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") promulgated by the United States Securities and Exchange Commission. Disclosures pertaining to the audited consolidated financial statements as at and for the year ended December 31, 2013 (the "2013 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 2013 Financial Statements are attached as Exhibit 99.1 to Suncor's annual report on Form 40-F for the year ended December 31, 2013 (the "Form 40-F").

Reserve estimates included herein are estimates only and can be significantly impacted by a variety of internal and external factors. For more information, see the discussion in the "Statement of Reserves Data and Other Oil and Gas Information — Significant Factors or Uncertainties Affecting Reserves Data" section in Suncor's 2013 Annual Information Form (the "2013 AIF"), which is contained in the Form 40-F. For more information as to the risks involved when estimating reserves, see "Risk Factors — Uncertainty of Reserves and Resources Estimates" in the 2013 AIF. Readers should also see Suncor's Management's Discussion and Analysis for the year ended December 31, 2013, which is attached as Exhibit 99.2 to the Form 40-F (the "2013 Management's Discussion and Analysis").

The reserve data presented herein may differ in relation to the format and the basis from which volumes are economically determined under Subpart 1200 and National Instrument 51-101 — "Standards of Disclosure of Oil and Gas Activities" ("NI 51-101"), as disclosed in the 2013 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.

The majority of Suncor's oil and gas reserves are in Canada. In order to align with the Company's segmented information in the 2013 Financial Statements, the 2013 Management's Discussion and Analysis and the 2013 AIF, the Company presents the following supplementary oil and gas disclosures by showing amounts associated with its Oil Sands operations, 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").

The 2013 AIF, 2013 Financial Statements and the 2013 Management's Discussion and Analysis are available under the Company's profile on the System for Electronic Document Analysis and Retrieval, which can be accessed at www.sedar.com.

	SCO				Bitumen				Crude Oil and NGLs⁽³⁾				Natural Gas				Total

At December 31,	(mmbbls)				(mmbbls)				(mmbbls)				(bcf)				(mmboe)
(net reserves, constant prices and costs)	2013		2012		2013		2012		2013		2012		2013		2012		2013		2012
Proved Developed
Oil Sands		1 804		1 873		153		164		—		—		—		—		1 957		2 037
Exploration and Production		—		—		—		—		171		196		38		539		177		286

		1 804		1 873		153		164		171		196		38		539		2 134		2 323

Proved Undeveloped
Oil Sands		516		460		1 566		721		—		—		—		—		2 082		1 180
Exploration and Production		—		—		—		—		46		55		6		7		47		57

		516		460		1 566		721		46		55		6		7		2 129		1 237

Proved
Oil Sands		2 320		2 333		1 719		885		—		—		—		—		4 040		3 217
Exploration and Production		—		—		—		—		216		251		44		546		223		343

		2 320		2 333		1 719		885		216		251		44		546		4 263		3 560

(net reserves, constant prices and costs)

Oil Sands
SCO (mmbbls)	2 359	(6	)	1	—	88	(109	)	—	2 333
Bitumen (mmbbls)	624	175		1	—	101	(16	)	—	885
Exploration and Production
Crude oil and NGLs⁽³⁾ (mmbbls)	270	19		—	—	1	(37	)	—	251
Natural gas (bcf)	871	(243	)	—	—	7	(89	)	—	546

Total	3 398	146		2	—	191	(178	)	—	3 560

(net reserves, constant prices and costs)

Oil Sands
SCO (mmbbls)	2 333	30	1	—	69	(112	)	—		2 320
Bitumen (mmbbls)	885	1	1	—	856	(23	)	—		1 719
Exploration and Production
Crude oil and NGLs⁽³⁾ (mmbbls)	251	12	—	—	2	(37	)	(12	)	216
Natural gas (bcf)	546	10	—	—	6	(61	)	(457	)	44

Total	3 560	45	2	—	928	(182	)	(89	)	4 263

b.: Proved oil and gas reserves are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible, from a given date forward, from known reservoirs, and under existing economic conditions, operating methods and government regulations.
c.: Proved developed oil and gas reserves are those quantities that can be expected to be recovered through existing wells with existing equipment and operating methods or in which the cost of the required equipment is relatively minor compared to the cost of a new well; and can be expected to be recovered through extraction equipment and infrastructure installed and operational at the time of the reserves estimate for projects that extract oil and gas by means not involving a well.
d.: Proved undeveloped oil and gas reserves are those quantities that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion.

(2): Reserve data tables may not add due to rounding.
(3): Natural gas liquids reserves are not significant and have been presented in combination with Crude Oil reserves.

	At December 31, 2013									At December 31, 2012

($ millions)	Oil Sands			Exploration and Production			Total			Oil Sands			Exploration and Production			Total
Exploration and evaluation assets⁽¹⁾		2 040			732			2 772			2 565			719			3 284
Oil and gas properties⁽²⁾		10 770			14 753			25 523			9 060			15 394			24 454
Plant and equipment⁽²⁾		41 357			907			42 264			38 277			942			39 219
— accumulated provision⁽²⁾		(12 124	)		(6 704	)		(18 828	)		(10 440	)		(5 691	)		(16 131	)

Total		42 043			9 688			51 731			39 462			11 364			50 826

(1): Exploration and evaluation assets largely represent amounts associated with unproved properties, but may include properties with proved reserves for which Suncor's Board of Directors have not sanctioned development. See note 18 of the 2013 Financial Statements.
(2): Oil and Gas Properties, Plant and Equipment and the accumulated provision largely represent amounts associated with proved properties. See note 17 of the 2013 Financial Statements.

