Capital Investment Update section of this MD&A for further details.
Non-GAAP Financial Measures
Certain financial measures in this MD&A namely operating earnings (loss), funds from (used in) operations, return on capital employed (ROCE), Oil Sands operations cash operating costs, In Situ cash operating costs, Fort Hills cash operating costs, Syncrude cash operating costs, refining margin, refining operating expense, free funds flow, discretionary free funds flow, and last-in, first-out (LIFO) inventory valuation methodology are not prescribed by GAAP. Operating earnings (loss), Oil Sands operations cash operating costs, Fort Hills cash operating costs, Syncrude cash operating costs and LIFO inventory valuation methodology are defined in the Advisories Non-GAAP Financial Measures section of this MD&A and reconciled to the most directly comparable GAAP measures in the Financial Information and Segment Results and Analysis sections of this MD&A. ROCE, funds from (used in) operations, free funds flow, discretionary free funds flow, refining margin, refining operating expense and In Situ cash operating costs are defined and reconciled, where applicable, to the most directly comparable GAAP measures in the Advisories Non-GAAP Financial Measures section of this MD&A.
Measurement Conversions
Crude oil and natural gas liquids volumes have been converted to mcfe on the basis of one bbl to six mcf in this MD&A. Also, certain natural gas volumes have been converted to boe or mboe on the same basis. Refer to the Advisories Measurement Conversions section of this MD&A.
Common Abbreviations
For a list of abbreviations that may be used in this MD&A, refer to the Advisories Common Abbreviations section of this MD&A.
Risks and Forward-Looking Information
The company's business, reserves, financial condition and results of operations may be affected by a number of factors, including, but not limited to, the factors described in the Risk Factors section of this MD&A.
This MD&A contains forward-looking information based on Suncor's current expectations, estimates, projections and assumptions. This information is subject to a number of risks and uncertainties, including those discussed in this MD&A and Suncor's other disclosure documents filed with Canadian securities regulatory authorities and the SEC, many of which are beyond the company's control. Users of this information are cautioned that actual results may differ materially. Refer to the Advisories Forward-Looking Information section of this MD&A for information on the material risk factors and assumptions underlying our forward-looking information.
2019 ANNUAL REPORT Suncor Energy Inc. 19
1. FINANCIAL AND OPERATING SUMMARY
Financial Summary
Year ended December 31 ($ millions, except per share amounts) | 2019 | 2018 | 2017 | ||||||
|
|||||||||
Gross revenues | 39 866 | 39 592 | 32 885 | ||||||
|
|||||||||
Royalties | (1 522 | ) | (1 050 | ) | (931 | ) | |||
|
|||||||||
Operating revenues, net of royalties | 38 344 | 38 542 | 31 954 | ||||||
|
|||||||||
Net earnings | 2 899 | 3 293 | 4 458 | ||||||
|
|||||||||
per common share basic | 1.86 | 2.03 | 2.68 | ||||||
|
|||||||||
per common share diluted | 1.86 | 2.02 | 2.68 | ||||||
|
|||||||||
Operating earnings (1) | 4 358 | 4 312 | 3 188 | ||||||
|
|||||||||
per common share basic | 2.80 | 2.65 | 1.92 | ||||||
|
|||||||||
Funds from operations (1) | 10 818 | 10 172 | 9 139 | ||||||
|
|||||||||
per common share basic | 6.94 | 6.27 | 5.50 | ||||||
|
|||||||||
Cash flow provided by operating activities | 10 421 | 10 580 | 8 966 | ||||||
|
|||||||||
per common share basic | 6.69 | 6.54 | 5.40 | ||||||
|
|||||||||
Dividends paid on common shares | 2 614 | 2 333 | 2 124 | ||||||
|
|||||||||
per common share basic | 1.68 | 1.44 | 1.28 | ||||||
|
|||||||||
Weighted average number of common shares in millions basic | 1 559 | 1 623 | 1 661 | ||||||
|
|||||||||
Weighted average number of common shares in millions diluted | 1 561 | 1 629 | 1 665 | ||||||
|
|||||||||
ROCE (1) (%) | 4.9 | 8.0 | 6.7 | ||||||
|
|||||||||
ROCE (1)(2) (%), excluding major projects in progress | 5.1 | 8.2 | 8.6 | ||||||
|
|||||||||
Capital expenditures (3) | 5 436 | 5 250 | 5 822 | ||||||
|
|||||||||
Asset sustainment and maintenance | 3 227 | 3 347 | 2 557 | ||||||
|
|||||||||
Economic investment | 2 209 | 1 903 | 3 265 | ||||||
|
|||||||||
Discretionary free funds flow (1) | 4 914 | 4 432 | 4 415 | ||||||
|
|||||||||
Balance sheet (at December 31) | |||||||||
|
|||||||||
Total assets | 89 435 | 89 579 | 89 494 | ||||||
|
|||||||||
Net debt (4)(5) | 16 010 | 15 129 | 12 907 | ||||||
|
|||||||||
Total liabilities | 47 393 | 45 574 | 44 111 | ||||||
|
20 2019 ANNUAL REPORT Suncor Energy Inc.
Operating Summary
Year ended December 31 | 2019 | 2018 | 2017 | |||||
|
||||||||
Production volumes (mboe/d) | ||||||||
|
||||||||
Oil Sands | 670.4 | 628.6 | 563.7 | |||||
|
||||||||
Exploration and Production | 106.8 | 103.4 | 121.6 | |||||
|
||||||||
Total | 777.2 | 732.0 | 685.3 | |||||
|
||||||||
Average price realizations (1) ($/boe) | ||||||||
|
||||||||
Oil Sands operations | 62.87 | 54.91 | 54.26 | |||||
|
||||||||
Fort Hills | 48.96 | 38.47 | | |||||
|
||||||||
Syncrude | 73.45 | 70.19 | 66.05 | |||||
|
||||||||
Exploration and Production | 82.92 | 86.96 | 66.20 | |||||
|
||||||||
Refinery crude oil processed (mbbls/d) | 438.9 | 430.8 | 441.2 | |||||
|
||||||||
Refinery utilization (2) (%) | ||||||||
|
||||||||
Eastern North America | 92 | 94 | 93 | |||||
|
||||||||
Western North America | 98 | 93 | 98 | |||||
|
||||||||
Total | 95 | 93 | 96 | |||||
|
||||||||
Refining margin (3) ($/bbl) | 33.15 | 34.50 | 24.20 | |||||
|
Segment Summary (1)
Year ended December 31 ($ millions) | 2019 | 2018 | 2017 | ||||||
|
|||||||||
Net (loss) earnings | |||||||||
|
|||||||||
Oil Sands | (427 | ) | 945 | 994 | |||||
|
|||||||||
Exploration and Production | 1 005 | 807 | 721 | ||||||
|
|||||||||
Refining and Marketing | 3 000 | 3 154 | 2 622 | ||||||
|
|||||||||
Corporate and Eliminations | (679 | ) | (1 613 | ) | 121 | ||||
|
|||||||||
Total | 2 899 | 3 293 | 4 458 | ||||||
|
|||||||||
Operating earnings (loss) (2) | |||||||||
|
|||||||||
Oil Sands | 1 622 | 885 | 939 | ||||||
|
|||||||||
Exploration and Production | 1 141 | 897 | 735 | ||||||
|
|||||||||
Refining and Marketing | 2 912 | 3 154 | 2 128 | ||||||
|
|||||||||
Corporate and Eliminations | (1 317 | ) | (624 | ) | (614 | ) | |||
|
|||||||||
Total | 4 358 | 4 312 | 3 188 | ||||||
|
|||||||||
Funds from (used in) operations (2) | |||||||||
|
|||||||||
Oil Sands | 6 061 | 4 964 | 4 734 | ||||||
|
|||||||||
Exploration and Production | 2 143 | 1 779 | 1 756 | ||||||
|
|||||||||
Refining and Marketing | 3 863 | 3 798 | 2 823 | ||||||
|
|||||||||
Corporate and Eliminations | (1 249 | ) | (369 | ) | (174 | ) | |||
|
|||||||||
Total funds from operations | 10 818 | 10 172 | 9 139 | ||||||
|
|||||||||
Change in non-cash working capital | (397 | ) | 408 | (173 | ) | ||||
|
|||||||||
Cash flow provided by operating activities | 10 421 | 10 580 | 8 966 | ||||||
|
2019 ANNUAL REPORT Suncor Energy Inc. 21
Suncor is an integrated energy company headquartered in Calgary, Alberta, Canada. We are strategically focused on developing one of the world's largest petroleum resource basins Canada's Athabasca oil sands. In addition, we explore for, acquire, develop, produce and market crude oil in Canada and internationally; we transport and refine crude oil, and we market petroleum and petrochemical products primarily in Canada. We also operate a renewable energy business and conduct energy trading activities focused principally on the marketing and trading of crude oil, natural gas, byproducts, refined products, and power.
For a description of Suncor's business segments, refer to the Segment Results and Analysis section of this MD&A.
Suncor's Strategy
Delivering competitive and sustainable returns to shareholders is a top priority of the company and we aim to maximize shareholder returns by focusing on our operational excellence, capital discipline through investment in high-value projects, and our commitment to environmental stewardship and sustainability. In an industry that has experienced volatility in recent years, we believe that Suncor is well positioned to succeed due to the company's competitive advantages: financial strength, including our ability to consistently generate free funds flow across a wide range of business environments, a highly efficient, tightly integrated suite of assets, an industry-leading long-life, low-decline oil sands reserves base, an offshore business that provides geographically diversified cash flow, and our investment in sustainability, technology and innovation.
Key components of Suncor's strategy include:
22 2019 ANNUAL REPORT Suncor Energy Inc.
2019 Highlights
Suncor generated a record $10.8 billion in funds from operations(1) in 2019, reflecting the ability of our integrated business to deliver strong results across a wide range of market conditions.
Suncor returned $4.9 billion in dividends and share repurchases to shareholders in 2019, representing 45% of total funds from operations, demonstrating our commitment to shareholder returns.
Oil Sands production increased 7%, despite being limited by the Government of Alberta's mandatory production curtailments, with a continued focus on operational excellence and improved reliability.
Exploration and Production (E&P) increased production with Hebron reaching nameplate ahead of schedule and first oil from Oda.
Refinery and Marketing (R&M) segment achieved new records and continued to deliver strong results in 2019.
2019 ANNUAL REPORT Suncor Energy Inc. 23
the prior year. Average refinery utilization was 95% in 2019, compared with 93% in 2018, reflecting the company's continued focus on operational excellence.
Continued focus on free funds flow growth by investing in projects that are economically robust, sustainability minded and technologically progressive.
24 2019 ANNUAL REPORT Suncor Energy Inc.
Net Earnings
Suncor's net earnings in 2019 were $2.899 billion, compared to $3.293 billion in 2018. Net earnings were impacted by the same factors that influenced operating earnings, which are described below. Other items affecting net earnings in 2019 and 2018 included:
Operating Earnings
Consolidated Operating Earnings Reconciliation(1)
Year ended December 31 ($ millions) | 2019 | 2018 | 2017 | |||||
|
||||||||
Net earnings | 2 899 | 3 293 | 4 458 | |||||
|
||||||||
Asset impairments | 3 352 | | | |||||
|
||||||||
Unrealized foreign exchange (gain) loss on U.S. dollar denominated debt | (590 | ) | 989 | (702 | ) | |||
|
||||||||
(Gain) on significant disposals and loss on equity investment(2) | (187 | ) | 30 | (437 | ) | |||
|
||||||||
Impact of income tax adjustments on deferred income taxes(3) | (1 116 | ) | | (124 | ) | |||
|
||||||||
Loss on interest rate swaps(4) | | | 20 | |||||
|
||||||||
Non-cash loss on early payment of long-term debt(5) | | | 28 | |||||
|
||||||||
Recognition of property damage insurance proceeds(6) | | | (55 | ) | ||||
|
||||||||
Operating earnings(1) | 4 358 | 4 312 | 3 188 | |||||
|
2019 ANNUAL REPORT Suncor Energy Inc. 25
Bridge Analysis of Consolidated Operating Earnings ($ millions)(1)
Suncor's consolidated operating earnings in 2019 were $4.358 billion, compared to $4.312 billion in the prior year. The increase was primarily a result of improved western Canadian crude oil differentials, including a substantial narrowing of heavy crude and SCO differentials, which more than offset lower benchmark pricing from the prior year. This led to an increase in Oil Sands price realizations and a net favourable inventory valuation change on crude feedstock costs, partially offset by increased deferral of profit on crude oil sales to R&M, and lower refining margins. Operating earnings in 2019 were also positively impacted by higher overall upstream production, attributed to improved reliability at Syncrude and the ramp up of Fort Hills and Hebron throughout 2019, partially offset by the impact of the Government of Alberta's mandatory production curtailments.
These factors were partially offset by an increase in expenses associated with Suncor's increased production in 2019. DD&A was further impacted by transition to IFRS 16, which also increased financing expenses.
Cash Flow Provided by Operating Activities and Funds from Operations
Consolidated funds from operations for 2019 were $10.818 billion, compared to $10.172 billion in 2018, and were impacted by the same factors as operating earnings described above, excluding the impact of DD&A expense.
Cash flow provided by operating activities, which includes changes in non-cash working capital, was $10.421 billion in 2019, compared to $10.580 billion in 2018, as the current year included a use of cash in working capital, compared to a source of cash in working capital in the prior year which was due to a decrease in accounts receivable balances and refinery inventory value associated with the declining price environment in the second half of 2018.
Results for 2018 Compared with 2017
Net earnings in 2018 were $3.293 billion, compared to $4.458 billion in 2017. The decrease in net earnings was impacted by the same factors impacting operating earnings described below, as well as an after-tax unrealized foreign exchange loss on the revaluation of U.S. dollar denominated debt in 2018, compared to an after-tax unrealized foreign exchange gain in 2017.
Operating earnings were $4.312 billion in 2018, compared to $3.188 billion in 2017. The increase was primarily due to improved overall benchmark crude pricing, increased refining margins, higher overall upstream production, primarily attributed to the ramp up of Fort Hills and Hebron and the increased working interest in Syncrude acquired in early 2018, as well as improved energy trading earnings. These factors were partially offset by an increase in expenses associated with the expansion of the company's production in 2018, an increase in maintenance expenditures at Syncrude and Oil Sands operations resulting from an increase in planned and unplanned maintenance, a decrease in the capitalization of borrowing costs with the commissioning of the company's major growth projects, as well as a net unfavourable inventory valuation change on declining crude feedstock costs at the end of 2018.
Consolidated funds from operations for 2018 were $10.172 billion, compared to $9.139 billion in 2017. Funds from operations were impacted by the same factors as operating earnings described above.
26 2019 ANNUAL REPORT Suncor Energy Inc.
Cash flow provided by operating activities, which includes changes in non-cash working capital, was $10.580 billion in 2018, compared to $8.966 billion in 2017, and reflected a source of cash from the company's working capital balances in 2018, compared to a use of cash in 2017, as a result of lower year end benchmarks.
Business Environment
Commodity prices, refining crack spreads and foreign exchange rates are important factors that affect the results of Suncor's operations.
Average for the year ended December 31 | 2019 | 2018 | 2017 | |||||
|
||||||||
WTI crude oil at Cushing (US$/bbl) | 57.05 | 64.80 | 50.95 | |||||
|
||||||||
Dated Brent Crude (US$/bbl) | 64.30 | 71.05 | 54.25 | |||||
|
||||||||
Dated Brent/Maya crude oil FOB price differential (US$/bbl) | 6.45 | 9.10 | 7.70 | |||||
|
||||||||
MSW at Edmonton (Cdn$/bbl) | 69.20 | 69.30 | 63.20 | |||||
|
||||||||
WCS at Hardisty (US$/bbl) | 44.25 | 38.50 | 38.95 | |||||
|
||||||||
Light/heavy differential for WTI at Cushing less WCS at Hardisty (US$/bbl) | (12.80 | ) | (26.30 | ) | (11.95 | ) | ||
|
||||||||
SYN-WTI differential (US$/bbl) | (0.60 | ) | (6.15 | ) | (1.27 | ) | ||
|
||||||||
Condensate at Edmonton (US$/bbl) | 52.85 | 61.05 | 51.55 | |||||
|
||||||||
Natural gas (Alberta spot) at AECO (Cdn$/mcf) | 1.75 | 1.50 | 2.15 | |||||
|
||||||||
Alberta Power Pool Price (Cdn$/MWh) | 54.95 | 50.20 | 22.15 | |||||
|
||||||||
New York Harbor 2-1-1 crack(1) (US$/bbl) | 19.90 | 19.40 | 18.20 | |||||
|
||||||||
Chicago 2-1-1 crack(1) (US$/bbl) | 17.05 | 17.40 | 16.80 | |||||
|
||||||||
Portland 2-1-1 crack(1) (US$/bbl) | 24.55 | 24.00 | 22.50 | |||||
|
||||||||
Gulf Coast 2-1-1 crack(1) (US$/bbl) | 19.15 | 18.40 | 17.70 | |||||
|
||||||||
Exchange rate (US$/Cdn$) | 0.75 | 0.77 | 0.77 | |||||
|
||||||||
Exchange rate (end of period) (US$/Cdn$) | 0.77 | 0.73 | 0.80 | |||||
|
Suncor's sweet SCO price realizations are influenced primarily by the price of WTI at Cushing and by the supply and demand of sweet SCO from Western Canada, which influences SCO differentials. Price realizations for sweet SCO were favourably impacted by a significant narrowing of SCO differentials, partially offset by a decrease in WTI at Cushing to US$57.05/bbl in 2019, from US$64.80/bbl in 2018.
Suncor also produces a specific grade of sour SCO, the price realizations for which are influenced by various crude benchmarks including, but not limited to, MSW at Edmonton and WCS at Hardisty, and which can also be affected by prices negotiated for spot sales. Prices for MSW at Edmonton in 2019 were relatively unchanged from 2018, while WCS at Hardisty increased to US$44.25 in 2019 compared to US$38.50 in 2018, reflecting the impact of narrowing western Canadian heavy crude differentials, in part due to mandatory production curtailments in Alberta. Sweet and sour SCO differentials in 2019 were favourable when compared to 2018.
Bitumen production that Suncor does not upgrade is blended with diluent to facilitate delivery on pipeline systems. Net bitumen price realizations are therefore influenced by both prices for Canadian heavy crude oil (WCS at Hardisty is a common reference) and prices for diluent (Condensate at Edmonton and SCO) and pipeline tolls. Bitumen price realizations can also be affected by bitumen quality and spot sales. Bitumen prices were favourably impacted by narrower heavy crude oil differentials in 2019.
Suncor's price realizations for production from East Coast Canada and E&P International assets are influenced primarily by the price for Brent crude, which averaged US$64.30/bbl in 2019, compared to US$71.05/bbl in 2018. Due to the nature of cargo shipments at the company's offshore assets, the timing associated with bulk cargo sales can result in price realizations that deviate from the average benchmark price over the period.
Suncor's refining margins are primarily influenced by industry benchmark crack spreads and, although the 3-2-1 crack spread is more commonly quoted, the company's refinery
2019 ANNUAL REPORT Suncor Energy Inc. 27
production is better aligned with a 2-1-1 crack spread, which more appropriately reflects the company's refined product mix of gasoline and distillates. Benchmark crack spreads are industry indicators approximating the gross margin on a barrel of crude oil that is refined to produce gasoline and distillates. More complex refineries can earn greater refining margins by processing less expensive, heavier crudes, or lighter crudes discounted relative to the WTI benchmark. Crack spreads do not necessarily reflect the margins of a specific refinery. Crack spreads quoted in the market are based on current crude feedstock prices whereas actual earnings are based on first-in, first-out (FIFO) inventory accounting, where a delay exists between the time that feedstock is purchased and when it is processed and sold to a third party. A FIFO loss normally reflects a declining price environment for crude oil and finished products, whereas FIFO gains reflect an increasing price environment for crude oil and finished products. Specific refinery margins are further impacted by actual crude purchase costs, refinery configuration, production mix and realized prices for refined products sales in markets unique to each refinery.
Natural gas used in Suncor's Oil Sands and Refining operations is primarily referenced to Alberta spot prices at AECO. The average AECO benchmark increased to $1.75/mcf in 2019, from $1.50/mcf in the prior year.
Excess electricity produced in Suncor's Oil Sands operations business is sold to the Alberta Electric System Operator, with the proceeds netted against the Oil Sands operations cash operating costs per barrel metric. The Alberta power pool price increased to an average of $54.95/MWh in 2019 from $50.20/MWh in the prior year.
The majority of Suncor's revenues from the sale of oil and natural gas commodities are based on prices that are determined by or referenced to U.S. dollar benchmark prices. The majority of Suncor's expenditures are realized in Canadian dollars. A decrease in the value of the Canadian dollar relative to the U.S. dollar will increase the revenues received from the sale of commodities. An increase in the value of the Canadian dollar relative to the U.S. dollar will decrease revenues received from the sale of commodities. In 2019, the Canadian dollar weakened in relation to the U.S. dollar as the average exchange rate decreased to US$0.75 per one Canadian dollar from US$0.77 per one Canadian dollar, which had a positive impact on price realizations for the company in 2019.
Conversely, some of Suncor's assets and liabilities, notably 65% of the company's debt, are denominated in U.S. dollars and translated to Suncor's reporting currency (Canadian dollars) at each balance sheet date. An increase in the value of the Canadian dollar relative to the U.S. dollar from the previous balance sheet date decreases the amount of Canadian dollars required to settle U.S. dollar denominated obligations.
Economic Sensitivities(1)(2)
The following table illustrates the estimated effects that changes in certain factors would have had on 2019 net earnings and funds from operations(3) if the listed changes had occurred.
(Estimated change, in $ millions) |
Net
Earnings |
Funds
From Operations(3) |
||||
|
||||||
Crude oil +US$1.00/bbl | 238 | 238 | ||||
|
||||||
Natural gas +Cdn$0.10/mcf | (24 | ) | (24 | ) | ||
|
||||||
WTI narrowing light/heavy differential +US$1.00/bbl | 23 | 23 | ||||
|
||||||
2-1-1 crack spreads +US$1.00/bbl | 153 | 153 | ||||
|
||||||
Foreign exchange +$0.01 US$/Cdn$ related to operating activities(4) | (221 | ) | (221 | ) | ||
|
||||||
Foreign exchange on U.S. dollar denominated debt +$0.01 US$/Cdn$ | 159 | | ||||
|
28 2019 ANNUAL REPORT Suncor Energy Inc.
4. SEGMENT RESULTS AND ANALYSIS
Suncor has classified its operations into the following segments:
OIL SANDS
Suncor's Oil Sands segment, with assets located in the Athabasca oil sands of northeast Alberta, recovers bitumen from mining and in situ operations. Bitumen is either upgraded into SCO for refinery feedstock and diesel fuel, or blended with diluent for direct sale to market through the company's midstream infrastructure and its marketing activities. The Oil Sands segment includes:
EXPLORATION AND PRODUCTION
Suncor's E&P segment consists of offshore operations off the east coast of Canada and in the North Sea, and onshore assets in Libya and Syria.
REFINING AND MARKETING
The R&M segment consists of two primary operations, the refining and supply and marketing operations discussed below, as well as the infrastructure supporting the marketing and supply of refined products, crude oil, natural gas, power and byproducts.
2019 ANNUAL REPORT Suncor Energy Inc. 29
throughout Canada and the U.S., and the St. Clair ethanol plant in Ontario.
CORPORATE AND ELIMINATIONS
The Corporate and Eliminations segment includes the company's investments in renewable energy projects, and other activities not directly attributable to any other operating segment.
OIL SANDS
2019 Highlights
Strategy and Investment Update
Suncor holds one of the largest resource positions in the Athabasca oil sands. Management is committed to delivering safe, reliable, low-cost production, while being leaders in growth, technical innovation and environmental sustainability. The company has developed a unique asset base within the oil sands and has established a regional advantage given the close proximity of the company's assets to one another. This collection of high-quality assets, combined with a long-life, low-decline reserves base and industry-leading expertise, provides the opportunity to continue to advance technology and innovation investments and high return growth projects while growing annual free funds flow.
The company's ability to leverage technology and innovation is at the core of our strategy supporting our financial, social and environmental goals. Investments to replace its coke-fired boilers with a cogeneration facility at its Oil Sands Base Plant is expected to provide reliable steam generation required for Suncor's extraction and upgrading, at a lower cost and with significantly lower carbon emissions. The facility is also expected to generate electricity that will be transmitted to Alberta's power grid, providing a lower carbon power alternative while delivering value to Suncor.
30 2019 ANNUAL REPORT Suncor Energy Inc.
Additional technology projects, including the continued deployment of AHS, and innovative tailings technology advancements, including Permanent Aquatic Storage Structure, demonstrate the importance technology and innovation have in increasing efficiency and lowering operating costs while improving our environmental and safety performance.
Suncor remains committed to increasing reliability and enhancing the integration of our existing assets for profitable growth. The investment in the bi-directional interconnecting pipelines between Syncrude and Oil Sands Base Plant will provide increased operational flexibility, enabling higher reliability, utilization and profit optimization for all Syncrude partners. The pipelines are expected to be in service in the second half of 2020.
Cost management and capital discipline in Oil Sands will continue to be top priorities as the company expects to manage controllable operating costs through initiatives that include co-ordinated maintenance strategies, equipment standardization and the adoption of digital technologies. Capital discipline continues to focus on managing investment opportunities, including asset synergies and sustainability priorities, strategically investing in projects that are economically robust, sustainably minded and technologically progressive. With these factors in mind, the company has identified opportunities to debottleneck Firebag, including the completion of our emulsion handling project this year, integrate well pad development and expand our Solvent steam-assisted gravity drainage program. Our near-term expectation is to have actual Firebag production at nameplate capacity of 203,000 bbls/d in 2021, assuming no production curtailment, with the potential to add up to 30,000 bbls/d of lower capital intensity and lower carbon production by 2024-25.
Through Suncor's midstream and logistics network, the company secures market access, optimizes price realizations associated with the marketing of crude oil and byproducts and natural gas supply, manages inventory levels, and limits the impacts of external market factors, such as pipeline disruptions, lack of egress or outages at refining customers.
Financial Highlights(1)
Year ended December 31 ($ millions) | 2019 | 2018 | 2017 | ||||||
|
|||||||||
Gross revenues | 18 347 | 15 743 | 13 274 | ||||||
|
|||||||||
Less: Royalties | (917 | ) | (398 | ) | (355 | ) | |||
|
|||||||||
Operating revenues, net of royalties | 17 430 | 15 345 | 12 919 | ||||||
|
|||||||||
Net (loss) earnings | (427 | ) | 945 | 994 | |||||
|
|||||||||
Adjusted for: | |||||||||
|
|||||||||
Asset impairment | 2 959 | | | ||||||
|
|||||||||
Gain on significant disposal(2) | | (60 | ) | | |||||
|
|||||||||
Insurance proceeds(3) | | | (55 | ) | |||||
|
|||||||||
Impact of income tax rate adjustment on deferred taxes | (910 | ) | | | |||||
|
|||||||||
Operating earnings(4) | 1 622 | 885 | 939 | ||||||
|
|||||||||
Funds from operations(4) | 6 061 | 4 964 | 4 734 | ||||||
|
2019 ANNUAL REPORT Suncor Energy Inc. 31
Bridge Analysis of Operating Earnings ($ millions)(1)
Operating earnings in Oil Sands operations were $1.622 billion in 2019, compared to $885 million in 2018. The increase in operating earnings is primarily due to improved western Canadian crude oil differentials, including a substantial narrowing of heavy crude and SCO differentials, which more than offset lower benchmark pricing from the prior year and resulted in higher Oil Sands price realizations. Strong Syncrude reliability and the ramp up of production at Fort Hills throughout 2018 contributed to the overall increase in Oil Sands production in 2019 compared to the prior year, despite being limited by mandatory production curtailments. Operating earnings were unfavourably impacted by higher operating costs, higher royalties and DD&A associated with the increase in production.
Oil Sands had a net loss of $427 million in 2019, compared to net earnings of $945 million in 2018, and was impacted by the same factors as operating earnings described above. In addition, 2019 net earnings included the impact of a non-cash impairment charge of $2.803 billion after-tax on the company's share of the Fort Hills assets, described below, partially offset by a one-time deferred income tax recovery of $910 million associated with a staged reduction to the Alberta corporate income tax rate of 1% each year from 2019 to 2022.
Funds from operations for the Oil Sands segment were $6.061 billion in 2019, compared to $4.964 billion in 2018, and were influenced by the same factors that impacted operating earnings, adjusted for the impact of non-cash DD&A.
Production Volumes(1)
Year ended December 31
(mbbls/d) |
2019 | 2018 | 2017 | ||||
|
|||||||
Upgraded product (SCO and diesel) | 313.3 | 280.3 | 317.7 | ||||
|
|||||||
In Situ non-upgraded bitumen | 99.5 | 138.0 | 111.7 | ||||
|
|||||||
Total Oil Sands operations production | 412.8 | 418.3 | 429.4 | ||||
|
|||||||
Fort Hills bitumen | 85.3 | 66.1 | | ||||
|
|||||||
Syncrude (sweet SCO and diesel) | 172.3 | 144.2 | 134.3 | ||||
|
|||||||
Total | 670.4 | 628.6 | 563.7 | ||||
|
Oil Sands operations production decreased to 412,800 bbls/d in 2019 from 418,300 bbls/d in 2018, primarily due to mandatory production curtailments. Mandatory production curtailments largely impacted the company's non-upgraded bitumen production and resulted in an increased yield loss as the company maximized production to its upgraders in order to produce higher value SCO. In 2019, SCO production increased to 313,300 bbls/d, with upgrader utilization of 90%, compared to SCO production of 280,300 bbls/d and upgrader utilization of 80% in the prior year, reflecting strong reliability in 2019 and reduced maintenance.
Fort Hills bitumen production increased to 85,300 bbls/d in 2019 from 66,100 bbls/d in 2018, due to the ramp up in production throughout 2018, partially offset by the impact of mandatory production curtailments. Fort Hills remains
32 2019 ANNUAL REPORT Suncor Energy Inc.
adversely impacted by mandatory production curtailments due to the continued, disproportionate effect of curtailment as it is applied on a 2018 production basis when the asset was ramping up to full production rates. In 2019, the company was able to partially mitigate impacts of curtailment on production by internally transferring credits from Oil Sands operations during planned maintenance and purchasing third-party curtailment credits.
Suncor's share of Syncrude production increased to 172,300 bbls/d in 2019, compared to 144,200 bbls/d in 2018, marking the second best year of production in the asset's history, even with mandatory production curtailments. The increase is primarily due to strong reliability and lower maintenance resulting in upgrader utilization of 85% in 2019, compared to 70% in the prior year. In 2019, Syncrude was able to partially mitigate the impact of curtailment on production by purchasing curtailment credits from partners and third parties.
Sales Volumes and Mix
Year ended December 31
(mbbls/d) |
2019 | 2018 | 2017 | |||||
|
||||||||
Oil Sands operations sales volumes | ||||||||
|
||||||||
Sweet SCO | 113.5 | 96.1 | 107.9 | |||||
|
||||||||
Diesel | 26.0 | 28.8 | 27.5 | |||||
|
||||||||
Sour SCO | 171.8 | 162.6 | 183.6 | |||||
|
||||||||
Upgraded product (SCO) | 311.3 | 287.5 | 319.0 | |||||
|
||||||||
In Situ non-upgraded bitumen | 101.4 | 134.0 | 110.6 | |||||
|
||||||||
Oil Sands operations | 412.7 | 421.5 | 429.6 | |||||
|
||||||||
Fort Hills bitumen | 86.1 | 57.3 | | |||||
|
||||||||
Syncrude sweet SCO | 172.3 | 144.2 | 134.3 | |||||
|
||||||||
Total | 671.1 | 623.0 | 563.9 | |||||
|
Sales volumes for Oil Sands operations decreased to 412,700 bbls/d in 2019, compared to 421,500 bbls/d in 2018, reflecting the same factors impacting production volumes.
Bitumen sales at Fort Hills increased to 86,100 bbls/d, net to Suncor, in 2019, from 57,300 bbls/d in the prior year, consistent with the increase in production.
Bitumen Production from Operations
Year ended December 31 | 2019 | 2018 | 2017 | |||||
|
||||||||
Oil Sands Base | ||||||||
|
||||||||
Bitumen production (mbbls/d) | 289.9 | 258.8 | 305.4 | |||||
|
||||||||
Bitumen ore mined (thousands of tonnes/day) | 434.8 | 378.0 | 464.4 | |||||
|
||||||||
Bitumen ore grade quality (bbls/tonne) | 0.67 | 0.68 | 0.66 | |||||
|
||||||||
In Situ | ||||||||
|
||||||||
Bitumen production Firebag (mbbls/d) | 187.0 | 204.0 | 181.5 | |||||
|
||||||||
Steam-to-oil ratio Firebag | 2.7 | 2.7 | 2.7 | |||||
|
||||||||
Bitumen production MacKay River (mbbls/d) | 29.2 | 36.0 | 31.1 | |||||
|
||||||||
Steam-to-oil ratio MacKay River | 3.0 | 2.9 | 3.1 | |||||
|
||||||||
Total In Situ bitumen production (mbbls/d) | 216.2 | 240.0 | 212.6 | |||||
|
||||||||
Total Oil Sands operations bitumen production (mbbls/d) | 506.1 | 498.8 | 518.0 | |||||
|
||||||||
Fort Hills | ||||||||
|
||||||||
Bitumen production (mbbls/d) | 85.3 | 66.1 | | |||||
|
||||||||
Bitumen from froth | | 1.3 | | |||||
|
||||||||
Bitumen ore mined (thousands of tonnes/day) | 140.5 | 106.2 | | |||||
|
||||||||
Bitumen ore grade quality (bbls/tonne) | 0.61 | 0.63 | | |||||
|
||||||||
Syncrude | ||||||||
|
||||||||
Bitumen production (mbbls/d) | 205.4 | 172.0 | 163.6 | |||||
|
||||||||
Bitumen ore mined (thousands of tonnes/day) | 330.5 | 277.5 | 252.7 | |||||
|
||||||||
Bitumen ore grade quality (bbls/tonne) | 0.62 | 0.62 | 0.63 | |||||
|
||||||||
Total Oil Sands bitumen production (mbbls/d) | 796.8 | 738.2 | 681.6 | |||||
|
Oil Sands operations bitumen production increased to 506,100 bbls/d in 2019, compared to 498,800 bbls/d in 2018. The increase is primarily due to strong upgrader reliability and the associated increase in mined bitumen volumes, partially offset by lower non-upgraded In Situ production due to mandatory production curtailments after maximizing the volume of Firebag bitumen upgraded into SCO.
Bitumen production at Syncrude increased in 2019 to 205,400 bbls/d from 172,000 bbls/d in 2018, and was impacted by the same factors as production described above.
2019 ANNUAL REPORT Suncor Energy Inc. 33
Price Realizations
Year ended December 31
Net of transportation costs, but before royalties ($/bbl) |
2019 | 2018 | 2017 | ||||||
|
|||||||||
Oil Sands operations | |||||||||
|
|||||||||
SCO and diesel | 69.65 | 68.97 | 61.47 | ||||||
|
|||||||||
Bitumen | 42.08 | 24.70 | 33.47 | ||||||
|
|||||||||
Crude sales basket (all products) | 62.87 | 54.91 | 54.26 | ||||||
|
|||||||||
Crude sales basket, relative to WTI | (13.20 | ) | (29.24 | ) | (11.91 | ) | |||
|
|||||||||
Fort Hills bitumen | 48.96 | 38.47 | | ||||||
|
|||||||||
Syncrude sweet SCO | 73.45 | 70.19 | 66.05 | ||||||
|
|||||||||
Syncrude, relative to WTI | (2.62 | ) | (13.97 | ) | (0.12 | ) | |||
|
Average price realizations at Oil Sands operations increased to $62.87/bbl in 2019 compared to $54.91/bbl in 2018, primarily due to the narrowing of heavy crude and SCO differentials resulting from mandatory production curtailments in the province of Alberta, and the impact of a weaker Canadian dollar, partially offset by a decrease in the WTI benchmark price.
Average price realizations for Fort Hills bitumen were $48.96/bbl in 2019 and were higher than In Situ bitumen realizations due to a higher proportion of sales being made in the U.S. mid-continent and the U.S. Gulf Coast, where Suncor is able to utilize its logistics network to access favourable pricing in the U.S. market, combined with the higher quality associated with paraffinic froth-treated bitumen produced at Fort Hills. Average price realizations were higher than the prior year due to the improved heavy crude oil differential and the impact of a weaker Canadian dollar, partially offset by a decrease in the WTI benchmark price.
Suncor's average price realization for Syncrude sales increased in 2019 to $73.45/bbl, compared to $70.19/bbl in 2018, due to narrower SCO differentials and the impact of a weaker Canadian dollar, partially offset by decreased WTI benchmark pricing.
Royalties
Royalties were higher in 2019 relative to 2018, primarily due to higher bitumen pricing and production volumes.
Expenses and Other Factors
Total operating and transportation expenses for 2019 were higher relative to 2018, as described in detail below. See the Cash Operating Costs section below for further details.
At Oil Sands operations, operating costs increased when compared to the prior year as a result of higher costs associated with increased production of higher value SCO barrels, an increase in contractor mining costs for increased ore volumes processed, higher commodity costs and unplanned maintenance costs.
At Fort Hills, operating costs in 2019 were higher compared to the prior year due to the ramp up of production in 2018 and an increase in planned maintenance.
Suncor's share of Syncrude operating costs were lower than the prior year, primarily due to lower unplanned maintenance costs resulting from improved reliability.
Oil Sands transportation costs in 2019 were comparable to the prior year.
DD&A expense for 2019 increased when compared to 2018 due to additional depreciation associated with the transition to IFRS 16.
34 2019 ANNUAL REPORT Suncor Energy Inc.
Year ended December 31 | 2019 | 2018 | 2017 | ||||||
|
|||||||||
Oil Sands operating, selling and general expense (OS&G) | 8 027 | 7 577 | 6 262 | ||||||
|
|||||||||
Oil Sands operations cash operating costs(1) reconciliation | |||||||||
|
|||||||||
Oil Sands operations OS&G | 4 639 | 4 222 | 4 067 | ||||||
|
|||||||||
Non-production costs(2) | (179 | ) | (100 | ) | (106 | ) | |||
|
|||||||||
Excess power capacity and other(3) | (241 | ) | (237 | ) | (232 | ) | |||
|
|||||||||
Inventory changes | 48 | (14 | ) | 1 | |||||
|
|||||||||
Oil Sands operations cash operating costs(1) ($ millions) | 4 267 | 3 871 | 3 729 | ||||||
|
|||||||||
Oil Sands operations cash operating costs(1) ($/bbl) | 28.20 | 25.25 | 23.80 | ||||||
|
|||||||||
Fort Hills cash operating costs(1) reconciliation | |||||||||
|
|||||||||
Fort Hills OS&G | 921 | 832 | | ||||||
|
|||||||||
Non-production costs(2) | (115 | ) | (120 | ) | | ||||
|
|||||||||
Inventory changes | 9 | 55 | | ||||||
|
|||||||||
Fort Hills cash operating costs(1) ($ millions) | 815 | 767 | | ||||||
|
|||||||||
Fort Hills cash operating costs(1) ($/bbl) | 26.15 | 31.20 | | ||||||
|
|||||||||
Syncrude cash operating costs(1) reconciliation | |||||||||
|
|||||||||
Syncrude OS&G | 2 467 | 2 523 | 2 195 | ||||||
|
|||||||||
Non-production costs(2) | (82 | ) | (33 | ) | (37 | ) | |||
|
|||||||||
Syncrude cash operating costs(1) ($ millions) | 2 385 | 2 490 | 2 158 | ||||||
|
|||||||||
Syncrude cash operating costs(1) ($/bbl) | 37.95 | 47.25 | 44.05 | ||||||
|
Oil Sands operations cash operating costs per barrel(1) averaged $28.20 in 2019, compared to $25.25 in 2018, reflecting higher contractor mining, commodity and unplanned maintenance costs, as well as higher costs associated with the production of higher value SCO barrels. Total Oil Sands operations cash operating costs increased to $4.267 billion from $3.871 billion in the prior year.
In 2019, non-production costs, which are excluded from Oil Sands operations cash operating costs, were higher than the prior year, primarily due to an increase in research and development costs and share-based compensation expense.
Oil Sands operations inventory changes in 2019 reflect a build of higher value SCO, partially offset by a draw of bitumen inventory.
Fort Hills cash operating costs per barrel averaged $26.15 in 2019, compared to $31.20 in 2018, reflecting the impact of the production ramp up throughout 2018.
Syncrude cash operating costs per barrel decreased to $37.95 in 2019, compared to $47.25 in the previous year, due to improved upgrader reliability and decreased maintenance costs. Suncor's share of total Syncrude cash operating costs decreased to $2.385 billion from $2.490 billion in 2018. Higher non-production costs compared to the prior year is due to an increase in share-based compensation expense.
Non-Cash Asset Impairment
Due to continued volatility in the crude oil price environment and resulting declines in forecasted heavy crude oil prices, the company performed an asset impairment test on its Fort Hills cash generating unit (CGU) in the Oil Sands segment. As a result, the company recorded a non-cash impairment charge of $2.80 billion (net of taxes of $0.91 billion) on its share of the Fort Hills project using the following asset-specific assumptions:
The recoverable amount of the Fort Hills CGU was $7.7 billion as at December 31, 2019, which also includes the cost of carbon compliance in accordance with current provincial and federal regulations which starts at $30/tonne in 2020, reaches $50/tonne by 2022 and escalates at the rate of inflation thereafter. The estimate of the recoverable amount is most sensitive to the WCS price forecast and
2019 ANNUAL REPORT Suncor Energy Inc. 35
discount rate. A 5% decrease in price would have resulted in an increase to the impairment charge of approximately $1.2 billion (after-tax) on the company's share of the Fort Hills assets. A 1% increase in the discount rate would have resulted in an increase to the impairment charge of approximately $900 million (after-tax) on the company's share of the Fort Hills assets.
Planned Maintenance
Planned maintenance at MacKay River originally scheduled for the third quarter of 2020 has been accelerated to the first quarter of 2020 to coincide with an outage that occurred in the fourth quarter of 2019, in an effort to minimize impacts to annual production. Planned Upgrader 2 maintenance at Oil Sands operations and an annual turnaround at Syncrude are planned for the second quarter of 2020. Maintenance at Oil Sands operations Upgrader 1 is scheduled for the third quarter of 2020, extending into the fourth quarter of 2020. The anticipated impact of these maintenance events has been reflected in the company's 2020 guidance.
EXPLORATION AND PRODUCTION
2019 Highlights
Strategy and Investment Update
The E&P segment delivers geographically diversified cash flows and focuses primarily on low-cost projects that deliver significant returns, cash flow and long term-value.
The Terra Nova ALE project is scheduled to commence in the second quarter of 2020, with the vessel returning to service in the fourth quarter of 2020. Production at Terra Nova is planned to resume once the project is completed. The project is expected to extend the production life and capacity of the existing Terra Nova asset by approximately a decade. Execution of this work provides an opportunity to complete enhancements to the Floating Production, Storage and Offloading vessel to increase production capacity and efficiency to enable reliable operations over its extended life.
The company has ongoing development activities offshore the east coast of Canada and in the U.K. North Sea, intended to leverage existing facilities and infrastructure to provide incremental production and extend the productive life of existing fields. These activities are planned to continue in 2020, with development drilling at Hebron and Hibernia, the West White Rose Project, Buzzard Phase 2, and the Fenja project in Norway. The Rosebank project is currently in the pre-sanction phase with a sanction decision planned for late 2022.
Through Suncor's midstream and logistics network, the company secures market access, optimizes price realizations associated with crude oil marketing, manages inventory levels and limits the impacts of external market factors.
36 2019 ANNUAL REPORT Suncor Energy Inc.
Financial Highlights(1)
Year ended December 31 ($ millions) | 2019 | 2018 | 2017 | ||||||
|
|||||||||
Gross revenues(2) | 3 372 | 3 474 | 3 177 | ||||||
|
|||||||||
Less: Royalties(2) | (302 | ) | (257 | ) | (266 | ) | |||
|
|||||||||
Operating revenues, net of royalties | 3 070 | 3 217 | 2 911 | ||||||
|
|||||||||
Net earnings | 1 005 | 807 | 721 | ||||||
|
|||||||||
Adjusted for: | |||||||||
|
|||||||||
Asset Impairment | 393 | | | ||||||
|
|||||||||
(Gain) on significant disposals and loss on equity investment(3) | (187 | ) | 90 | | |||||
|
|||||||||
Impact of income tax rate adjustments on deferred income taxes(4) | (70 | ) | | 14 | |||||
|
|||||||||
Operating earnings(5) | 1 141 | 897 | 735 | ||||||
|
|||||||||
Funds from operations(5) | 2 143 | 1 779 | 1 756 | ||||||
|
Bridge Analysis of Operating Earnings ($ millions)(1)
Operating earnings were $1.141 billion for E&P in 2019, compared to $897 million in the prior year, with the increase largely due to the receipt of $264 million, after-tax, for insurance proceeds related to the company's assets in Libya and prior year losses recorded on an equity investment in Canbriam, which was sold in 2019. Operating earnings were
negatively impacted by lower price realizations consistent with the decline in the Brent crude benchmark, higher DD&A and increased royalties. The insurance proceeds received may be subject to a provisional repayment that may be dependent on the future performance and cash flows from Suncor's Libyan assets.
2019 ANNUAL REPORT Suncor Energy Inc. 37
Net earnings were $1.005 billion for the E&P segment in 2019, compared to $807 million in 2018, and were impacted by the same factors as operating earnings described above. In addition, net earnings in 2019 included an after-tax impairment charge of $393 million against the company's interest in White Rose, as discussed below, and a one-time deferred income tax recovery of $70 million associated with a staged reduction to the Alberta corporate income tax rate of 1% each year from 2019 to 2022. Net earnings in 2019 also included an after-tax gain of $139 million on the sale of the company's interest in Canbriam and an after-tax gain of $48 million related to the sale of certain non-core assets.
Funds from operations were $2.143 billion in 2019, compared to $1.779 billion in 2018. The increase was largely due to the same factors that impacted operating earnings above, adjusted for the impact of non-cash DD&A.
Production Volumes
Year ended December 31 | 2019 | 2018 | 2017 | |||||
|
||||||||
E&P Canada | ||||||||
|
||||||||
Terra Nova (mbbls/d) | 11.6 | 11.7 | 11.5 | |||||
|
||||||||
Hibernia (mbbls/d) | 20.1 | 22.1 | 28.5 | |||||
|
||||||||
White Rose (mbbls/d) | 4.7 | 6.6 | 11.4 | |||||
|
||||||||
Hebron (mbbls/d) | 23.5 | 13.0 | 0.4 | |||||
|
||||||||
North America Onshore (mboe/d) | | 0.5 | 1.9 | |||||
|
||||||||
Total E&P Canada production (mboe/d) | 59.9 | 53.9 | 53.7 | |||||
|
||||||||
E&P International | ||||||||
|
||||||||
Buzzard (mboe/d) | 31.9 | 34.2 | 43.8 | |||||
|
||||||||
Golden Eagle (mboe/d) | 9.0 | 12.4 | 19.6 | |||||
|
||||||||
United Kingdom (mboe/d) | 40.9 | 46.6 | 63.4 | |||||
|
||||||||
Norway Oda (mboe/d) | 3.7 | | | |||||
|
||||||||
Libya (mbbls/d) | 2.3 | 2.9 | 4.5 | |||||
|
||||||||
Total E&P International production (mboe/d) | 46.9 | 49.5 | 67.9 | |||||
|
||||||||
Total Production (mboe/d) | 106.8 | 103.4 | 121.6 | |||||
|
||||||||
Total Sales Volumes (mboe/d) | 106.0 | 102.8 | 120.8 | |||||
|
E&P Canada production volumes increased to 59,900 boe/d in 2019 from 53,900 boe/d in 2018, primarily due to the ramp up of Hebron production throughout 2019 and the continued staged return of White Rose to normal operating rates, partially offset by an unplanned outage at Hibernia during the year.
E&P International production volumes averaged 46,900 boe/d in 2019, compared to 49,500 boe/d in 2018, with the increased production from Oda, which began production in 2019, more than offset by natural declines in the U.K.
Price Realizations
Year ended December 31
Net of transportation costs, but before royalties |
2019 | 2018 | 2017 | |||||
|
||||||||
Exploration and Production | ||||||||
|
||||||||
E&P Canada Crude oil and natural gas liquids ($/bbl) | 84.86 | 87.82 | 69.16 | |||||
|
||||||||
E&P Canada Natural gas ($/mcf) | | 1.94 | 1.77 | |||||
|
||||||||
E&P International ($/boe) | 81.09 | 86.77 | 65.46 | |||||
|
||||||||
E&P average price ($/boe) | 82.92 | 86.96 | 66.20 | |||||
|
Average price realizations from E&P Canada and E&P International in 2019 were lower than 2018, due to the decrease in benchmark prices for Brent crude in 2019 and the timing of cargo sales.
Royalties
E&P royalties were higher in 2019 due to an increase in East Coast Canada sales volumes.
Expenses and Other Factors
Operating expenses were marginally higher in 2019, compared to 2018, primarily due to the addition of Hebron operating costs and an increase in maintenance expense.
DD&A and impairment expenses increased in 2019, compared to the prior year, primarily due to the ramp up of Hebron production volumes, partially offset by decreased production in the U.K.
Exploration expense increased in 2019, as compared to 2018, as a result of exploration charges for non-commercial drilling results off the east coast of Canada and in the U.K. North Sea.
Financing expenses and other were favourable in 2019, compared to 2018, due to prior year losses recorded on an equity investment in Canbriam, which was sold in 2019.