Costs Incurred for Property Acquisition, Exploration and Development Activities

	Year ended December 31, 2013						Year ended December 31, 2012

($ millions)	Oil Sands		Exploration and Production		Total		Oil Sands		Exploration and Production		Total
Unproved property acquisition		—		2		2		—		—		—
Proved property acquisition		—		—		—		—		—		—
Exploration⁽¹⁾		196		308		504		185		250		435
Development⁽²⁾		4 322		1 247		5 569		4 983		1 235		6 218

Total		4 518		1 557		6 075		5 168		1 485		6 653

(1): Includes amounts capitalized to Exploration and Evaluation as well as those charged to Exploration Expense on the Consolidated Balance Sheet and the Consolidated Statements of Comprehensive Income, respectively, of the 2013 Financial Statements.
(2): Includes amounts capitalized to Property, Plant and Equipment on the Consolidated Balance Sheet of the 2013 Financial Statements that relate to the Company's decommissioning and restoration activities.

The Results of Operations are contained within the segmented results of the Company's Oil and Gas Producing Activities presented below.

	At December 31, 2013								At December 31, 2012

($ millions)	Oil Sands		Exploration and Production			Total			Oil Sands			Exploration and Production			Total
Operating revenues, net of royalties		12 230		5 217			17 447			10 818			4 845			15 663
Other Income		64		381			445			20			71			91

		12 294		5 598			17 892			10 838			4 916			15 754
Purchases of crude oil and products		460		568			1 028			211			444			655
Operating, selling and general		5 837		676			6 513			5 365			795			6 160
Transportation		482		127			609			337			182			519
Depreciation, depletion, amortization and impairment		2 439		1 804			4 243			3 964			1 857			5 821
Exploration		115		207			322			71			238			309
Gain on disposal of assets		—		(130	)		(130	)		(29	)		(1	)		(30	)
Project start-up costs		15		—			15			57			—			57
Voyageur upgrader project charges		82		—			82			—			—			—
Finance expenses		135		33			168			127			81			208

Earnings before Income Taxes		2 729		2 313			5 042			735			1 320			2 055
Income taxes		689		1 313			2 002			267			1 182			1 449

Net Earnings		2 040		1 000			3 040			468			138			606

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 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, and adjusted for decommissioning and restoration activities and 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 NGLs, and natural gas reserves provided herein will be recovered. Actual SCO, bitumen, crude oil and NGLs, 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:

	Brent North Sea		WTI Cushing Oklahoma		WCS Hardisty Alberta		Light Sweet Edmonton Alberta		Pentanes Plus Edmonton Alberta		AECO Gas		B.C. Gas Westcoast Station 2		National Balancing Point North Sea

Year	US$/bbl		US$/bbl		Cdn$/bbl		Cdn$/bbl		Cdn$/bbl		Cdn$/mmbtu		Cdn$/mmbtu		Cdn$/mmbtu
2013		109.05		96.90		73.66		91.50		103.39		3.10		3.06		10.74
2012		111.96		94.71		72.83		87.50		102.42		2.33		2.26		9.35

	At December 31, 2013									At December 31, 2012

($ millions)	Oil Sands			Exploration and Production			Total			Oil Sands			Exploration and Production			Total
Future cash inflows		297 638			24 014			321 652			243 856			29 116			272 972
Future production costs		(146 172	)		(4 925	)		(151 097	)		(115 805	)		(6 769	)		(122 574	)
Future development costs		(76 042	)		(2 508	)		(78 550	)		(64 192	)		(3 652	)		(67 844	)
Future income tax expenses		(16 649	)		(11 486	)		(28 135	)		(13 988	)		(10 477	)		(24 465	)

Future net cash flows		58 775			5 095			63 870			49 871			8 218			58 089
Annual 10% Discount Factor		(38 402	)		(1 085	)		(39 487	)		(30 760	)		(2 237	)		(32 997	)

Standardized measure of discounted future net cash flows		20 373			4 010			24 383			19 111			5 981			25 092

Changes in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves

($ millions)

Standardized measure of discounted future net cash flows — beginning of year	25 092		34 301
Sales and transfers of oil and gas produced	(8 463	)	(9 055	)
Net change in sales prices and operating costs related to future production	2 193		(15 031	)
Net change due to extensions, discoveries and improved recovery	(38	)	2 643
Net change due to acquisitions and dispositions	(888	)	33
Net change due to revisions in quantity estimates	999		1 949
Previously estimated development costs incurred during the period	4 363		4 351
Changes in estimated future development costs	(1 743	)	(229	)
Accretion of discount	2 180		3 286
Net change in income taxes	688		2 844

Standardized measure of discounted future net cash flows — end of year	24 383		25 092