Non-Cash Asset Impairment
Due to an increase to forecasted capital expenditures within the White Rose CGU, the company performed an asset impairment test as at December 31, 2019. As a result, the company recorded a non-cash impairment charge of $393 million (net of taxes of $128 million) on its share of the White Rose assets using the following asset-specific assumptions:
38 2019 ANNUAL REPORT Suncor Energy Inc.
The recoverable amount of the White Rose CGU was $360 million as at December 31, 2019, which also includes the cost of carbon compliance in accordance with current provincial and federal regulations which starts at $30/tonne in 2020, reaches $50/tonne by 2022 and escalates at the rate of inflation thereafter. The estimate of the recoverable amount is most sensitive to the Brent price forecast and discount rate. A 5% decrease in price would have resulted in an increase to the impairment charge of approximately $85 million (after-tax) on the company's share of the White Rose assets. A 1% increase in the discount rate would have resulted in an increase to the impairment charge of approximately $35 million (after-tax) on the company's share of the White Rose assets.
Planned Maintenance of Operated Assets
The Terra Nova ALE project is scheduled to commence in the second quarter of 2020, with the vessel returning to service in the fourth quarter of 2020. Production at Terra Nova is planned to resume once the project is completed. The project is expected to extend the production life and capacity of the existing Terra Nova asset. The anticipated impact of the asset being offline has been reflected in the company's 2020 guidance.
REFINING AND MARKETING
2019 Highlights
Strategy and Investment Update
The R&M network serves to maximize Suncor's integrated returns by extending the value chain from oil sands production to the end customer and is a key component of Suncor's integrated business model. The company aims to operate its refineries at optimal levels of utilization to provide reliable offtake and secure pricing for a portion of the production from the Oil Sands segment.
In 2019, Suncor continued to leverage its strong Petro-Canada brand through a nationwide campaign to increase sales volumes and non-petroleum revenues through the company's network of convenience stores and car washes and will continue these efforts in 2020.
Through Suncor's midstream and logistics network, the company secures market access, optimizes price realizations associated with refined products and crude oil supply, manages inventory levels and limits the impacts of external market factors.
2019 ANNUAL REPORT Suncor Energy Inc. 39
Year ended December 31 ($ millions) | 2019 | 2018 | 2017 | ||||||
|
|||||||||
Operating revenues | 22 304 | 23 778 | 19 755 | ||||||
|
|||||||||
Net earnings | 3 000 | 3 154 | 2 622 | ||||||
|
|||||||||
Adjusted for: | |||||||||
|
|||||||||
Impact of income tax rate adjustments on deferred taxes(2) | (88 | ) | | (140 | ) | ||||
|
|||||||||
Gain on significant disposal(3) | | | (354 | ) | |||||
|
|||||||||
Operating earnings(4) | 2 912 | 3 154 | 2 128 | ||||||
|
|||||||||
Funds from operations(4) | 3 863 | 3 798 | 2 823 | ||||||
|
Bridge Analysis of Operating Earnings ($ millions)(1)
R&M contributed annual operating earnings of $2.912 billion in 2019, compared with $3.154 billion in 2018. The decrease was attributable to lower refining margins attributed primarily to significantly narrower crude differentials, lower marketing margins, and higher DD&A, partially offset by a FIFO gain in 2019 compared to a FIFO loss in the prior year associated with the significant decline in crude and refined product benchmarks near the end of 2018.
Net earnings in 2019 were $3.000 billion, compared to net earnings of $3.154 billion in 2018, and were impacted by the same factors as operating earnings described above. 2019 net earnings also included a one-time deferred income tax recovery of $88 million associated with a staged reduction to the Alberta corporate income tax rate of 1% each year from 2019 to 2022.
R&M achieved an annual funds from operations record of $3.863 billion in 2019, compared to $3.798 billion in 2018, due primarily to the same factors that impacted operating earnings described above, excluding the impacts of non-cash DD&A.
40 2019 ANNUAL REPORT Suncor Energy Inc.
Volumes
Year ended December 31 | 2019 | 2018 | 2017 | |||||
|
||||||||
Crude oil processed (mbbls/d) | ||||||||
|
||||||||
Eastern North America | 203.3 | 208.1 | 206.4 | |||||
|
||||||||
Western North America | 235.6 | 222.7 | 234.8 | |||||
|
||||||||
Total | 438.9 | 430.8 | 441.2 | |||||
|
||||||||
Refinery utilization(1)(2) (%) | ||||||||
|
||||||||
Eastern North America | 92 | 94 | 93 | |||||
|
||||||||
Western North America | 98 | 93 | 98 | |||||
|
||||||||
Total | 95 | 93 | 96 | |||||
|
||||||||
Refined Product Sales (mbbls/d) | ||||||||
|
||||||||
Gasoline | 246.6 | 245.6 | 242.9 | |||||
|
||||||||
Distillate | 218.1 | 203.4 | 199.3 | |||||
|
||||||||
Other | 74.7 | 78.4 | 88.3 | |||||
|
||||||||
Total | 539.4 | 527.4 | 530.5 | |||||
|
||||||||
Refining margin(2) ($/bbl) | 33.15 | 34.50 | 24.20 | |||||
|
||||||||
Refining operating expense(2) ($/bbl) | 5.35 | 5.35 | 5.05 | |||||
|
Refinery utilization averaged 95% in 2019, compared with 93% in 2018. The increase in utilization was primarily due to a decrease in planned maintenance in 2019 compared to 2018, with the Edmonton refinery undergoing its first full plant turnaround in its history in 2018.
Total refined products sales were 539,400 bbls/d in 2019, compared to 527,400 bbls/d in 2018, with record volumes sold in the marketing channels in 2019, including a new annual record for Canadian retail sales reflecting continued strong product demand.
Prices and Margins
Refining and Product Supply prices and margins, including FIFO inventory valuation, were slightly higher in 2019 compared to 2018, and were impacted primarily by the following factors:
Marketing gross margins in 2019 were lower than in the prior year, primarily due to finished product market conditions.
Expenses and Other Factors
Operating and transportation expenses were higher in 2019 compared to 2018, primarily due to an increase in business development costs and share-based compensation expense.
DD&A increased in 2019 compared to the prior year due to the implementation of IFRS 16.
Planned Maintenance
The company has a number of planned maintenance events, including a two-week planned maintenance event at the Commerce City refinery in the first quarter of 2020, a two-week turnaround at the Sarnia refinery scheduled in the second quarter of 2020, a four-week turnaround at the Edmonton refinery scheduled in the third quarter of 2020, and a six-week turnaround at the Montreal refinery in the third quarter and fourth quarter of 2020. The estimated impact of these maintenance events has been reflected in the company's 2020 guidance.
CORPORATE AND ELIMINATIONS
2019 Highlights
2019 ANNUAL REPORT Suncor Energy Inc. 41
Strategy and Investment Update
Returning value to shareholders continues to be a top priority for Suncor, as demonstrated by the company's history of dividend increases and commitment to its share repurchase program. Since the start of 2017, the company has completed $12.4 billion in share repurchases as of February 25, 2020, which is approximately 21% of the total outstanding common shares of the company. In 2020, the Board of Directors has approved up to a further $2.0 billion in share repurchases, reinforcing the company's ability to generate cash flow and its commitment to return cash to shareholders.
Investment in wind power and being a part of the emerging biofuel industry is a key component of Suncor's climate change action plan. In 2019, Suncor sanctioned the Forty Mile Wind Power Project in southern Alberta. This 200 MW renewable power project has an estimated total capital spend of $300 million, with 25% of the capital spent in 2019 and the remainder to be spent over the next two years. This investment approach in renewable energy is expected to generate significant value through sustainable power generation and retention of the generated carbon credits for utilization in Suncor's upstream business. This project enables Suncor to make meaningful progress towards its sustainability goal of a 30% GHG emissions intensity reduction by 2030.
In 2020, the company expects to continue to accelerate its digital transformation and implement new digital technologies across the enterprise to help improve the safety, productivity, reliability and environmental performance of our operations. As part of its digital transformation, Suncor has entered into a strategic alliance with Microsoft. This alliance enables Suncor to utilize Microsoft's full range of cloud solutions to empower a connected and collaborative workforce, build an agile data platform to increase analytics capabilities, and partner with experts while gaining access to leading edge technologies.
Financial Highlights(1)
Year ended December 31 ($ millions) | 2019 | 2018 | 2017 | ||||||
|
|||||||||
Net (loss) earnings | (679 | ) | (1 613 | ) | 121 | ||||
|
|||||||||
Adjusted for: | |||||||||
|
|||||||||
Unrealized foreign exchange (gain) loss on U.S. dollar denominated debt | (590 | ) | 989 | (702 | ) | ||||
|
|||||||||
Loss on interest rate swaps(2) | | | 20 | ||||||
|
|||||||||
Non-cash loss on early payment of long-term debt(3) | | | 28 | ||||||
|
|||||||||
Gain on significant disposal(4) | | | (83 | ) | |||||
|
|||||||||
Impact of income tax rate adjustments on deferred income taxes(5) | (48 | ) | | 2 | |||||
|
|||||||||
Operating loss(6) | (1 317 | ) | (624 | ) | (614 | ) | |||
|
|||||||||
Corporate and Renewables | (1 113 | ) | (876 | ) | (532 | ) | |||
|
|||||||||
Eliminations Intersegment profit (eliminated) realized | (204 | ) | 252 | (82 | ) | ||||
|
|||||||||
Funds used in operations(6) | (1 249 | ) | (369 | ) | (174 | ) | |||
|
42 2019 ANNUAL REPORT Suncor Energy Inc.
Corporate and Renewables
Corporate incurred an operating loss of $1.113 billion in 2019, compared with an operating loss of $876 million in 2018, reflecting lower operational foreign exchange gains in 2019 in comparison to the prior year, an increase in share-based compensation expense, higher interest expenses and lower capitalized interest. Suncor capitalized $122 million of its borrowing costs in 2019 as part of the cost of major development assets and construction projects in progress, compared to $156 million in the prior year, with the decrease resulting from the staged commissioning of Fort Hills in 2018.
Year ended December 31 | 2019 | 2018 | 2017 | ||||
|
|||||||
Renewable Energy power generation marketed (gigawatt hours)(1) | 184 | 183 | 255 | ||||
|
Eliminations Intersegment profit (eliminated) realized
Eliminations reflect the deferral or realization of profit on crude oil sales from Oil Sands to R&M. Consolidated profits are only realized when the refined products produced from internal purchases of crude feedstock have been sold to third parties. In 2019, the company eliminated $204 million of after-tax intersegment profit, compared to a realization of profit of $252 million in the prior year. The change year-over-year was primarily due to the increase in Oil Sands crude margins in 2019, as lower margin crude feedstock inventory sourced internally from Oil Sands was sold and replaced by higher margin crude feedstock inventory, resulting in an elimination of profit at the enterprise level.
The net loss for Corporate and Eliminations was $679 million in 2019, compared to a net loss of $1.613 billion in 2018. In addition to the factors impacting operating earnings discussed above, the net loss in 2019 included a $590 million unrealized after-tax foreign exchange gain on the revaluation of U.S. dollar denominated debt and a $48 million deferred income tax recovery associated with the Government of Alberta's staged reduction of the corporate income tax rate from 12% to 8% over the next four years. The net loss in the prior year included a $989 million unrealized after-tax foreign exchange loss on the revaluation of U.S. dollar denominated debt.
Funds used in operations for the Corporate and Eliminations segment were $1.249 billion in 2019, compared to $369 million in 2018, and were influenced by the same factors that impacted operating earnings, adjusted for the non-cash component of share-based compensation expense.
2019 ANNUAL REPORT Suncor Energy Inc. 43
5. FOURTH QUARTER 2019 ANALYSIS
Financial and Operational Highlights(1)
Three months ended December 31
($ millions, except as noted) |
2019 | 2018 | |||||
|
|||||||
Net (loss) earnings | |||||||
|
|||||||
Oil Sands | (2 682 | ) | (377 | ) | |||
|
|||||||
Exploration and Production | (162 | ) | (115 | ) | |||
|
|||||||
Refining and Marketing | 558 | 762 | |||||
|
|||||||
Corporate and Eliminations | (49 | ) | (550 | ) | |||
|
|||||||
Total | (2 335 | ) | (280 | ) | |||
|
|||||||
Operating earnings (loss)(2) | |||||||
|
|||||||
Oil Sands | 277 | (377 | ) | ||||
|
|||||||
Exploration and Production | 231 | 108 | |||||
|
|||||||
Refining and Marketing | 558 | 762 | |||||
|
|||||||
Corporate and Eliminations | (284 | ) | 87 | ||||
|
|||||||
Total | 782 | 580 | |||||
|
|||||||
Funds from (used in) operations(2) | |||||||
|
|||||||
Oil Sands | 1 405 | 607 | |||||
|
|||||||
Exploration and Production | 555 | 331 | |||||
|
|||||||
Refining and Marketing | 793 | 873 | |||||
|
|||||||
Corporate and Eliminations | (200 | ) | 196 | ||||
|
|||||||
Total funds from operations | 2 553 | 2 007 | |||||
|
|||||||
Changes in non-cash working capital | (249 | ) | 1 033 | ||||
|
|||||||
Cash flow provided by operating activities | 2 304 | 3 040 | |||||
|
|||||||
Production volumes (mboe/d) | |||||||
|
|||||||
Oil Sands | 662.3 | 740.8 | |||||
|
|||||||
Exploration and Production | 115.9 | 90.2 | |||||
|
|||||||
Total | 778.2 | 831.0 | |||||
|
Net Loss
Suncor had a consolidated net loss for the fourth quarter of 2019 of $2.335 billion, compared to a net loss of $280 million for the prior year quarter. The net loss was affected by the same factors that influenced operating earnings described subsequently in this section of this document. Other items affecting net losses over these periods included:
Cash Flow provided by Operating Activities and Funds from Operations
Funds from operations were $2.553 billion in the fourth quarter of 2019, compared to $2.007 billion in the fourth quarter of 2018, and were influenced by the same factors impacting operating earnings described in the Segmented Analysis below, excluding the impact of DD&A and share-based compensation expenses.
Cash flow provided by operating activities, which includes changes in non-cash working capital, was $2.304 billion in the fourth quarter of 2019, compared to $3.040 billion in the fourth quarter of 2018, and was influenced by the same factors impacting operating earnings noted below, excluding the impact of DD&A and share-based compensation expenses. In addition, cash flow provided by operating activities was impacted by a use of cash from working capital in 2019 as compared to a source of cash in 2018, which was due to a decrease in accounts receivable balances and refinery inventory value associated with lower year end benchmark prices.
Segmented Analysis
Oil Sands
The Oil Sands segment had operating earnings of $277 million in the fourth quarter of 2019, compared to an operating loss of $377 million in the prior year quarter. The improved results were primarily due to higher realized crude prices due to improved western Canadian crude oil differentials, including a substantial narrowing of heavy crude and SCO differentials, more than offsetting benchmark pricing declines. This was partially offset by lower overall production volumes due to planned maintenance and mandatory production curtailments and higher DD&A.
44 2019 ANNUAL REPORT Suncor Energy Inc.
Oil Sands operations production was 418,100 bbls/d in the fourth quarter of 2019, compared to 432,700 bbls/d in the prior year quarter. The decrease in production was primarily due to maintenance, including planned annual coker maintenance at Oil Sands Base, increased yield loss associated with higher SCO production, mandatory production curtailments and an outage at MacKay River, which is expected to return to operation early in the second quarter of 2020. Upgrader utilization was 86% in the fourth quarter of 2019, compared to 79% in the prior year period.
Fort Hills production averaged 87,900 bbls/d in the fourth quarter of 2019, compared to 98,500 bbls/d in the prior year quarter. The decrease in production was due to planned maintenance, which was completed during the quarter, and mandatory production curtailments. Fort Hills remains adversely impacted by mandatory production curtailments due to the continued, disproportionate effect of curtailment as it is applied on a 2018 production basis when the asset was ramping up to full production rates. However, the company was able to partially mitigate production impacts by internally transferring credits from Oil Sands operations and purchasing third-party credits.
Suncor's share of Syncrude production and sales was 156,300 bbls/d in the fourth quarter of 2019, compared to 209,600 bbls/d in the prior year quarter. The decrease in production was primarily due to planned maintenance that commenced in the third quarter of 2019 and was completed in the fourth quarter, compared to no planned maintenance in the prior year quarter, and mandatory production curtailments. Upon completion of maintenance, Syncrude was able to partially mitigate the impacts of curtailment on production by purchasing curtailment credits from partners and third parties.
Sales volumes for Oil Sands operations were 417,600 bbls/d in the fourth quarter of 2019, compared to 460,500 bbls/d in the prior year quarter, and were influenced by the same factors influencing production, combined with a draw in inventory in the prior year quarter.
Exploration and Production
Operating earnings for the E&P segment were $231 million in the fourth quarter of 2019, compared to $108 million in the prior year quarter, primarily as a result of higher East Coast Canada production volumes and crude price realizations, partially offset by higher royalties and DD&A related to the increased production. Financing and other expenses in the fourth quarter of 2019 were lower when compared to the fourth quarter of 2018, as the prior year quarter had equity losses related to an investment in Canbriam that the company subsequently sold.
Production volumes for E&P Canada were 69,600 boe/d in the fourth quarter of 2019, compared to 47,900 boe/d in the prior year quarter. The increase in production was primarily due to the ramp up of Hebron production throughout 2019 and the impact of a temporary production interruption due to a major storm system that impacted all E&P East Coast Canada assets in the prior year quarter.
E&P International production increased to 46,300 boe/d in the fourth quarter of 2019, from 42,300 boe/d in the prior year quarter, primarily due to increased production from Oda, which began production near the end of the first quarter of 2019, partially offset by natural declines in the U.K.
Refining and Marketing
R&M operating earnings in the fourth quarter of 2019 were $558 million, compared to $762 million in the prior year quarter. The decrease in operating earnings was primarily due to lower refining margins, attributed to significantly narrower crude differentials, lower refinery crude throughput, and lower marketing margins, partially offset by a lower FIFO loss, as the prior year quarter included a significant FIFO loss associated with the decline in crude and refined product benchmarks.
Refinery crude throughput was 447,500 bbls/d in the fourth quarter of 2019, compared to 467,900 bbls/d in the prior year quarter. Both periods achieved high utilization rates at 97% and 101%, respectively.
Refined product sales increased in the fourth quarter of 2019 to 534,600 bbls/d, compared to 530,600 bbls/d in the prior year quarter, reflecting strong retail sales volumes.
Corporate and Eliminations
Corporate and Eliminations had an operating loss of $284 million in the fourth quarter of 2019, compared to operating earnings of $87 million in the fourth quarter of 2018. During the fourth quarter of 2019, the company realized $11 million of after-tax intersegment profit, compared to a realization of $265 million of after-tax intersegment profit in the prior year quarter. The realization of deferred profit in the fourth quarter of 2019 was driven by the decrease in Oil Sands price realizations over the quarter, as higher margin crude refinery feedstock inventory sourced internally from Oil Sands was sold and replaced by lower margin crude feedstock inventory. The realization of deferred profit in the prior year quarter was driven by the decrease in oil sand benchmark prices, as a result of the significant widening of crude differentials.
The increased loss was also attributable to a share-based compensation expense incurred in the fourth quarter of 2019, as compared to a share-based compensation recovery in the prior year quarter, and a lower operational foreign exchange gain than in the prior year quarter. Suncor capitalized $37 million of its borrowing costs in the fourth quarter of 2019 as part of the cost of major development assets and construction projects in progress, compared to $28 million in the prior year quarter.
2019 ANNUAL REPORT Suncor Energy Inc. 45
Financial Summary
Three months ended
($ millions, unless otherwise noted) |
Dec 31
2019 |
Sept 30
2019 |
June 30,
2019 |
Mar 31
2019 |
Dec 31
2018 |
Sept 30
2018 |
June 30,
2018 |
Mar 31
2018 |
||||||||||||
|
||||||||||||||||||||
Total production (mboe/d) | ||||||||||||||||||||
|
||||||||||||||||||||
Oil Sands | 662.3 | 670.0 | 692.2 | 657.2 | 740.8 | 651.7 | 547.6 | 571.7 | ||||||||||||
|
||||||||||||||||||||
Exploration and Production | 115.9 | 92.3 | 111.7 | 107.1 | 90.2 | 92.1 | 114.1 | 117.7 | ||||||||||||
|
||||||||||||||||||||
778.2 | 762.3 | 803.9 | 764.3 | 831.0 | 743.8 | 661.7 | 689.4 | |||||||||||||
|
||||||||||||||||||||
Revenues and other income | ||||||||||||||||||||
|
||||||||||||||||||||
Operating revenues, net of royalties | 9 487 | 9 803 | 10 071 | 8 983 | 8 561 | 10 847 | 10 327 | 8 807 | ||||||||||||
|
||||||||||||||||||||
Other income (loss) | 111 | 93 | 27 | 414 | 384 | 16 | 101 | (57 | ) | |||||||||||
|
||||||||||||||||||||
9 598 | 9 896 | 10 098 | 9 397 | 8 945 | 10 863 | 10 428 | 8 750 | |||||||||||||
|
||||||||||||||||||||
Net (loss) earnings | (2 335 | ) | 1 035 | 2 729 | 1 470 | (280 | ) | 1 812 | 972 | 789 | ||||||||||
|
||||||||||||||||||||
per common share basic (dollars) | (1.52 | ) | 0.67 | 1.74 | 0.93 | (0.18 | ) | 1.12 | 0.60 | 0.48 | ||||||||||
|
||||||||||||||||||||
per common share diluted (dollars) | (1.52 | ) | 0.67 | 1.74 | 0.93 | (0.18 | ) | 1.11 | 0.59 | 0.48 | ||||||||||
|
||||||||||||||||||||
Operating earnings(1) | 782 | 1 114 | 1 253 | 1 209 | 580 | 1 557 | 1 190 | 985 | ||||||||||||
|
||||||||||||||||||||
per common share basic(1) (dollars) | 0.51 | 0.72 | 0.80 | 0.77 | 0.36 | 0.96 | 0.73 | 0.60 | ||||||||||||
|
||||||||||||||||||||
Funds from operations(1) | 2 553 | 2 675 | 3 005 | 2 585 | 2 007 | 3 139 | 2 862 | 2 164 | ||||||||||||
|
||||||||||||||||||||
per common share basic(1) (dollars) | 1.66 | 1.72 | 1.92 | 1.64 | 1.26 | 1.94 | 1.75 | 1.32 | ||||||||||||
|
||||||||||||||||||||
Cash flow provided by operating activities | 2 304 | 3 136 | 3 433 | 1 548 | 3 040 | 4 370 | 2 446 | 724 | ||||||||||||
|
||||||||||||||||||||
per common share basic (dollars) | 1.50 | 2.02 | 2.19 | 0.98 | 1.90 | 2.70 | 1.50 | 0.44 | ||||||||||||
|
||||||||||||||||||||
ROCE(1) (%) for the twelve months ended | 4.9 | 9.7 | 10.4 | 8.2 | 8.0 | 9.7 | 8.3 | 6.5 | ||||||||||||
|
||||||||||||||||||||
ROCE(1)(2) (%) excluding major projects in progress for the twelve months ended | 5.1 | 9.9 | 10.6 | 8.3 | 8.2 | 10.4 | 9.5 | 7.8 | ||||||||||||
|
||||||||||||||||||||
After-tax unrealized foreign exchange gain (loss) on U.S. dollar denominated debt | 235 | (127 | ) | 221 | 261 | (637 | ) | 195 | (218 | ) | (329 | ) | ||||||||
|
||||||||||||||||||||
Common share information (dollars) | ||||||||||||||||||||
|
||||||||||||||||||||
Dividend per common share | 0.42 | 0.42 | 0.42 | 0.42 | 0.36 | 0.36 | 0.36 | 0.36 | ||||||||||||
|
||||||||||||||||||||
Share price at the end of trading | ||||||||||||||||||||
|
||||||||||||||||||||
Toronto Stock Exchange (Cdn$) | 42.56 | 41.79 | 40.85 | 43.31 | 38.13 | 49.98 | 53.50 | 44.49 | ||||||||||||
|
||||||||||||||||||||
New York Stock Exchange (US$) | 32.80 | 31.58 | 31.16 | 32.43 | 27.97 | 38.69 | 40.68 | 34.54 | ||||||||||||
|
46 2019 ANNUAL REPORT Suncor Energy Inc.
Business Environment
Three months ended
(average for the period ended, except as noted) |
Dec 31
2019 |
Sept 30
2019 |
June 30
2019 |
Mar 31
2019 |
Dec 31
2018 |
Sept 30
2018 |
June 30
2018 |
Mar 31
2018 |
||||||||||||
|
||||||||||||||||||||
WTI crude oil at Cushing | US$/bbl | 56.95 | 56.45 | 59.85 | 54.90 | 58.85 | 69.50 | 67.90 | 62.90 | |||||||||||
|
||||||||||||||||||||
Dated Brent crude | US$/bbl | 63.30 | 61.90 | 68.85 | 63.20 | 67.80 | 75.25 | 74.40 | 66.80 | |||||||||||
|
||||||||||||||||||||
Dated Brent/Maya FOB price differential | US$/bbl | 9.30 | 5.20 | 6.90 | 5.00 | 4.35 | 10.20 | 12.40 | 7.70 | |||||||||||
|
||||||||||||||||||||
MSW at Edmonton | Cdn$/bbl | 68.10 | 68.35 | 73.40 | 66.45 | 42.70 | 82.10 | 80.95 | 72.45 | |||||||||||
|
||||||||||||||||||||
WCS at Hardisty | US$/bbl | 41.10 | 44.20 | 49.20 | 42.50 | 19.50 | 47.35 | 48.65 | 38.60 | |||||||||||
|
||||||||||||||||||||
Light/heavy crude oil differential for WTI at Cushing less WCS at Hardisty | US$/bbl | (15.85 | ) | (12.25 | ) | (10.65 | ) | (12.40 | ) | (39.35 | ) | (22.15 | ) | (19.25 | ) | (24.30 | ) | |||
|
||||||||||||||||||||
SYN-WTI (differential) premium | US$/bbl | (0.70 | ) | 0.40 | 0.15 | (2.30 | ) | (21.60 | ) | (0.90 | ) | (0.65 | ) | (1.45 | ) | |||||
|
||||||||||||||||||||
Condensate at Edmonton | US$/bbl | 53.00 | 52.00 | 55.90 | 50.55 | 45.30 | 66.80 | 68.50 | 63.15 | |||||||||||
|
||||||||||||||||||||
Natural gas (Alberta spot) at AECO | Cdn$/mcf | 2.50 | 0.95 | 1.05 | 2.55 | 1.60 | 1.20 | 1.20 | 1.75 | |||||||||||
|
||||||||||||||||||||
Alberta Power Pool Price | Cdn$/MWh | 46.95 | 46.85 | 56.35 | 70.75 | 55.55 | 54.45 | 56.00 | 34.95 | |||||||||||
|
||||||||||||||||||||
New York Harbor 2-1-1 crack(1) | US$/bbl | 18.50 | 19.75 | 22.40 | 19.10 | 18.75 | 19.50 | 21.45 | 17.95 | |||||||||||
|
||||||||||||||||||||
Chicago 2-1-1 crack(1) | US$/bbl | 14.45 | 17.05 | 21.55 | 15.30 | 16.25 | 19.90 | 19.10 | 14.30 | |||||||||||
|
||||||||||||||||||||
Portland 2-1-1 crack(1) | US$/bbl | 25.75 | 23.85 | 29.15 | 19.35 | 24.25 | 22.05 | 28.75 | 21.05 | |||||||||||
|
||||||||||||||||||||
Gulf Coast 2-1-1 crack(1) | US$/bbl | 17.10 | 20.00 | 21.70 | 17.85 | 17.45 | 19.30 | 20.50 | 16.35 | |||||||||||
|
||||||||||||||||||||
Exchange rate | US$/Cdn$ | 0.76 | 0.76 | 0.75 | 0.75 | 0.76 | 0.77 | 0.77 | 0.79 | |||||||||||
|
||||||||||||||||||||
Exchange rate (end of period) | US$/Cdn$ | 0.77 | 0.76 | 0.76 | 0.75 | 0.73 | 0.77 | 0.76 | 0.78 | |||||||||||
|
Significant or Unusual Items Impacting Net Earnings
Trends in Suncor's quarterly net earnings and cash flow provided by operating activities are driven primarily by production volumes, which can be significantly impacted by factors such as mandatory production curtailments in the province of Alberta, which began on January 1, 2019 and was in effect for the duration of 2019.
Trends in Suncor's quarterly net earnings and cash flow provided by operating activities are also affected by changes in commodity prices, price differentials, refining crack spreads and foreign exchange rates, as described in the Financial Information section of this MD&A. In addition to the impacts of changes in production volumes and business environment, net earnings over the last eight quarters were affected by the following events or significant adjustments:
2019 ANNUAL REPORT Suncor Energy Inc. 47
Capital and Exploration Expenditures by Segment
Year ended December 31 ($ millions) | 2019 | 2018 | 2017 | |||||
|
||||||||
Oil Sands | 3 522 | 3 546 | 5 059 | |||||
|
||||||||
Exploration and Production | 1 070 | 946 | 824 | |||||
|
||||||||
Refining and Marketing | 818 | 856 | 634 | |||||
|
||||||||
Corporate and Eliminations | 148 | 58 | 34 | |||||
|
||||||||
Total | 5 558 | 5 406 | 6 551 | |||||
|
||||||||
Less: capitalized interest on debt | (122 | ) | (156 | ) | (729 | ) | ||
|
||||||||
5 436 | 5 250 | 5 822 | ||||||
|
Capital and Exploration Expenditures by Type, excluding capitalized interest(1)
Year ended December 31, 2019 ($ millions) |
Asset
Sustainment and Maintenance(2) |
Economic
Investment(3) |
Total | |||||
|
||||||||
Oil Sands | ||||||||
|
||||||||
Oil Sands Base | 1 667 | 164 | 1 831 | |||||
|
||||||||
In Situ | 113 | 575 | 688 | |||||
|
||||||||
Fort Hills | 331 | 72 | 403 | |||||
|
||||||||
Syncrude | 493 | 46 | 539 | |||||
|
||||||||
Exploration and Production | 5 | 1 011 | 1 016 | |||||
|
||||||||
Refining and Marketing | 566 | 245 | 811 | |||||
|
||||||||
Corporate and Eliminations | 52 | 96 | 148 | |||||
|
||||||||
3 227 | 2 209 | 5 436 | ||||||
|
In 2019, Suncor's capital expenditures on property, plant and equipment and exploration activities totalled $5.436 billion, excluding capitalized borrowing costs of $122 million. Activity in 2019 included the following:
Oil Sands Base
Oil Sands Base asset sustainment and maintenance capital expenditures were $1.667 billion in 2019 and were primarily focused on ensuring continued safe, reliable and efficient operations, as well as environmental compliance, such as the continued development of tailings infrastructure. The company's planned maintenance program in 2019 included planned maintenance at Upgrader 1 in the spring and major maintenance at Upgrader 2 in the fall, the continued development of tailings infrastructure in addition to other reliability and sustainment projects across the operation.
Oil Sands Base economic capital of $164 million in 2019 was focused on projects expected to improve productive capacity. This also included the company's investment to progress low-carbon power generation by replacing its coke-fired boilers with a new cogeneration facility and the construction of interconnecting pipelines between Suncor's Oil Sands Base and Syncrude.
In Situ
In Situ capital expenditures were $688 million, of which $575 million was directed towards economic investment activities, which focused on the ongoing design and construction of well pads to develop additional reserves that are expected to maintain existing production levels at Firebag and MacKay River in future years as production from existing well pads declines.
Fort Hills
Fort Hills capital expenditures were $403 million in 2019, with $72 million directed towards economic investment spending.
48 2019 ANNUAL REPORT Suncor Energy Inc.
Asset sustainment and maintenance capital expenditures of $331 million included mine and tailings development to support ongoing operations.
Syncrude
Syncrude capital expenditures were $539 million in 2019, the majority of which was for asset sustainment and maintenance capital expenditures focused on improving asset reliability and included capital related to turnarounds and maintenance.
Exploration and Production
E&P capital and exploration expenditures were $1.016 billion in 2019, and were primarily focused on economic investment projects, including development drilling at Hibernia, Hebron and Buzzard, and development work on Terra Nova, Fenja and the West White Rose projects.
Refining and Marketing
R&M capital expenditures were $811 million in 2019, and were primarily related to the ongoing sustainment of and enhancement to refinery and retail operations, and other economic investment projects on logistics and the company's retail and wholesale network, including an electric vehicle fast-charging network.
Corporate
Corporate capital expenditures were $148 million, primarily directed towards the company's information technology initiatives and the Forty Mile Wind Power Project.
Suncor anticipates 2020 capital expenditures to be directed to the following projects and initiatives:
Oil Sands Operations
For 2020, plans for economic investment will include capital to progress low-carbon power generation to replace the coke-fired boilers and continued construction of the interconnecting pipelines between Suncor's Oil Sands Base Plant and Syncrude. Additional investment to maintain production capacity at existing facilities includes continued development of new reserves by building new well pads at In Situ and improving mining efficiency through the continued implementation of AHS.
Asset sustainment and maintenance capital will focus on tailings management and planned maintenance at Upgraders 1 and 2.
Fort Hills
Asset sustainment and maintenance capital expenditures for 2020 will focus on ongoing development of mining and tailings management projects to preserve production capacity. In addition, Fort Hills continues to invest in improving mining efficiency through the implementation of AHS.
Syncrude
For 2020, plans for economic investment will include capital to progress the Mildred Lake Extension-West Mine and continued construction of the interconnecting pipelines between Suncor's Oil Sands Base and Syncrude, which are expected to enhance integration between the assets and increase reliability at Syncrude.
Sustaining capital expenditures for 2020 will focus on planned maintenance and reliability programs aimed at maintaining production capacity.
Exploration and Production
Capital expenditures for 2020 are expected to include economic investments at West White Rose Project, Hibernia, Buzzard, and Hebron, as well as the Norwegian Fenja project.
In 2019, the company sanctioned the Terra Nova ALE project, which is expected to extend the life of Terra Nova by approximately a decade and is planned for execution in 2020.
Refining and Marketing
The company expects that sustaining capital will focus on ongoing sustainment and enhancement to refinery and retail operations, and other economic investment projects on logistics and the company's retail and wholesale network.
Corporate
For 2020, the company plans to make economic investments in digital technology initiatives and the Forty Mile Wind Power Project in southern Alberta, which was sanctioned in 2019.
2019 ANNUAL REPORT Suncor Energy Inc. 49
8. FINANCIAL CONDITION AND LIQUIDITY
Liquidity and Capital Resources
At December 31 ($ millions, except as noted) | 2019 | 2018 | 2017 | ||||||
|
|||||||||
Cash flow provided by (used in) | |||||||||
|
|||||||||
Operating activities | 10 421 | 10 580 | 8 966 | ||||||
|
|||||||||
Investing activities | (5 088 | ) | (6 697 | ) | (5 019 | ) | |||
|
|||||||||
Financing activities | (5 537 | ) | (4 426 | ) | (4 223 | ) | |||
|
|||||||||
Foreign exchange (loss) gain on cash and cash equivalents | (57 | ) | 92 | (68 | ) | ||||
|
|||||||||
Decrease in cash and cash equivalents | (261 | ) | (451 | ) | (344 | ) | |||
|
|||||||||
Cash and cash equivalents, end of year | 1 960 | 2 221 | 2 672 | ||||||
|
|||||||||
Return on Capital Employed (%)(1) | |||||||||
|
|||||||||
Excluding major projects in progress(2)(3) | 5.1 | 8.2 | 8.6 | ||||||
|
|||||||||
Including major projects in progress(2) | 4.9 | 8.0 | 6.7 | ||||||
|
|||||||||
Net debt to funds from operations(1)(4)(5) (times) | 1.5 | 1.5 | 1.4 | ||||||
|
|||||||||
Interest coverage on long-term debt (times) | |||||||||
|
|||||||||
Earnings basis(6) | 3.4 | 6.4 | 6.5 | ||||||
|
|||||||||
Funds from operations basis(1)(5)(7) | 13.4 | 14.1 | 11.2 | ||||||
|
Cash Flow provided by Operating Activities
Cash flow provided by operating activities was $10.421 billion in 2019 compared to $10.580 billion in 2018. Cash flow provided by operating activities was positively impacted by the improved western Canadian crude oil differentials, including a substantial narrowing of heavy crude and SCO differentials, from the prior year which led to an increase in Oil Sands price realizations. Cash flow provided by operating activities in 2019 was also positively impacted by higher overall upstream production despite mandatory curtailments as well as after-tax insurance proceeds of $264 million related to the company's assets in Libya. These factors were more than offset by lower refining margins and an increase in expenses associated with the increased production, and reflected a use of cash from the company's working capital balances in 2019, as compared to a source of cash in 2018.
Cash Flow used in Investment Activities
Cash flow used in investing activities was $5.088 billion in 2019 compared to $6.697 billion in 2018. The decrease was primarily due to less acquisition activity in 2019 compared to the prior year, which included the purchase of an additional 5% interest in Syncrude. This was partially offset by an increase in capital and exploration expenditures and other investments.
Cash Flow used in Financing Activities
Cash flow used in financing activities was $5.537 billion in 2019, compared to $4.426 billion in 2018. The increase was primarily due to a net decrease in short-term debt, lease liability payments, and an increase in dividends paid, partially offset by a decrease in the purchase of the company's own common shares under its normal course issuer bid (NCIB), and a net increase of long-term debt in 2019.
Management of debt levels continues to be a priority for Suncor given the company's long-term growth plans and future expected volatility in the pricing environment. Suncor believes a phased and flexible approach to existing and future growth projects should assist the company in maintaining its ability to manage project costs and debt levels.
Capital Resources
Suncor's capital resources consist primarily of cash flow provided by operating activities, cash and cash equivalents
50 2019 ANNUAL REPORT Suncor Energy Inc.
and available credit facilities, including commercial paper. Suncor's management believes the company will have the capital resources to fund its planned 2020 capital spending program of $5.4 to $6.0 billion and to meet current and future working capital requirements through cash and cash equivalents balances, cash flow provided by operating activities, available committed credit facilities, issuing commercial paper and accessing capital markets. The company's cash flow provided by operating activities depends on a number of factors, including commodity prices, production and sales volumes, refining and marketing margins, operating expenses, taxes, royalties and foreign exchange rates.
The company has invested excess cash in short-term financial instruments that are presented as cash and cash equivalents. The objectives of the company's short-term investment portfolio are to ensure the preservation of capital, maintain adequate liquidity to meet Suncor's cash flow requirements and deliver competitive returns derived from the quality and diversification of investments within acceptable risk parameters. The maximum weighted average term to maturity of the short-term investment portfolio is not expected to exceed six months, and all investments will be with counterparties with investment grade debt ratings.
Available Sources of Liquidity
Cash and Cash Equivalents
Included in cash and cash equivalents of $1.960 billion at December 31, 2019 are short-term investments with weighted average days to maturity of approximately 17 days. In 2019, the company earned approximately $38 million of interest income on these investments.
Financing Activities
Suncor's interest on debt and lease liabilities (before capitalized interest) in 2019 was $997 million, an increase from $897 million in 2018, due to the issuance of $750 million of new debt, the transition to IFRS 16 and the unfavourable impact of a weaker average Canadian dollar on U.S. dollar denominated debt, partially offset by the significant decrease in short-term debt in 2019 and the repayment of US$140 million of higher interest rate long-term debt.
Available lines of credit at December 31, 2019 increased to $4.701 billion, compared to $3.608 billion at December 31, 2018, primarily as a result of the repayment of short-term indebtedness.
A summary of total and unutilized credit facilities at December 31, 2019 is as follows:
($ millions) | 2019 | |||
|
||||
Fully revolving and expires in 2023 | 3 500 | |||
|
||||
Fully revolving and expires in 2022 | 3 241 | |||
|
||||
Fully revolving and expires in 2021 | 1 455 | |||
|
||||
Can be terminated at any time at the option of the lenders | 132 | |||
|
||||
Total credit facilities | 8 328 | |||
|
||||
Credit facilities supporting outstanding commercial paper | (2 155 | ) | ||
|
||||
Credit facilities supporting standby letters of credit | (1 284 | ) | ||
|
||||
Total unutilized credit facilities(1) | 4 889 | |||
|
Total Debt to Total Debt Plus Shareholders' Equity
Suncor is subject to financial and operating covenants related to its bank debt and public market debt. Failure to meet the terms of one or more of these covenants may constitute an Event of Default as defined in the respective debt agreements, potentially resulting in accelerated repayment of one or more of the debt obligations. The company is in compliance with its financial covenant that requires total debt to not exceed 65% of its total debt plus shareholders' equity. At December 31, 2019, total debt to total debt plus shareholders' equity was 29.9% (December 31, 2018 28.3%) and increased due to the implementation of IFRS 16 and impairment charges recorded in 2019. The company is currently in compliance with all operating covenants as at December 31, 2019.
At December 31
($ millions, except as noted) |
2019 | 2018(1) | ||||
|
||||||
Short-term debt | 2 155 | 3 231 | ||||
|
||||||
Current portion of long-term debt | | 191 | ||||
|
||||||
Current portion of long-term lease liabilities | 310 | 38 | ||||
|
||||||
Long-term debt | 12 884 | 12 668 | ||||
|
||||||
Long-term lease liabilities | 2 621 | 1 222 | ||||
|
||||||
Total debt | 17 970 | 17 350 | ||||
|
||||||
Less: Cash and cash equivalents | 1 960 | 2 221 | ||||
|
||||||
Net debt | 16 010 | 15 129 | ||||
|
||||||
Shareholders' equity | 42 042 | 44 005 | ||||
|
||||||
Total debt plus shareholders' equity | 60 012 | 61 355 | ||||
|
||||||
Total debt to total debt plus shareholders' equity (%) | 29.9 | 28.3 | ||||
|
2019 ANNUAL REPORT Suncor Energy Inc. 51
Change in Net Debt
($ millions) | ||||
|
||||
Total debt December 31, 2018 | 17 350 | |||
|
||||
Increase in long-term debt | 557 | |||
|
||||
Decrease in short-term debt | (982 | ) | ||
|
||||
January 1, 2019 increase in lease liabilities associated with IFRS 16 | 1 792 | |||
|
||||
Increase in lease liability during the year | 186 | |||
|
||||
Lease payments | (307 | ) | ||
|
||||
Foreign exchange on debt, and other | (626 | ) | ||
|
||||
Total debt December 31, 2019 | 17 970 | |||
|
||||
Less: Cash and cash equivalents December 31, 2019 | 1 960 | |||
|
||||
Net debt December 31, 2019 | 16 010 | |||
|
At December 31, 2019, Suncor's net debt was $16.010 billion, compared to $15.129 billion at December 31, 2018. During 2019, total debt increased by $620 million, primarily due to the impact of the adoption of IFRS 16, which added $1.792 billion in lease liability to the company's balance sheet, a net increase in long-term debt and additional leases entered into in 2019, partially offset by the repayment of $982 million of short-term debt, favourable foreign exchange rates on U.S. dollar denominated debt, as compared to December 31, 2018, and lease principal payments made in 2019.
For the year ended December 31, 2019, the company's net debt to funds from operations measure was 1.5 times, which is lower than management's maximum target of less than 3.0 times.
Credit Ratings
The company's credit ratings impact its cost of funds and liquidity. In particular, the company's ability to access unsecured funding markets and to engage in certain activities on a cost-effective basis is primarily dependent upon maintaining a strong credit rating. A lowering of the company's credit rating may also have potentially adverse consequences for the company's funding capacity or access to the capital markets, may affect the company's ability, and the cost, to enter into normal course derivative or hedging transactions, and may require the company to post additional collateral under certain contracts.
As at February 26, 2020, the company's long-term senior debt ratings are:
Long-Term Senior Debt | Rating |
Long-Term
Outlook |
|||
|
|||||
Standard & Poor's | A- | Stable | |||
|
|||||
Dominion Bond Rating Service | A (low | ) | Stable | ||
|
|||||
Moody's Investors Service | Baa1 | Stable | |||
|
As at February 26, 2020, the company's commercial paper ratings are:
Commercial Paper |
Cdn
Program Rating |
U.S.
Program Rating |
||
|
||||
Standard & Poor's | A-1 (low | ) | A-2 | |
|
||||
Dominion Bond Rating Service | R-1 (low | ) | Not rated | |
|
||||
Moody's Investors Service | Not rated | P2 | ||
|
Refer to the Description of Capital Structure Credit Ratings section of Suncor's 2019 AIF for a description of credit ratings listed above.
Common Shares
Outstanding Shares
(thousands) | December 31, 2019 | ||
|
|||
Common shares | 1 531 874 | ||
|
|||
Common share options exercisable | 21 535 | ||
|
|||
Common share options non-exercisable | 12 347 | ||
|
As at February 25, 2020, the total number of common shares outstanding was 1,526,810,321 and the total number of exercisable and non-exercisable common share options outstanding was 33,019,526. Once exercisable, each outstanding common share option may be exercised for one common share.
Share Repurchases
In May 2019, Suncor renewed its NCIB to continue to repurchase its common shares through the facilities of the Toronto Stock Exchange (TSX), New York Stock Exchange and/or alternative trading platforms between May 6, 2019 and May 5, 2020. In December 2019, following the approval by Suncor's Board of Directors to increase the company's share repurchase program to $2.5 billion, the TSX accepted a notice filed by Suncor of its intention to amend its NCIB effective as of December 30, 2019. The notice provided that Suncor may increase the maximum number of common shares that may be purchased for cancellation between May 6, 2019 and May 5, 2020 from 50,252,231 common shares, or approximately 3% of Suncor's issued and outstanding common shares as at April 30, 2019, to
52 2019 ANNUAL REPORT Suncor Energy Inc.
78,549,178 common shares, or approximately 5% of Suncor's issued and outstanding common shares as at April 30, 2019. Suncor security holders may obtain a copy of the notice, without charge, by contacting the company.
Since commencing its share buyback program in 2011, Suncor has purchased 316,307,436 common shares as of February 25, 2020 for a total return to shareholders of $12.4 billion under this program, with close to half of these share repurchases occurring in the last 3 years. Subsequent to the end of the year, Suncor's Board of Directors approved a further share repurchase program of up to $2 billion.
Contractual Obligations, Commitments, Guarantees, and Off-Balance Sheet Arrangements
In addition to the enforceable and legally binding obligations in the table below, Suncor has other obligations for goods and services that were entered into in the normal course of business, which may terminate on short notice, including commitments for the purchase of commodities for which an active, highly liquid market exists, and which are expected to be re-sold shortly after purchase.
The company does not believe it has any guarantees or off-balance sheet arrangements that have, or are reasonably likely to have, a current or future material effect on the company's financial condition or financial performance, including liquidity and capital resources.
In the normal course of business, the company is obligated to make future payments, including contractual obligations and non-cancellable commitments.
Payment due by period | |||||||||||||||
($ millions) | 2020 | 2021 | 2022 | 2023 | 2024 | Thereafter | Total | ||||||||
|
|||||||||||||||
Fixed and revolving term debt(1) | 722 | 2 127 | 864 | 625 | 1 594 | 17 183 | 23 115 | ||||||||
|
|||||||||||||||
Decommissioning and restoration costs(2) | 482 | 230 | 252 | 239 | 241 | 11 492 | 12 936 | ||||||||
|
|||||||||||||||
Long-term contracts, pipeline capacity and energy services commitments(3) | 1 772 | 1 372 | 1 305 | 1 315 | 1 229 | 10 084 | 17 077 | ||||||||
|
|||||||||||||||
Exploration work commitments | 7 | 44 | | | | 465 | 516 | ||||||||
|
|||||||||||||||
Other long-term obligations(4) | 2 | 20 | 20 | 20 | 19 | | 81 | ||||||||
|
|||||||||||||||
Total(5) | 2 985 | 3 793 | 2 441 | 2 199 | 3 083 | 39 224 | 53 725 | ||||||||
|
Transactions with Related Parties
The company enters into transactions with related parties in the normal course of business. These transactions primarily include sales to associated entities in the company's R&M segment and service provisions to Fort Hills. For more information on these transactions and for a summary of Compensation of Key Management Personnel, refer to note 30 to the 2019 audited Consolidated Financial Statements.
Financial Instruments
The company uses derivative financial instruments, such as physical and financial contracts, to manage certain exposures to fluctuations in interest rates, commodity prices and foreign currency exchange rates, as part of its overall risk management program, as well as for trading purposes. For the year ended December 31, 2019, the pre-tax earnings impact of risk management and trading activities was $155 million (2018 pre-tax earnings of $255 million).
Gains or losses related to derivatives are recorded as Other Income in the Consolidated Statements of Comprehensive Income.
2019 ANNUAL REPORT Suncor Energy Inc. 53
($ millions) | 2019 | 2018 | |||||
|
|||||||
Fair value outstanding, beginning of year | 60 | (105 | ) | ||||
|
|||||||
Cash settlements received during the year | (254 | ) | (90 | ) | |||
|
|||||||
Changes in fair value recognized in earnings during the year | 155 | 255 | |||||
|
|||||||
Fair value outstanding, end of year | (39 | ) | 60 | ||||
|
The fair value of derivative financial instruments is recorded on the Consolidated Balance Sheets.
Fair value of derivative contracts at
|
2019 | 2018 | ||||
|
||||||
Accounts receivable | 94 | 215 | ||||
|
||||||
Accounts payable | (133 | ) | (155 | ) | ||
|
||||||
(39 | ) | 60 | ||||
|
Risks Associated with Derivative Financial Instruments
Suncor may be exposed to certain losses in the event that counterparties to derivative financial instruments are unable to fulfil their obligations under these contracts. The company minimizes this risk by entering into agreements with investment grade counterparties. Risk is also minimized through regular management review of the potential exposure to and credit ratings of such counterparties. Suncor's exposure is limited to those counterparties holding derivative contracts with net positive fair values at a reporting date.
Suncor's risk management activities are subject to periodic reviews by management to determine appropriate hedging requirements based on the company's tolerance for exposure to market volatility, as well as the need for stable cash flow to finance future growth. Commodity risk management and trading activities are governed by a separate risk management group that reviews and monitors practices and policies and provides independent verification and valuation of these activities.
For further details on our derivative financial instruments, including assumptions made in the calculation of fair value, a sensitivity analysis of the effect of changes in commodity prices on our derivative financial instruments, and additional discussion of exposure to risks and mitigation activities, refer to note 26 to the company's 2019 audited Consolidated Financial Statements.
54 2019 ANNUAL REPORT Suncor Energy Inc.
9. ACCOUNTING POLICIES AND CRITICAL ACCOUNTING ESTIMATES
Suncor's significant accounting policies are described in note 3 to the audited Consolidated Financial Statements for the year ended December 31, 2019.
Adoption of New IFRS Standards
IFRS 16 Leases
Effective January 1, 2019, the company adopted IFRS 16 which replaces IAS 17 and requires the recognition of most leases on the balance sheet. IFRS 16 effectively removes the classification of leases as either finance or operating leases and treats all leases as finance leases for lessees with optional exemptions for short-term leases where the term is twelve months or less. The accounting treatment for lessors remains essentially unchanged, with the requirement to classify leases as either finance or operating.
The company has selected the modified retrospective transition approach, electing to adjust opening retained earnings with no restatement of comparative figures. As such, comparative information continues to be reported under IAS 17 and IFRIC 4. The details of accounting policies under IAS 17 and IFRIC 4 are disclosed separately if they are different from those under IFRS 16 and the impact of the change is disclosed below.
The company's accounting policy under IFRS 16 is as follows:
At inception of a contract, the company assesses whether a contract is, or contains, a lease based on whether the contract conveys the right to control the use of an identified asset for a period of time in exchange for consideration.
The company recognizes a right-of-use asset and a lease liability at the lease commencement date. The right-of-use asset is initially measured based on the initial amount of the lease liability adjusted for any lease payments made at or before the commencement date, plus any initial direct costs incurred and an estimate of costs to dismantle and remove the underlying asset or to restore the underlying asset or the site on which it is located, less any lease incentives received. The assets are depreciated to the earlier of the end of the useful life of the right-of-use asset or the lease term, where judgment is applied to determine the lease term of the lease contracts in which the company has a renewal option, using the straight-line method as this most closely reflects the expected pattern of consumption of the future economic benefits. In addition, the right-of-use assets may be periodically reduced by impairment losses, if any, and adjusted for certain remeasurements of the lease liability.
The lease liability is initially measured at the present value of the lease payments that are not paid at the commencement date, discounted using the interest rate implicit in the lease or, if that rate cannot be readily determined, the company's incremental borrowing rate. Lease payments include fixed payments, and variable payments that are based on an index or rate.
Cash payments for the principal portion of the lease liability are presented within the financing activities section and the interest portion of the lease liability is presented within the operating activities section of the statement of cash flows. Short-term lease payments and variable lease payments not included in the measurement of the lease liability are presented within the operating activities section of the statement of cash flows.
The lease liability is measured at amortized cost using the effective interest method. It is remeasured when there is a change in future lease payments arising from a change in an index or rate, if there is a change in the company's estimate of the amount expected to be payable under a residual value guarantee, or if the company changes its assessment of whether it will exercise a purchase, extension or termination option.
When the lease liability is remeasured in this way, a corresponding adjustment is made to the carrying amount of the right-of- use asset, or is recorded in profit or loss if the carrying amount of the right-of-use asset has been reduced to zero.
Under IAS 17
In the comparative period, the company classified leases that transferred substantially all of the risks and rewards of ownership as finance leases. When this was the case, the leased assets were measured initially at an amount equal to the lower of their fair value and the present value of minimum lease payments. Minimum lease payments were the payments over the lease term that the lessee was required to make, excluding any contingent rent.
Subsequently, the assets were accounted for in accordance with the accounting policy applicable to that asset.
Assets held under other leases were classified as operating leases and were not recognized in the company's statement of financial position. Payments made under operating leases were recognized in profit or loss on a straight-line basis over the term of the lease. Lease incentives received were recognized as an integral part of the total lease expense over the term of the lease.
As part of the initial application of IFRS 16, the company also chose to apply the following transitional provisions:
Right-of-use assets are measured at:
2019 ANNUAL REPORT Suncor Energy Inc. 55
The company applied the following practical expedients when applying IFRS 16 to leases previously classified as operating leases under IAS 17:
The following table summarizes the impact of adopting IFRS 16 on the company's Consolidated Balance Sheets at January 1, 2019. Prior period amounts have not been restated. The effects of the transition have been recognized through retained earnings in equity.
($ millions) Increase (Decrease) |
December 31
2018 |
Adjustments due
to IFRS 16 |
January 1
2019 |
||||||
|
|||||||||
Assets | |||||||||
|
|||||||||
Current assets | |||||||||
|
|||||||||
Accounts receivable | 3 206 | (2 | ) | 3 204 | |||||
|
|||||||||
Property, plant and equipment, net | 74 245 | (1 267 | ) | 72 978 | |||||
|
|||||||||
Right-of-use assets, net | | 3 059 | 3 059 | ||||||
|
|||||||||
Liabilities and Shareholders' Equity | |||||||||
|
|||||||||
Current liabilities | |||||||||
|
|||||||||
Current portion of long-term debt | 229 | (38 | ) | 191 | |||||
|
|||||||||
Current portion of lease liabilities | | 276 | 276 | ||||||
|
|||||||||
Current portion of provisions | 667 | (1 | ) | 666 | |||||
|
|||||||||
Long-term debt | 13 890 | (1 222 | ) | 12 668 | |||||
|
|||||||||
Long-term lease liabilities | | 2 777 | 2 777 | ||||||
|
|||||||||
Other long-term liabilities | 2 346 | (1 | ) | 2 345 | |||||
|
|||||||||
Provisions | 6 984 | (20 | ) | 6 964 | |||||
|
|||||||||
Deferred income taxes | 12 045 | 5 | 12 050 | ||||||
|
|||||||||
Equity | 44 005 | 14 | 44 019 | ||||||
|
The following table reconciles the company's operating lease commitments as at December 31, 2018, as previously disclosed in the company's Consolidated Financial Statements as at and for the year ended December 31, 2018, to the additional lease liabilities recognized on initial application of IFRS 16 as at January 1, 2019.
Reconciliation
($ millions) |
January 1
2019 |
|||
|
||||
Operating leases as at December 31, 2018(1) | 2 457 | |||
|
||||
Exemption for short-term leases | (42 | ) | ||
|
||||
Discounting | (623 | ) | ||
|
||||
Additional lease liabilities recognized due to adoption of IFRS 16 as at January 1, 2019 | 1 792 | |||
|
For leases that were previously classified as finance leases under IAS 17, within Property, Plant and Equipment, the carrying amount of the right-of-use asset and the lease liability recognized upon initial application as at January 1, 2019 was determined to be the carrying amount of the finance lease asset and liability under IAS 17 immediately before transition.
The lease liabilities recognized in accordance with IFRS 16 were discounted using the company's incremental borrowing rate upon initial application. The weighted average discount rate used for additional leases recognized as a result of application of IFRS 16 was 3.85% as at January 1, 2019.
56 2019 ANNUAL REPORT Suncor Energy Inc.
Uncertainty over Income Tax Treatments
In June 2017, the IASB issued IFRIC 23 Uncertainty over Income Tax Treatments. The interpretation clarifies the accounting for current and deferred tax liabilities and assets in circumstances in which there is uncertainty over income tax treatments. The interpretation requires an entity to consider whether it is probable that a taxation authority will accept an uncertain tax treatment. If the entity considers it to be not probable that a taxation authority will accept an uncertain tax provision, the interpretation requires the entity to use the most likely amount or the expected value. The company adopted the amendment on its effective date of January 1, 2019. The adoption of this amendment did not have any impact on the company's consolidated financial statements.
Recently Announced Accounting Pronouncements
The standards, amendments and interpretations that are issued, but not yet effective up to the date of authorization of the company's 2019 audited Consolidated Financial Statements, and that may have an impact on the disclosures and financial position of the company are disclosed below. The company intends to adopt these standards, amendments and interpretations when they become effective.
Definition of a Business
In October 2018, the IASB issued Definition of a Business (Amendments to IFRS 3). The amendments narrowed and clarified the definition of a business. The amendments include an election to use a concentration test. This is a simplified assessment that results in an asset acquisition if substantially all of the fair value of the gross assets is concentrated in a single identifiable asset or a group of similar identifiable assets. If an election to use a concentration test is not made, or the test failed, then the assessment focuses on the existence of a substantive process. One important distinction is that "goodwill" can only be recognized as a result of acquiring a business, but not as a result of an asset acquisition. The amendments are effective for annual periods beginning on or after January 1, 2020 and are to be applied prospectively.
Significant Accounting Estimates and Judgments
The preparation of financial statements in accordance with IFRS requires management to make estimates and judgments that affect reported assets, liabilities, revenues, expenses, gains, losses, and disclosures of contingencies. These estimates and judgments are subject to change based on experience and new information. The financial statement areas that require significant estimates and judgments are as follows:
Oil and Gas Reserves
The company's estimate of oil and gas reserves is considered in the measurement of depletion, depreciation, impairment, and decommissioning and restoration obligations. The estimation of reserves is an inherently complex process and involves the exercise of professional judgment. All reserves have been evaluated at December 31, 2019 by independent qualified reserves evaluators. Oil and gas reserves estimates are based on a range of geological, technical and economic factors, including projected future rates of production, projected future commodity prices, engineering data, and the timing and amount of future expenditures, all of which are subject to uncertainty. Estimates reflect market and regulatory conditions existing at December 31, 2019, which could differ significantly from other points in time throughout the year, or future periods. Changes in market and regulatory conditions and assumptions can materially impact the estimation of net reserves.
Oil and Gas Activities
The company is required to apply judgment when designating the nature of oil and gas activities as exploration, evaluation, development or production, and when determining whether the costs of these activities shall be expensed or capitalized.
Exploration and Evaluation Costs
Certain exploration and evaluation costs are initially capitalized with the intent to establish commercially viable reserves. The company is required to make judgments about future events and circumstances and applies estimates to assess the economic viability of extracting the underlying resources. The costs are subject to technical, commercial and management review to confirm the continued intent to develop the project. Level of drilling success or changes to project economics, resource quantities, expected production techniques, production costs and required capital expenditures are important judgments when making this determination. Management uses judgment to determine when these costs are reclassified to Property, Plant and Equipment based on several factors, including the existence of reserves, appropriate approvals from regulatory bodies, joint arrangement partners and the company's internal project approval process.
Determination of Cash Generating Units (CGUs)
A CGU is the lowest grouping of integrated assets that generate identifiable cash inflows that are largely independent of the cash inflows of other assets or groups of assets. The allocation of assets into CGUs requires significant judgment and interpretations with respect to the integration between assets, the existence of active markets, similar exposure to market risks, shared infrastructure, and the way in which management monitors the operations.
Asset Impairment and Reversals
Management applies judgment in assessing the existence of impairment and impairment reversal indicators based on various internal and external factors.
2019 ANNUAL REPORT Suncor Energy Inc. 57
The recoverable amount of CGUs and individual assets is determined based on the higher of fair value less costs of disposal or value in use calculations. The key estimates the company applies in determining the recoverable amount normally include estimated future commodity prices, discount rates, expected production volumes, future operating and development costs, tax rates, and refining margins. In determining the recoverable amount, management may also be required to make judgments regarding the likelihood of occurrence of a future event. Changes to these estimates and judgments will affect the recoverable amounts of CGUs and individual assets and may then require a material adjustment to their related carrying value.
Decommissioning and Restoration Costs
The company recognizes liabilities for the future decommissioning and restoration of Exploration and Evaluation assets and Property, Plant and Equipment based on estimated future decommissioning and restoration costs. Management applies judgment in assessing the existence and extent as well as the expected method of reclamation of the company's decommissioning and restoration obligations at the end of each reporting period. Management also uses judgment to determine whether the nature of the activities performed is related to decommissioning and restoration activities or normal operating activities.
Actual costs are uncertain and estimates may vary as a result of changes to relevant laws and regulations related to the use of certain technologies, the emergence of new technology, operating experience, prices and closure plans. The estimated timing of future decommissioning and restoration may change due to certain factors, including reserves life. Changes to estimates related to future expected costs, discount rates, inflation assumptions, and timing may have a material impact on the amounts presented.
Employee Future Benefits
The company provides benefits to employees, including pensions and other post-retirement benefits. The cost of defined benefit pension plans and other post-retirement benefits received by employees is estimated based on actuarial valuation methods that require professional judgment. Estimates typically used in determining these amounts include, as applicable, rates of employee turnover, future claim costs, discount rates, future salary and benefit levels, the return on plan assets, mortality rates and future medical costs. Changes to these estimates may have a material impact on the amounts presented.
Other Provisions
The determination of other provisions, including, but not limited to, provisions for royalty disputes, onerous contracts, litigation and constructive obligations, is a complex process that involves judgment about the outcomes of future events, the interpretation of laws and regulations, and estimates on the timing and amount of expected future cash flows and discount rates.
Income Taxes
Management evaluates tax positions, annually or when circumstances require, which involves judgment and could be subject to differing interpretations of applicable tax legislation. The company recognizes a tax provision when a payment to tax authorities is considered probable. However, the results of audits and reassessments and changes in the interpretations of standards may result in changes to those positions and, potentially, a material increase or decrease in the company's assets, liabilities and net earnings.
Deferred Income Taxes
Deferred tax assets are recognized when it is considered probable that deductible temporary differences will be recovered in the foreseeable future. To the extent that future taxable income and the application of existing tax laws in each jurisdiction differ significantly from the company's estimate, the ability of the company to realize the deferred tax assets could be impacted.
Deferred tax liabilities are recognized when there are taxable temporary differences that will reverse and result in a future outflow of funds to a taxation authority. The company records a provision for the amount that is expected to be settled, which requires judgment as to the ultimate outcome. Deferred tax liabilities could be impacted by changes in the company's judgment of the likelihood of a future outflow and estimates of the expected settlement amount, timing of reversals, and the tax laws in the jurisdictions in which the company operates.
Fair Value of Financial Instruments
The fair value of a financial instrument is determined, whenever possible, based on observable market data. If not available, the company uses third-party models and valuation methodologies that utilize observable market data that includes forward commodity prices, foreign exchange rates and interest rates to estimate the fair value of financial instruments, including derivatives. In addition to market information, the company incorporates transaction-specific details that market participants would utilize in a fair value measurement, including the impact of non-performance risk.
Functional Currency
The designation of the functional currency of the company and each of its subsidiaries is a management judgment based on the composition of revenue and costs in the locations in which it operates.
58 2019 ANNUAL REPORT Suncor Energy Inc.
Suncor is committed to a proactive program of enterprise risk management intended to enable decision-making through consistent identification and assessment of risks inherent to its assets, activities and operations. Some of these risks are common to operations in the oil and gas industry as a whole, while some are unique to Suncor. The realization of any of the following risks could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Volatility of Commodity Prices
Suncor's financial performance is closely linked to prices for crude oil in the company's upstream business and prices for refined petroleum products in the company's downstream business and, to a lesser extent, to natural gas and electricity prices in the company's upstream business where natural gas and power are both inputs and outputs of production processes. The prices for all of these commodities can be influenced by global and regional supply and demand factors, which are factors that are beyond the company's control and can result in a high degree of price volatility.
Crude oil prices are also affected by, among other things, global economic health (particularly in emerging markets), market access constraints, regional and international supply and demand imbalances, political developments and government action (including the mandatory production curtailments recently imposed by the Government of Alberta), decisions by OPEC to not impose quotas on its members, compliance or non-compliance with quotas agreed upon by OPEC members and other countries, and weather. These factors impact the various types of crude oil and refined products differently and can impact differentials between light and heavy grades of crude oil (including blended bitumen), and between conventional oil and SCO.
Refined petroleum product prices and refining margins are also affected by, among other things, crude oil prices, the availability of crude oil and other feedstock, levels of refined product inventories, regional refinery availability, market access, marketplace competitiveness, and other local market factors. Natural gas prices in North America are affected by, among other things, supply and demand, and by prices for alternative energy sources. Decreases in product margins or increases in natural gas prices could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
In addition, oil and natural gas producers in North America, and particularly in Canada, may receive discounted prices for their production relative to certain international prices, due in part to constraints on the ability to transport and sell such products to international markets. A failure to resolve such constraints may result in continued discounted or reduced commodity prices realized by oil and natural gas producers such as Suncor. Suncor's production from Oil Sands includes significant quantities of bitumen and SCO that may trade at a discount to light and medium crude oil. Bitumen and SCO are typically more expensive to produce and process. In addition, the market prices for these products may differ from the established market indices for light and medium grades of crude oil. As a result, the price received for bitumen and SCO may differ from the benchmark they are priced against. Future quality differentials are uncertain and unfavourable differentials could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
In the fourth quarter of 2018, there was insufficient market access capacity to remove production from the Western Canada Sedimentary Basin causing the differential between WTI and WCS to widen significantly. The situation triggered a response from the Government of Alberta in the form of a mandatory production curtailment, which commenced in early 2019. Such circumstances may result in worsening and/or prolonged price volatility and/or further negative impacts on market dynamics that cannot currently be fully anticipated. Wide differentials, such as those experienced in the fourth quarter of 2018 or a prolonged period of low and/or volatile commodity prices, particularly for crude oil, could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations, and may also lead to the impairment of assets, or to the cancellation or deferral of Suncor's growth projects.
Market Access
Suncor's production of bitumen is expected to grow. The markets for bitumen blends or heavy crude oil are more limited than those for light crude oil, making them more susceptible to supply and demand changes and imbalances (whether as a result of the availability, proximity, and capacity of pipeline facilities, railcars, or otherwise). Heavy crude oil generally receives lower market prices than light crude, due principally to the lower quality and value of the refined product yield and the higher cost to transport the more viscous product on pipelines, and this price differential can be amplified due to supply and demand imbalances.
Market access for Suncor's oil sands production may be constrained by insufficient pipeline takeaway capacity, including the lack of new pipelines due to an inability to secure required approvals and negative public perception. There is a risk that constrained market access for oil sands production, growing inland production and refinery outages could create widening differentials that could impact the profitability of product sales. Market access for refined products may also be constrained by insufficient takeaway capacity, which could create a supply/demand imbalance. The occurrence of any of the foregoing could have a material
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adverse effect on the company's business, financial condition, reserves and results of operations.
Major Operational Incidents (Safety, Environmental and Reliability)
Each of Suncor's primary operating businesses Oil Sands, E&P, and Refining and Marketing requires significant levels of investment in the design, operation, and maintenance and decommissioning of facilities, and carries the additional economic risk associated with operating reliably or enduring a protracted operational outage. The breadth and level of integration of Suncor's operations adds complexity.
The company's businesses also carry the risks associated with environmental and safety performance, which is closely scrutinized by governments, the public and the media, and could result in a suspension of or inability to obtain regulatory approvals and permits, or, in the case of a major environmental or safety incident, delays in resuming normal operations, fines, civil suits or criminal charges against the company.
In general, Suncor's operations are subject to operational hazards and risks such as, among others, fires (including forest fires), explosions, blow-outs, power outages, prolonged periods of extreme cold or extreme heat, severe winter climate conditions, flooding, droughts and other extreme weather conditions, railcar incidents or derailments, the migration of harmful substances such as oil spills, gaseous leaks or a release of tailings into water systems, pollution and other environmental risks, and accidents, any of which can interrupt operations or cause personal injury or death, or damage to property, equipment (including information technology and related data and controls systems), and the environment.
The reliable operation of production and processing facilities at planned levels and Suncor's ability to produce higher value products can also be impacted by, among other things, failure to follow the company's policies, standards and operating procedures or operate within established operating parameters, equipment failure through inadequate maintenance, unanticipated erosion or corrosion of facilities, manufacturing and engineering flaws, and labour shortage or interruption. The company is also subject to operational risks such as sabotage, terrorism, trespass, theft and malicious software, network or cyber attacks.
In addition to the foregoing factors that affect Suncor's business generally, each business unit is susceptible to additional risks due to the nature of its business, including, among others, the following:
Although the company maintains a risk management program, which includes an insurance component, such insurance may not provide comprehensive coverage in all circumstances, nor are all such risks insurable. The company self-insures some risks, and the company's insurance coverage does not cover all the costs arising out of the allocation of liabilities and risk of loss arising from Suncor operations.
The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Government/Regulatory and Policy Effectiveness
Suncor's businesses operate under federal, provincial, territorial, state and municipal laws in numerous countries. The company is also subject to regulation and intervention by governments in oil and gas industry matters, such as, among others, land tenure, royalties, taxes (including income taxes), government fees, production rates (including restrictions on production), environmental protection, wildlife, fish, safety performance, the reduction of GHG and other emissions, the export of crude oil, natural gas and other products, interactions with foreign governments, the
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awarding or acquisition of exploration and production rights, oil sands leases or other interests, the imposition of specific drilling obligations, control over the development, reclamation and abandonment of fields and mine sites, mine financial security requirements, approval of logistics infrastructure, and possibly expropriation or cancellation of contract rights. As part of ongoing operations, the company is also required to comply with a large number of EH&S regulations under a variety of Canadian, U.S., U.K., Norwegian and other foreign, federal, provincial, territorial, state and municipal laws and regulations. Failure to comply with applicable laws and regulations may result in, among other things, the imposition of fines and penalties, production constraints, a compulsory shutdown of facilities or suspension of operations, reputational damage, delays, increased costs, denial of operating and growth permit applications, censure, liability for cleanup costs and damages, and the loss of important licences and permits.
Before proceeding with most major projects, including significant changes to existing operations, Suncor must obtain various federal, provincial, territorial, state and municipal permits and regulatory approvals, and must also obtain licences to operate certain assets. These processes can involve, among other things, Indigenous and stakeholder consultation, environmental impact assessments and public hearings, government intervention and may be subject to conditions, including security deposit obligations and other commitments. Compliance can also be affected by the loss of skilled staff, inadequate internal processes and compliance auditing.
Failure to obtain, comply with, satisfy the conditions of or maintain regulatory permits, licences and approvals, or failure to obtain them on a timely basis or on satisfactory terms, could result in prosecution, fines, delays, abandonment or restructuring of projects and increased costs, all of which could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations. Suncor's businesses can also be indirectly impacted by a third party's inability to obtain regulatory approval for a shared infrastructure project or a third-party infrastructure project on which a portion of Suncor's business depends.
Changes in government policy, regulation or other laws, or the interpretation thereof, or opposition to Suncor's projects or third-party pipeline and infrastructure projects that delays or prevents necessary permits or regulatory approvals, or which makes current operations or growth projects less profitable or uneconomic could materially impact Suncor's operations, existing and planned projects, financial condition, reserves and results of operations. Obtaining necessary approvals or permits has become more difficult due to increased public opposition and Indigenous consultation requirements as well as increased political involvement. The federal government's Impact Assessment Act (formerly Bill C-69) also came into force in August 2019 and will impact the manner in which large energy projects are approved. This development could also lead to significant delays and additional compliance costs, and staffing and resource levels, and also increase exposure to other risks to Suncor's business, including environmental or safety non-compliance, permit approvals, and project development and execution, all of which could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Suncor is subject to the mandatory production curtailments imposed by the Government of Alberta that commenced in early 2019. The duration, extent and consequences of the curtailments to Suncor's business are not fully known; however, prolonged production curtailment or changes to the curtailment levels could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Greenhouse Gas Emissions and Targets
Among other sustainability goals, Suncor has committed to reducing the total GHG emissions intensity of its oil and gas petroleum products by 30% by 2030 (based on a 2014 baseline year). Our ability to lower GHG emissions on both an absolute basis and in respect of our 2030 total emissions reduction target is subject to numerous risks and uncertainties and our actions taken in implementing these objectives may also expose us to certain additional and/or heightened financial and operational risks.
A reduction in GHG emissions relies on, among other things, our ability to implement and improve energy efficiency at all of our facilities, future development and growth opportunities, develop and deploy new technologies, invest in low-carbon power and transition to low-carbon fuels. In the event that we are unable to implement these strategies and technologies as planned without negatively impacting our expected operations or business plans, or in the event that such strategies or technologies do not perform as expected, we may be unable to meet our GHG targets or goals on the current timelines, or at all.
In addition, achieving our GHG emission reductions target and goals could require significant capital expenditures and resources, with the potential that the costs required to achieve our target and goals materially differ from our original estimates and expectations, which differences may be material. In addition, the shift in resources and focus towards emissions reduction could have a negative impact on our operating results. The overall final cost of investing in and implementing an emissions-intensity reduction strategy and technologies in furtherance of such strategy, and the resultant change in the deployment of our resources and focus, could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
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Competition
The global petroleum industry is highly competitive in many aspects, including the exploration for and the development of new sources of supply, the acquisition of crude oil and natural gas interests, and the refining, distribution and marketing of refined petroleum products. Suncor competes in virtually every aspect of its business with other energy companies. The petroleum industry also competes with other industries in supplying energy, fuel and related products to consumers. The increasing volatility of the political and social landscape at provincial, federal, territorial, state, municipal and international levels adds complexity.
For Suncor's Oil Sands business, it is difficult to assess the number, level of production and ultimate timing of all potential new projects or when existing production levels may increase. Although current commodity pricing and increased regulatory requirements have slowed certain larger projects in the short term, an increase in the level of activity may have an impact on regional infrastructure, including pipelines, and could place stress on the availability and cost of all resources required to build and run new and existing oil sands operations.
For Suncor's Refining and Marketing business, management expects that fluctuations in demand for refined products, margin volatility and overall marketplace competitiveness will continue. In addition, to the extent that the company's downstream business unit participates in new product markets, it could be exposed to margin risk and volatility from either cost and/or selling price fluctuations.
There is a risk that increased competition could cause costs to increase, put further strain on existing infrastructure and cause margins for refined and unrefined products to be volatile, and impact demand for Suncor's products, which could have a material adverse effect on Suncor's business, financial condition and results of operations.
Carbon Risk
Public support for climate change action and receptivity to alternative/renewable energy technologies has grown in recent years. Governments in Canada and around the world have responded to these shifting societal attitudes by adopting ambitious emissions reduction targets and supporting legislation, including measures relating to carbon pricing, clean energy and fuel standards, and alternative energy incentives and mandates. There has also been increased activism and public opposition to fossil fuels, and oil sands in particular.
Existing and future laws and regulations may impose significant liabilities on a failure to comply with their requirements. Concerns over climate change, fossil fuel extraction, GHG emissions, and water and land-use practices could lead governments to enact additional or more stringent laws and regulations applicable to Suncor and other companies in the energy industry in general, and in the oil sands industry in particular.
Changes to environmental regulations, including regulation relating to climate change, could impact the demand for, formulation or quality of the company's products, or could require increased capital expenditures, operating expenses, abandonment and reclamation obligations and distribution costs, which may not be recoverable in the marketplace and which may result in current operations or growth projects becoming less profitable or uneconomic. In addition, such regulatory changes could necessitate that Suncor develop new technologies. Such technology development could require a significant investment of capital and resources, and any delay in or failure to identify and develop such technologies or obtain regulatory approvals for these technology projects could prevent Suncor from obtaining regulatory approvals for projects or being able to successfully compete with other companies. Increasing environmental regulation in the jurisdictions in which Suncor operates may also make it difficult for Suncor to compete with companies operating in other jurisdictions with fewer or less costly regulations. In addition, legislation or policies that limit the purchase of production from the oil sands may be adopted in domestic and/or foreign jurisdictions, which, in turn, may limit the world market for Suncor's upstream production and reduce the prices the company receives for its products, and could result in delayed development, stranded assets or the company being unable to further develop its resources. The complexity, breadth and velocity of changes in environmental regulation make it extremely difficult to predict the potential impact to Suncor.
Suncor continues to monitor the international and domestic efforts to address climate change. While it currently appears that GHG regulations and targets will continue to become more stringent, and while Suncor continues its efforts to reduce the intensity of its GHG emissions, the absolute GHG emissions of the company may rise as a result of growth. Increases in GHG emissions may impact the profitability of the company's projects, as Suncor will be subject to incremental levies and taxes. There is also a risk that Suncor could face litigation initiated by third parties relating to climate change, including litigation pertaining to GHG emissions, the production, sale, or promotion of fossil fuels and petroleum products, and/or disclosure. For example, the Board of County Commissioners of Boulder County, the Board of County Commissioners of San Miguel County and the City of Boulder, all of Colorado, have brought an action against Suncor and certain of its subsidiaries seeking, among other things, compensation for impacts they allege with respect to climate change. In addition, the mechanics of implementation and enforcement of the OSELA are currently under review and it is not yet possible to predict the impact on Suncor. However, such impact could be material.
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These developments and future developments could adversely impact the demand for Suncor's products, the ability of Suncor to maintain and grow its production and reserves, and Suncor's reputation, and could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Environmental Compliance
Tailings Management and Water Release
Each oil sands mine is required under the Tailings Directive to seek approval for its updated fluid tailings management plans. If a mine fails to meet a condition of its approved plan, the applicable company could be subject to enforcement actions, including being required to curtail production, and financial consequences, including being subject to a compliance levy or being required to post additional security under the MFSP. The full impact of the TMF, the Tailings Directive and updates to the dam regulations, including the financial consequences of exceeding compliance levels, is not yet fully known, as certain associated policy updates and regulation updates are still under development. Such updates could also restrict the technologies that the company may employ for tailings management, which could adversely impact the company's business plans. There could also be risks if the company's tailings management operations fail to operate as anticipated. The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
In addition, an integrated water management approach to support operations and successful reclamation and closure requires the release of treated oil sands mine water to the environment, which is not currently permitted for oil sands mines under existing laws. There is no certainty as to when regulations authorizing such water release would be enacted, the content of any such regulations, and the ability of and timing for the company to obtain the required approvals under such regulations to permit such water release. The absence of effective government regulations in this area could impact the success and timing of closure and reclamation plans, which could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Alberta's Land-Use Framework (LARP)
The implementation of, and compliance with, the terms of the LARP may adversely impact Suncor's current properties and projects in northern Alberta due to, among other things, environmental limits and thresholds. The impact of the LARP on Suncor's operations may be outside of the control of the company, as Suncor's operations could be impacted as a result of restrictions imposed due to the cumulative impact of development by the other operators in the area and not solely in relation to Suncor's direct impact. The uncertainty of changes in Suncor's future development and existing operations required as a result of the LARP could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Alberta Environment and Parks (AEP) Water Licences
Suncor currently relies on water obtained under licences from AEP to provide domestic and utility water for the company's Oil Sands business. Water licences, like all regulatory approvals, contain conditions to be met in order to maintain compliance with the licence. There can be no assurance that the licences to withdraw water will not be rescinded or that additional conditions will not be added. It is also possible that regional water management approaches may require water-sharing agreements between stakeholders. In addition, the expansion of the company's projects may rely on securing licences for additional water withdrawal, and there can be no assurance that these licences will be granted in a timely manner or that they will be granted on terms favourable to Suncor. There is also a risk that future laws or changes to existing laws or regulations relating to water access could cause capital expenditures and operating expenses relating to water licence compliance to increase. The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Species at Risk Act
Woodland caribou have been identified as "threatened" under the Species at Risk Act (Canada). In response to the Government of Canada's Recovery Strategy for Woodland Caribou, provincial caribou range plans are being developed. Suncor has existing, planned and potential future projects within caribou ranges in Alberta. The development and implementation of range plans in these areas may have an impact on the pace and amount of development in these areas and could potentially increase costs for restoration or offsetting requirements, which could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Air Quality Management
A number of Canadian federal and provincial air quality regulations and frameworks are currently being developed, changed and/or implemented, which could have an impact on the company's existing and planned projects by requiring the company to invest additional capital or incur additional operating and compliance expenses, including, among other things, potentially requiring the company to retrofit equipment to meet new requirements and increase monitoring and mitigation plans. The full impact of these regulations and frameworks is not yet known; however, they could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
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Alberta Wetland Policy
Pursuant to the Alberta Wetland Policy, development in wetland areas may be obligated to avoid wetlands or mitigate the development's effects on wetlands. Although the full impact of the policy on Suncor is not yet fully known, certain Suncor operations and growth projects will be affected by aspects of the policy where avoidance is not possible and wetland reclamation or replacement may be required, which could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Information Security
The efficient operation of Suncor's business is dependent on computer hardware, software and networked systems, including the systems of cloud providers and third parties with which Suncor conducts business. Digital transformation continues to increase the number of, and complexity of, such systems. In the ordinary course of Suncor's business, Suncor collects and stores sensitive data, including intellectual property, proprietary business information and personal information of the company's employees and retail customers. Suncor's operations are also dependent upon a large and complex information framework. Suncor relies on industry accepted security measures, controls and technology to protect Suncor's information systems and securely maintain confidential and proprietary information stored on the company's information systems, and has adopted a continuous process to identify, assess and manage threats to the company's information systems. While Suncor has an information and cyber security program in place, the measures, controls and technology on which the company relies may not be adequate due to the increasing volume, sophistication and rapidly evolving nature of cyber threats. Suncor's information technology and infrastructure, including process control systems, may be vulnerable to attacks by malicious persons or entities motivated by, among others, geopolitical, financial or activist reasons, or breached due to employee error, malfeasance or other disruptions, including natural disasters and acts of war. Any such attack or breach could compromise Suncor's networks, and the information Suncor stores could be accessed, publicly disclosed, lost, stolen or compromised. Any such attack, breach, access, disclosure or loss of information could result in legal claims or proceedings, liability under laws that protect the privacy of personal information, regulatory penalties, disruptions to Suncor's operations, decreased performance and production, increased costs, and damage to Suncor's reputation, physical harm to people or the environment, or other negative consequences to Suncor or third parties, which could have a material adverse effect on Suncor's business, financial condition and results of operations. Although the company maintains a risk management program, which includes an insurance component that may provide coverage for the operational impacts from an attack to, or breach of, Suncor's information technology and infrastructure, including process control systems, the company does not maintain stand-alone cyber insurance. Furthermore, not all cyber risks are insurable. As a result, Suncor's existing insurance may not provide adequate coverage for losses stemming from a cyber attack to, or breach of, its information technology and infrastructure.
Security and Terrorist Threats
Security threats and terrorist or activist activities may impact Suncor's personnel, which could result in injury, death, extortion, hostage situations and/or kidnapping, including unlawful confinement. A security threat, terrorist attack or activist incident targeted at a facility or office owned or operated by Suncor could result in the interruption or cessation of key elements of Suncor's operations. Outcomes of such incidents could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Project Development and Execution
There are certain risks associated with the development and execution of Suncor's major projects and the commissioning and integration of new facilities within its existing asset base.
Project development and execution risk consists of four related primary risks:
Project development and execution can also be impacted by, among other things:
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The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Technology Risk
There are risks associated with sustainability, growth and other capital projects that rely largely or partly on new technologies and the incorporation of such technologies into new or existing operations, including that the results of the application of new technologies may differ from simulated, test or pilot environments, or that third-party intellectual property protections may impede the development and implementation of new technology. The success of projects incorporating new technologies cannot be assured. Advantages accrue to companies that can develop and adopt emerging technologies in advance of competitors. The inability to develop, implement and monitor new technologies may impact the company's ability to develop its new or existing operations in a profitable manner or comply with regulatory requirements, which could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Cumulative Impact and Pace of Change
In order to achieve Suncor's business objectives, the company must operate efficiently, reliably and safely, and, at the same time, deliver growth and sustaining projects safely, on budget and on schedule. The ability to achieve these two sets of objectives is critically important for Suncor to deliver value to shareholders and stakeholders. These ambitious business objectives compete for resources, and may negatively impact the company should there be inadequate consideration of the cumulative impacts of prior and parallel initiatives on people, processes and systems. The establishment of the Transformation Management Office to support Suncor's digital transformation is expected to assist with the transformation, but there is still a risk that these objectives may exceed Suncor's capacity to adopt and implement change. The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Joint Arrangement Risk
Suncor has entered into joint arrangements and other contractual arrangements with third parties, including arrangements where other entities operate assets in which Suncor has ownership or other interests. These joint arrangements include, among others, those with respect to Syncrude, Fort Hills, In Situ assets, and operations in Suncor's E&P Canada and E&P International businesses. The success and timing of activities relating to assets and projects operated by others, or developed jointly with others, depend upon a number of factors that are outside of Suncor's control, including, among others, the timing and amount of capital expenditures, the timing and amount of operational and maintenance expenditures, the operator's expertise, financial resources and risk management practices, the approval of other participants, and the selection of technology.
These co-owners may have objectives and interests that do not coincide with and may conflict with Suncor's interests. Major capital decisions affecting joint arrangements may require agreement among the co-owners, while certain operational decisions may be made solely at the discretion of the operator of the applicable assets. While joint venture counterparties may generally seek consensus with respect to major decisions concerning the direction and operation of the assets and the development of projects, no assurance can be provided that the future demands or expectations of the parties relating to such assets and projects will be met satisfactorily or in a timely manner. Failure to satisfactorily meet demands or expectations by all of the parties may affect the company's participation in the operation of such assets or in the development of such projects, the company's ability to obtain or maintain necessary licences or approvals, or the timing for undertaking various activities. In addition, disputes may arise pertaining to the timing, scope, funding and/or capital commitments with respect to projects that are being jointly developed.
The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
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Financial Risks
Energy Trading and Risk Management Activities and the Exposure to Counterparties
The nature of Suncor's energy trading and risk management activities, which may make use of derivative financial instruments to manage its exposure to commodity price and other market risks, creates exposure to financial risks, which include, but are not limited to, the following:
The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition and results of operations.
Exchange Rate Fluctuations
The company's 2019 audited Consolidated Financial Statements are presented in Canadian dollars. The majority of Suncor's revenues from the sale of oil, natural gas and petroleum products are based on prices that are determined by, or referenced to, U.S. dollar benchmark prices, while the majority of Suncor's expenditures are realized in Canadian dollars. The company also owes a portion of its debt in U.S. dollars. Suncor's financial results, therefore, can be affected significantly by the exchange rates between the Canadian dollar and the U.S. dollar. The company also undertakes operations administered through international subsidiaries, and, therefore, to a lesser extent, Suncor's results can be affected by the exchange rates between the Canadian dollar and the euro, the British pound and the Norwegian krone. These exchange rates may vary substantially and may give rise to favourable or unfavourable foreign currency exposure. A decrease in the value of the Canadian dollar relative to the U.S. dollar will increase the revenues received from the sale of commodities. An increase in the value of the Canadian dollar relative to the U.S. dollar will decrease revenues received from the sale of commodities. A decrease in the value of the Canadian dollar relative to the U.S. dollar from the previous balance sheet date increases the amount of Canadian dollars required to settle U.S. dollar denominated obligations. As at December 31, 2019, the Canadian dollar strengthened in relation to the U.S. dollar to $0.77 from $0.73 at the start of 2019. Exchange rate fluctuations could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Interest Rate Risk
The company is exposed to fluctuations in short-term Canadian and U.S. interest rates as Suncor maintains a portion of its debt capacity in revolving and floating rate credit facilities and commercial paper, and invests surplus cash in short-term debt instruments and money market instruments. Suncor is also exposed to interest rate risk when debt instruments are maturing and require refinancing, or when new debt capital needs to be raised. The company is also exposed to changes in interest rates when derivative instruments are used to manage the debt portfolio, including hedges of prospective new debt issuances. Unfavourable changes in interest rates could have a material adverse effect on Suncor's business, financial condition and results of operations.
Issuance of Debt and Debt Covenants
Suncor expects that future capital expenditures will be financed out of cash and cash equivalents balances, cash flow provided by operating activities, available committed credit facilities, issuing commercial paper and accessing capital markets. This ability is dependent on, among other factors, commodity prices, the overall state of the capital markets, and financial institutions and investor appetite for investments in the energy industry generally, and the company's securities in particular. To the extent that external sources of capital become limited or unavailable or available on unfavourable terms, the ability to make capital investments and maintain existing properties may be constrained.
If the company finances capital expenditures in whole or in part with debt, that may increase its debt levels above industry standards for oil and gas companies of similar size. Depending on future development and growth plans, additional debt financing may be required that may not be available or, if available, may not be available on favourable terms, including higher interest rates and fees. Neither the articles of Suncor (the Articles) nor its by-laws limit the amount of indebtedness that may be incurred; however, Suncor is subject to covenants in its existing credit facilities and seeks to avoid an unfavourable cost of debt. The level of the company's indebtedness, from time to time, could impair its ability to obtain additional financing on a timely basis to take advantage of business opportunities that may arise and could negatively affect its credit ratings.
Suncor is required to comply with financial and operating covenants under existing credit facilities and debt securities. Covenants are reviewed based on actual and forecast results and the company has the ability to make changes to its
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development plans, capital structure and/or dividend policy to comply with covenants under the credit facilities. If Suncor does not comply with the covenants under its credit facilities and debt securities, there is a risk that repayment could be accelerated and/or the company's access to capital could be restricted or only be available on unfavourable terms.
Rating agencies regularly evaluate the company, including its subsidiaries. Their ratings of Suncor's long-term and short-term debt are based on a number of factors, including the company's financial strength, as well as factors not entirely within its control, including conditions affecting the oil and gas industry generally, and the wider state of the economy. Credit ratings may be important to customers or counterparties when Suncor competes in certain markets and when it seeks to engage in certain transactions, including transactions involving over-the-counter derivatives. There is a risk that one or more of Suncor's credit ratings could be downgraded, which could potentially limit its access to private and public credit markets and increase the company's cost of borrowing.
The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Royalties and Taxes
Suncor is subject to royalties and taxes imposed by governments in numerous jurisdictions.
Royalties can be impacted by changes in crude oil and natural gas pricing, production volumes, and capital and operating costs, by changes to existing legislation or PSCs, and by results of regulatory audits of prior year filings and other such events. The final determination of these events may have a material impact on the company's royalties expense.
An increase in Suncor's royalties expense, income taxes, property taxes, carbon taxes, levies, tariffs, duties, quotas, border taxes, and other taxes and government-imposed compliance costs could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Dividends and Share Repurchases
Suncor's payment of future dividends on its common shares and future share repurchases by Suncor of its common shares will be dependent on, among other things, legislative and stock exchange requirements, the company's financial condition, results of operations, cash flow, the need for funds to finance ongoing operations and growth projects, debt covenants and other business considerations as the company's Board considers relevant. There can be no assurance that Suncor will continue to pay dividends or repurchase shares in the future.
E&P Reserves Replacement
Suncor's future offshore production, and therefore its cash flows and results of operations from E&P, are highly dependent upon success in exploiting its current reserves base and acquiring or discovering additional reserves. Without additions to its E&P reserves through exploration, acquisition or development activities, Suncor's production from its offshore assets will decline over time as reserves are depleted. The business of exploring for, developing or acquiring reserves is capital intensive. To the extent Suncor's cash flow is insufficient to fund capital expenditures and external sources of capital become limited or unavailable, Suncor's ability to make the necessary capital investments to maintain and expand its reserves will be impaired. In addition, Suncor may be unable to develop or acquire additional reserves to replace its crude oil and natural gas production at acceptable costs.
Uncertainties Affecting Reserves Estimates
There are numerous uncertainties inherent in estimating quantities of reserves, including many factors beyond the company's control. Suncor's actual production, revenues, royalties, taxes, and development and operating expenditures with respect to the company's reserves will vary from its estimates, and such variances could be material.
Third-Party Service Providers
Suncor's businesses are reliant on the operational integrity of a large number of third-party service providers, including input and output commodity transport (pipelines, rail, trucking, marine) and utilities associated with various Suncor and jointly owned facilities, including electricity. A disruption in service or limited availability by one of these third parties can also have a dramatic impact on Suncor's operations and growth plans. Pipeline constraints that affect takeaway capacity or supply of inputs, such as hydrogen and power for example, could impact the company's ability to produce at capacity levels. Disruptions in pipeline service could adversely affect commodity prices, Suncor's price realizations, refining operations and sales volumes, or limit the company's ability to produce and deliver production. These interruptions may be caused by the inability of the pipeline to operate or by the oversupply of feedstock into the system that exceeds pipeline capacity. Short-term operational constraints on pipeline systems arising from pipeline interruption and/or increased supply of crude oil have occurred in the past and could occur in the future. There is a risk that third-party outages could impact Suncor's production or price realizations, which could have a material adverse effect on Suncor's business, financial condition and results of operations.
Foreign Operations
The company has operations in a number of countries with different political, economic and social systems. As a result, the company's operations and related assets are subject to a
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number of risks and other uncertainties arising from foreign government sovereignty over the company's international operations, which may include, among other things:
Currency restrictions and restrictions on repatriation of funds;
If a dispute arises in the company's foreign operations, the company may be subject to the exclusive jurisdiction of foreign courts or may not be able to subject foreign persons to the jurisdiction of a court in Canada or the U.S. In addition, as a result of activities in these areas and a continuing evolution of an international framework for corporate responsibility and accountability for international crimes, there is a risk the company could also be exposed to potential claims for alleged breaches of international or local law.
The impact that future potential terrorist attacks, regional hostilities or political violence, such as that experienced in Libya and Syria, may have on the oil and gas industry, and on our operations in particular, is not known at this time. This uncertainty may affect operations in unpredictable ways, including disruptions of fuel supplies and markets, particularly crude oil, and the possibility that infrastructure facilities, including pipelines, production facilities, processing plants and refineries, could be direct targets of, or collateral damage of, an act of terror, political violence or war. Suncor may be required to incur significant costs in the future to safeguard its assets against terrorist activities or to remediate potential damage to its facilities. There can be no assurance that Suncor will be successful in protecting itself against these risks and the related safety and financial consequences.
Despite Suncor's training and policies around bribery and other forms of corruption, there is a risk that Suncor, or some of its employees or contractors, could be charged with bribery or corruption. Any of these violations could result in onerous penalties. Even allegations of such behaviour could impair Suncor's ability to work with governments or non-government organizations and could result in the formal exclusion of Suncor from a country or area, sanctions, fines, project cancellations or delays, the inability to raise or borrow capital, reputational impacts and increased investor concern.
The occurrence of any of the foregoing could have a material adverse effect on Suncor's business, financial condition, reserves and results of operations.
Skills, Resource Shortage and Reliance on Key Personnel
The successful operation of Suncor's businesses and the company's ability to expand operations will depend upon the availability of, and competition for, skilled labour and materials supply. There is a risk that the company may have difficulty sourcing the required labour for current and future operations. The risk could manifest itself primarily through an inability to recruit new staff without a dilution of talent, to train, develop and retain high-quality and experienced staff without unacceptably high attrition, and to satisfy an employee's work/life balance and desire for competitive compensation. The labour market in Alberta has been historically tight, and, while the current economic situation has partially moderated this effect, it remains a risk to be managed. The increasing age of the company's existing workforce and changing skillsets as technology continues to evolve adds further pressure. The availability of competent and skilled contractors for current and future operations is also a risk depending on market conditions. Materials may also be in short supply due to smaller labour forces in many manufacturing operations. Suncor's ability to operate safely and effectively and complete all projects on time and on budget has the potential to be significantly impacted by these risks and this impact could be material.
The company's success also depends in large measure on certain key personnel. The loss of the services of such key personnel could have a material adverse effect on the company. The contributions of the existing management team to the immediate and near-term operations of the company are likely to continue to be of central importance for the foreseeable future.
Labour Relations
Hourly employees at Suncor's oil sands facilities (excluding MacKay River), all of the company's refineries, and the majority of the company's terminal and distribution operations are represented by labour unions or employee associations. Approximately 31% of the company's employees were covered by collective agreements at the end of 2019. Negotiations for new collective agreements are in progress for two facilities across the company. Any work interruptions involving the company's employees (including as a result of a strike or lockout), contract trades utilized in the company's projects or operations, or any jointly owned facilities operated by another entity present a significant risk to the company and could have a material adverse effect on Suncor's business, financial condition and results of operations.
68 2019 ANNUAL REPORT Suncor Energy Inc.
Land Claims and Indigenous Consultation
Indigenous Peoples have claimed Indigenous title and rights to portions of Western Canada. In addition, Indigenous Peoples have filed claims against industry participants relating in part to land claims, which may affect the company's business.
The requirement to consult with Indigenous Peoples in respect of oil and gas projects and related infrastructure has also increased in recent years. In addition, in recent years, the Canadian federal government and the provincial government in Alberta have made a commitment to renew their relationships with the Indigenous Peoples of Canada. The federal government has stated it now fully supports the United Nations Declaration on the Rights of Indigenous Peoples (the Declaration) without qualification and that Canada intends "nothing less than to adopt and implement the Declaration in accordance with the Canadian Constitution". At this time, it is unclear how the Declaration will be adopted into Canadian law and the impact of the Declaration on the Crown's duty to consult with Indigenous Peoples.
Suncor is unable to assess the effect, if any, that any such land claims, consultation requirements with Indigenous Peoples or adoption of the Declaration into Canadian law may have on Suncor's business; however, the impact may be material.
Litigation Risk
There is a risk that Suncor or entities in which it has an interest may be subject to litigation, and claims under such litigation may be material. Various types of claims may be raised in these proceedings, including, but not limited to, environmental damage, climate change and the impacts thereof, breach of contract, product liability, antitrust, bribery and other forms of corruption, tax, patent infringement, disclosure, employment matters and in relation to an attack, breach or unauthorized access to Suncor's information technology and infrastructure. Litigation is subject to uncertainty and it is possible that there could be material adverse developments in pending or future cases. Unfavourable outcomes or settlements of litigation could encourage the commencement of additional litigation. Suncor may also be subject to adverse publicity and reputational impacts associated with such matters, regardless of whether Suncor is ultimately found liable. There is a risk that the outcome of such litigation may be materially adverse to the company and/or the company may be required to incur significant expenses or devote significant resources in defence against such litigation, the success of which cannot be guaranteed.
Trade Risk Relating to CUSMA
If CUSMA is ratified, Canada will no longer be subject to the proportionality provisions in NAFTA's energy chapter, enabling Canada to expand oil and gas exports beyond the U.S. Further, a change to the oil and gas rules of origin under CUSMA will allow Canadian exporters to more easily qualify for duty-free treatment for shipments to the U.S. Canada must, however, notify the U.S. of its intention to enter into free trade talks with any "non-market economies" under CUSMA, which may include China or any other importers of Canadian oil and gas exports. Although CUSMA has been signed, Canada has yet to ratify CUSMA according to its legislative processes before it goes into effect and replaces NAFTA. The outcome of the ratification process in Canada is not complete and is therefore uncertain. If CUSMA is not ratified and adopted by all three countries, the sale and transportation of Suncor's products within North America could be affected in a manner which could negatively impact Suncor's business, financial condition and results from operations.
Control Environment
Based on their inherent limitations, disclosure controls and procedures and internal controls over financial reporting may not prevent or detect misstatements, and even those controls determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation. Failure to adequately prevent, detect and correct misstatements could have a material adverse effect on how Suncor's business, financial condition and results of operations are reported.
Insurance Coverage
Suncor maintains insurance coverage as part of its risk management program. However, such insurance may not provide comprehensive coverage in all circumstances, nor are all such risks insurable. The company self-insures some risks, and the company's insurance coverage does not cover all the costs arising out of the allocation of liabilities and risk of loss arising from Suncor operations.
Suncor's insurance policies are generally renewed on an annual basis and, depending on factors such as market conditions, the premiums, policy limits and/or deductibles for certain insurance policies can vary substantially. In some instances, certain insurance may become unavailable or available only for reduced amounts of coverage. Significantly increased costs could lead the company to decide to reduce, or possibly eliminate, coverage. In addition, insurance is purchased from a number of third-party insurers, often in layered insurance arrangements, some of whom may discontinue providing insurance coverage for their own policy or strategic reasons. Should any of these insurers refuse to continue to provide insurance coverage, the company's overall risk exposure could be increased.
2019 ANNUAL REPORT Suncor Energy Inc. 69
Control Environment
Based on their evaluation as of December 31, 2019, Suncor's Chief Executive Officer and Chief Financial Officer concluded that the company's disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the United States Securities Exchange Act of 1934, as amended (the Exchange Act)), are effective to ensure that information required to be disclosed by the company in reports that are filed or submitted to Canadian and U.S. securities authorities is recorded, processed, summarized and reported within the time periods specified in Canadian and U.S. securities laws. In addition, as of December 31, 2019, there were no changes in the internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) that occurred during the year ended December 31, 2019 that have materially affected, or are reasonably likely to materially affect, the company's internal control over financial reporting. Management will continue to periodically evaluate the company's disclosure controls and procedures and internal control over financial reporting and will make any modifications from time to time as deemed necessary.
The effectiveness of our internal control over financial reporting as at December 31, 2019 was audited by KPMG LLP, an independent registered public accounting firm, as stated in their report, which is included in our audited Consolidated Financial Statements for the year ended December 31, 2019.
Based on their inherent limitations, disclosure controls and procedures and internal control over financial reporting may not prevent or detect misstatements, and even those controls determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.
Corporate Guidance
There have been no changes to the corporate guidance ranges previously issued on December 2, 2019. For further details and advisories regarding Suncor's 2020 corporate guidance, see www.suncor.com/guidance.
70 2019 ANNUAL REPORT Suncor Energy Inc.
Non-GAAP Financial Measures
Certain financial measures in this MD&A namely operating earnings (loss), ROCE, funds from (used in) operations, free funds flow, discretionary free funds flow, Oil Sands operations cash operating costs, In Situ cash operating costs, Fort Hills cash operating costs, Syncrude cash operating costs, refining margin, refining operating expense and LIFO inventory valuation methodology are not prescribed by GAAP. These non-GAAP financial measures are included because management uses the information to analyze business performance, leverage and liquidity, and it may be useful to investors on the same basis. These non-GAAP financial measures do not have any standardized meaning and, therefore, are unlikely to be comparable to similar measures presented by other companies. Therefore, these non-GAAP financial measures should not be considered in isolation or as a substitute for measures of performance prepared in accordance with GAAP. Except as otherwise indicated, these non-GAAP measures are calculated and disclosed on a consistent basis from period to period. Specific adjusting items may only be relevant in certain periods.
(a) Operating Earnings (Loss)
Operating earnings (loss) is a non-GAAP financial measure that adjusts net earnings (loss) for significant items that are not indicative of operating performance. Management uses operating earnings (loss) to evaluate operating performance, because management believes it provides better comparability between periods. For the years ended December 31, 2019, December 31, 2018 and December 31, 2017, consolidated operating earnings (loss) are reconciled to net earnings (loss) in the Financial Information section of this MD&A and operating earnings (loss) for each segment are reconciled to net earnings (loss) in the Segment Results and Analysis section of the MD&A. Operating earnings (loss) for the three months ended December 31, 2019 and December 31, 2018 are reconciled to net earnings (loss) below.
(b) Bridge Analyses of Operating Earnings
Throughout this MD&A, the company presents charts that illustrate the change in operating earnings from the comparative period through key variance factors. These factors are analyzed in the Operating Earnings narratives following the bridge analyses in that particular section of the MD&A. These bridge analyses are presented because management uses this presentation to analyze performance.
(c) Return on Capital Employed (ROCE)
ROCE is a non-GAAP financial measure that management uses to analyze operating performance and the efficiency of Suncor's capital allocation process. Average capital employed is calculated as a twelve-month average of the capital employed balance at the beginning of the twelve-month period and the month-end capital employed balances throughout the remainder of the twelve-month period. Figures for capital employed at the beginning and end of the twelve-month period are presented to show the changes in the components of the calculation over the twelve-month period.
2019 ANNUAL REPORT Suncor Energy Inc. 71
The company presents two ROCE calculations one including and one excluding the impacts on capital employed of major projects in progress. Major projects in progress includes accumulated capital expenditures and capitalized interest for significant projects still under construction or in the process of being commissioned, and acquired assets that are still being evaluated. Management uses ROCE excluding the impacts of major projects in progress on capital employed to assess performance of operating assets.
Year ended December 31
($ millions, except as noted) |
2019 | 2018 | 2017 | |||||||||
|
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Adjustments to net earnings | ||||||||||||
|
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Net earnings attributed to common shareholders | 2 899 | 3 293 | 4 458 | |||||||||
|
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Add after-tax amounts for: | ||||||||||||
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||||||||||||
Unrealized foreign exchange (gain) loss on U.S. dollar denominated debt | (590 | ) | 989 | (702 | ) | |||||||
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Net interest expense | 638 | 541 | 158 | |||||||||
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A | 2 947 | 4 823 | 3 914 | |||||||||
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Capital employed beginning of twelve-month period | ||||||||||||
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Net debt | 15 129 | 12 907 | 14 414 | |||||||||
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Shareholders' equity | 44 005 | 45 383 | 44 630 | |||||||||
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59 134 | 58 290 | 59 044 | ||||||||||
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Capital employed end of twelve-month period | ||||||||||||
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Net debt | 16 010 | 15 129 | 12 907 | |||||||||
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Shareholders' equity | 42 042 | 44 005 | 45 383 | |||||||||
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58 052 | 59 134 | 58 290 | ||||||||||
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Average capital employed | B | 60 402 | 60 347 | 58 667 | ||||||||
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ROCE including major projects in progress (%) | A/B | 4.9 | 8.0 | 6.7 | ||||||||
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Average capitalized costs related to major projects in progress | C | 2 452 | 1 412 | 12 901 | ||||||||
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ROCE excluding major projects in progress (%)(1) | A/(B-C) | 5.1 | 8.2 | 8.6 | ||||||||
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(d) Funds from (used in) Operations(1)
Funds from (used in) operations is a non-GAAP financial measure that adjusts a GAAP measure cash flow provided by (used in) operating activities for changes in non-cash working capital, which management uses to analyze operating performance and liquidity. Changes to non-cash working capital can include, among other factors, the timing of offshore feedstock purchases and payments for fuel and income taxes, and the timing of cash flows related to accounts receivable and accounts payable, which management believes reduces comparability between periods.
72 2019 ANNUAL REPORT Suncor Energy Inc.
Oil Sands |
Exploration and
Production |
Refining and Marketing | |||||||||||||||||||
Year ended December 31 ($ millions) | 2019 | 2018 | 2017 | 2019 | 2018 | 2017 | 2019 | 2018 | 2017 | ||||||||||||
|
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Net (loss) earnings | (427 | ) | 945 | 994 | 1 005 | 807 | 721 | 3 000 | 3 154 | 2 622 | |||||||||||
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Adjustments for: | |||||||||||||||||||||
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Depreciation, depletion, amortization and impairment | 8 170 | 4 024 | 3 782 | 1 505 | 967 | 1 028 | 823 | 684 | 685 | ||||||||||||
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Deferred income taxes | (1 565 | ) | 351 | 170 | (215 | ) | (112 | ) | (113 | ) | (49 | ) | 72 | (147 | ) | ||||||
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Accretion | 221 | 209 | 195 | 43 | 48 | 45 | 6 | 7 | 7 | ||||||||||||
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Unrealized foreign exchange (gain) loss on U.S. dollar denominated debt | | | | | | | | | | ||||||||||||
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Change in fair value of financial instruments and trading inventory | 21 | (59 | ) | 13 | 16 | (89 | ) | 42 | 70 | (32 | ) | 45 | |||||||||
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(Gain) loss on disposal of assets | (14 | ) | (108 | ) | (50 | ) | (228 | ) | 91 | | (11 | ) | (7 | ) | (354 | ) | |||||
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Share-based compensation | 16 | (28 | ) | (3 | ) | | (5 | ) | 6 | 3 | (21 | ) | 5 | ||||||||
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Exploration expenses | | | | 66 | 11 | 41 | | | | ||||||||||||
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Settlement of decommissioning and restoration liabilities | (413 | ) | (428 | ) | (305 | ) | (32 | ) | (23 | ) | (31 | ) | (19 | ) | (17 | ) | (17 | ) | |||
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Other | 52 | 58 | (62 | ) | (17 | ) | 84 | 17 | 40 | (42 | ) | (23 | ) | ||||||||
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Funds from (used in) operations | 6 061 | 4 964 | 4 734 | 2 143 | 1 779 | 1 756 | 3 863 | 3 798 | 2 823 | ||||||||||||
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(Increase) decrease in non-cash working capital | |||||||||||||||||||||
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Cash flow provided by operating activities | |||||||||||||||||||||
|
2019 ANNUAL REPORT Suncor Energy Inc. 73
(e) Free Funds Flow and Discretionary Free Funds Flow
Free funds flow is a non-GAAP financial measure that is calculated by taking funds from operations and subtracting capital expenditures, including capitalized interest. Discretionary free funds flow is a non-GAAP financial measure that is calculated by taking funds from operations and subtracting asset sustainment and maintenance capital, inclusive of associated capitalized interest, and dividends. Discretionary free funds flow reflects cash available for increasing distributions to shareholders and to fund growth investments. Management uses discretionary free funds flow to measure the capacity of the company to increase returns to shareholders and grow the business. The following is a reconciliation of discretionary free funds flow for Suncor's last three years of operations.
($ millions) | 2019 | 2018 | 2017 | |||||
|
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Funds from operations | 10 818 | 10 172 | 9 139 | |||||
|
||||||||
Asset sustaining and maintenance capital and dividends(1) | (5 904 | ) | (5 740 | ) | (4 724 | ) | ||
|
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Discretionary free funds flow | 4 914 | 4 432 | 4 415 | |||||
|
(f) Oil Sands Operations, In Situ, Fort Hills and Syncrude Cash Operating Costs
Oil Sands operations, In Situ, Fort Hills and Syncrude cash operating costs are non-GAAP financial measures. Oil Sands operations cash operating costs are calculated by adjusting Oil Sands segment OS&G expense (a GAAP measure based on sales volumes) for i) costs pertaining to Fort Hills and Syncrude operations; ii) non production costs that management believes do not relate to the production performance of Oil Sands operations, including, but not limited to, share-based compensation adjustments, research and the expense recorded as part of a non-monetary arrangement involving a third-party processor; iii) revenues associated with excess capacity, including excess power generated and sold that is recorded in operating revenue; iv) project startup costs; and v) the impacts of changes in inventory levels, such that the company is able to present cost information based on production volumes. To determine In Situ cash operating costs, Oil Sands operations cash operating costs are further adjusted to remove costs pertaining to Oil Sands operations mining and upgrading. Syncrude and Fort Hills cash operating costs are calculated by adjusting Syncrude OS&G expense and Fort Hills OS&G expense, respectively, for non-production costs that management believes do not relate to the production performance of Syncrude operations or Fort Hills operations, respectively, including, but not limited to, share-based compensation, research and project startup costs, if applicable. Oil Sands operations, Fort Hills and Syncrude cash operating costs are reconciled in the Segment Results and Analysis Oil Sands section of this document. Management uses cash operating costs to measure operating performance. Oil Sands operations cash operating costs in 2019 were $4.267 billion and included $729 million related to In Situ production for In Situ cash operating costs per barrel of $9.25, based on total In Situ production of 216,200 bbls/d.
(g) Refining Margin and Refining Operating Expense
Refining margin and refining operating expense are non-GAAP financial measures. Refining margin is calculated by adjusting R&M segment operating revenues, other income and purchases of crude oil and products (GAAP measures) for non-refining margin pertaining to the company's supply, marketing and ethanol businesses, and the company's former lubricants business, which was disposed of in early 2017. Refinery operating expense is calculated by adjusting R&M segment OS&G for i) non-refining costs pertaining to the company's supply, marketing and ethanol businesses and the company's former lubricants business; and ii) non-refining costs that management believes do not relate to the production of refined products, including, but not limited to, share-based compensation and enterprise shared service allocations. Management uses refining margin and refining operating expense to measure operating performance on a production barrel basis.
74 2019 ANNUAL REPORT Suncor Energy Inc.
Year ended December 31
($ millions, except as noted) |
2019 | 2018 | 2017 | ||||||
|
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Refining margin reconciliation | |||||||||
|
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Gross margin, operating revenues less purchases of crude oil and products | 7 008 | 7 122 | 5 744 | ||||||
|
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Other income | 75 | 68 | 16 | ||||||
|
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Non-refining margin | (1 320 | ) | (1 351 | ) | (1 541 | ) | |||
|
|||||||||
Refining margin | 5 763 | 5 839 | 4 219 | ||||||
|
|||||||||
Refinery production(1) (mbbls) | 173 705 | 169 138 | 174 461 | ||||||
|
|||||||||
Refining margin ($/bbl) | 33.15 | 34.50 | 24.20 | ||||||
|
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Refining operating expense reconciliation | |||||||||
|
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Operating, selling and general expense | 2 173 | 2 043 | 2 003 | ||||||
|
|||||||||
Non-refining costs | (1 246 | ) | (1 142 | ) | (1 121 | ) | |||
|
|||||||||
Refining operating expense | 927 | 901 | 882 | ||||||
|
|||||||||
Refinery production(1) | 173 705 | 169 138 | 174 461 | ||||||
|
|||||||||
Refining operating expense ($/bbl) | 5.35 | 5.35 | 5.05 | ||||||
|
(h) Impact of First-in, First-out (FIFO) Inventory Valuation on Refining and Marketing Net Earnings
GAAP requires the use of a FIFO valuation methodology. For Suncor, this results in a lag between the sales prices for refined products, which reflects current market conditions, and the amount recorded as the cost of sale for the related refinery feedstock, which reflects market conditions at the time when the feedstock was purchased.
Suncor prepares and presents an estimate of the impact of using a FIFO inventory valuation methodology compared to a LIFO methodology, because management uses the information to analyze operating performance and compare itself against refining peers that are permitted to use LIFO inventory valuation under United States GAAP (U.S. GAAP).
The company's estimate is not derived from a standardized calculation and, therefore, may not be directly comparable to similar measures presented by other companies, and should not be considered in isolation or as a substitute for measures of performance prepared in accordance with GAAP or U.S. GAAP.
2019 ANNUAL REPORT Suncor Energy Inc. 75
(i) Operating Earnings Reconciliations Fourth Quarter 2019 and 2018(1)
Three months ended December 31 | Oil Sands |
Exploration and
Production |
Refining and
Marketing |
Corporate
and Eliminations |
Total | |||||||||||||||||
($ millions) | 2019 | 2018 | 2019 | 2018 | 2019 | 2018 | 2019 | 2018 | 2019 | 2018 | ||||||||||||
|
||||||||||||||||||||||
Net (loss) earnings as reported | (2 682 | ) | (377 | ) | (162 | ) | (115 | ) | 558 | 762 | (49 | ) | (550 | ) | (2 335 | ) | (280 | ) | ||||
|
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Asset Impairments | 2 959 | | 393 | | | | | | 3 352 | | ||||||||||||
|
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Unrealized foreign exchange (gain) loss on U.S. dollar denominated debt | | | | | | | (235 | ) | 637 | (235 | ) | 637 | ||||||||||
|
||||||||||||||||||||||
Non-cash loss on equity investment | | | | 223 | | | | | | 223 | ||||||||||||
|
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Operating earnings (loss) | 277 | (377 | ) | 231 | 108 | 558 | 762 | (284 | ) | 87 | 782 | 580 | ||||||||||
|
(j) Funds from Operations Reconciliations Fourth Quarter 2019 and 2018(1)
Three months ended December 31 | Oil Sands |
Exploration and
Production |
Refining and
Marketing |
Corporate
and Eliminations |
Total | ||||||||||||||||||
($ millions) | 2019 | 2018 | 2019 | 2018 | 2019 | 2018 | 2019 | 2018 | 2019 | 2018 | |||||||||||||
|
|||||||||||||||||||||||
Net (loss) earnings | (2 682 | ) | (377 | ) | (162 | ) | (115 | ) | 558 | 762 | (49 | ) | (550 | ) | (2 335 | ) | (280 | ) | |||||
|
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Adjustments for: | |||||||||||||||||||||||
|
|||||||||||||||||||||||
Depreciation, depletion, amortization and impairment | 5 081 | 1 019 | 803 | 199 | 211 | 184 | 18 | 17 | 6 113 | 1 419 | |||||||||||||
|
|||||||||||||||||||||||
Deferred income taxes | (890 | ) | 89 | (112 | ) | 3 | (7 | ) | (19 | ) | 7 | 87 | (1 002 | ) | 160 | ||||||||
|
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Accretion | 54 | 53 | 10 | 12 | 1 | 2 | | | 65 | 67 | |||||||||||||
|
|||||||||||||||||||||||
Unrealized foreign exchange (gain) loss on U.S. dollar denominated debt | | | | | | | (246 | ) | 688 | (246 | ) | 688 | |||||||||||
|
|||||||||||||||||||||||
Change in fair value of financial instruments and trading inventory | (20 | ) | (84 | ) | 13 | (37 | ) | (6 | ) | (27 | ) | | | (13 | ) | (148 | ) | ||||||
|
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(Gain) loss on disposal of assets | (1 | ) | (1 | ) | | 253 | (8 | ) | (2 | ) | | | (9 | ) | 250 | ||||||||
|
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Share-based compensation | 22 | (22 | ) | 2 | (3 | ) | 11 | (12 | ) | 28 | (51 | ) | 63 | (88 | ) | ||||||||
|
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Exploration expenses | | | 27 | 11 | | | | | 27 | 11 | |||||||||||||
|
|||||||||||||||||||||||
Settlement of decommissioning and restoration liabilities | (128 | ) | (91 | ) | (16 | ) | (8 | ) | (7 | ) | (5 | ) | | | (151 | ) | (104 | ) | |||||
|
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Other | (31 | ) | 21 | (10 | ) | 16 | 40 | (10 | ) | 42 | 5 | 41 | 32 | ||||||||||
|
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Funds from (used in) operations | 1 405 | 607 | 555 | 331 | 793 | 873 | (200 | ) | 196 | 2 553 | 2 007 | ||||||||||||
|
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(Decrease) increase in non-cash working capital | (249 | ) | 1 033 | ||||||||||||||||||||
|
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Cash flow provided by operating activities | 2 304 | 3 040 | |||||||||||||||||||||
|
76 2019 ANNUAL REPORT Suncor Energy Inc.
Certain crude oil and natural gas liquids volumes have been converted to mcfe or mmcfe on the basis of one bbl to six mcf. Also, certain natural gas volumes have been converted to boe or mboe on the same basis. Any figure presented in mcfe, mmcfe, boe or mboe may be misleading, particularly if used in isolation. A conversion ratio of one bbl of crude oil or natural gas liquids to six mcf of natural gas is based on an energy equivalency conversion method primarily applicable at the burner tip and does not necessarily represent value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, conversion on a 6:1 basis may be misleading as an indication of value.
Common Abbreviations
The following is a list of abbreviations that may be used in this MD&A:
Measurement | ||
bbl | barrel | |
bbls/d | barrels per day | |
mbbls/d | thousands of barrels per day | |
boe | barrels of oil equivalent | |
boe/d | barrels of oil equivalent per day | |
mboe |
|
thousands of barrels of oil equivalent |
mboe/d | thousands of barrels of oil equivalent per day | |
mcf | thousands of cubic feet of natural gas | |
mcfe | thousands of cubic feet of natural gas equivalent | |
mmcf | millions of cubic feet of natural gas | |
mmcf/d | millions of cubic feet of natural gas per day | |
mmcfe | millions of cubic feet of natural gas equivalent | |
mmcfe/d | millions of cubic feet of natural gas equivalent per day | |
m3 | cubic metres | |
MW | Megawatts | |
MWh | Megawatt hour | |
Places and Currencies |
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U.S. | United States | |
U.K. | United Kingdom | |
B.C. | British Columbia | |
$ or Cdn$ | Canadian dollars | |
US$ | United States dollars | |
£ | Pounds sterling | |
€ | Euros | |
Financial and Business Environment |
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DD&A | Depreciation, depletion and amortization | |
WTI | West Texas Intermediate | |
WCS | Western Canadian Select | |
SCO | Synthetic crude oil | |
SYN | Synthetic crude oil benchmark | |
MSW | Mixed Sweet Blend | |
NYMEX | New York Mercantile Exchange |
Forward-Looking Information
This MD&A contains certain forward-looking statements and forward-looking information (collectively, forward-looking statements) within the meaning of applicable Canadian and U.S. securities laws and other information based on Suncor's current expectations, estimates, projections and assumptions that were made by the company in light of information available at the time the statement was made and consider Suncor's experience and its perception of historical trends, including expectations and assumptions concerning: the accuracy of reserves and resources estimates; commodity prices and interest and foreign exchange rates; the performance of assets and equipment; capital efficiencies and cost savings; applicable laws and government policies; future production rates; the sufficiency of budgeted capital expenditures in carrying out planned activities; the availability and cost of labour, services and infrastructure; the satisfaction by third parties of their obligations to Suncor; the development and execution of projects; and the receipt, in a timely manner, of regulatory and third-party approvals. All statements and information that address expectations or projections about the future, and statements and information about Suncor's strategy for growth, expected and future expenditures or investment decisions, commodity prices, costs, schedules, production volumes, operating and financial results, future financing and capital activities, and the expected impact of future commitments are forward-looking statements. Some of the forward-looking statements may be identified by words like "expects", "anticipates", "will", "estimates", "plans", "scheduled", "intends", "believes", "projects", "indicates", "could", "focus", "vision", "goal", "outlook", "proposed", "target", "objective", "continue", "should", "may", "potential", "future", "opportunity", "would", "priority" and similar expressions.
Forward-looking statements in this MD&A include references to:
Suncor's strategy, business plans and expectations about projects, the performance of assets, production volumes and capital expenditures, including:
2019 ANNUAL REPORT Suncor Energy Inc. 77
industry-leading long-life, low-decline oil sands reserves base, an offshore business that provides geographically diversified cash flow and its investment in sustainability, technology and innovation;
78 2019 ANNUAL REPORT Suncor Energy Inc.
MacKay River in future years as production from existing well pads declines.
The anticipated duration and impact of planned maintenance events, including:
Also:
Forward-looking statements are not guarantees of future performance and involve a number of risks and uncertainties, some that are similar to other oil and gas companies and some that are unique to Suncor. Suncor's actual results may differ materially from those expressed or implied by its forward-looking statements, so readers are cautioned not to place undue reliance on them.
The financial and operating performance of the company's reportable operating segments, specifically Oil Sands, E&P, and R&M, may be affected by a number of factors.
Factors that affect Suncor's Oil Sands segment include, but are not limited to, volatility in the prices for crude oil and other production, and the related impacts of fluctuating light/heavy and sweet/sour crude oil differentials; changes in the demand for refinery feedstock and diesel fuel, including the possibility that refiners that process the company's proprietary production will be closed, experience equipment failure or other accidents; Suncor's ability to operate its Oil Sands facilities reliably in order to meet production targets; the output of newly commissioned facilities, the performance of which may be difficult to predict during initial operations; Suncor's dependence on pipeline capacity and other logistical constraints, which may affect the company's ability to distribute products to market; Suncor's ability to finance Oil Sands growth and sustaining capital expenditures; the availability of bitumen feedstock for upgrading operations, which can be negatively affected by poor ore grade quality, unplanned mine equipment and extraction plant maintenance, tailings storage, and in situ reservoir and equipment performance, or the unavailability of third-party bitumen; changes in operating costs, including the cost of labour, natural gas and other energy sources used in oil sands processes; and the company's ability to complete projects, including planned maintenance events, both on time and on budget, which could be impacted by competition from other projects (including other oil sands projects) for goods and services and demands on infrastructure in Alberta's Wood Buffalo region and the surrounding area (including housing, roads and schools).
Factors that affect Suncor's E&P segment include, but are not limited to, volatility in crude oil and natural gas prices; operational risks and uncertainties associated with oil and gas activities, including unexpected formations or pressures, premature declines of reservoirs, fires, blow-outs, equipment failures and other accidents, uncontrollable flows of crude
2019 ANNUAL REPORT Suncor Energy Inc. 79
oil, natural gas or well fluids, and pollution and other environmental risks; adverse weather conditions, which could disrupt output from producing assets or impact drilling programs, resulting in increased costs and/or delays in bringing on new production; political, economic and socio-economic risks associated with Suncor's foreign operations, including the unpredictability of operating in Libya due to ongoing political unrest; and market demand for mineral rights and producing properties, potentially leading to losses on disposition or increased property acquisition costs.
Factors that affect Suncor's R&M segment include, but are not limited to, fluctuations in demand and supply for refined products that impact the company's margins; market competition, including potential new market entrants; the company's ability to reliably operate refining and marketing facilities in order to meet production or sales targets; and risks and uncertainties affecting construction or planned maintenance schedules, including the availability of labour and other impacts of competing projects drawing on the same resources during the same time period.
Additional risks, uncertainties and other factors that could influence the financial and operating performance of all of Suncor's operating segments and activities include, but are not limited to, changes in general economic, market and business conditions, such as commodity prices, interest rates and currency exchange rates; fluctuations in supply and demand for Suncor's products; the successful and timely implementation of capital projects, including growth projects and regulatory projects; risks associated with the development and execution of Suncor's projects and the commissioning and integration of new facilities; the possibility that completed maintenance activities may not improve operational performance or the output of related facilities; the risk that projects and initiatives intended to achieve cash flow growth and/or reductions in operating costs may not achieve the expected results in the time anticipated or at all; competitive actions of other companies, including increased competition from other oil and gas companies or from companies that provide alternative sources of energy; labour and material shortages; actions by government authorities, including the imposition or reassessment of, or changes to, taxes, fees, royalties, duties and other government-imposed compliance costs, and mandatory production curtailment orders and changes thereto; changes to laws and government policies that could impact the company's business, including environmental (including climate change), royalty and tax laws and policies; the ability and willingness of parties with whom Suncor has material relationships to perform their obligations to the company; the unavailability of, or outages to, third-party infrastructure that could cause disruptions to production or prevent the company from being able to transport its products; the occurrence of a protracted operational outage, a major safety or environmental incident, or unexpected events such as fires (including forest fires), equipment failures and other similar events affecting Suncor or other parties whose operations or assets directly or indirectly affect Suncor; the potential for security breaches of Suncor's information technology and infrastructure by malicious persons or entities, and the unavailability or failure of such systems to perform as anticipated as a result of such breaches; security threats and terrorist or activist activities; the risk that competing business objectives may exceed Suncor's capacity to adopt and implement change; risks and uncertainties associated with obtaining regulatory, third-party and stakeholder approvals outside of Suncor's control for the company's operations, projects, initiatives, and exploration and development activities and the satisfaction of any conditions to approvals; the potential for disruptions to operations and construction projects as a result of Suncor's relationships with labour unions that represent employees at the company's facilities; the company's ability to find new oil and gas reserves that can be developed economically; the accuracy of Suncor's reserves, resources and future production estimates; market instability affecting Suncor's ability to borrow in the capital debt markets at acceptable rates or to issue other securities at acceptable prices; maintaining an optimal debt to cash flow ratio; the success of the company's risk management activities using derivatives and other financial instruments; the cost of compliance with current and future environmental laws, including climate change laws; risks relating to increased activism and public opposition to fossil fuels and oil sands; risks and uncertainties associated with closing a transaction for the purchase or sale of a business, asset or oil and gas property, including estimates of the final consideration to be paid or received; the ability of counterparties to comply with their obligations in a timely manner; risks associated with joint arrangements in which the company has an interest; risks associated with land claims and Indigenous consultation requirements; the risk that the company may be subject to litigation; the impact of technology and risks associated with developing and implementing new technologies; and the accuracy of cost estimates, some of which are provided at the conceptual or other preliminary stage of projects and prior to commencement or conception of the detailed engineering that is needed to reduce the margin of error and increase the level of accuracy. The foregoing important factors are not exhaustive.
Many of these risk factors and other assumptions related to Suncor's forward-looking statements are discussed in further detail throughout this MD&A, including under the heading Risk Factors, and the company's 2019 AIF and Form 40-F on file with Canadian securities commissions at www.sedar.com and the United States Securities and Exchange Commission at www.sec.gov. Readers are also referred to the risk factors and assumptions described in other documents that Suncor files from time to time with securities regulatory authorities. Copies of these documents are available without charge from the company.
The forward-looking statements contained in this MD&A are made as of the date of this MD&A. Except as required by applicable securities laws, we assume no obligation to update publicly or otherwise revise any forward-looking statements or the foregoing risks and assumptions affecting such forward-looking statements, whether as a result of new information, future events or otherwise.
80 2019 ANNUAL REPORT Suncor Energy Inc.
CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
The Board of Directors
Suncor Energy Inc.
We, KPMG LLP, consent to the use of our report, dated February 26, 2020, with respect to the consolidated financial statements and the effectiveness of internal control over financial reporting included in this Annual Report on Form 40-F.
We, KPMG LLP, also consent to the incorporation by reference of such report in the Registration Statements on Form S-8 (No. 333-87604, No. 333-112234, No. 333-118648, No. 333-124415, No. 333-149532, No. 333-161021 and No. 333-161029) and on From F-10 (No. 333-225338) of Suncor Energy Inc.
"KPMG LLP"
Chartered Professional Accountants
Calgary, Alberta, Canada
February 27, 2020
Consent of PricewaterhouseCoopers LLP
CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
We hereby consent to the inclusion in this Annual Report on Form 40-F for the year ended December 31, 2019 of Suncor Energy Inc. of our report dated February 28, 2019, relating to the Consolidated Financial Statements which appear in this Annual Report.
We also consent to the incorporation by reference in the Registration Statements on Form S-8 (No. 333-87604), Form S-8 (No. 333-112234), Form S-8 (No. 333-118648), Form S-8 (No. 333-124415), Form S-8 (No. 333-149532), Form S-8 (No. 333-161021), Form S-8 (No. 33-161029) and Form F-10 (No. 333-225338) of Suncor Energy Inc. of our report dated February 28, 2019 referred to above.
We also consent to reference to us under the heading "Interests of Experts," which appears in this Annual Report on Form 40-F which is incorporated by reference in such Registration Statements.
"PricewaterhouseCoopers LLP"
Chartered Professional Accountants
Calgary, Alberta, Canada
February 27, 2020
Consent of GLJ Petroleum Consultants Ltd.
TO: |
Suncor Energy Inc.
The Securities and Exchange Commission The Securities Regulatory Authorities of Each of the Provinces and Territories of Canada |
Dear Sirs/Mesdames:
Re: Suncor Energy Inc. ("Suncor")
We refer to the following reports (the "Reports") prepared by GLJ Petroleum Consultants Ltd. ("GLJ"):
which provide GLJ's reports on proved and probable reserves evaluations of Suncor's Canadian mining and in-situ leases that were evaluated as at December 31, 2019.
We hereby consent to being named and to the use of, reference to and excerpts and information derived from the said Reports by Suncor in its:
We have read the Form 40-F, Annual Report, AIF and Prospectuses and have no reason to believe that there are any misrepresentations in the information contained therein that is derived from our Reports or that are within our knowledge as a result of the services which we performed in connection with the Reports.
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Yours very truly, | |||
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GLJ PETROLEUM CONSULTANTS LTD. |
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"Tim R. Freeborn" |
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Tim R. Freeborn, P. Eng.
|
Dated:
February 27, 2020
Calgary, Alberta, Canada
Consent of Sproule Associates Limited and Sproule International Limited
TO: |
Suncor Energy Inc. | |
|
The Securities and Exchange Commission | |
|
The Securities Regulatory Authorities of Each of the Provinces and Territories of Canada |
Dear Sirs/Mesdames:
Re: Suncor Energy Inc. ("Suncor")
We refer to the following reports (the "Reports") prepared by Sproule Associates Limited and Sproule International Limited:
which provide our reports on proved and probable reserves evaluations pursuant to Canadian disclosure requirements of Suncor's Canadian offshore conventional assets and international operations that were evaluated as at December 31, 2019.
We hereby consent to being named and to the use of, reference to and excerpts and information derived from the said Reports by Suncor in its:
We have read the Form 40-F, Annual Report, AIF and Prospectuses and have no reason to believe that there are any misrepresentations in the information contained therein that is derived from our Reports or that are within our knowledge as a result of the services which we performed in connection with the Reports.
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Sincerely, | |
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SPROULE ASSOCIATES LIMITED AND SPROULE INTERNATIONAL LIMITED |
|
|
"Cameron P. Six" |
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Cameron P. Six, P.Eng.
|
Dated:
February 27, 2020
Calgary, Alberta, Canada
I, Mark S. Little, certify that:
DATE: February 27, 2020 |
/s/ MARK S. LITTLE
Mark S. Little President and Chief Executive Officer |
I, Alister Cowan, certify that:
DATE: February 27, 2020 |
/s/ ALISTER COWAN
Alister Cowan Chief Financial Officer |
CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350,
AS ENACTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002
In connection with the annual report of Suncor Energy Inc. (the "Company") on Form 40-F for the fiscal year ending December 31, 2019 as filed with the Securities and Exchange Commission on the date hereof (the "Report"), I, MARK. S. LITTLE, President and Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that:
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/s/ MARK S. LITTLE
Mark S. Little President and Chief Executive Officer Suncor Energy Inc. |
|
|
DATE: February 27, 2020 |
CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350,
AS ENACTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002
In connection with the annual report of Suncor Energy Inc. (the "Company") on Form 40-F for the fiscal year ending December 31, 2019 as filed with the Securities and Exchange Commission on the date hereof (the "Report"), I, ALISTER COWAN, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that:
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/s/ ALISTER COWAN
Alister Cowan Chief Financial Officer Suncor Energy Inc. |
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DATE: February 27, 2020 |
Supplementary Oil and Gas Disclosures (unaudited)
The following disclosures are presented in accordance with United States Financial Accounting Standards Board ("FASB") Topic 932 "Extractive Activities Oil and Gas" and Subpart 1200 of Regulation S-K ("Subpart 1200") of the United States Securities and Exchange Commission. Disclosures pertaining to the audited consolidated financial statements as at and for the year ended December 31, 2019 (the "2019 Consolidated Financial Statements") of Suncor Energy Inc. ("Suncor" or the "company") were prepared in accordance with International Financial Reporting Standards as issued by the International Accounting Standards Board and Canadian generally accepted accounting principles contained within Part 1 of the Chartered Professional Accountants Canada Handbook, which differ in material respects from financial statements prepared in accordance with United States generally accepted accounting principles. The 2019 Consolidated Financial Statements are attached as Exhibit 99.1 to Suncor's annual report on Form 40-F for the year ended December 31, 2019 (the "Form 40-F").
Reserves Data
Reserves data included herein are estimates only and can be significantly impacted by a variety of internal and external factors. For more information on the risks involved when estimating reserves, see the discussion in the "Statement of Reserves Data and Other Oil and Gas Information Significant Risk Factors and Uncertainties Affecting Reserves" section in Suncor's 2019 Annual Information Form (the "2019 AIF"), which is contained in the Form 40-F. Readers should also see Suncor's Management's Discussion and Analysis for the year ended December 31, 2019, which is attached as Exhibit 99.2 to the Form 40-F (the "2019 Management's Discussion and Analysis").
The reserves data presented herein, with an effective date of December 31, 2019, may differ in relation to the format and the basis from which volumes are economically determined under National Instrument 51-101 "Standards of Disclosure for Oil and Gas Activities" ("NI 51-101"), as disclosed in the 2019 AIF. Subpart 1200 requires disclosure of net proved reserves, after royalties, using the average of the first-day-of-the-month prices for the twelve-month period prior to the end of the reporting period, whereas NI 51-101 requires disclosure of gross and net reserves, estimated using forecast prices and costs.
Net Proved Oil and Gas Reserves(1)(2)
The majority of Suncor's oil and gas reserves are in Canada. In order to align with the company's segmented information in the 2019 Consolidated Financial Statements, the 2019 Management's Discussion and Analysis and the 2019 AIF, the company presents the following supplementary oil and gas disclosures by showing amounts associated with its Oil Sands segment, which are exclusively in Canada and produce synthetic crude oil ("SCO") and bitumen, separate from other Canadian operations, which are aggregated with Suncor's international operations (collectively, "Exploration and Production") and produce crude oil, natural gas and natural gas liquids ("NGLs"). Exploration and Production reserves are in offshore Canada, offshore UK, and offshore Norway.
|
SCO
(mmbbls) |
Bitumen
(mmbbls) |
Crude Oil(3)
(mmbbls) |
Natural Gas
(bcf) |
Total
(mmboe) |
||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
At December 31, (net reserves,
constant prices and costs) |
2019 | 2018 | 2019 | 2018 | 2019 | 2018 | 2019 | 2018 | 2019 | 2018 | |||||||||||||||||||||
Proved Developed |
|||||||||||||||||||||||||||||||
Oil Sands |
2,032 | 2,183 | 951 | 1,003 | | | | | 2,984 | 3,186 | |||||||||||||||||||||
Exploration and Production |
| | | | 110 | 91 | 1 | 1 | 111 | 91 | |||||||||||||||||||||
|
2,032 | 2,183 | 951 | 1,003 | 110 | 91 | 1 | 1 | 3,094 | 3,277 | |||||||||||||||||||||
Proved Undeveloped |
|||||||||||||||||||||||||||||||
Oil Sands |
542 | 522 | 581 | 602 | | | | | 1,123 | 1,123 | |||||||||||||||||||||
Exploration and Production |
| | | | 49 | 67 | 9 | 10 | 51 | 69 | |||||||||||||||||||||
|
542 | 522 | 581 | 602 | 49 | 67 | 9 | 10 | 1,173 | 1,193 | |||||||||||||||||||||
Proved |
|||||||||||||||||||||||||||||||
Oil Sands |
2,574 | 2,704 | 1,532 | 1,605 | | | | | 4,106 | 4,309 | |||||||||||||||||||||
Exploration and Production |
| | | | 160 | 158 | 11 | 11 | 161 | 160 | |||||||||||||||||||||
|
2,574 | 2,704 | 1,532 | 1,605 | 160 | 158 | 11 | 11 | 4,267 | 4,469 | |||||||||||||||||||||
Reconciliation of Net Proved Oil and Gas Reserves
(net reserves,
constant prices and costs) |
Balance at
December 31 2017 |
Revisions of
Previous Estimates(4) |
Improved
Recovery |
Acquisitions |
Extensions
and Discoveries(5) |
Production | Dispositions(6) |
Balance at
December 31 2018 |
|||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Oil Sands |
|||||||||||||||||||||||||
SCO (mmbbls) |
2,737 | 52 | | 71 | (156 | ) | | 2,704 | |||||||||||||||||
Bitumen |
1,640 | 12 | | 18 | (65 | ) | | 1,605 | |||||||||||||||||
Exploration and Production |
| ||||||||||||||||||||||||
Crude oil(3) (mmbbls) |
140 | 16 | | 7 | 27 | (33 | ) | | 158 | ||||||||||||||||
Natural gas (bcf) |
6 | 1 | | 10 | | (3 | ) | (3 | ) | 11 | |||||||||||||||
Total (mmboe) |
4,519 | 80 | | 98 | 28 | (254 | ) | (1 | ) | 4,469 | |||||||||||||||
(net reserves,
constant prices and costs) |
Balance at
December 31 2018 |
Revisions of
Previous Estimates(4) |
Improved
Recovery |
Acquisitions |
Extensions
and Discoveries(5) |
Production | Dispositions |
Balance at
December 31 2019 |
|||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Oil Sands |
|||||||||||||||||||||||||
SCO (mmbbls) |
2,704 | 33 | | | | (164 | ) | | 2,574 | ||||||||||||||||
Bitumen |
1,605 | (6 | ) | 2 | | | (68 | ) | | 1,532 | |||||||||||||||
Exploration and Production |
|||||||||||||||||||||||||
Crude oil(3) (mmbbls) |
158 | 30 | 1 | | 5 | (35 | ) | | 160 | ||||||||||||||||
Natural gas (bcf) |
11 | 1 | | | 1 | (2 | ) | | 11 | ||||||||||||||||
Total (mmboe) |
4,469 | 57 | 2 | | 5 | (267 | ) | | 4,267 | ||||||||||||||||
Notes to Reserves Data:
Capitalized Costs
|
At December 31, 2019 | At December 31, 2018 | |||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
($ millions)
|
Oil Sands |
Exploration
and Production |
Total | Oil Sands |
Exploration
and Production |
Total | |||||||||||||
Exploration and evaluation assets(1) |
2,178 | 250 | 2,428 | 2,100 | 219 | 2,319 | |||||||||||||
Oil and gas properties(2)(3) |
18,795 | 21,801 | 40,596 | 17,083 | 20,763 | 37,846 | |||||||||||||
Plant and equipment(2)(3) |
66,451 | 1,074 | 67,525 | 63,213 | 1,104 | 64,317 | |||||||||||||
accumulated provision(2) |
(30,581 | ) | (15,298 | ) | (45,879 | ) | (22,654 | ) | (14,075 | ) | (36,729 | ) | |||||||
Total |
56,843 | 7,827 | 64,670 | 59,742 | 8,011 | 67,753 | |||||||||||||
Costs Incurred for Property Acquisition, Exploration and Development Activities
|
Year ended December 31, 2019 | Year ended December 31, 2018 | |||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
($ millions)
|
Oil Sands |
Exploration
and Production |
Total | Oil Sands |
Exploration
and Production |
Total | |||||||||||||
Unproved property acquisition |
| | | | 32 | 32 | |||||||||||||
Proved property acquisition |
| | | 1,143 | 82 | 1,225 | |||||||||||||
Exploration(1) |
204 | 248 | 452 | 73 | 179 | 252 | |||||||||||||
Development(2) |
3,580 | 992 | 4,572 | 3,398 | 800 | 4,198 | |||||||||||||
Total |
3,784 | 1,240 | 5,024 | 4,614 | 1,093 | 5,707 | |||||||||||||
Results of Operations for Oil and Gas Producing Activities(1)(2)
|
Year ended December 31, 2019 | Year ended December 31, 2018 | |||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
($ millions)
|
Oil Sands |
Exploration
and Production |
Total | Oil Sands |
Exploration
and Production |
Total | |||||||||||||
Operating revenues, net of royalties |
17,430 | 3,070 | 20,500 | 15,345 | 3,217 | 18,562 | |||||||||||||
Other income (loss) |
172 | 430 | 602 | 387 | (68 | ) | 319 | ||||||||||||
|
17,602 | 3,500 | 21,102 | 15,732 | 3,149 | 18,881 | |||||||||||||
Purchases of crude oil and products |
1,407 | | 1,407 | 1,563 | | 1,563 | |||||||||||||
Operating, selling and general |
8,027 | 525 | 8,552 | 7,577 | 507 | 8,084 | |||||||||||||
Transportation |
1,293 | 80 | 1,373 | 1,144 | 85 | 1,229 | |||||||||||||
Depreciation, depletion, amortization and impairment |
8,170 | 1,505 | 9,675 | 4,024 | 967 | 4,991 | |||||||||||||
Exploration |
127 | 129 | 256 | 44 | 78 | 122 | |||||||||||||
(Gain) loss on disposal of assets |
(14 | ) | (228 | ) | (242 | ) | (108 | ) | 91 | (17 | ) | ||||||||
Finance expenses |
318 | 73 | 391 | 320 | 46 | 366 | |||||||||||||
(Loss) earnings before income taxes |
(1,726 | ) | 1,416 | (310 | ) | 1,168 | 1,375 | 2,543 | |||||||||||
Income taxes (recovery) expense |
(1,299 | ) | 411 | (888 | ) | 223 | 568 | 791 | |||||||||||
Net (loss) earnings |
(427 | ) | 1,005 | 578 | 945 | 807 | 1,752 | ||||||||||||
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves
The standardized measure of discounted future net cash flows relating to Suncor's proved oil and gas reserves are calculated in accordance with FASB Topic 932 "Extractive Activities Oil and Gas". Future cash inflows are estimated using the trailing twelve-month average price, which are also used in estimating the entity's proved oil and gas reserves. Future development and production costs, including the associated decommissioning and restoration activities, are calculated by estimating the expenditures to be incurred in developing and producing the proved oil and gas reserves at the end of the year, based on year-end costs and assuming continuation of existing economic conditions. The appropriate year-end statutory tax rates, with consideration of future tax rates already legislated, were applied to the future pretax net cash flows, less the tax basis of the properties involved. A prescribed rate of 10% is applied to discount the future net cash flows.
The calculation of the standardized measure of discounted future net cash flows is based upon information prepared by the company's independent qualified reserves evaluators (which includes decommissioning and restoration activities), and adjusted for future income taxes.
It should not be assumed that the estimates of future net cash flows presented in the tables below represent the fair market value of the reserves. There is no assurance that the price and cost assumptions will be attained and variances could be material. Future changes to income tax, royalty and environmental regulations could also have a significant impact on the respective assumptions. There is no guarantee that the estimates for SCO, bitumen, crude oil, and natural gas reserves provided herein will be recovered. Actual SCO, bitumen, crude oil, and natural gas reserves may be greater than or less than the estimates provided herein.
The following twelve-month average prices were used to calculate the standardized measure of discounted future net cash flows:
Year
|
Brent
North Sea |
WTI
Cushing Oklahoma |
WCS
Hardisty Alberta |
Light
Sweet Edmonton Alberta |
Pentanes Plus
Edmonton Alberta |
AECO
Gas |
National
Balancing Point North Sea |
|||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
|
US$/bbl
|
US$/bbl
|
Cdn$/bbl
|
Cdn$/bbl
|
Cdn$/bbl
|
Cdn$/mmbtu
|
Cdn$/mmbtu
|
|||||||||||||||
2019 |
63.15 | 55.69 | 57.22 | 67.66 | 68.70 | 1.66 | 6.69 | |||||||||||||||
2018 |
71.54 | 65.56 | 50.44 | 70.07 | 79.39 | 1.46 | 10.03 | |||||||||||||||
|
At December 31, 2019 | At December 31, 2018 | |||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
($ millions)
|
Oil Sands |
Exploration
and Production |
Total | Oil Sands |
Exploration
and Production |
Total | |||||||||||||
Future cash inflows |
251,040 | 13,218 | 264,258 | 247,927 | 14,259 | 262,186 | |||||||||||||
Future production costs |
(145,374 | ) | (3,960 | ) | (149,334 | ) | (132,241 | ) | (3,446 | ) | (135,687 | ) | |||||||
Future development costs |
(52,917 | ) | (3,287 | ) | (56,204 | ) | (56,071 | ) | (3,175 | ) | (59,246 | ) | |||||||
Future income tax expenses |
(10,716 | ) | (1,764 | ) | (12,480 | ) | (14,491 | ) | (1,988 | ) | (16,479 | ) | |||||||
Future net cash flows |
42,033 | 4,207 | 46,240 | 45,124 | 5,650 | 50,774 | |||||||||||||
10% Discount Factor |
(22,655 | ) | (308 | ) | (22,963 | ) | (23,280 | ) | (1,227 | ) | (24,507 | ) | |||||||
Standardized measure of discounted future net cash flows |
19,378 | 3,899 | 23,277 | 21,844 | 4,423 | 26,267 | |||||||||||||
Changes in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves
($ millions)
|
2019 | 2018 | |||||
---|---|---|---|---|---|---|---|
Standardized measure of discounted future net cash flows beginning of year |
26,267 | 21,831 | |||||
Sales and transfers of oil and gas produced |
(8,005 | ) | (6,998 | ) | |||
Net changes in sales prices and operating costs related to future production |
(5,673 | ) | 6,277 | ||||
Net change due to extensions, discoveries and improved recovery |
2,632 | 3,923 | |||||
Net change due to acquisition and dispositions |
| 1,228 | |||||
Net change due to revisions in quantity estimates |
(834 | ) | 1,630 | ||||
Previously estimated development costs incurred during the period |
4,077 | 3,805 | |||||
Changes in estimated future development costs |
(314 | ) | (6,010 | ) | |||
Accretion of discount |
2,773 | 2,210 | |||||
Net change in income taxes |
2,353 | (1,629 | ) | ||||
Standardized measure of discounted future net cash flows end of year |
23,277 | 26,267 | |||||